Smart Grid Virtual Program - EPRImydocs.epri.com/docs/Portfolio/PDF/2010_PDU-VP3.pdf · Electric...

Electric Power Research Institute 2010 Portfolio

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Smart Grid

Program Overview

Program Description For 2010, EPRI is offering three strategic collections of research projects or programs in “virtual programs.” These virtual programs have been designed to provide focus for solutions of key issues the industry is facing.

A smart grid incorporates information and communications technology into every aspect of electricity generation, delivery and consumption. It takes acquired data and turns it into information which can then be used to support decisions leading to effective responses. This research program draws knowledge from recognized work in the IntelliGrid program as well as from smart grid demonstration projects. It also includes a number of programs that will have impacts on smart grid grids, such as renewable integration, electric transportation, energy storage and grid operations and planning, to name a few.


IntelliGrid - Program 161

Program Overview

Program Description The IntelliGrid(sm) program develops and evaluates technologies and methodologies for implementing a smart power grid infrastructure. The program focus is on the communications and information infrastructure that will become the foundation for many smart grid applications, as well as the implementation of security for this infrastructure. When this enabling infrastructure is matched with smart grid applications in transmission, distribution, or at a customer interface, then the resulting smart grid can reach significant gains in reliability, capacity, demand response, and offer value added customer services.

A major early accomplishment of the EPRI research is the IntelliGrid Architecture, an open-standards, requirements-based approach for integrating data networks and equipment that enable interoperability between devices and systems. The Intelligrid Architecture is supported by the Intelligrid Methodology that has since been adopted as an IEC Publicly Available Specification (PAS). This methodology describes the application of use cases for defining the requirements of a new technology in a way that provides traceability and allows the definition of standards based on the requirements.The Intelligrid research provides members with the methodologies, tools, recommendations for standards, and unbiased assessments of technologies when implementing new system-wide technology solutions for wide area monitoring and control, advanced equipment diagnostics, distribution automation, demand response, distributed resource integration, and advanced metering.

Research Value With the knowledge acquired through this research program, program members will have access to information that can help them in these ways:

• Development and support of standards-based approaches for achieving interoperability of technologies that make up a smart grid.

• Industry coordination and up-to-date technology information for members. • Utility implementation approaches and results for smart grid technologies and systems. • Roadmaps for implementing a smart grid. • Coordination with smart grid applications and technology development to assure interoperability. • Cost/benefit assessments for smart grid applications and technologies, especially with respect to

implementing open, standards-based systems. • Understanding communications and information system architecture requirements to support a smart

grid. • Assistance in how best to deploy monitoring, communications, computing, and information technology

to address unique business and regulatory drivers, addressing questions as to which products and technologies to use, when to implement solutions, how to integrate new and existing systems, and how to manage and secure systems.

• Effective and consistent security and system management policies.

Approach EPRI research in the IntelliGrid program will yield a variety of data and knowledge that will be beneficial to members of the program. This information will come in a number of forms and is expected to include:

• IntelliGrid architecture providing methodology, tools, and recommendations for standards and technologies for utility use in planning, specifying, and procuring the communications and information systems to support smart grid applications such as wide area monitoring and control, advanced metering, distribution automation, and demand response.

IntelliGrid - Program 161 p. 1


• Support of roadmap development for individual utility smart grid implementation plans. • Establishment of a living laboratory for assessing devices, systems, and technologies. • Development of a relay laboratory for evaluating advanced data integration and control approaches. • Coordination with member smart grid implementations and laboratory assessments.

Accomplishments In the past, the IntelliGrid program has delivered valuable information that has helped its members and the industry in numerous ways. Some examples include:

• The IntelliGrid Profiling & Mapping report provides an analysis of research and development (R&D) programs whose goal is to improve the intelligence of the electric power infrastructure. The study updates the information of the previous assessment of ten selected grid R&D programs, characterizing their vision, mission, governance, budget, promotion activities, and technical program portfolio, including main objectives, completed or ongoing projects, deliverables, and accomplishments. It also adds three international organizations to the scope of the previous assessment scope.

• The IntelliGrid Architecture provides the technical foundation for federal government's efforts to identify, develop and harmonize smart grid interoperability standards

• The AMI Security supplemental project has developed the cyber security requirements and policies for advanced metering systems

• The IntelliGrid methodology has been used by several utilities to develop Smart Grid roadmaps.

Current Year Activities • Industry coordination and tech transfer to provide industry guidance on smart grid implementations • Migration path for IEC 61850 implementation and coordination with CIM standards • Guidebook for using the common information model (CIM) for distribution applications • Common Information Model (CIM) Interoperability tests for transmission, distribution, and advanced

metering • Guidelines for deploying communications infrastructure for transmission operations, advanced distribution

automation, demand response, and energy efficiency • Regular reports on laboratory testing of technologies and products • Security requirements and recommendations for advanced metering infrastructure (AMI) • Coordination of security requirements and recommendations for compliance - transmission, distribution,

and customer interface infrastructure

Estimated 2010 Program Funding $4.0M

Program Manager Donald Von Dollen, 650-855-2679, [email protected]



Summary of Projects

PS161A IntelliGrid Technology Transfer and Industry Coordination (063528)

Project Set Description This project set provides the overall industry coordination and high-level tech transfer activities related to continued development of the utility infrastructure to support smart grids. It supports users of the IntelliGrid architecture methods and introduces potential users to the benefits of migrating towards an intelligent grid. Every activity is designed to enhance access to research results—so continuing and new funders of the IntelliGrid program alike will find value. The Intelligrid program includes membership of utilities, vendors, public organizations, and other research organizations. One of the important objectives through this project set is to enhance coordination across all the different research organizations and industry organizations (for example, the Department of Energy [DOE], the Institute of Electrical and Electronics Engineers [IEEE] Intelligent Systems Coordinating Committee, and European smart grids efforts) working on the development and definition of future system architectures and integration needs.

Project Number Project Title Description

P161.001 Intelligrid Technology Transfer and Industry Coordination

The project provides coordination across the industry. Important efforts include: • Maintaining information about smart grid deployment activities

across the industry and sharing this information in the form of case studies so that members can learn from the lessons of previous deployments.

• Coordination of industry-wide use-case repository (in conjunction with the smart grid demonstration initiative).

• Smart grid roadmap workshop for sharing of information related to roadmaps for a smart grid implementation.

• Coordination of standards activities and reports to members about important standards development activities (IEEE, IEC, etc.)

• Report on industry wide smart grid activities - this is an update from previous reports.

• Coordination with international smart grid initiatives - report to members for lessons learned.

P161.001 Intelligrid Technology Transfer and Industry Coordination (065585)

Key Research Question Utilities increasingly deploy advanced technologies (monitoring, communications, computing, and information technologies) to enhance system operation and maintenance and to enable demand response and energy efficiency applications. The challenge utilities face is how to deploy these technologies efficiently and cost-effectively to meet today’s needs as well as future needs. Some of their questions include which applications to deploy and when to do so; what are the requirements for these technologies; what technologies are available that meet these requirements; what are the costs and benefits of different alternatives; how new systems should be integrated with existing systems; how these systems should be managed and secured.

Approach This project provides coordination across the industry for smart grid technology implementation and deployment. Numerous smart grid efforts are under way at individual utilities, at the Department of Energy, in various standards organizations, and internationally. This project provides coordination across all these efforts



so that members can take advantage of important developments and lessons learned across the entire industry. Coordination is achieved through sharing of use cases, member forums, webcasts, newsletters, and workshops.

Impact • Promotes the cost-effective integration of communications and information infrastructure for support of

advanced applications and diverse vendor products in transmission, distribution, and end-use systems • Promotes interoperability among vendor products, lowering capital costs for members • Provides the most current information on technical, policy and implementation issues related to smart

grids • Provides coordination with a wide variety of research and industry initiatives related to development and

definition of a smart grid

How to Apply Results Utility executives responsible for “grid of the future” planning, information technology (IT) architects designing the infrastructure to support the future grid, and project engineers deploying systems can use the project results as information resources. These resources are intended to familiarize members with the latest in technology advancements, as well as highlight vendor activities on smart grid efforts.

2010 Products

Product Title & Description Planned Completion Date Product Type

Repository of Smart Grid Demonstrations, Deployments and Use Cases: Web-based repository will compile information on Smart Grid demonstrations, pilots and deployments. The repository will also compile publicly available smart grid business cases.

12/31/10 Technical Resource

Smart Grid Cases Studies: The Smart Grid case studies will profile a utility's specific Smart Grid deployment. The report will describe how the company approached the deployment, the technology choices made, architectural decision made, anticipated benefits, regulatory drivers, etc.

12/31/10 Technical Update

Tracking and Coordination of Industry Smart Grid Activities: Regular reports will be provided to funders that describe industry Smart Grid activities. Activities will include policy, legislative, standards, demonstrations and research and development. Reports will provide up-to-date information that will be valuable to utilities and non-utilities alike.


Smart Grid Roadmap Workshop: This workshop will provide will bring together utilities that have developed or are currently developed a smart grid roadmap to share plans, experiences and lessons learned. 2010 will mark the third annual Smart Grid Roadmap workshop.

12/31/10 Workshop, Training, or Conference

PS161B Infrastructure for Intelligent Transmission Systems (063437)

Project Set Description The Infrastructure for Intelligent Transmission Systems project set is focusing on the communications and IT infrastructure, technology gaps to achieve an open and interoperable system and migration strategies. The transmission system is using already extensive and sophisticated instrumentation and applications. This project set will assess additional possible communications needs for real-time applications and identify strategies to migrate from the existing communications and data models to interoperable, common database models and communications standards by developing enterprise wide use cases for advanced transmission applications.




P161.003 Common Information Model and Information Integration for Transmission Applications

This project develops requirements and use cases for advanced transmission operations. These requirements serve as the basis for data and device models for emerging standards as well as for contributions to standards activities within key industry organizations such as IEC, IEEE, NIST and others.

P161.015 Smart Transmission System Implementation Strategies

This project will create strategies for utilities migrating existing transmission communications technology to a system wide communications and IT infrastructure. Lessons learned will be documented in case studies.

P161.003 Common Information Model and Information Integration for Transmission Applications (063286)

Key Research Question Federal and state regulators and legislators are increasingly driving utilities towards the concept of a smart grid. Several utilities have embraced this concept and are aggressively installing the infrastructure to make the concept a reality. For transmission systems, a smart grid may provide a wide-area view of system performance and health. It may anticipate events and take action to avoid them or minimize their impact. Robust and highly integrated communications and distributed computing infrastructures will be needed to create a smart grid. These infrastructures need to be interoperable across vendor equipment and across the enterprise. Achieving the necessary level of interoperability requires the development and industry adoption of a tightly coupled suite of standards. The Common Information Model (CIM) provides a common language for integrating applications across the enterprise and is a foundation standard for smart grids. IEC 61850, Distributed Network Protocol (DNP), and the Internet Protocol (IP) also are key standards. Significant work has been done on these standards, but a substantial amount of work is needed.

Approach This project develops requirements and use cases for advanced transmission operations. These requirements, in turn, serve as the basis for data and device models for emerging standards and as the basis for advanced applications that can be developed using equipment from different vendors. This project tracks and makes contributions to activities within key standards organizations such as IEC, IEEE and industry organizations such as DOE, National Institute of Standards and Technology (NIST), Federal Energy Regulatory Commission (FERC), National Association of Regulatory Utility Commissioners (NARUC), and National Electrical Manufacturer’s Association (NEMA) relating to transmission smart grid applications. CIM interoperability tests will be conducted with vendor products.

Impact This project could have the following impacts:

• Promote true interoperability and enable integration of applications across the enterprise via systems built to open standards

• Promote standards that enable competitive equipment procurement and result in 20-25% capital cost reductions for advanced automation equipment

• Enable improved life-cycle savings through equipment that is common and well known to systems administrators



How to Apply Results Utility control center information technology project managers, automation project engineers, operators, and transmission planners will use the tools and knowledge produced in this project to apply the CIM standard within their organization. The results from this project will help the utility to plan for future requirements for upgrades to its energy management systems and when procuring next-generation transmission operations equipment such as relays and protection equipment.

2010 Products


Transmission Common Information Model (CIM) Workshop: This will be a two day industry workshop for status of 2010 and 2011 CIM design allowing transmission system applications to integrate with distribution systems (applications). The CIM facilitates integration between applications and systems and provides maximum value as more systems share data . Recent work that has been completed or is in final stages now that can be part of a lower costing utility solution.


Common Information Model (CIM) Tools Workshop: This project is a two day industry workshop to teach and demonstrate various CIM Tools that have been developed to facilitate CIM implementations. Modern tools have been designed over recent years to support the multiple interoperability tests (IOP's) and are applicable for individual utility CIM implementations.


Conduct industry CIM/GID interoperability tests in conjunction with current IEC revisions: EPRI will work with several vendors to test the interoperability of their products in conformance with the CIM / Generic Interface Definition (GID) standard.


P161.015 Smart Transmission System Implementation Strategies (069294)

Key Research Question Recent focus on accelerating the implementation of smart transmission systems technologies within the confines of the existing infrastructure has significant challenges. Since the transition will take a number of years, operating in the mixed state of partial smart grid and partial legacy will be challenging. Research is needed to determine how a utility transitions to a smart grid while maintaining continuity of service during the transition and to determine what options are available to have smart equipment co-mingled with legacy devices. Also, are there benefits to different implementation strategies. Should a company implement by voltage class or by geographic region or some other approach. What are the pros and cons to the various approaches?

Approach This project will document the proposed and actual transition approaches to implementing a smart grid by various utilities and assess the issues associated with the implementation strategy. We will also look at the various approaches proposed or being implemented by various utilities in implementing smart grid and assess the pros and cons. Actual lessons learned will be documented and communicated.

Impact This project could have these impacts:

• Utility members will be able to better understand the pros and cons of various implementation methods and the challenges associated with each.



• Utility members will be able to plan, design, develop, and implement a better smart grid implementation strategy for their company and better understand the benefits achieved using different approaches.

How to Apply Results Utility members will be able to apply the knowledge gained from the project products for designing and implementing smart grid technologies effectively through the transition from legacy environments to smart grid.

2010 Products


Implementation Strategy Assessment: This project will perform an assessment of a selection of smart grid implementations at utilities for best practices, lessons learned and other insights beneficial to utilities considering adoption of smart grids.


Information Sharing across T&D operations: This project will focus on value of smart grid enabled information sharing across the T&D enterprise. This will be a joint project with PS161C.


PS161C Infrastructure for Intelligent Distribution Systems (063438)

Project Set Description The Infrastructure for Intelligent Distribution Systems project set focuses on the communications and IT infrastructure necessary to achieve fully integrated distribution operations. It will address design issues when integrating diverse communications at scale, attempting to isolate communications complexity from the distribution operations applications. Data management is another focus. Distribution operations deal with a large number of data points and parameters. Integrating all the data using a common interface model may improve data quality, efficiency and reduce redundancy.


P161.004 Communication Technologies for Smart Distribution Applications

The project develops requirements and initial designs for communications infrastructure for advanced distribution automation applications. These designs are based on emerging next generation open standards and will also assist in the development of the infrastructure necessary to meet next generation application needs.

P161.005 Enterprise Information Sharing for Smart Distribution Applications

This project will produce a guidebook to Enterprise Application Integration (EAI) suites.

P161.004 Communication Technologies for Smart Distribution Applications (063428)

Key Research Question Federal and state regulators and legislators are increasingly driving utilities towards more advanced functions and applications on the distribution system. The distribution system communication infrastructure must be robust enough to meet future needs for reliability as well as have the capacity for implementing advanced distribution automation applications. In addition, systems maintenance will require a careful integration between field equipment and back office information systems. Robust and highly integrated communications and distributed computing infrastructures will be needed to support foreseen applications. In addition the key



standards targeted for distribution systems operations need to be integrated and harmonized to integrate field equipment with back office systems as appropriate.

Approach The project will build upon and further industry requirements for advanced distribution operations. The requirements will use the use case formats from the IntelliGrid program and will provide a systems architecture perspective on advanced distribution operations. These requirements provide the basis for developing initial designs for next generation distribution communications. Details for basic understanding of functional and technical capabilities of the key applications supported will be included in the requirements write ups. The applications include, but are not limited to system protection, integrated volt var management, fault location, isolation and restoration, integration of customer metering, demand response and distributed resource integration. The report also will provide a detailed and systematic analysis of issues directly related to the integration, interoperability, and performance of the communication networks for distribution applications. The focus will be to better understand the design issues associated with integrating key communications infrastructures as well as the behavior of individual networks especially when integrated on large scales. Emphasis will be to identify the integration and implementation methods and techniques to isolate the riding applications from the complexities of underlying individual networks to assure seamless and secure integration and access with consistent and predictable performance.

Impact • Utility members will be able to make use of both the requirements as well as advanced designs for

application to their own systems. • The architecture perspective will also provide critical input for the development of the industry standards

necessary to support the next generation of distribution operations • Key standards development provides a robust communications infrastructure for supporting next

generation equipment • Utility members will be able to plan, design, develop, and implement a reliable and functional network with

consistent performance and predictable results. They will be able to mitigate the risks associated with the integration and performance issues in a typical large network of heterogeneous technologies and systems.

How to Apply Results Utility members will be able to apply the knowledge gained from the project for designing and implementing communication networks for their distribution operations. In addition the results can be contributed to the key standards organizations developing advanced distribution automation communications. These include efforts underway within the IEC, IEEE and related standards communities and consortia. In this way the results become part of the standards based equipment that utility members can procure.Members will be able to make informed and sound decisions on how to design and implement a functional, secure, efficient, and predictable communication network.

2010 Products


Managing the Communications Infrastructure for Distribution Operations: Managing the Distribution Communications Infrastructure (what’s installed where, controlling what equipment, running what firmware, communicating how, configured how?) Challenge: managing the security, including keeping up with compliance issues (NERC CIP) -- must keep in mind the myriad technologies, processes, and regulations.




P161.005 Enterprise Information Sharing for Smart Distribution Applications (065546)

Key Research Question A smart distribution infrastructure can be realized by smart applications to synthesize information from a host of data repositories and other applications. The interfaces for these applications are often custom, one-off interfaces, which require development work that does not increase the functionality of the application itself. A set of common interfaces could help reduce development effort for new applications as well as ensuring that the information can be shared across a utility's enterprise. The Common Information Model (CIM) can serve as the common language for these interfaces at a utility's back office environment. In addition, communication with devices in the field as well as device-to-device communication can benefit from standard object models for distribution equipment used for smart automation.

Approach A guidebook to Enterprise Application Integration (EAI) suites will be developed. Enterprise Application Integration (EAI) suites are software products that provide the capability to share data between applications within the enterprise. This includes solutions for dealing with applications that run on different operating systems, database architectures, programming languages, and the broad category of legacy applications. This project also tracks and makes contributions to activities within key standards organizations such as IEC, IEEE, and industry organizations such as DOE, NIST, and NERC.

Impact • Promote true interoperability and enable integration of applications across the enterprise via systems built

to open standards. • Enable improved life-cycle savings through equipment that is common and well-known to system

administrators.

How to Apply Results Distribution system operators and information technology managers can use the knowledge produced in this project as guidance in procuring, installing, and maintaining an EAI suite appropriate for their utility's goals and objectives for system integration for distribution operations.

2010 Products


Distribution Operations Guide to Enterprise Application Integration (EAI) Suites: Application and system integration best practices; the judicious use of the Common Information Model (CIM) for information exchange; overview, benefits, and cautions for Enterprise Application Integration (EAI) suites.

12/31/10 Technical Report

Distribution CIM Interoperability Testing: Annual interoperability testing of the Distribution CIM standards to vet the standards and to identify where they need to be improved.




PS161D Infrastructure and Technology for Advanced Metering, Integrating Demand Response and Energy Efficiency (063439)

Project Set Description This project set focuses on development and demonstration of low-cost, standards-based, two-way communications between energy service providers and their customers and demonstration of technologies that integrate with this communications infrastructure through the EPRI Living Laboratory. The project also addresses the information integration approaches for making customer information such as AMI part of the overall information system available for advanced applications. The resulting interactive exchange of information provides enhanced reliability and security, lower energy bills, and new, value-added services—ultimately fostering greater satisfaction among electricity consumers. The living laboratory provides an independent, unbiased assessment of technologies and products. Finally, the project set offers strategic and societal benefits by supporting greater power system reliability, functionality and consumer value; enhanced system security; improved energy efficiency; accelerated rate of reduction of carbon emissions; lower costs for infrastructure upgrades and expansion; and greater economic productivity.


P161.006 Communication Technology Assessment & Testing for AMI, HAN & Distributed Energy Resources

The project will test leading AMI, HAN, and DER communication power line, radio, and broadband technologies in laboratories test and field demonstrations as well as identify the gaps in the standards.

P161.007 Communications Architecture Development for Integrating, AMI, HAN, & DER into the Smart Grid

The project develops requirements and initial designs for communications infrastructure for advanced customer systems applications. These designs are based on emerging next generation open standards and will also assist in the further development of the infrastructure necessary to meet next generation application needs.

P161.008 Life Cycle Management of AMI, HAN, and DER Communication Technologies

This project designs a process for utilities to deal with AMI,HAN and DER technologies from selection, through testing, implementation, configuration, operations, upgrades, and eventual technology retirement. This may lead to a comprehensive life cycle management methodology for utilities to select, integrated and manage the technology cost effectively, reliably and securely.

P161.006 Communication Technology Assessment & Testing for AMI, HAN & Distributed Energy Resources (063432)

Key Research Question Utilities are deploying Advanced Metering Infrastructure (AMI) & Home Area Network (HAN) technologies in their service territories to create a 2-way communication network between the grid and end use devices at the customer premises. This communication infrastructure will enable the utility to send dynamic pricing signals to the customer premises during peak demand periods to reduce electricity consumption and create operational savings. Additionally, utilities are looking to integrate other Distributed Energy Resources (DER) such as thermal and electric storage, Photovoltaics (PV), and Wind Power with the grid at various levels to offset the growing demand for electricity with a low carbon alternative. The diversity and complexity of the communication technologies being considered for these applications requires objective lab and field testing of products and systems to validate their specifications and identify the technology gaps that need to be filled for commercial viability of these solutions.



Approach The project will test leading AMI, HAN, and DER communication technologies based on power line, RF, and broadband networks in lab and field tests and document the findings in EPRI technical reports. The project will also identify the gaps in the standards for the communication interfaces of AMI, HAN, and DER technologies that need to be filled to offer vendor agnostic integration of these technologies to the grid.

Impact • Utility members will be able to develop their own assessment of various communication networks in a

timely manner by referencing the technical reports as a single consolidated resource. • Utility members will be able to plan, design, develop, and implement a reliable and functional

communication network with consistent performance and predictable results. They may be able to mitigate the risks associated with the integration and performance issues in a typical large network of AMI, HAN, and DER systems across their service territories.

• Utility members will have empirical data to accelerate the development and adoption of the missing standards for communication in AMI, HAN, and DER

How to Apply Results The operational side of distribution companies will use the EPRI technical reports to help them implement the research results.

Information technology (IT), information security staff (within a distribution company), and the chief information officer’s organization (CIO of the distribution company) also can use the results of this project. Knowledgeable IT staff will use results to calibrate their own implementations of AMI, HAN and DER within their own service territories. The CIOs will use the results to design data integration architecture.

The IT experts within the electric utility trade organizations and state and federal agencies focused on grid security are also good audiences for the research results. These organizations will find the research is valuable in helping to understand the current status of AMI, HAN, and DER and determining the technology gaps for future innovation.

Standards organizations (for example, IEC, International Organization for Standardization [ISO], American National Standards Institute [ANSI], and National Institute of Standards and Technology [NIST]) can use these results guidelines for future interoperability standards work.

2010 Products


Test Plans for RF and Power Line Base AMI Systems: The Technical Update will provide a detailed test plan for leading AMI Vendor Technologies with HAN interface on the Smart Meters that will provide the Member Utility AMI implementation teams a comprehensive guide for testing and verifying the features and characteristics of the products. The Test plan will include Characterization, Functional, Installation, and Manufacturing tests.




P161.007 Communications Architecture Development for Integrating, AMI, HAN, & DER into the Smart Grid (067466)

Key Research Question The customer communications infrastructure needs to be effectively integrated on at least two fronts. The primary category of system integration has to include revenue cycle services and customer internetworking systems for advanced rate structures, demand response and energy efficiency. The second category should include homes and businesses that are installing renewable and other forms of generation which have to be prepared for more dynamic integration with transmission and distribution operations. The industry must strive for consistency in how large numbers of customers integrate with real-time power grid operations. Multiple standards are developing in these areas but the industry needs some key convergence on communications infrastructure and open standards to achieve the levels of interoperability, equipment management and security now envisioned for the smart grid. One of the key needs of the industry is to achieve convergence on application level communications. Another emerging issue is to achieve closure on some critical core networking functions such as naming and addressing and establishing a robust communications management infrastructure. One of the big challenges facing the industry is achieving the necessary level of cooperation, harmonization and integration to achieve interoperable systems development. In addition to integrating customer operations with T&D operations, the infrastructure must also assist in the integration of other key industry standards. Critical industries include industrial, commercial building automation, plug-in electric vehicles as well as residential in-building communications.

Approach The project will evaluate industry requirements developed to this point and, as appropriate, build upon them to provide an initial foundation for a complete customer communications architecture. In particular, the requirements should address the key areas where customer operations will interact with utility operations including both revenue cycle services and T&D operations. Industry requirements for advanced customer communications will, in turn, be used to develop designs for an architecture that effectively integrates with key interfaces to T&D operations. The requirements will utilize the use case formats from the IntelliGrid program and will provide a systems architecture perspective necessary for integrating key applications across the operating domains. The proposed designs will draw upon the requirements and make use of leading industry standards across industries and domains. Standards for this architecture include but are not limited to the following organizations: IEC, IEEE, ASHRAE, ANSI, and SAE. Initial designs will build from prior industry work for integrating across the standards. The analysis will also identify key areas where development work is still needed to be able to converge on important elements of the infrastructure, including application level communications and fundamental networking functions.

Impact • Utility members will be able to make use of both the requirements as well as advanced designs for

application to their own systems and procurement plans. • The architecture perspective will also provide critical input for the development of the industry standards

necessary to support the next generation of customer communications operations for emerging applications.

• Key standards development provides a robust communications infrastructure for supporting next generation equipment.

• Utility members will be able to plan, design, develop, and implement a reliable and functional network with consistent performance and predictable results. They may be able to mitigate the risks associated with the integration and performance issues in a typical large network of heterogeneous technologies and systems.



How to Apply Results Utility members will be able to apply the knowledge gained from the project for designing and implementing communication networks for their next generation revenue cycle and demand response operations as well as T&D integration.In addition the results from this work can be contributed to the key standards organizations developing advanced distribution automation communications. These include efforts within the key industry standards communities and consortia. In this way the results become part of the standards based equipment that utility members can procure.Members will be able to make informed and technically sound decisions on how to design and implement a functional, secure, efficient, and predictable communication network.

2010 Products


Analysis of Architecturally Significant Use Cases for Demand Response & Load Management Programs: This report will identify and analyze use cases from Intelligrid, SCE, and other sources that impact the architecture of the network used for Demand Response Programs in Customer Premises. The report will define the environments within the Customer Premises that are impacted by the use cases and provide detailed description of the interfaces between these environments from the top down on the GWAC Stack. This mapping will be used in the future to identify the key standards that are applicable at those interfaces.


P161.008 Life Cycle Management of AMI, HAN, and DER Communication Technologies (067467)

Key Research Question Utilities that are investing in Smart Grid technologies will require a "no regrets" path from technology selection, through testing, implementation, configuration, operations, upgrades, and eventual product retirement. Each phase of this Smart Grid life cycle needs extensive analysis, planning, and management which can stretch the human and financial resources of a utility. A comprehensive Life Cycle Management methodology needs to be developed for the utility industry to adopt so that Smart Grid technologies such as AMI, HAN, and DER can be integrated cost effectively, reliably and securely.

Approach This multi-year project will produce a series of deliverables that focus on each phase of a Smart Grid technology life cycle. The first phase deliverable will be a use-case based approach to identify the AMI, HAN, and DER technology requirements for utilities. The second phase deliverable will be a set of test procedures for the variety of AMI, HAN, and DER technologies that utilities are considering for their Smart Grid projects. The third phase deliverable will be a detailed set of implementation procedures for each type of technology which will provide the sequence of steps necessary for successful implementation that avoids costly redesigns or technical inconsistencies. The fourth phase deliverable will provide a "best practices" guide to configuring the AMI, HAN, and DER technologies for optimal performance. The fifth phase deliverable will provide recommendations for day-to-day operations and management of the AMI, HAN, and DER technologies with particular focus on data processing, transmission, and storage. The fifth phase deliverable will provide guidelines for hardware and software upgrades, firmware version control, asset management, and techniques for upgrading that minimize the downtime of Smart Grid technologies. The sixth phase deliverable will provide the metrics for determining when a particular AMI, HAN, or DER technology has reached "end of life" and detailed steps to replace the technology with new solutions in a way that causes the least disruption to grid availability and reliability.



Impact The availability of such a comprehensive "Life Cycle Management" tool for AMI, HAN, and DER technologies will accelerate the utility adoption of these technologies by reducing the technical and economic uncertainty associated with these technologies. Utilities can plan their human, capital, and infrastructure resources around such investments in a better way and optimize their long term operational costs. By standardizing the life cycle management of AMI, HAN, and DER technologies, utilities can cost effectively integrate such resources from other utilities and independent power producers through mergers, acquisitions, and partnerships. AMI, HAN, and DER product vendors can use the "Life Cycle Management" methodology as a guide to design new products or modify existing products to better conform to the utilities' requirements.

How to Apply Results Utility operations personnel can use this tool as a guide for each phase of the AMI, HAN, and DER technology life cycle. Utility IT staff can use this tool to identify the areas where they need to collaborate with the operations side to develop seamless IT processes for the successful implementation of these technologies. Public utilities commissioners can use this tool as a guide to determine the financial incentives to be given to the utilities during each phase to cover costs and keep Smart Grid technologies economically viable. AMI, HAN, and DER vendors can use the recommendations and requirements from this tool to develop future technology roadmaps that adhere to certain standards for communications, certification, reliability, and durability for long term competitive advantage.

2010 Products


Use Case Analysis for AMI & DER Requirements Definition: This report will analyze the various use cases for AMI and DER available in the industry and identify a set of requirements that utilities can use as templates for their RFPs to vendors. The use cases will be broken down into architecturally significant, process focused, and regulatory/policy oriented to provide a comprehensive set of requirements.


PS161E Security Issues for the Power System Communication, Information, and Control Infrastructure (065456)

Project Set Description The Security for the Power Systems Communications, Information and Control Infrastructure project set focuses on improving cyber security for members. A key value is best practice sharing among members which is facilitated by EPRI in periodic workshops. These workshops provide a forum where members can discuss lessons learned and share experiences. This research will also conduct interoperability testing of secure implementations of wide area communications and inter and intra substation communications technologies. Communications reaching beyond substations and feeder devices reaching meters and home automation networks will require extending the overall security and device management architecture.


P161.011 Wide Area Communication Security (EMS, SCADA, PMUs, Smart Grid Components – including secure ICCP)

This project facilitates best practice sharing among members in periodic workshops. These workshops provide a forum where members can discuss lessons learned and share experiences. This project will also conduct interoperability testing of secure implementations of wide area communications and develop security architectures for advanced wide area applications.



P161.012 Security Issues for the Intelligent Distribution Infrastructure

This project will focus on facilitate the Security Interoperability testing for DNP and define functional requirements for managing the security features of substations and feeder devices.

P161.013 Security & Management of AMI, HAN, & DER

This project will assess security of AMI, HAN and DER technologies and develop a database of use cases of security and management requirements as well as survey the security policies and guidelines of relevant national agencies.

P161.011 Wide Area Communication Security (EMS, SCADA, PMUs, Smart Grid Components – including secure ICCP) (065590)

Key Research Question SCADA/EMS, substation control systems and plant process control systems are the central nervous systems for a utility as they provide the means for trouble free, reliable operation of the bulk power transmission system. The Smart Grid initiative has created the need for seamless integration. These systems have become more vulnerable to internal and external intruders as open architecture and wide area communications have become more prevalent. Since electric power infrastructures are increasingly being stretched to their operational limits, they are becoming more fragile and vulnerable to attack. Increased linking, operating the transmission system at close to operational limits, and new national security requirements all point to a need for an increased focus on the security of the power system.

Approach This project will have 3 deliverables in 2010.

Information Sharing and Lessons Learned in securing EMS/SCADA systems This deliverable will focus on information sharing to facilitate the industry's technical and operational response to infrastructure threats. Member-directed, collaborative sharing of technical information via three annual workshops, occasional webcasts and other communications as required has been a key component of this information security program since its inception.

Facilitated workshops provide an opportunity for members to discuss security practices, concerns, solutions, and other topics of mutual interest with EPRI, other industry experts, and peers. Representatives from regulatory and research agencies (such as the Department of Homeland Security [DHS], Department of Energy [DOE], National Laboratories, North American Electric Reliability Corporation [NERC], and Federal Energy Regulatory Commission [FERC]), vendors, and other subject matter experts are regularly invited to participate in these workshops, which provide first-hand interaction with security professionals directly related to the electric power industry sector.

Information sharing also consists of timely information e-mailed directly to members and provided through periodic web casts on pertinent issues. Topical application documents (such as policies and procedures, guidelines, primers, frameworks, and methodologies) also are delivered to contributors of this project.

Secure ICCP (TASE.2) Interoperability testing Secure ICCP is an extension of the existing standard ICCP (IEC 60870-6), with security recommendations that adopt transport layer security (TLS/SSL) into the appropriate layer of the TASE.2 profile. TLS/SSL is a transport layer certificate-based security approach providing encryption and authentication. Utilities exchange critical real-time data from ICCP connections and thus require a more effective mechanism to manage and administer digital certificates for authenticating secure ICCP links. A product was developed in 2008 (Product ID.1018285) to meet this need. A prototype of this solution will be tested in 2009 and promoted to vendors. This deliverable will focus on the interoperability testing of the Secure ICCP products from multiple vendors. This enables utilities to easily implement secure ICCP communications.



Develop Security Architecture for PMU network Use the EPRI PMU/Relay lab setup to develop Security Architecture for PMU network.

Impact • Maintain awareness of emerging security technologies and the appropriate and cost-effective applications

of those technologies to secure communications within EMS networks • Maintain knowledge of common industry security practices • Maintain awareness of national research efforts, provide input on their applicability, and contribute to

directing future research in beneficial directions • Maintain current knowledge of NERC cyber security standards as they evolve and understand the

commonly accepted methods to become and remain compliant with them • Update to IEC standards on secure SCADA protocols DNP3 and ICCP. • Provide Security architecture for PMU network

How to Apply Results The workshops are aimed at attracting utility personnel who have the responsibility or want to gain more knowledge on utility security infrastructure. When these people attend any of the project workshops, they discuss security issues with colleagues in a trusted environment (workshops), learn what has worked and failed for other utilities and, hence, are able to avoid false starts and wasted efforts. They contribute to the improvement of security for the North American electric power industry, and provide direction to national research efforts to ensure that they provide products and technologies that are beneficial to the industry. Additional deliverables will enable Secure ICCP implementation in a timely manner. Security Architecture for PMU network will provide timely frame work for design and implementation of PMUs.

2010 Products


Secure ICCP interoperability Test Results 12/31/10 Technical Report

Secure DNP3 Interoperability Test Results 12/31/10 Technical Report

Security Architecture for PMU network 12/31/10 Technical Report

Three Workshops: Same as for 2009 with modifications to address issues of (then) current security concern 12/31/10

Workshop, Training, or Conference

P161.012 Security Issues for the Intelligent Distribution Infrastructure (067470)

Key Research Question DNP3.0 Security Interoperability Testing:DNP3.0 protocol is being adopted worldwide as the standard protocol for inter- and intra-substations communication and communication between substations and control centers. IEC TC57 WG15 (International Electro technical Commission, Technical Committee 57, Working Group 15) has developed standards to ensure security of these communications under IEC 62351-5 for both serial DNP3.0 and DNP3.0 over Transmission Control Protocol / Internet Protocol (TCP/IP) communications. Correctly implementing these standards requires significant expertise and an in-depth knowledge of the standards.

IEC 61850 has been widely used in Europe, and North American utilities are slowly migrating to obtain high bandwidth and more secure communications for advanced substation and substation-to-control-center communications. It is important to obtain in-depth knowledge of security advantages with the migration or implementation to IEC-61850 for substation communications. Developing Security and network management



tool for IEC-61850:IEC-61850 is advanced SCADA communication protocol based on the object oriented model. It is and will be widely used in Advanced Distribution Control Systems to enable the Smart Distribution applications. IEC-61850 provides detailed object definitions for security and device management. It is required to create guides to assist in the development of this type of tool.

Approach DNP3.0 Security Interoperability Testing:

In 2009 Secure DNP Specifications will be completed and tested so that the vendor community will start implementing the standards in to their products. In 2010 this work will be continued to perform Interoperability Testing of multiple vendor implementations to ensure the protocol can be deployed in timely manner while securing control system infrastructure. The Project Team will promote the standards specifications to be implemented in vendor products in 2009. Interested vendors can bring their products for this interoperability testing to ensure that utilities who deployed various vendor product can benefit from the results while implementing secure DNP is SCADA control systems involving both serial and TCP/IP implementations. Deliverables of this project will involve developing techniques and procedures, tailored to the contributor’s needs, to effectively secure DNP3.0 at substations and DNP3.0 communications from substations to control centers.

Developing Security and network management tool for IEC-61850: This project deliverable will be a technical report evaluating the IEC-61850 objects related to security management. The goal is develop guidelines for developing a tool to monitor and manage IEC-61850 devices from a security perspective.

Impact • Obtain the techniques to securely implement DNP3.0 based on IEC-62351-5 standards of data modeling

features to capture and communicate the complete functionality within substations • Be able to securely utilize DNP3.0 from current serial implementation to address NERC Critical

Infrastructure Protection (CIP) • Be able to migrate from Serial DNP3.0 communication to DNP.3 over TCP/IP in a secure way • Be able to group substation control blocks to allow secure switching between groups as the operational

situation may dictate • Be able to securely monitor substation activity • Ability to securely send commands to the substation • Ability to securely store configured substation data • Provide guidance on security management tool development for managing IEC-61850 devices

How to Apply Results SCADA engineers will implement Secure DNP3 products while applying security measures to their control system. This will also enable utilities comply to NERC CIP requirements.

2010 Products


Security and Device management tool guide book for IEC-61850 12/31/10 Technical Report

Secure DNP3 Interoperability Test Results 12/31/10 Technical Report



P161.013 Security & Management of AMI, HAN, & DER (067471)

Key Research Question Advanced Metering Infrastructure (AMI) and Home Area Networks (HAN) are two enabling technologies that will allow electric utilities to establish a two-way communication network to offer Demand Response (DR) programs to their residential and light commercial customers to reduce peak load. Additionally, integration of Distributed Energy Resources (DER) such as electric/thermal storage, photovoltaics, and wind power into the utility grid will reduce the growth of expensive and polluting central generation capacity. The extension of the utility communication network into the customer systems to harness the benefits of AMI, HAN, and DER will expose the informational assets of both the utility and the customers unless security policies are enforced to block unauthorized access and limit information dissemination to a “need-to-know” basis. The utilities, the AMI, HAN, and DER technology vendors, and the customers all have to abide by a consistent set of security standards and methodologies to maintain a safe, reliable, and consistently available smart grid in the 21st century. To enforce the security policies on hundreds of thousands or even low millions of AMI, HAN, and DER nodes in a utility grid requires remote management tools that can provide fault, configuration, accounting, performance, and security management in a scalable manner. Comprehensive security and management of AMI, HAN, and DER is critical for the economic viability of utilities that deploy these technologies in a Smart Grid of the future.

Approach This project will focus on the security and management features of leading AMI, HAN, and DER technologies and how they will fit into the overall security architecture of an electric utility’s smart grid. The project combines a theoretical and empirical approach to security and management to offer advice and tangible results to the planners, designers, and implementers of AMI, HAN, and DER at the sponsoring utilities. The project will provide a database of use cases to distill a set of security and management requirements from member utilities AMI, HAN, and DER projects often benchmarked against EPRI’s own lab tests on similar technologies. The project will track the information security and management related policies and guidelines for the utility industry from U.S. national agencies such as FERC, NERC, Federal Bureau of Investigation (FBI), and National Security Agency (NSA) and provide security briefs to the project sponsors on a regular basis. This project will be carried out in close coordination with the Utilities Communications Architecture (UCA) Open Smart Grid Working Group.

Impact • Create a benchmark of information security and management standards and methodologies for utility

AMI, HAN and DER rollout programs • Create a repository of information on AMI, HAN, and DER security and management relevant national

policies and guidelines • Create working relationship with the UCA Open Smart Grid Working Group to develop new security and

management standards and methodologies and address technology gaps in the market • Conduct empirical testing of commercially available security and management tools in EPRI Living Lab

and member utility labs to identify technology and standards gaps

How to Apply Results The member utilities that sponsor this project will receive periodic EPRI Technical Reports, Technical Updates, and Technical Briefs on AMI, HAN, and DER security/management documenting the findings from literature search, surveys, and lab tests. The project technical team will be available to the sponsoring member utilities to discuss the project products and advice on the specifics.




2010 Products


System Security Requirements for Home Area Networks: This report will sift through the security related use cases to identify the known threats to Home Area Networks and determine a list of cyber security requirements to mitigate the risks posed by these threats. The report will provide overviews of any recommended security practices from ISO, ITU, IEEE, and IEC to protect Home Area Networks from various sources of intrusion.



Grid Operations - Program 39

Program Overview

Program Description Grid operation is a fundamentally important function for utilities, transmission companies, and ISOs/RTOs. EPRI foresees the following industry trends:

• More reliability standards • Increasingly aging infrastructures and workforce • Increasing renewables, demand response, and need for storage. Based on these trends, system operators will operate transmission systems in a complex environment. EPRI members have the following technical needs:

• Improve real-time situation awareness • Improve wide area protection and control performance • Improve capabilities to handle extreme events and restore the system.

Research Value In 2010, the Grid Operations program will offer its members a focused research portfolio:

• Situational Awareness Project Set, which helps system operators improve monitoring and visualization capabilities

• Online Analysis Project Set, which helps system operators improve real-time analyzing capabilities • System Control Project Set, which helps system operators improve control capabilities. By deploying these advanced technologies, program members will:

• Improve system reliability and reduce operational risks • Increase transfer capability and reduce congestion cost • Reduce the risk of blackouts and improve restoration time to reduce outage costs • Improve coordination between operations and planning. The vision of the Grid Operation program is to help members develop next-generation monitoring, analyzing, and controlling capabilities to help enable a smart transmission grid.

Approach The Grid Operations program offers members both short- and long-term value in a variety of ways, including:

• Helping anticipate the future, and developing strategies and roadmaps • Developing methods and tools • Demonstrating and deploying technologies • Providing training and staff development • Sharing knowledge, information and experience • Building networking and outreach opportunities.

Accomplishments EPRI's Grid Operations program has provided critically needed technologies and information for its members over many years. Examples include:

Grid Operations - Program 39 p. 1


• Generic Operator Training Simulator (OTS), Version 2.0. The EPRI Generic Operator Training Simulator is a PC-based training simulator that allows hands-on training for dispatchers, using a generic 29-station model. The Generic OTS, which can be run on multiple platforms, allows for realistic simulations of many power system phenomena. Users may employ a generic power and light model, or incorporate their own models into the OTS. The generic OTS has also been integrated with several Energy Management System (EMS) vendors.

• Situation Awareness (SA) in Power System Operations. This technical update represents a detailed study of the use of color, automated systems, and predictive SA tools in the power industry. Data was gathered through site visits with three control centers and an online color survey. A total of 27 survey responses from 25 separate EPRI members were collected and analyzed.

• Prototyping a Decision Support Tool for Evaluation of System Restoration Strategy Options. This project studied industry practice and documentation of system restoration plans. A new concept, generic restoration milestone (GRM) during system restoration, was proposed. Based on that, a prototype decision support tool for evaluating system restoration strategy options was developed. A specific restoration strategy can be established by a combination of GRMs based on the system characteristics, energy sources and constraints of power grids, and then be examined by simulations. Different combinations or sequences lead to different strategy options and performances. Simulation studies have shown that the developed decision support tool enables a power system in a blackout status to restart and self-organize various parts until it achieves complete restoration.

Current Year Activities In 2010, this research program expects to accomplish:

• Technical report on advanced alarm management • Technical report on human-centered situational awareness • Technical update on integrating substation and equipment health information to improve operation

awareness • Technical update on indicating cascading outages using measurement data • Technical update on real-time reactive reserve requirements and optimal allocation among resources • Technical update on measurement-based voltage stability monitoring and control for control center • Measurement-based voltage stability analysis software • Technical update on online stability assessment with comprehensive dynamic models • Technical report on preventive and emergency controls to minimize the impact of system separation • Decision support tool of interactive system restoration software • Operator Training Simulator (OTS) software


Program Manager Pei Zhang, 650-855-2244, [email protected]



Summary of Projects

PS39D New Control Center Applications (069243)

Project Set Description The objective of this project is to develop operational applications to help system operators improve on-line monitoring, analysis, and control functions.


P39.007 Development of Next Generation Control Center Applications

This project expects to develop operational applications to help system operators improve on-line monitoring, analysis, and control functions.

P39.008 Guidelines for Implementing Dynamic Thermal Circuit Rating (DTCR) in EMS

The research project will develop practical guidelines for integrating DTCR into EMS.

P39.007 Development of Next Generation Control Center Applications (069244)

Key Research Question System operators are operating transmission systems that are becoming increasingly complex. EPRI organized a workshop in 2009 to discuss the key operation issues faced by the industry. Key technical issues include:

• Reliability • Forward looking analysis • Data sharing capabilities • Visualization • Smart grid impact to operations • Topology solutions • Voltage collapse • Equipment health. A new set of operating tools is needed to improve system operators’ monitoring, analysis, and control capabilities.

Approach The objective of this project is to develop operational applications to help system operators improve on-line monitoring, analysis, and control functions. In 2010, EPRI project team will focus on the following tasks:

• Task 1: The EPRI project team will organize a series of webcasts and workshops to work with industry advisors and vendors on developing the functional requirements for next-generation control center applications.

• Task 2: Based on the functional requirements developed in Task 1, EPRI will issue a request for proposal to EMS vendors. After receiving the responses, EPRI will work with industry advisors to review the proposals and determine the vendor who can perform the work. EPRI will work with the selected vendor to develop next-generation control center applications, monitor the status of development work, and organize a series of webcasts and workshops to provide industry advisors with technical updates on a regular basis. EPRI will also test the developed applications to ensure their quality.



Impact With deployment of the advanced technologies developed through this program, members will:

• Improve system reliability and reduce operational risks • Increase transfer capability and reduce congestion cost • Reduce the risk of blackouts and improve restoration time to reduce outage costs • Improve coordination between operations and planning.

How to Apply Results The methods and tools developed in this project can be implemented at control centers and used by operators and operational planners. Members can utilize the methods as functional specifications to develop advanced EMS application tools, and can implement the tool into EMS to manage reactive power in operating environments. EPRI will provide application services to help members apply the technologies developed through this project as well as through supplemental project opportunities.

2010 Products


Functional Requirements of New Control Center Applications: The technical updates documents the functional requirements of next-generation control center applications.


P39.008 Guidelines for Implementing Dynamic Thermal Circuit Rating (DTCR) in EMS (069245)

Key Research Question The ratings of power equipment via DTCR (Dynamic Thermal Circuit Rating) are typically 5% to 15% higher than conventional static ratings. Application of dynamic ratings may enhance economical operation by enabling less constrained operation and timely mitigation action to avoid dangerous system insecurity conditions by tracking the thermal state of equipment. There are a number of practical implementation issues to consider, including SCADA/EMS flexibility and capability, communication links, instrument reliability, and engineering acceptance regarding dynamic rating and its variability. Due to these issues, dynamic ratings are still not widely integrated into power system operations.

Dynamic thermal ratings must be integrated into power system operations if they are to be useful. This project will develop and document practical guidelines whereby dynamic ratings and monitoring data can be useful in system operations, both as displayed values to operators in EMS and as input for many other EMS applications.

Approach This project plans to focus on the following activities:

• Identify practical issues hindering the wide integration of DTCR into power system operations and seek to understand operators' perspectives on DTCR through surveys and workshops. These implementation issues may include flexibility and capability of current EMS and its applications in incorporating dynamic ratings, reliability and functionality of measurement devices, availability and reliability of communication links to SCADA/EMS, practical methods for utilizing varying weather and loading conditions to calculate or predict dynamic ratings, and representing and storing continuously changing ratings in EMS. The survey and workshop should help achieve wider engineering acceptance for integrating DTCR into EMS, and learn what system operators need from DTCR and its EMS applications.



• Develop functional specifications for implementing DTCR into EMS, and practical guidelines to resolve the aforementioned issues in incorporating DTCR into the EMS based on thorough engineering and market efficiency studies as well as an investigation of utility practices in using DTCR.

• Future year efforts may include demonstrating the beneficial impact of integrating DTCR into EMS in terms of improved system reliability and efficiency. The specific scope may depend on the number of participants, but could include deploying instruments at appropriate locations, communicating monitoring data with SCADA/EMS, and interpreting and utilizing the dynamic ratings from DTCR in EMS applications based on the technical guidelines developed.

Impact Successful completion of this project could:

• Help operators take advantage of increased power equipment utilization • Improve operators’ situational awareness of potentially dangerous or damaging situations, and help them

act appropriately to reduce loading due to DTCR implemented into EMS • Improve system reliability • Help system operators avoid false congestion and security alarms by providing sound operating limits

through real-time ratings of system equipment • Provide sound engineering judgments in applying dynamic ratings to operational decisionmaking.

How to Apply Results • Operators can better understand the value and issues of using dynamic ratings in system operations

through practical guidelines developed through this project. • ISOs or RTOs may integrate DTCR into their EMS applications based on the guidelines, and pursue

improved system and market efficiency. • Transmission owners may achieve benefits in terms of increased equipment utilization and reliability, and

avoid damaging critical components.

2010 Products


Guidelines for Implementing Dynamic Thermal Circuit Rating (DTCR) in EMS: This technical report will summarize research efforts in 2010. Results are expected to include an examination of practical issues and guidelines for implementing DTCR into EMS.


PS39A Situational Awareness (067422)

Project Set Description The Situational Awareness Project Set is designed to help system operators improve situational awareness through better monitoring and visualization capabilities.


P39.001 Human-Centered Situational Awareness

Develop human factor guidelines for improving the situational awareness of operators.

P39.009 Improve Operational Awareness using Component Health Information

This project will develop functional requirements for integrating sensors and substation information into system operations and develop algorithms to utilize advanced sensors to anticipate equipment failures.





P39.010 Indication of Potential Cascading Outages using Measured Data

This project will develop a measurement-based complementary strategy of simulation-based DSA tools for indicating potential cascading outages by precursor signal recognition.

P39.001 Human-Centered Situational Awareness (055940)

Key Research Question Situational awareness by grid operators is the single most important factor in preventing blackouts. Human-centered research is needed to increase operator situational awareness. In many cases, grid operators suffer from information overload, which impairs their ability to implement corrective actions in a timely fashion to prevent continuing cascading events that can cost millions or even billions of dollars in direct costs and socioeconomic impacts.

Approach This project will continue research in improving situational awareness in view of today's challenges of integrating large-scale and highly variable wind power plants into grid operation. EPRI will develop human factor guidelines for improving operators' situational awareness through standardized human-machine interfaces and streamlined visualization software. The program will continue work done in 2008 that developed guidelines for color usage, automation, and predictive awareness for grid operations. It will identify new types of data or information that will be needed to increase operator awareness due to the integration of renewable and variable generation. It will also propose standard ways of displaying salient information graphically (e.g., with icons) and appropriate visual and audible effects to convey the most important information to grid operators. In addition, the project will propose effective ways to inform operators which remedial actions to take when an alarm state is activated. A report and a public workshop open to software vendors will be held to deliver the results of this research.

Impact • Provide effective guidelines to system operators and in-house IT support staff for improving situational

awareness. • Provide input for functional specifications of new energy control center designs for human-machine

interfaces. • Avoid millions of dollars in potential economic losses from cascading blackouts by reducing the probability

of such blackouts. • Speed operators’ ability to recognize potential problems and take corrective actions with better human

factor designs. • Simplify grid operators’ tasks of monitoring wide-area transmission grids through enhanced visualization

of system stressors, with drill-down capabilities at various levels. • Afford operators more lead time to head off any potential problems later in the day by providing predictive

situational awareness.

How to Apply Results Research results in situational awareness will be published in technical updates for EPRI members to use as training materials. The public workshop will be a forum for disseminating the guidelines and research results of this entire project. By opening the workshop to the public and vendors, as was done in 2008, EPRI's research results will deliver greater benefits to the public and increase the speed of implementation.


2010 Products


Workshop on situation awareness guidelines: This workshop will present human factor guidelines for improving the situational awareness of operators through standardized human-machine interfaces and streamlined visualization software. It will be open to the public and software vendors will be invited.


Guidelines for Human-centered Situational Awareness: A technical update to document standard ways of displaying salient information graphically (e.g., with icons) and appropriate visual and audible effects to convey the most important information to grid operators.


P39.009 Improve Operational Awareness using Component Health Information (069241)

Key Research Question System operators seek forward-looking functionality to identify potential problems, their likelihood of occurrence, and how they affect operating margins. Current EMS systems do not provide a flexible tool for that type of analysis. The wide application of online monitoring devices (such as sensors) creates an opportunity to improve situational awareness. The technical challenge will be integrating equipment health information into system-wide operations to improve situational awareness.

Approach This project will work to develop and demonstrate a new methodology to quantify equipment health information based on a measured data streams from advanced sensors. Incorporating such a method into existing EMS functions would create a new application to improve operation awareness. The research activities may include:

• Host a Project Initiation Meeting to review, interpret and disseminate key results of using monitoring devices to calculate or predict equipment health condition at transmission and substation levels. Sharing information and experiences will help members understand available technologies and avoid duplication of effort.

• Develop mathematical models to predict failure rates for different components using real-time sensors. To avoid problems of system complexity and compatibility, the project team will specify and recommend one type of advanced metering technology for a particular part of the grid (e.g., generator, transmission line, or transformer). Unlike traditional failure rate predictions, which use historical off-line measurements to estimate the longevity of applications using the devices, models will use real-time sensing data with history to predict failures and facilitate preventive actions.

• Integrate and centralize substation and equipment health information into system operation. Although predicted component failure information based on sensor technologies will be valuable for early identification of component outage, it will further require a set of models to be useful for system-wide assessment of transmission reliability. The project team will assess the integrated modeling platform in the existing EMS and define additional requirements for integrating substation and sensor information.

Impact • Innovation: First-of-its-kind, focused analysis introducing the concept of sensory information in

transmission grid operations • Process excellence: Highly automated methodology helping utility assessment and management of

transmission operations to improve situational awareness



• Commitment to members: Work with utility members to predict and quantify equipment health condition in system operations, and provide members with decision-support information to improve situational awareness

• Commitment to society: Avoid damaging and costly blackouts of transmission grids

How to Apply Results Results of this research will be available to EPRI members in a report that documents the potential capability of sensory information for improving situational awareness. Functional specifications will also be available to EPRI members in a report that documents extra EMS functionality needed for integrating substation and sensory information.

2010 Products


Functional Requirements: Integration of Substation and Equipment Health Information to Improve Operation Awareness: The predicted component failure information provided by metering technologies is valuable for early identification of component outage. However, to be useful for system-wide assessment of transmission reliability, they require a set of upgrades for existing EMS models and function. This product will assess an integrated modeling platform in existing EMS functions.


Future Year Products


Integration of Substation and Equipment Health Information to Improve Operation Awareness: This report will document the proposed mathematical models used to predict failure rates for different components using real-time sensors.


P39.010 Indication of Potential Cascading Outages using Measured Data (069242)

Key Research Question Simulation-based Dynamic Stability Assessment (DSA) tools have difficulty recognizing the early stages of cascading outages because:

• They must wait for state estimation results to assess online stability; however, state estimators cannot capture dangerous real-time changes in operating conditions, which are critically important in alerting operators to potential cascading outages.

• They simulate only pre-defined N-1 or N-2 critical contingencies; however, in fact, failures that are likely to trigger cascading outages are quite unpredictable.

Thus, new situation awareness technology for real-time indication of potential cascading outages needs to be developed. Since PMUs can provide real-time and synchronized measurements of system variables for operators to monitor system dynamics, they may be the basis for a new situation awareness technology. EPRI research shows that “precursor signals,” which indicate potential cascading and instability, usually appear in the real-time measurements of some system variables before an irreversible system collapse happens. These signals are abnormalities in either the values or dynamic patterns of those variables, and are easily captured if PMUs are applied. Consequently, the timely capture of precursor signals from PMU



measurement data will help operators recognize potential cascading outages and take preventive actions according to control guidelines.

Key research questions concerning the early recognition of cascading outages include:

• Are there any common characteristics of precursor signals that can be learned offline? • How will operators recognize precursor signals in real time from PMU data? • Where can PMUs be placed for effective recognition of cascading outages?

Approach This multi-year project will develop new situation awareness technology for the early indication of potential cascading outages using measurements from PMUs or other devices. The project may include the following activities:

• Simulate cascading scenarios on several test power systems to investigate the common characteristics of the precursor signals indicating instability. The project team may investigate two types of precursor signals: abnormal values, and abnormal dynamic patterns of system variables. An approach to clearly visualize precursor signals will be developed.

• Identify methods select buses for monitoring precursor signals and create criteria for PMU placement. • Perform technology investigations and development for quick recognition and evaluation of precursor

signals. The risk of cascading outages will be estimated in real time for system operators to decide whether to take preventive actions.

• Future year efforts may test and validate the developed situation awareness scheme using simulation data about cascading outages or real measurement data regarding large disturbances.

Impact This project is expected impact members' operations and benefit the public in the following ways:

• Reduce the risk of blackouts by providing a real-time situation awareness scheme for early indication of potential instability or cascading outages

• Improve real-time situation awareness through better monitoring and visualization capabilities • Help system operators understand the precursor signals indicating potential cascading outages • Suggest preferred buses to install PMUs for real-time monitoring and visualization purposes.

How to Apply Results System planners may use the tools developed to study the precursor signals of cascading outages in their systems, and identify buses to equip with PMUs.

System operators may use the situation awareness scheme developed to monitor their systems and visualize precursor signals of potential cascading outages. They can also estimate the real-time risk of cascading outages as a reference for making decisions of preventive control.

EPRI will offer the following supplemental project opportunities to help members apply this work:

• Investigating the precursor signals of potential cascading outages from measurement data • Indicating potential cascading outages using pattern recognition technologies.



2010 Products


Indication of Potential Cascading Outages using Measurement Data: 12/31/10 Technical Update

PS39B Online Analysis (067423)

Project Set Description The Online Analysis Project Set is designed to help system operators develop preventative control strategies through better online analyzing capabilities.


P39.003 Real-time Reactive Reserve Requirements and Optimal Allocation Among Resources

The reactive power management project has developed methods and tools to help system operators and operational planners find voltage stability problem areas and determine the corresponding required reactive power reserves for each area. This project will continue R&D efforts for optimally allocating the required reactive power reserve and investigating the dynamic voltage recovery standard.

P39.004 Measurement-based Voltage Stability Monitoring and Control

EPRI has designed a three-level hierarchical measurement-based voltage stability monitoring, analysis, and control architecture. This project will develop the tools based on the algorithms produced from the past efforts. This project will also enrich the measurement-based approach by developing functional specifications at the control center level for operators to visualize the voltage stability margin information calculated at local substations and load centers.

P39.003 Real-time Reactive Reserve Requirements and Optimal Allocation Among Resources (063323)

Key Research Question Voltage stability is a major concern in power system operation and a leading factor that limits power transfers in the prevailing open access environment. Reactive supply is an important ingredient in maintaining healthy power system voltages and facilitating power transfers. Inadequate reactive supply is a major factor in causing voltage instability or collapse events. It is the responsibility of system planners and operators to plan for reactive power requirements and make any short-term arrangements needed to ensure that adequate reactive power resources will be available.

Approach EPRI aims to develop better methods for effective reactive power management, considering all nonlinearities, to achieve efficient use of reactive power sources, sinks, and voltage control from generation and transmission facilities. Before 2010, EPRI developed an automated method and a software package that can identify "coherent reactive power zones" or "critical voltage control areas" (VCAs) using Decision Tree (DT) techniques from on-line system snapshots and determine required reactive power reserves using regression trees (RT) for each of the identified VCAs based on key system attributes. In 2010, the project will focus on the following activities:



• Develop methods to determine the needed static and dynamic reactive power support, and identify the optimal location to allocate the required reactive power reserve. Using this information, system operators can develop the most effective preventive control actions to avoid voltage instability.

• Review the existing dynamic voltage recovery standards and then investigate the proper dynamic voltage recovery standards from the required reactive power reserve point.

Impact • Reduce operational risk associated with voltage instability and voltage collapse events. • Increase power transfer capabilities using the existing transmission infrastructure.

How to Apply Results The methods and tools developed through this project can be implemented at control centers and used by operators and operational planners. EPRI will provide application service to help members apply the technologies developed from this project.

2010 Products


Real-time Reactive Reserve Requirements and Optimal Allocation among Resources: This technical report will document methods to allocate the required reactive power among resources in real-time in addition to the results of investigations on dynamic voltage recovery standards.


P39.004 Measurement-based Voltage Stability Monitoring and Control (067445)

Key Research Question Voltage stability is a major concern in power system operations and a leading factor that limits power transfers in the prevailing open access environment. Voltage stability assessment (VSA) is a computer simulation tool to help operators monitor and control system voltage stability. The accuracy of VSA results depend on the accuracy with which the generation, load, and transmission facilities are modeled. Uncertainties in these factors pose challenges to obtaining accurate voltage stability analysis results using a VSA program, which may in turn lead operators to make incorrect decisions and increase the risk of voltage collapse. Moreover, a VSA program also relies on the state estimator to provide steady-state solution for further analysis. In extreme operating conditions when the state estimator fails to converge, VSA programs also fail to help operators monitor and control system voltage stability.

Given the limitations of VSA programs, this project will investigate using measurement data from synchro-phasors (e.g. PMUs) installed at the substation level to calculate voltage stability margin in real time and send that information to the control center to help system operators monitor system voltage stability.

Approach EPRI envisions measurement-based voltage stability monitoring, analysis, and control as a three-level hierarchical control architecture, and has invented an algorithm called "Voltage Instability Load Shedding" (VILS) that continuously calculates the voltage stability margin at a local bus using real-time measured voltage and current waveforms. EPRI has also invented another algorithm, "Measurement-based Voltage Stability Monitoring and Control for Load Centers," that can calculate in real-time the voltage stability margin for an entire load center using the synchronized voltage and current measurement data obtained at its boundary substations with PMUs installed. The calculated voltage stability margin—which is expressed as active, reactive, and apparent power—can be used as the adaptive criteria to determine when a local bus or load center reaches the voltage stability limit. In 2010, the project will focus on the following activities:



• Develop a software package based on the VILS algorithm to help system operators monitor the voltage stability condition at the substation level using measurement data.

• Develop a software package based on the Measurement-based Voltage Stability Monitoring and Control for Load Centers algorithm to help system operators monitor the voltage stability condition at the control center level using real-time PMU data obtained at the boundary substations of each load center.

• Engage the operators of participating utilities and experts in human factors to design an effective human-machine interface to convey critical voltage stability information calculated at the local substations and load centers.

The Measurement-based Voltage Stability Monitoring and Control project requires multi-year efforts. Looking into the future, the EPRI project team may develop a visualization tool based on the design obtained to help system operators monitor the voltage stability profile of the entire transmission network using PMUs. This will broaden the visualization methods to help system operators increase situation awareness. The EPRI project team will also work with the industry pioneers to demonstrate the three-level hierarchical control architecture.

Impact • Improve system operators' capabilities to monitor and control voltage stability of the transmission system

using PMUs • Provide a safety net to prevent wide-area fast voltage collapse • Validate computation results provided by the simulation-based approach

How to Apply Results The results of this project offer system operators a new method and set of tools to monitor, analyze, and control wide-area voltage stability conditions of the entire transmission system. System operators can implement the VILS algorithm at a load center’s key substations to calculate the voltage stability margin at those substations. The calculated voltage stability margin at each key substation can then be transmitted to a central substation of the load center or the control center. System operators then apply methods developed through this project to calculate the voltage stability margin for the entire load center. System operators can use the visualization tool developed at the control center level to monitor and control the voltage stability condition of the entire transmission system. EPRI also provides an application service to help members implement this technology through supplemental projects.

2010 Products


Voltage Instability Load Shedding: The Voltage Instability Load Shedding (VILS) software package is a tool to help system operators monitor voltage stability condition at the substation level.

12/31/10 Software

Functional Specifications of Measurement-based Voltage Stability Analysis at Control Centers: The Functional Specifications of Measurement-based Voltage Stability Analysis at Control Centers technical report provides a design document to help system operators visualize the critical voltage stability information calculated at local substations and load centers.




PS39C System Control (067424)

Project Set Description The System Control Project Set is designed to help system operators reduce the risk of blackouts and expedite restoration time through better on-line controlling capabilities.


P39.005 Development of Methods to Reduce Restoration Time

This project will provide a decision support tool for evaluating and designing system restoration strategies to reduce restoration time and determine the preferred level of blackstart capability.

P39.006 Preventive and Emergency Control to Minimize the Impact of System Separation

This project will develop preventive and emergency control schemes for minimizing the impact of system separation, identifying potential system separation conditions, and enabling better execution of controlled system separation.

P39.005 Development of Methods to Reduce Restoration Time (067563)

Key Research Question System restoration is a critical task of power system operations. Following a power outage, operators in the control center work with field crews to re-establish the generation and transmission systems and then pick up load and restore service. System reliability depends heavily on the efficiency of system restoration. Unfortunately, few decision support tools are available for operators and restoration planners today. System restoration is still primarily manual work. Restoration plans are developed off-line with basic simulation tools, and then used as guidelines for operators in an on-line environment. Operators need to utilize their experience and also adapt to actual outages and available resources during the system restoration process. Recent major blackout events are powerful reminders that system restoration requires advanced decision support tools. Blackout events and aging transmission infrastructures in the United States demand a focus on R&D for system restoration and its associated decision support tools.

Based on a new concept called "Generic Restoration Milestone" (GRM), a decision support tool was prototyped by EPRI in 2008 for evaluating and designing restoration strategies. A specific restoration strategy can be established by a combination of GRMs based on system conditions. Different GRM combinations lead to different strategy options. This tool helps evaluate different restoration strategy options to determine an effective strategy without violating security constraints. R&D must be conducted to develop necessary computational models and techniques for this tool. Research will be enhanced by estimating the restoration time for each given scenario and the adequacy of blackstart capability.

Approach This multi-year project focuses on developing computer simulations and realistic system models. In 2010, this project will continue R&D efforts in enhancing the decision support tool. The project may include the following activities:

• Continue the development of computational models and techniques for evaluating restoration strategy options and estimating system restoration time to enhance the decision support tool.

• Develop an interactive system restoration software tool, which may be applied either by operators to practice restorations or by planners to design restoration strategies. A reference procedure for designing an effective restoration strategy may be developed and documented in detail. The EPRI project team may also study how to integrate this tool with the EPRI Operator Training Simulator (OTS).



• Based on this decision support tool, develop an approach to determine the preferred level of blackstart capability.

• Validate the decision support tool and the level of blackstart capability on realistic power grid models. Industry advisors may be consulted concerning specific systems and scenarios.

Impact This research project may benefit the public and impact members' operations in the following ways:

• Provide methods to reduce system restoration time and lower the costs of power outages • Improve power system reliability by determining the preferred level of blackstart capability • Help system operators practice system restoration using an interactive software tool • Help system planners evaluate and develop restoration strategies using an interactive software tool.

How to Apply Results System planners may use the interactive software support tool to evaluate restoration strategy options and design more effective system restoration strategies. System operators may use the interactive software tool to practice system restoration. EPRI may offer training courses and supplemental project opportunities to help members enrich their system restoration knowledge and improve their restoration practices.

2010 Products


Development of Methods to Reduce Restoration Time and Determine the Preferred Level of Blackstart Capability 12/31/10 Technical

Update

A Decision Support Tool for Evaluating Restoration Strategy Options 12/31/10 Software

P39.006 Preventive and Emergency Control to Minimize the Impact of System Separation (067446)

Key Research Question Many utilities are operating transmission systems closer to security limits in order to meet the requirements of a rapidly growing electricity market. There is a higher probability that unexpected events (e.g. snow storms or hurricanes) could cause multiple lines in a transmission system to trip and even lead to system separation. System separation (spontaneous or controlled) may impact the transmission system in the following ways:

• For any island whose load cannot be supported by local generation, excessive load must be dropped to maintain voltage and frequency at acceptable levels. If the lack of generation is significant—e.g. in the case that a load center is islanded—large-area power outages will be inevitable.

• The action of separating the system may cause severe generator oscillations in each island, which, if not damped in a timely manner, may lead to instability and further system separation.

In fact, the impact of system separation can be reduced if appropriate preventive and emergency control actions are taken, such as:

• Preventive generator re-dispatching and power-flow reconfiguration to reduce the imbalance in each potential island before separation

• Emergent generation rejection and load shedding within each island after separation to stabilize generators and regulate frequency and bus voltages.




Those preventive and emergency control actions need to be studied. Potential separation conditions should be known, helping system operators decide whether to add control to system separation. PMUs can provide important real-time data to help detect system separation and improve controlled separation.

Approach This multi-year project on system separation will develop preventive and emergency control schemes to reduce the impact of system and may include the following activities:

• Investigate possible separation scenarios for a study system and develop an on-line algorithm to identify high-risk separation scenarios for the current operating condition and network configuration. Available emergency control capabilities of each potential island will be investigated. Potential sets of separation points will be analyzed and compared for each high-risk separation scenario. The set of separation points with the minimum need for preventive and emergency control may be suggested if controlled separation is considered.

• Determine inter-area power flows for each high-risk separation scenario to reduce the load dropped after separation. Once the risk of any scenario reaches a predefined alert level, the scheme could provide operators with preventive control options.

• Future year activities may investigate a PMU-based algorithm for real-time detection of system separation. Once separation is detected, the emergency control scheme may provide operators with load shedding or generation rejection suggestions to quickly stabilize each island and regulate frequency and voltages.

Impact This research project may benefit the public and impact members' operations in the following ways:

• Provide methods to lower the impact of system separation and the risk of large-scale power outages • Increase members’ knowledge of potential system separation scenarios and instability issues involved in

system separation • For members with controlled separation strategies, this research will improve the execution of controlled

system separation.

How to Apply Results System planners can conduct separation studies using the approaches developed to identify high-risk separation scenarios and potential separation points. System planners can utilize the preventive and emergency control schemes developed to study preventive and emergency control options for system operators.

Results of this project will help system operators execute the best preventive control option to reduce the impact of potential system separation once its risk reaches an alert level. In addition, system operators may execute the best emergency control option once system separation is detected.

EPRI may offer supplemental project opportunities to help utility members apply this work.

2010 Products


Preventive and Emergency Control to Minimize the Impact of System Separation 12/31/10 Technical

Update


Grid Planning - Program 40

Program Overview

Program Description Utilities, transmission companies, and ISOs/RTOs need to plan for future demand growth and provide transmission services for changing generation portfolios. The challenge of meeting reliability requirements with the addition of variable generation and allowing demand response as a capacity resource may necessitate transmission planning to reassess the planning objectives. Planning for peak load scenarios may not be sufficient. Evaluation of additional scenarios such as low load and shoulder load, as well as intermittent availability of variable resources may also be required. Variable resources have two other characteristics that need to be addressed in planning: uncertainty, and a regional nature beyond the traditional utility boundaries. Strategic issues that grid planners need to resolve include:

• Increasing uncertainty of future generation and load • Higher utilization of transmission assets and right-of-waysHigher reliability standards and greater regional

planning. A second focus of this program is to identify and develop solutions and decision support tools for planners to deal with specific technology gaps to improve overall planning activities.

Research Value Participation in EPRI's Grid Planning program could produce:

• A framework of adjusted planning objectives to deal with supply and load uncertainties • Standard planning characteristics of non-traditional resources and resource capacities • Improved modeling and simulation capabilities of more complex operating conditions • Understanding of the impact of reliability standards • Robust transmission systems.

Approach The Grid Planning program will facilitate an industry forum in which stakeholders define the objectives for a planning framework that can meet these challenges. Implementing this framework may lead to the creation of a robust transmission grid capable of meeting the variability of renewable resources, regional availability of those resources, and higher utilization of transmission assets. In addition, the program will continue to focus on assessing, developing, and demonstrating new algorithms and methodologies to improve modeling and simulation capabilities, facilitate smoother cooperation between utilities connected to the same grid for model exchange and model reduction technologies, and reliability assessment.

Accomplishments The Grid Planning program has delivered valuable information that has helped its members and the industry in numerous ways. Some examples include:

• Probabilistic Risk Assessment (PRA) Version 4.1—The PRA software reads load flow text files as well as probabilistic information, then computes and displays reliability indices through a Graphical User Interface. When applied to power delivery systems, this methodology provides the ability to determine the probability or likelihood of an undesirable event on the transmission system and a measure of its severity. PRA combines a probabilistic measure of the likelihood of undesirable events with a measure of the consequence of the events into a single reliability index, the Probabilistic Reliability Index (PRI).

• Utility Application Experiences of Probabilistic Risk Assessment Method—This technical report summarizes recent utility experiences applying EPRI's PRA methodology, which offers greater accuracy

Grid Planning - Program 40 p. 1


than traditional deterministic approaches for assessing grid reliability. PRA methodology has already been used by many utilities since 2001, and sufficient data are now available for the power industry to move toward widespread implementation. These studies enable system planners to receive complementary information in addition to traditional deterministic contingency analysis results. Displaying deterministic and probabilistic risk assessment results on charts, tables, and maps enables the visualization of complex reliability information effectively.

• Comprehensive Load Modeling for System Planning Studies - This technical report presents valuable information related to both measurement-based and component-based load modeling. It also presents a clear, step-by-step current best-practice approach to comprehensive load modeling for planning studies. Detailed data on laboratory tests of key load components—such as air conditioners, compact fluorescent lighting, and high-definition televisions—are presented. Results on many measurement-based load model parameter derivation attempts and what was learned from these exercises are also presented.

Current Year Activities In 2010, this program expects to accomplish these objectives:

• Facilitate a review and adjustment, if necessary, of an overall planning framework and objectives • Evaluate the economics of options to increase transmission system capacity • Produce assessments and case studies on applications using synchro-phasors • Facilitate effective inter-utility model exchange and network reduction • Assess the possibility of deriving model information from mining metering data contained in data stores • Expand reliability assessment methodologies to include historical availability information.





Summary of Projects

PS40D Strategic Planning (069250)

Project Set Description The Strategic Planning Project Set focuses on the strategic and economic aspects of transmission planning. Before performing detailed studies, planners needs to evaluate strategic options for adding transmission capacity. Such options are addressed in this research.


P40.008 Development of New Planning Framework

The project will focus on developing a consensus for a new planning framework to address variability, uncertain characteristics of load response as a resource, and regional planning.

P40.009 Economic Assessment of Technology Options for Increasing Transmission Capacity

This project develops the understanding and tools to effectively include incremental and major line and systems upgrades into planning, including prioritization of specific improvements to achieve the optimum system improvement.

P40.010 Application Surveillance and Success Stories of Synchro Phasors

The objective of this project is to gather and document successful applications of synchro-phasor devices, helping members realize their full value in improving electric power system reliability and efficiency.

P40.011 Portfolio Planning Under Uncertainty

This research project will develop methods to model uncertainties and their implications for transmission planning with an emphasis on utilizing a portfolio approach for addressing risk.

P40.008 Development of New Planning Framework (069251)

Key Research Question Various stakeholders—including state regulators, utilities, environmental advocates, transmission owners, grid operators, and energy developers—expect the integration of renewable resources into the grid. Variability and regional concentrations of renewable resources may change overall planning objectives. While in the past it was sufficient for utility planners to focus on a limited number of peak scenarios, it will now be necessary to plan for many different scenarios, including low loads with high availability of variable resources affecting regions beyond the traditional planning boundaries.

This means that traditional integrated planning exercises will likely be supplanted by integrated planning conducted by multiple entities. In addition, variables such as load and supply forecasts, the location and characteristics of new generation, and the timing of new transmission facilities are now less certain than in the past. Furthermore, system operations may have to accommodate load following supply to dispose of available unscheduled energy through storage or the charging of plug-in hybrid electric vehicles (PHEVs). The characteristics of supply and demand become less distinct and may require different considerations when planning for the overall system due to the trend to accept demand response as part of overall capacity planning. While common planning goals remain, identifying regional least-cost options for generation and transmission investment are needed to address the objectives and include these trends.

Approach This research project will facilitate a consensus-building industry forum, inviting stakeholders to help define the objectives for a planning framework that can meet the challenges of creating a robust transmission grid. This grid should be adapted to deal the with the variability and regional availability of renewable resources as well as other changing operational requirements of the grid.



The framework for this new transmission planning process recognizes the reality of current organizational structures within the electric power industry and the changing needs of energy consumers. The industry forum will be tasked with identifying the existing structures and changing needs, and then envisioning a new overarching structure that can build on current practice and move toward satisfying new planning requirements such as:

• Handling increasing uncertainties of future generation and load • Meeting higher reliability standards and broader regional planning needs.

Impact • Enable planners to identify optimal and feasible states in various time scales, with integrated analyses of

economics, security, and adequacy. • Enable greater utilization of current generation resources and increase potential for greater efficiencies. • Optimize the use of existing assets. • Provide predictable and foreseeable bounded results instead of "zero-to-perfect" one-time exercises. • Enhance understanding among neighboring entities, thus promoting regional cooperation.

How to Apply Results A series of webcasts and a workshop will be held to gather input regarding existing practices and to present the integrated planning framework. These products will provide information for members to start applying the methodology and concepts in their own planning process.

2010 Products


Workshop on Methodology and Planning Framework: A workshop will be organized to train members on the research results on the methodology and planning framework, as will be documented in a technical update report.


Report on New Planning Framework: This report will document research results in 2010. It will describe the planning methodology and planning framework, define holistic objectives in terms of metrics, develop holistic methodology and approach that will meet the new TPL standards, and define multiple base cases and sensitivity cases.


P40.009 Economic Assessment of Technology Options for Increasing Transmission Capacity (069252)

Key Research Question With new transmission construction difficult to pursue, incremental upgrades may be considered first, followed by major upgrades. Such measures could include a voltage upgrade, implementing FACTS (Flexible AC Transmission System), and adding advanced high-temperature low-sag conductors to the existing system as demand increases. The opportunity to increase transmission capability through upgrades is large, and they need to be considered in system planning decisions. Understanding the impact of incremental and major upgrades in system planning will help planners make economic decisions while considering the costs and limitations of such upgrades.

In addition, planners understand that while capacity improvements on selected lines may increase capacity, they may only have limited impact on overall system capacity. Prioritization of possible improvements is necessary to get the most system value from specific capacity improvements.



Increased power flows on transmission circuits can be achieved by controlling circuit parameters such as current, voltage, phase angle, or timing of current flow. Often, upgrade of a single parameter, such as current or voltage, provides increased power flows. However, controlling more than one parameter, while typically more expensive than a single-parameter upgrade, offers distinct benefits. This option not only allows a utility to increase the capacity of an overhead line, but also enhances the power flow performance of the entire transmission system.

Approach This project will address planning issues related to incremental upgrades, such as dynamic ratings and major upgrades including voltage, FACTS, and advanced high-temperature low-sag conductors. It addresses power flow upgrades achieved by controlling more than one of the system’s parameters. The project selects different advanced technologies at various stages of maturity for evaluation in power flow management applications. It also examines the economics of applying such technologies to develop a tool for making the financial decisions associated with implementing such technologies. The project will further explore systematic methodologies of prioritizing capacity upgrades to get the most economical capacity improvements for the overall transmission system.

The tasks addressed in this project include:

• Develop planning methodologies to integrate incremental and major power flow upgrades. Existing transmission planning tools focus on new equipment additions and new line construction. It is important to review existing planning methodologies (both deterministic and probabilistic methods) and propose new ways of considering incremental and major power flow upgrades.

• Investigate the feasibility of applying incremental upgrades and major power flow upgrades when adding new generation, including wind and solar.

• Document the technical and economic benefits of each upgrade option, and providing engineering requirements.

• Develop study methodologies to prioritize possible line upgrades.

Impact This project may help system planners and operators communicate and realize the economic benefits of advanced transmission technologies in these ways:

• Perform cost-benefit analysis to evaluate planning options • Communicate operational benefits and translate them into reliability and economic benefits suitable for

planning analyses • Provide an economic basis for strengthening grids and deferring investment in new transmission • Improve robustness of the transmission grid through the application of advanced technologies • Provide a method to forecast reduced risks and costs of major outages • Demonstrate how advanced technology can relieve transmission bottlenecks and increase operating

efficiency • Help quantify higher quality maintenance, protection, and operation information for increased robustness

and integrity of transmission grids.

How to Apply Results The materials developed will deal with incorporating incremental and major improvements, including advanced transmission technologies, as planning options for enhancing the transmission grid. By understanding how to apply the technology options, system planners can enhance the robustness and flexibility of their plans for a very reliable and high-capacity system.



2010 Products


Methodologies for Economically Assessing Technology Options for Increased Transmission Capacity 12/31/10 Technical

Update

Economic Case Studies of Technology Options for Increased Transmission Capacity 12/31/10 Technical

Update

P40.010 Application Surveillance and Success Stories of Synchro Phasors (069253)

Key Research Question Power systems continue to be stressed as they are operated in many instances at or near full capacity. Wide Area Measurement Systems (WAMS) are technologies that may bring major advances in power system operation, protection, and maintenance. Key building blocks of WAMS are synchro-phasors, widely known as phasor measurement units (PMUs).

Time-synchronized phasor measurements of bus voltages and line currents are becoming available via PMUs and other system components. These measurements are highly accurate and provide phase angle information previously missing from conventional measurements on which most EMS functions rely. A large number of PMUs have been installed, or are planned to be installed, in systems such as the Eastern Interconnection (EI), Western System Coordination Council, and ERCOT in Texas.

This technology is expected to improve state estimate, oscillation detection and control, voltage stability monitoring and control, load model validation, and system restoration, and event analysis that may lead to power systems being routinely operated close to full capacity. However, only a few applications and successes have been realized using this technology.

Approach The objective of this project is to find, assess, and document successful applications of synchro-phasors by surveying the industry for potential and successful uses of this technology. The project will document possible value derived from the technology as well as experiences and plans, and will create a list of new and existing applications that can derive enhanced value from detailed synchro-phasor technology.

The approach is to include the following activities:

• Conduct a survey of planners and operators on the uses of synchro-phasor data. The team will also outline a qualitative framework for assessing efforts required to obtain the expected value.

• Conduct an international workshop to gather industry experts who have developed or propose applications of synchro-phasor data. Participants will present their applications and case studies that convert raw synchro-phasor data into information leading to actionable decisions.

• Perform a technical gap analysis, and publish a summary of research needs. The results of this workshop will be published as technical proceedings available to workshop participants and project members, with the intent of communicating openly the benefits of increased application and use of synchro-phasors.

Impact This project helps document and communicate the full value of synchro-phasors. With successful applications of synchro-phasors, members should realize the following benefits:

• Communication and lessons learned on the value of synchro-phasors • Improved performance and functionality of existing monitoring and control applications • Improved situational awareness through better monitoring and visualization capabilities



• Maximum utilization of existing transmission assets and extended equipment life • Better assessments of transmission system adequacy • Verified load models, through dynamic analysis of measurement data • Cost-benefit analyses that evaluate planning options for installing synchro-phasor systems • Enhanced system reliability and efficiency • Promising new benefits from integrating synchro-phasors into system operations, maintenance, and

planning.

How to Apply Results The goal of this project is to identify features and functions of synchro-phasor devices that support and enhance system operations, maintenance, and planning. Members can use the qualitative ranking framework, workshop, and report to communicate internally the prospects of installing synchro-phasor systems and utilizing this data across system operations, maintenance, and planning departments.

2010 Products


Application Success Stories of Synchro-Phasors 12/31/10 Technical Update

P40.011 Portfolio Planning Under Uncertainty (069254)

Key Research Question Transmission planners face a complex future. They need decision-support methods that assess future business uncertainties, and the interactions and impacts of those uncertainties, to optimize investments with respect to expense, revenue, timing, risk and reliability.

New technical developments such as stochastic generation (wind and solar), energy storage, and the smart grid, as well as uncertainties in emission regulations, load growth, power and fuel market pricing, and siting permissions, contribute to the difficulty of transmission planning. Long lead times for permits and construction as well as large capital expenditures exacerbate exposure to risks.

At the same time, energy companies are increasingly adopting "enterprise risk management" practices. Top executives expect transmission planners to contribute a well-thought-out understanding of the potential impact of their function on overall corporate risk exposure.

Approach This research project will develop methods to model uncertainties and their implications for transmission planning. Because exposures in different portions of the asset mix may collectively reduce or exacerbate particular risks, emphasis is placed on utilizing a portfolio approach for handling risk.

Research will consist of enumerating the types of uncertainties, creating mathematical descriptions of their nature and mutual influence, and using analytic methods to explore impacts on candidate asset portfolios and alternative future courses of action. There may be a need to develop new risk metrics and measures. Some of the analytic approaches to be explored in this project may be based on methods that have been successfully applied for analyzing the behavior and impact of power markets, fuel markets, and loads. Particular care will be taken to reflect the potential impact of rare but highly impactful “tail events” (“black swans”) on the portfolio of assets and obligations.



Impact The methods developed through this project are intended to help transmission planners assess the behavior, interaction and impact of the most important risk exposures their transmission investments will face. Such tools would enable them to make investment decisions more quickly and with greater confidence, as they will be able to ascertain and include a wider range of potential future outcomes. These methods would also help planners provide management with better information to use in corporate assessments of enterprise risk.

How to Apply Results Participating members should expect to receive new methodologies and education via reports, webcasts and seminars. Spreadsheet implementations may be developed and distributed, to the extent they are warranted and funded, for algorithm testing. A limited number of opportunities will exist for members to serve as a study case in developing the needs and methodologies, or a study case in applying the methodologies.

2010 Products


Transmission Portfolio Planning Under Uncertainty 12/31/10 Technical Update

PS40A Modeling and Standardization (067425)

Project Set Description The Modeling and Standardization Project Set is designed to help system planners improve modeling and data preparation capabilities.


P40.012 Determination of Load Composition using Smart Meter Data

This research project develops novel methodologies for determining dynamically changing load classes and compositions using smart meters.

P40.013 Development of Standard Models for Dynamic Components

This new EPRI research project develops base support to reinforce existing industry efforts, as needed, to progress toward standard, international CIM models. The project will also organize workshops to educate members in the proper utilization of these models.

P40.014 Transmission System Model Management

This project expects to develop an efficient transmission network management tool, facilitating and expediting the processes of building and managing electric power network models for system planners.

P40.012 Determination of Load Composition using Smart Meter Data (069246)

Key Research Question Component-based load modeling for power flow and stability studies is a common approach used by planners to represent various load characteristics. It is a bottom-up process that utilizes load surveys and understanding of the behavior of typical devices to assign the percentage compositions of the components of a chosen load model structure, representing the total load at a specific bus of a bulk power system.



This project explores an alternative approach to deriving model parameter information by mining the metering data retrieved by automated meter infrastructures and stored in data stores. This approach may lead to more up-to-date and accurate models due to the fact that it is based on measurements.

Approach This multi-year research project may focus on the following tasks:

• Investigating techniques and methods for mining, analyzing, and deriving load model parameters from the extensive load data retrieved from widely deployed smart meters

• Expanding the existing component-based load model structures and parameters to store load information derived from the metered data

• Examining load characteristics and compositions by customer type—including residential, industrial, and commercial—and comparing them with existing load modeling approaches to determine a simplified load representation in existing load models.

• Capturing seasonal or annual statistics of regional load classes and compositions, and developing methods to predict changes of bus loads for adequate representation in planning base cases.

For this multi-year project, the EPRI project team may focus on the tasks outlined. Future research directions may explore the possibilities of adjusting load models more rapidly.

Impact • Help planning and operations engineers accurately determine load composition using smart meters,

which may result in accurate operating limits. • Enable operations engineers to capture dynamically changing load compositions and provide foundations

for dependable on-line dynamic security assessment. • Help system operators avoid false congestion and security alarms by providing sound operating limits

through accurate load models. • Help system planners improve modeling and standardization capabilities.

How to Apply Results • Planning engineers may utilize the seasonal load class and composition values statistically determined

through the proposed schemes to validate and revise models on an on-going basis to satisfy NERC model validation requirements.

• Operations engineers may utilize the proposed methodologies to obtain updated load compositions.

2010 Products


Determination of Load Composition using Smart Meter Data: This report will document research results in 2010. Topics may include methodologies for determining dynamically changing load classes and compositions using smart meters, as well as functional requirements to implement these methodologies.




P40.013 Development of Standard Models for Dynamic Components (069247)

Key Research Question Power system planners rely on proper power system modeling to simulate system dynamic performance when assessing the need for transmission system reinforcements and additions.

Planning and modeling tools have lagged behind recent developments in generation and transmission technologies. Some examples are the proliferation of wind generation technologies and the recent large numbers of thyristor-based and voltage-source converter-based static VAR systems, which have additional control features such as coordinated switching of existing shunt devices. Modeling issues related to renewable technologies are addressed in EPRI program 173. This program focuses on modeling issues related to conventional generation technologies and power electronic transmission devices such as FACTS.

Research must be performed to meet the growing demand for modeling capabilities as more and more power electronic devices are installed across the system. Research is needed to assess the current status of dynamic models and tools, and to develop a plan to build upon existing efforts ensuring a sustainable development of generic, non-proprietary dynamic models for planning studies related to modern devices such as FACTS.

Approach This project aims to develop an open library of generic models appropriate for the dynamic analysis of transmission and generation equipment. In addition, a key focus is providing workshops on model usage and application. With the objective to provide power engineers with generic non-proprietary models, this project has the following activities:

• Survey existing models and modeling efforts, and assess the status of these efforts in terms of the ability of the models to represent a variety of device configurations. With this assessment, the team will develop a plan for enhancing these models as a collaborative effort to produce newly needed generic models.

• Develop a generic model library, coordinated with efforts such as the WECC Modeling and Validation Working Group. This activity will engage a team of industry and vendor support, and comprises the majority of the project. It will proceed for several years, with a series of status reports in webcast form, presentations at WECC MVWG meetings (which are public meetings), and periodic workshops to report results and future plans.

• Coordinate efforts with the international standards effort of the CIM for Dynamics Working Group, with the goal of promoting model and data standardization of the generic model library.

• Develop tutorials and webcast materials to communicate not only what the power electronics library models are, but how they can be used in practice. These tutorials will, as much as possible, be developed through case study examples and lessons learned from practice.

For this multi-year project, EPRI will focus on the surveying existing models and develop the generic planning models. Coordination efforts with the CIM for Dynamics Working Group will take place in parallel, and become more concentrated in later years as new models are tested, verified, and documented.

Impact Power system operators and planners will have new capabilities to more accurately study modern and existing devices for various solutions to system dynamic performance issues, including voltage stability, transient stability, and more. Utilization of generic models with standardized data formats will reduce study preparation and enhance the ability to exchange data among different power engineers on a consistent basis. Development of these models is intended to take place within the context of existing power system simulation tools and promote their further development for new and enhanced applications. All model development is intended to be open source to facilitate their easy implementation by existing software vendors and maximize benefit to EPRI members and the industry.



In summary, this project provides value to its members through:

• Improved modeling and standardization capability • Better study of system dynamic performance and interactions • Enhanced data preparation and data exchange efforts • Promoting existing tool enhancements to allow members to utilize the full capabilities of the new dynamic

models.

How to Apply Results EPRI offers project status updates, training webcasts, and reporting exercises that cover the strengths of these generic models and how to apply them for system studies that investigate new and different solutions to operations and planning challenges. Members will develop the capabilities to utilize the new generic model library and enhancements in standard simulation tools to improve planning accuracy and handle new advanced transmission technologies in their planning studies.

2010 Products


Workshop on Modeling Modern Static Var Systems: This workshop will contain presentations of component models and how they can best be applied in practice. Case studies and lessons learned will communicate the use and value of the modeling library.


Generic Modeling of Transmission and Synchronous Generation Technologies: This report will document components of the modeling library and the presentation materials on how they can best be applied in practice. Case studies and lessons learned will communicate the value of the modeling library.


P40.014 Transmission System Model Management (069248)

Key Research Question Utilities, ISO/RTOs, and Regional Reliability Coordinators develop many power flow models, such as seasonal on-peak or off-peak base cases, based on expert knowledge in power system analysis as well as past experience. This model building should be conducted annually. However, it also requires laborious and time-consuming collaborative efforts among a group of transmission system planning engineers to collect, check, and merge extensive amounts of network model data from diverse data sources.

Utilities can easily access the model data or the status of their own system or network components from their own database and build the network model. However, building equivalent models for neighboring utilities is still challenging because there are no systematic guidelines for representing the level of detail for external networks. This often results in inadequate models, which may be a significant source of errors in network security analyses.

It is not uncommon for planning engineers to spend extra hours and effort to run unsolved cases due to erroneous data simply because no systematic engineering tool has been developed for these routine but important tasks. Therefore, it is highly desired to investigate methods for adequately representing external electric networks, develop techniques for merging network models from diverse sources, and develop an efficient transmission system model management tool.



Approach The objective of this project is to develop transmission system model management techniques and tools that will facilitate and expedite conventional model building and management practices of system planning engineers. The project may focus on the following tasks:

• Identify existing problems attributable to lack of adequate models of external networks • Develop a comprehensive set of guidelines for modeling external networks, and investigate techniques to

represent them adequately • Investigate methods for translating and merging diverse network models into to a common network model • Develop functional requirements for a model management tool, including model reduction for neighboring

networks for most common applications • Identify tools, methods, and techniques to identify model inconsistencies.

Impact This research project should improve transmission planning engineers’ work efficiency by saving time and effort for routine collection, verification, and merging of data models:

• Improve modeling and standardization capabilities • Expedite the time-consuming model building process • Manage extensive model data from diverse sources • Avoid human errors and build more accurate and credible base cases on time • Provide a platform for planners to share and communicate their ideas and expertise.

How to Apply Results The network model management tool can be incorporated into utilities' standard processes and facilitate the model building process. System planners may exploit the useful functionalities of the tool to:

• Manipulate network model data residing in the core database • Identify errors in the model parameters, visualize the network model, merge cases, and convert the

network model to be compatible with specific analytical tools. • Import, export, view, and manipulate data, as well as run embedded auxiliary application tools • Avoid erroneous model data, because the software will automatically identify and tag data anomalies • Audit the entire modeling building process.

2010 Products


Transmission System Model Management: This engineering tool will facilitate and expedite the processes of building and managing electric power network models for system planning engineers.

12/31/10 Software

Transmission System Model Management: A technical report on the functional requirements and processes of building and managing electric power network models for system planning engineers.




PS40B Reliability Assessment (067426)

Project Set Description The Reliability Assessment and Standards Project Set is designed to help system planners assess the reliability of future transmission networks, taking into account the uncertainties of generation, load, and market. Projects also help members comply with ERO standards.


P40.003 Application of Transmission Availability Statistics for Reliability Assessment

This project will catalog transmission availability data (TAD) according to event likelihood, use the TAD to build a probabilistic measure of likelihood for various categories of contingencies, and then make a forward-looking estimate of risk level using the PRA-compatible assessment of a constant risk level (in which Risk = Likelihood x Consequence).

P40.015 Balancing Economics and Reliability to Evaluate Planning Options in a Competitive Environment

This project is expected to develop a multi-objective model to consider both reliability and economics for transmission expansion planning, and then develop decision support tools to prioritize plan options. Case studies will be performed to evaluate different scenarios to demonstrate the proposed model and tools.

P40.003 Application of Transmission Availability Statistics for Reliability Assessment (062079)

Key Research Question New tools and transmission reliability assessment and planning methods are needed to help transmission planners conduct studies that comply with whatever reliability criteria are adopted. The direction of these emerging reliability standards is toward more comprehensive assessment of single and multiple contingencies with or without cascading effects, with ranges of consequences in terms of overloads, voltage violations, and load curtailments to prevent voltage collapse.

Approach • Categorize and develop a probabilistic measure of likelihood for various categories of contingencies. It

seems possible for the various contingency events in the current Tables 1 and 2 to be re-categorized into five or six groups based on "order of magnitude of likelihood." Each order of magnitude of likelihood is ten times less likely than the preceding order.

• Develop a forward-looking estimate of component outages using historical off-line measurements to estimate component outages. This approach would be consistent with Probabilistic Risk Assessment when the industry has collected enough transmission outage data to enable it to be applied to obtain rapid learning and the resulting benefits in the context of risk-based transmission reliability.

• Investigate the relationship between risk level and deterministic criteria. A number of utilities are already performing PRA studies for their transmission planning. The advantages of using PRA have been demonstrated in the nuclear power industry. It would be desirable to have a pathway for the power industry to transition from the current deterministic planning criteria in TPL-001 to probabilistic planning criteria, without waiting for another major revision to the TPL standard.

Impact • Quantify the degree of robustness of a transmission grid • Enable more comprehensive reliability assessment of transmission plans • Meet and exceed existing reliability standards



How to Apply Results The advanced reliability assessment method can be used by utilities, ISOs, and RTOs to evaluate the robustness of transmission plans and the extent to which they satisfy existing NERC reliability standards. EPRI will offer supplemental project opportunities to apply the methods and tools developed through this project to help members perform expansion planning studies and design economical, efficient, reliable, and robust transmission systems.

2010 Products


Probabilistic Measure of Likelihood for Various Categories of Contingencies: This report will categorize and develop a probabilistic measure of likelihood for various categories of contingencies.




Tools for Advanced Transmission Reliability Assessment and Planning: The software will provide tools to apply the methodology for advanced transmission reliability assessment and planning, with example case studies for illustration.

12/31/11 Software

P40.015 Balancing Economics and Reliability to Evaluate Planning Options in a Competitive Environment (069249)

Key Research Question After the electric industry was restructured in the 1990s to provide open transmission access and introduce competition into wholesale electricity markets, the reliability of the transmission grid became dependent on a combination of assets provided by independent commercial developers and regulated electric utility companies with a statutory obligation to deliver safe and adequate service to retail customers.

In a competitive environment, increasing network flexibility is desirable. One challenge is that the construction time of transmission projects is much longer than that of generation projects. Typically, new transmission projects require five to 10 years to design and build. In order to maintain the system's long-term reliability, new transmission projects must be available now or in development to meet future needs. A key question to consider is who should pay for transmission expansion. In nodal or zonal electricity markets, transmission investments are usually market driven activities. It is generally agreed that basing transmission expansion decisions on market drivers is in an incomplete strategy.

Approach A sustainable transmission expansion plan should be able to meet future transmission capacity requirements, provide return on investment, and ensure a level of reliability and quality expected by customers. This program uses the concept of integrating financial and engineering analyses. New methods and tools can evaluate uncertainties and alternatives, then compare investments for reliability and economics. These methods or tools should have this functionality:

• Economic evaluation of a proposed transmission planning project is necessary for minimizing financial risk and ensuring optimal benefits from the investment plan. Reliability evaluation of a proposed transmission planning project is necessary to improve reliability and ensure the satisfaction of customers.




Based on these two objectives, a multi-objective model will be built to consider these two factors simultaneously.

• The objective of transmission expansion is to relieve current congestion and potential transmission bottlenecks. In principle, prioritizing transmission expansion options should be based on assessing reliability level against the following formula: (Cost of Expansion - Expected Annualized Cost Savings x Duration Years).

• To identify future transmission bottlenecks, detailed analysis of market conditions to forecast power transfer requirements related to generation expansion and load growth is necessary, and scenario analysis will provide information for this purpose.

Impact • Quantify the degree of robustness of a transmission grid and build consensus on transmission

enhancements • Enable more comprehensive reliability assessments of transmission plans by evaluating economics and

reliability • Meet existing reliability standards and pursue maximum economic benefits

How to Apply Results The project concepts and tools can be used by utilities, ISOs, and RTOs to evaluate the robustness of their transmission plans and the extent to which they satisfy existing NERC reliability standards. EPRI will offer supplemental project opportunities to apply the methods and tools developed through this project to help members perform expansion planning studies and design economical, efficient, reliable, and robust transmission systems.

2010 Products


Balancing Economics and Reliability to Evaluate Planning Options under Competitive Environment: This report will document the proposed multi-objective model to consider both reliability and economics. Economic evaluation of a proposed transmission planning project is necessary to minimize financial risk and ensure the optimal benefits from the investment plan. Reliability evaluation of a proposed transmission planning project is necessary to improve transmission reliability and ensure customer satisfaction. Based on these two objectives, a multi-objective model will be built to consider these two factors simultaneously.




Decision support tools to prioritizing plan options: The objective of transmission expansion is to relieve current congestion and potential transmission bottlenecks. In principle, prioritizing transmission expansion options can be accomplished by comparing reliability level against the formula (Cost of Expansion - Expected Annualized Cost Savings x Duration Years).

12/30/11 Software


Smart Distribution Applications and Technologies - Program 124

Program Overview

Program Description New technologies will be critical to future smart grid operation. These technologies will include advanced sensors for understanding conditions in real time, power electronics technologies to improve performance and provide fast response to system changes, and new protection and switching technologies that facilitate automation. The future smart grid must integrate widespread distributed resources as part of the normal operation of the system. The distribution management system, automation systems, protection systems, planning tools, and more must all be designed to accommodate this new paradigm.

Automating the distribution system provides one of the most cost-effective ways to improve distribution reliability. It is critical to understand the benefits that can be achieved compared to alternatives, the technology required to achieve those benefits, and the overall economics. The distribution management system (DMS) will be the centerpiece of the smart distribution system in the future. Research is required to provide not only technology development and assessments in these areas, but also standards to ensure interoperability and industry deployment opportunities for smart grid technologies.

The Smart Distribution Applications and Technologies program focuses on implementing smart grid technologies at the distribution level. The program coordinates with EPRI’s Intelligrid program, in which research focuses on the communications and information infrastructure to support the smart grid. This program specifies, develops, and applies distribution technologies and applications that take advantage of the communications and information infrastructure developed in the Intelligrid program. The program provides industry coordination and technology assessments for smart distribution system technologies and applications, while also working on actual development and implementation of key technologies.

Research Value With the knowledge acquired through this research program, members will have access to resources that:

• Provide the foundation for collaborative research and technology assessments that assist members with the specification and deployment of smart distribution systems

• Coordinate with DOE, IEEE, and other industry organizations to develop and maintain the Distribution Automation Application Guidebook

• Provide technology assessments and updates on new technologies that will become an integral part of smart distribution systems

• Provide the foundation for new power electronics technologies that will integrate with the smart distribution system

• Develop and evaluate new monitoring systems and sensors that will integrate with smart distribution systems, including technologies that will automatically identify equipment and system problems

• Develop and evaluate new software and control systems to improve the performance of smart distribution systems

• Develop and evaluate approaches for integrating advanced metering system infrastructure with smart distribution system applications.

Approach EPRI research in smart distribution applications will yield a variety of data and knowledge that will be beneficial to members of the program. This information will come in a number of forms and is expected to include:

• Initial version of the Distribution Automation Application Guidebook

Smart Distribution Applications and Technologies - Program 124 p. 1


• International workshop on Advanced Distribution Automation™ (ADA™) and Distribution System of the Future

• PQA/ADA Conference and Exhibition • Updated Smart Distribution System Roadmap • Technology Watch for distribution smart grid technologies • Final plan and design for IUT field prototype • Field prototype of modular solid-state switchgear • Advanced controls and simulation methods for implementing smart grid applications (e.g., loss reduction,

equipment performance optimization, fault location) • Recommended approaches and key applications for integrating advanced metering infrastructure with

smart distribution systems • Commercialization and integration of distribution fault anticipator technology.

Accomplishments The Distribution Applications and Technologies program has delivered valuable information that has helped its members and the industry in numerous ways. Some examples include:

• An interim report titled Advanced Distribution Automation Guide Development, which describes the first stages of developing a guide intended to serve as a central tool to help members implement ADA/smart distribution systems. As the utility industry is rapidly moving to modernize its distribution systems, the smart distribution system of the future will be based on ADA, which will enable new capabilities to increase flexibility, improve reliability, and expand customer services. Smart distribution systems will use new intelligent electronic devices and will integrate advanced metering infrastructure (AMI) data into real-time monitoring systems needed to enable ADA operations.

• EPRI has proposed the concept of a solid-state transformer that has the potential and feasibility to meet the above-mentioned needs of the utility power delivery system. The ability to provide a wide range of services and improved operational benefits has put solid-state transformer technology—the Intelligent Universal Transformer™ (IUT™)—in the forefront of this endeavor. The 100-kVA Intelligent Universal Transformer Development report documents the design and development of this technology.

Current Year Activities In the coming year, this research program expects to accomplish these objectives:

• Initial version of the Distribution Automation Guidebook • International Workshop on ADA and Distribution System of the Future • PQA/ADA Conference and Exhibition • Updated Smart Distribution System Roadmap • Technology Watch for distribution smart grid technologies • Final plan and design for IUT field prototype • Field prototype of modular solid-state switchgear • Advanced controls and simulation methods for implementing smart grid applications (e.g., loss reduction,

equipment performance optimization, fault location) • Recommended approaches and key applications for integrating advanced metering infrastructure with

smart distribution systems • Commercialization and integration of distribution fault anticipator technology.


Program Manager Matthew Olearczyk, 704-595-2257, [email protected]



Summary of Projects

PS124A Technology Transfer, Technology Watch, and Industry Coordination (058488)

Project Set Description This Project Set will provide information and technology transfer products to the industry to help members understand the state of the art in automating distribution systems. The project set sponsors the PQA/ADA conference, international workshops, technology watch, and development of the industry application guide for distribution automation in cooperation with the IEEE Distribution Automation Working Group.


P124.001 Technology Transfer, Technology Watch, and Industry Coordination

This project is the main technology transfer effort for the Smart Distribution Applications and Technologies program. Products include conferences, workshops, technology assessments, and ongoing guidebook development. This project also maintains the Smart Distribution R&D Roadmap that provides guidance for the entire program.

P124.001 Technology Transfer, Technology Watch, and Industry Coordination (067459)

Key Research Question The utility industry is rapidly moving to modernize distribution systems, including wider use of advanced distribution automation (ADA) systems. There is a need to coordinate both domestic and international research activities to efficiently develop technologies, software, standards, and other capabilities for the smart distribution system of the future. There is also a need to incorporate the best practices emerging from the utility and vendor communities into engineering tools to facilitate high-quality automation practices with uniform procedures and standardization wherever possible.

Utilities need to assess relevant new technologies, software, and services emerging from the research and vendor communities to better understand the value of these products and how they can be most effectively used in advancing future system development and operations. There is also a need to evaluate performance through actual field application experience with emerging capabilities. This can be done by coordinating assessments and lessons learned across the many deployments and trial projects going on throughout the world.

Approach This project will develop and maintain a Distribution Automation Application Guidebook that can serve as a central tool to help utilities implement advanced distribution automation systems based on the latest technologies, research, and application experience. This industry guidebook will be a living document that will be available in both electronic form and periodically published versions. The online version will be delivered as a web-based product. Cooperation with the IEEE Distribution Automation Working Group will facilitate industry-wide participation in the guidebook's development.

This project supports annual activities to capture knowledge broadly from the industry and disseminate it. The information will be used to support strategic planning and coordinate the collaboration between domestic and international programs wherever possible. EPRI will continue to convene an Annual International Workshop on ADA and the Distribution System of the Future. The workshop provides a roundtable forum for reviewing the status of key international programs and developing plans for ongoing coordination and collaboration among the programs. This workshop also provides the basis for an annual update to the roadmap for smart distribution system development. EPRI will also continue to conduct the annual joint PQA/ADA Conference with international participation. The large open conference, which is jointly sponsored by Programs 1 and 124,



includes papers and tutorials on a broad range of topics pertaining to power quality, ADA, and the distribution system of the future. Conference proceedings are documented on a compact disc.

EPRI will assess key technology and software products as well as advanced distribution automation system approaches. Technologies to be assessed will include automated reconfiguration systems, technologies for advanced voltage and VAR control, new power electronics, technologies for integration with automated distribution systems, advanced distribution sensors and monitoring technologies (including integrating advanced metering systems with distribution automation), and advanced simulation technologies for distribution management, including real-time state estimation. Monthly web-based technology updates will be issued on important industry developments. The monthly updates will be combined into an annual report on automation technologies.

Impact • Coordinates the development and maintenance of an industry guidebook on smart distribution

applications and technologies • Helps utilities apply new technologies more effectively by understanding important application issues,

technology limitations, and functionality • Provides an educational resource for utility personnel involved in automating distribution systems • Helps coordinate industry developments in distribution automation to ensure interoperability and

successful integration with utility systems • Helps members choose from among the technology, software, and system-level options for smart

distribution systems • Coordinates and disseminates information on worldwide activities in smart distribution systems

How to Apply Results Electric distribution managers, engineers, information technology specialists, and planners will use the project results to help develop smart distribution systems with improved reliability, improved power quality, better efficiency, and increased customer services. Implementation of project results will improve technology selection and application, and will help ensure interoperability of technologies with utility systems. Project results will be used as educational resources, technology guides to support specification development, and tools for assessing technology options.

2010 Products


Update to Smart Distribution Application Guide : The Smart Distribution Application Guide is developed as a web-based guidebook in cooperation with the IEEE Distribution Automation Working Group. Important new additions to the guidebook will be summarized as an EPRI update report.


PQA/ADA Conference: The PQA/ADA Conference provides a forum for new technology and application descriptions and presentations, including exhibits. The conference is sponsored jointly with the Power Quality Program (Program 1).


International Workshop on Smart Distribution Systems: The International Workshop on Smart Distribution Systems will continue the annual coordination of research activities around the world on distribution automation and related technologies. The workshop provides the basis for updating the Smart Distribution Development Roadmap.


Technology Watch Updates: Smart Distribution Technology Watch updates will be developed monthly as web-based reports and then combined into an EPRI technical update report at the end of the year.




PS124B New Technologies for Smart Distribution Systems (058489)

Project Set Description This Project Set develops and evaluates new technologies for smart distribution systems that could become an integral part of the future distribution infrastructure. There are two ongoing projects in the power electronics area: the Intelligent Universal Transformer (IUT) and the Multifunction Solid-state Switchgear System (4-S). These two projects are complemented by two others related to improving monitoring technologies for integration with distribution automation and control: sensors for real-time distribution system monitoring, and advanced meter application issues and testing. Together, these projects support a cross-section of important technology developments in the industry.


P124.002 Multifunction Solid-State Switchgear System (4-S)

This project develops a first-generation modular power-electronic replacement for conventional distribution switchgear that can be widely used in distribution switchgear applications.

P124.003 Intelligent Universal Transformer

The project develops the first-generation power-electronic replacement for conventional distribution transformers.

P124.004 Sensors and Technologies for Distribution Asset Management and Equipment Diagnostics

This project will evaluate sensor technologies for current and voltage monitoring as well as equipment diagnostics and asset management.

P124.005 Advanced Meter Application Issues and Testing

This project will use a combination of laboratory and field testing to develop lifetime characteristics of advanced metering applications and equipment.

P124.002 Multifunction Solid-State Switchgear System (4-S) (060481)

Key Research Question Major issues addressed by the 4-S product include switching without the need for sulfur hexafluoride (SF6) or another interrupting medium, faster switching to provide more options for fault clearing and system reconfiguration, switching transient control (e.g., capacitor banks), and fault current limiting. The 4-S also provides a monitoring node capability for integration with ADA monitoring systems. The 4-S can reduce costly inventory expenses associated with the variety of switchgear products currently needed for distribution systems. In addition, it is more parts-wise repairable than conventional switchgear, which will enable more instances of repair over total replacement of failed units, with attendant cost savings.

Approach The EPRI Multifunction Solid-state Switchgear System is a first-generation power-electronic replacement for conventional distribution switchgear. The goal of EPRI’s 4-S project is to develop a first-generation modular power-electronic replacement for conventional distribution switchgear that can be widely used in distribution switchgear applications.

Project work in 2009 will continue the 2008 development of an S-GTO-based 4.16-kV transfer switch. EPRI contracted Silicon Power Corp. (SPCO) to define the project plan for development, testing, and supply of a prototype 15-kV class S-GTO-based static transfer switch (SSTS). In 2008, SPCO was contracted to build and test the prototype 4.16-kV SSTS and demonstrate key performance and benefits over a thyristor-based static transfer switch. In 2009, SPCO will work with EPRI to select a host utility for testing the field prototype. EPRI will develop a plan to test and evaluate the SSTS in pre-commercial field prototype form and to identify and resolve flaws or user problems prior to developing a specification for a first-generation commercial



product. SPCO will test, evaluate, and debug the field prototype at the host site. In 2008 and 2009, this project will develop and test two key 4-S functions:

• The Fast Transfer Switch, which facilitates rapid load transfer in utility-scale applications • The Sensor and Communication System, which acts as a monitoring node in the smart distribution

system.

Impact • Advanced modular designs for a solid-state switch can provide many functions for the smart distribution

system. • Advanced switchgear designs can be the basis of transient-free switching for automation applications like

circuit reconfiguration, load transfers, capacitor switching, and fault current limiting. • Prototype designs will illustrate the benefits of the technology and provide the foundation for a field

demonstration to assess performance. • Designs will also incorporate monitoring and communications that facilitate integration with smart

distribution systems.

How to Apply Results • Members will gain an understanding of new power electronics technology that may be the basis for many

switchgear applications as part of a smart distribution system. • Members will be able to use the results to develop designs for future smart distribution systems

incorporating new switching functionality. • Members will evaluate the prototype design to help understand the economics and application issues for

future system designs.

2010 Products


Final Report on Multifunction 4-S Development, First-Generation Product Specification, and Commercialization Plan: This report will document the prototype switch design, development, and testing. Conclusions and recommendations for applications and ongoing development needs will be included.


P124.003 Intelligent Universal Transformer (051716)

Key Research Question Conventional transformer costs and lead times are rising sharply. Conventional transformers suffer from poor energy conversion efficiency at partial loads, use liquid dielectrics that can result in costly spill cleanups, and provide only one function: stepping voltage. These transformers do not provide real-time voltage regulation, do not offer monitoring capabilities, and do not incorporate a communication link for use as distribution system monitoring nodes as part of a smart distribution system. At the same time, these transformers require costly spare inventories for multiple unit ratings, do not allow supply of three-phase power from a single-phase circuit, and are not parts-wise repairable. Future distribution transformers are also going to need to be an interface point for distributed resources (storage, plug-in hybrid electric vehicles, photovoltaics, and other distributed generation). A power-electronic system replacement for conventional transformers would resolve these issues.



Approach The Intelligent Universal Transformer is a first-generation power-electronic replacement for conventional distribution transformers. In 2007, a contractor was selected to develop the IUT and subsequently commercialize it. In this project, the team develops and tests field prototypes, working in conjunction with host utilities. Related business-case and utility-integration studies support IUT development work. Knowledge gained from prototype testing and debugging is used to prepare a specification for a first-generation commercially releasable product. Specific optional functions chosen for inclusion in the first-generation product are based on member priorities up to the limit of available funding. The project will also develop a commercialization plan and assess optional technologies for the IUT based on ongoing industry developments, market evaluations, and cost/benefit assessments.

Based on high-voltage semiconductor device availability, a 4.16-kV, 20-kVA IUT was identified as the first development target that would lead to a hardware bench model demonstration. In 2005, a laboratory bench model was designed and tested to establish proof of concept for a suitable high-voltage power electronic circuit topology for the IUT. The bench model was rated at 20 kVA with the input voltage rated at 2.4 kVRMS phase-to-neutral and output voltage rated at 120/240 V. The project team then decided to proceed with the next phase of developing field prototypes from OEMs interested in the IUT.

In 2007, a request for information (RFI) was issued to seek proposals to develop the 100-kVA 15-kV-class IUT as a field prototype and test it in a wide range of climatic zones. EPRI and its advisors reviewed the proposals, and Silicon Power Corporation (partnered with SatCon Technology Corp. and Howard Industries) was selected to develop the field prototype. Development started in 2008 and will be continued in 2009, when the unit will be factory tested and then tested at a host utility site. During the initial phase of this prototype development effort, it was decided that, at a minimum, the prototype design should meet the basic functionality of a conventional distribution transformer in terms of its capability for voltage transformation, and provide operational benefits in terms of standardizing the distribution transformer with respect to input/output voltage and kVA rating. Additionally, the minimum design will include a communication interface to allow remote monitoring and control of the IUT to detect component failures and allow dispatch of IUT functions. It is also expected that the IUT will be functionally capable of real-time voltage regulation at little additional cost relative to the basic voltage transformation function. Development of the smart transformer to interface with solar and energy storage devices will not be covered through this initial effort.

Impact • Provides an alternative technology (an advanced power-electronic system) for voltage transformation in

distribution systems at a time when conventional transformer costs and lead times are increasing rapidly • Eliminates the liquid dielectrics of conventional transformers and the associated costly spill cleanups • Provides a communication link and monitoring capability in the IUT to diagnose problems in the IUT • Supports parts-wise repair, enables distribution system monitoring, and supports advanced automation

and more efficient operations • Can improve energy efficiency of distribution operations because the IUT is more efficient than

conventional transformers at partial loads and because the added functionality improves efficiency in distribution system operations

• Reduces spare inventory costs associated with warehousing many types of conventional distribution transformers, due to the IUT’s modularity

• Reduces unit weight and size compared to conventional transformers • Offers added functionality, such as voltage regulation and distribution system monitoring capabilities,

compared to conventional transformers

How to Apply Results Electric distribution managers, engineers, and designers could use the IUT as a replacement for conventional distribution transformers, both in new installations and to replace aging units. Members can apply the IUT in situations where avoidance of spill cleanups from conventional transformers is most crucial, and then expand to wider usage over time. Distribution system managers can inventory modules of IUT systems that can be



configured for several rating levels and replace larger inventory requirements of many conventional transformers at different rating levels. Distribution system designers, information technology specialists, and operators can use IUTs as distribution system monitoring nodes to support system operations and advanced automation, and use optional functions (to be prioritized for inclusion in the IUT product by members) such as voltage regulation, configurations to supply three-phase power from a single-phase circuit, output ports for dc power and alternative ac frequencies, and interfaces with distributed generation.

2010 Products


Final Report on IUT Development, First-Generation Product Specification, and Commercialization Plan: This product provides the final documentation for this project.


P124.004 Sensors and Technologies for Distribution Asset Management and Equipment Diagnostics (067460)

Key Research Question The smart distribution system is built around a variety of sensors for both real-time applications and equipment diagnostics. These sensors must have reduced costs to allow widespread deployment, and they must incorporate communications that will allow integration with the smart distribution system infrastructure.

• Existing PTs and CTs are expensive and lack integrated communications. • Equipment diagnostics and asset management applications require a variety of new sensors to assess

asset health continually and report on important characteristics.

Approach This project builds on preliminary work being conducted though a Technology Innovation initiative to characterize a variety of sensor technologies that could become part of the smart distribution system in both overhead and underground applications. The project focuses on actual field assessments of new sensor and transducer technologies with integrated communications. The project will demonstrate the technologies, application issues, and integration with distribution management systems.

In addition, the project will demonstrate advanced current and voltage monitoring technologies with integrated communications. Issues to be evaluated include transducer accuracy, frequency response characteristics, interface issues, and communications functionality.

The project will also evaluate new sensor technologies for equipment diagnostics and asset management. This effort will include technologies such as temperature and other sensors for both overhead and underground applications.

Impact • Understanding of, and performance assessments for, new sensor technologies that can be part of smart

distribution systems • Development of application guidelines for new sensor technologies • Ability to integrate new sensor technologies with overall distribution management systems

How to Apply Results • Members will gain an understanding of new sensor technologies so that they can be included in new

smart distribution system designs.



• Members will understand the benefits and limitations of important new sensor technologies, and will receive application guidelines from actual field experiences.

• New sensor technologies must be integrated with overall distribution management systems, and can provide the basis for new real-time system performance optimization. Members will get a head start on developing and implementing these advanced applications through documentation of sensor functionality, accuracy, and applications.

2010 Products


Report of Advanced Sensor Technology Applications for Smart Distribution Systems: The report will continue to document important sensor technologies and their application as part of smart distribution systems.


P124.005 Advanced Meter Application Issues and Testing (067461)

Key Research Question Many utilities are in the process of evaluating and deploying advanced metering technologies. These technologies will become part of the smart distribution system of the future. However, there is little experience with the actual performance of these new meter technologies in field applications. There is a need to understand important field application issues, environmental performance characteristics, and the technology's ability to withstand voltage and current variations.

Approach This project focuses on evaluating application issues for advanced meters that will become part of the smart distribution system. It will use a combination of laboratory testing and actual field performance assessments to develop conclusions about advanced meter application issues and lifetime characteristics. This research has a number of important parts:

• Environmental testing in the laboratory. This project will use accelerated lifetime tests to understand the ability of advanced meters to withstand long-term environmental conditions.

• Voltage and current testing in the laboratory. This includes testing both the communications interfaces for the meters as well as voltage and current monitoring performance under adverse conditions.

• Characterization of the effect of harmonics and power factor on meter accuracy. Future meters may need to characterize customer impacts on harmonic distortion and power factor. This feature will require the ability to characterize customer load and generation accurately for both fundamental and harmonic conditions. Laboratory testing will characterize meter performance for non-sinusoidal conditions and for characterizing load power factor.

• Evaluation of important field application issues and performance through experience of initial advanced metering deployments. The project will work with members deploying advanced meters to identify lessons learned and important application issues associated with the meters.

• Advanced meters will need to continue to operate during power outages, to provide functionality for smart distribution systems (e.g., integration with outage management systems). The project will evaluate battery performance and meter performance during and following outages.

Impact • Understand application issues for advanced meters as they are integrated with smart distribution

systems. • Understand the expected lifetime for advanced meters for planning and budgeting of maintenance and

replacement plans.



• Understand the performance of advanced meters during transients and for characterizing harmonics and power factor. These could be important functions in the smart distribution system.

• Understand the impact of integrated communications with advanced meters on application issues (such as lifetime, maintenance requirements, and installation issues)

How to Apply Results • Members will be able to develop more accurate budgets and plans for advanced meter deployments. • Members will be able to develop better plans for integrating advanced meters with smart distribution

systems by understanding important application issues and meter limitations.

2010 Products


Testing and Performance Assessments for Advanced Meters: Continued updates to testing and field application assessments for advanced meters. 12/31/10 Technical

Update

PS124C New Applications for Smart Distribution Systems (062126)

Project Set Description This Project Set develops and evaluates emerging circuit, control, protection, and monitoring system capabilities for smart distribution systems. The Distribution Management System (DMS) of the future will need to integrate many functions to optimize system performance, reduce losses, optimize voltage and VAR control, and improve reliability through system reconfiguration and fast restoration. The DMS of the future must also enable integration of distributed resources with the normal operation of the distribution system. These applications will require new simulation functionality, as well as new monitoring and control systems.

The advantages and disadvantages of various options are evaluated in this Project Set, and actual field experience is documented. Specifications will be provided for integrating new functions into smart distribution systems. Projects will also evaluate specific distribution management applications that can take advantage of advanced metering systems. The resulting requirements for advanced metering systems will be documented, as will the integration requirements.


P124.006 New Methods for Active Distribution System Management

The project report in 2010 will focus on advanced distribution reconfiguration functions that take advantage of real-time state estimation, adaptive protection functions, control of smart switches and reclosers throughout the distribution system, and management of system loading. The functions may also incorporate demand response and load control to maximize system reliability.

P124.007 Distribution Applications Using Existing Information and Communications Infrastructures such as AMI

This project will involve working with members to characterize distribution communication infrastructure and advanced metering deployment opportunities, and how these systems can be integrated with distribution operations. Previous use cases will be reviewed and refined to characterize important applications, and requirements for the AMI and communication infrastructure will be derived. This work is expected to produce improved application guidelines for AMI and distribution communications to help obtain maximum functionality for distribution systems.



P124.006 New Methods for Active Distribution System Management (067462)

Key Research Question Smart distribution systems will incorporate a variety of new control and system optimization functions, as well as the ability to integrate a wide variety of distributed resources. These functions will take advantage of advanced sensors, system communication infrastructure, new switchgear technologies, and new modeling and simulation capabilities. Such functions need to be characterized and evaluated to determine the requirements for the DMSs of the future, which will include sensors, control technologies, modeling requirements, simulation tools, and communication infrastructure. Performance issues also need to be evaluated as these functions move to real-time applications.

Approach This project will characterize important functions and applications for smart distribution systems and develop guidelines for their implementation. These functions will include:

• Voltage and VAR control functions to optimize distribution system voltage and VAR flows (minimize losses). Controls can take advantage of distributed sensors and advanced metering to control capacitors and regulators throughout the system.

• Fault characterization and location through improved monitoring, fault indicators, and integration with system models.

• Automatic system reconfiguration to optimize the response to system faults, including adaptive protection systems and load management.

• Integration of demand response and distributed resources to optimize system performance. • Applications to minimize risk of outages based on loading profiles, system characteristics, weather

conditions, lightning, and other factors. • Applications for equipment and system diagnostics through integration of technologies like the

Distribution Fault Anticipator (DFA) and widespread sensors. The project will continue to develop advanced modeling and simulation tools that can be used to implement these advanced functions. The Distribution System Simulator (OpenDSS) software has been released as an open source platform to facilitate development of advanced functionality around the world. This platform is being developed through this research project in combination with efforts in the Green Circuits initiative and Smart Grid Demonstration projects. Functions demonstrated using the OpenDSS can then easily be implemented in commercial DMS platforms.

Impact • Advanced applications for smart distribution systems are where the real value of the technology

investment is realized. Members will understand the functionality of these advanced applications and how to implement them.

• Guidelines for optimizing system steady-state performance will be developed, including modeling, simulation, sensors, communications infrastructure, and integration.

• Guidelines for functions that improve the reliability of the distribution system—such as fault location, system reconfiguration, and adaptive protection systems—will be developed.

• Guidelines for functions that improve equipment and system diagnostics for improved asset management will be developed, including sensor requirements, modeling and simulation requirements, communications and data management, and implementation issues.

• Release of the Distribution System Simulator (OpenDSS) for open source development is enhancing development of advanced applications; this research program will coordinate those developments from around the world. Efforts will also be coordinated with industry developments such as DOE's GridLab-D.



How to Apply Results • Members will be able to better plan investments in smart distribution applications through an

understanding of application requirements and performance under different circumstances. • Members will be able to use the OpenDSS software as a platform for evaluating advanced applications

for their own distribution systems. Example applications will provide templates for these evaluations. • Members will be able to assess the economics and benefits of different applications as a function of their

implementation costs.

2010 Products


Evaluation of distribution reconfiguration functions in Advanced Distribution Management Systems: The project report in 2010 will focus on advanced distribution reconfiguration functions that take advantage of real-time state estimation, adaptive protection functions, control of smart switches and reclosers throughout the distribution system, and management of system loading. The functions may also incorporate demand response and load control to maximize system reliability.


P124.007 Distribution Applications Using Existing Information and Communications Infrastructures such as AMI (067463)

Key Research Question Utilities are deploying communication infrastructures and advanced metering systems for a variety of reasons, including reducing manpower costs for meter reading, and allowing remote disconnection and connection of customers. These infrastructures can provide important operational benefits for the distribution system but there are integration requirements for achieve these benefits. This project focuses on distribution management and operations applications that can utilize investments in advanced metering and the associated communication infrastructure.

Approach This project characterizes and evaluates important applications that can take advantage of advanced metering technologies, communications, and infrastructure. Important applications that will be evaluated and characterized in this project include:

• Improving the performance of outage management systems by integrating information from advanced meters

• Improving system voltage and VAR control using information from advanced meters • Improving fault location functionality using advanced metering infrastructure • Using advanced metering to improve load models and build better system simulation systems to take

advantage of advanced load models • Developing more accurate planning models and tools that take advantage of advanced metering data • Incorporating advanced metering as part of real-time state estimation systems for optimizing system

performance. These applications will be examined through detailed-use case development, and the requirements for advanced metering and communication systems to implement these functions will be characterized. As utilities deploy advanced metering systems, opportunities for deploying these functions will be identified and actual performance will also be characterized.




Impact • Members will understand the additional operational benefits that can be derived from advanced metering

infrastructure investments through detailed characterization of important applications and their associated requirements.

• Business cases for advanced metering that rely on distribution operations benefits as part of the plan will be more accurate.

• Members can develop accurate implementation and deployment plans for distribution operations functions that are built on AMI investments.

How to Apply Results • Members will use project results to develop more accurate AMI business plans and deployment plans. • Members will develop plans for future smart distribution systems that incorporate functions for improving

performance that are built on investments in advanced metering and the associated communications infrastructure.

• Members will understand the capabilities of advanced distribution performance optimization functions that take advantage of advanced metering.

2010 Products


Field Experience with Implementing Distribution Performance Optimization Functions that Integrate with Advanced Metering: This report will document actual field experience with deploying advanced distribution management functions that integrate with advanced metering systems. Application issues, performance, limitations, and needs for ongoing development will be identified.



Energy Storage - Program 94

Program Overview

Program Description The program implements a vision that energy storage systems may be essential when managing large quantities of variable renewable generation as well as peak loads. The program provides the industry with technical and economic information about the options to store energy as a means to manage variability and peak loads while enhancing grid reliability. By enabling wind integration, energy storage can help utilities reduce greenhouse gas (GHG) emissions. Distributed storage systems can create value to utility business operations by improving management of peak loads and mitigating outages, which can improve relationships with end use customers. The program provides valuable information from objective technology assessments, lab tests, field demonstrations, and case studies. The technologies that may be covered include large-scale, bulk storage options such as pumped hydro, nonfuel, adiabatic compressed air storage as well as many types of battery storage technologies such as sodium-sulfur (NaS), lithium-ion (Li-ion), zinc-air (Zn-Ar), zinc-bromine (ZnBr), and other emerging flow battery systems. While the main focus is on electric energy storage, the program also monitors and assess emerging distributed generation technologies based on member needs. The program is an integral part of related research in EPRI's IntelliGrid, Smart Distribution Applications, Electric Transportation, and Renewable Resources Integration programs.


• Objective, unbiased information can help support strategic and corporate planning, renewable portfolio standards, and regulatory inquiries in the area of energy storage and distributed resources.

• Technical characteristics and costs of nonfuel compressed air cycles can aid in planning for increasing and improving wind integration.

• Information to support deployment and planning decisions for electric storage options may help meet needs for grid support and peak management.

• Industry white papers help inform regulators and policy makers on the value and applications of energy storage within the electric grid.

• Members gain best practices for using energy storage for grid asset management, reliability, end-user energy management, and meeting utility renewable and other “green” initiatives.

Approach EPRI research in energy storage will yield a variety of information and knowledge that will be beneficial to members of the program. This information will come in a number of formats and is expected to include:

• Strategic intelligence reports and specific technology assessments of energy storage and emerging distributed energy resource options

• Industry white papers to inform stakeholders on the role and value of energy storage • Nieghborhood energy storage systems for end-user peak load management and outage mitigation • On-line database for all energy storage and distributed energy resource (DER) options • Best practices and specifications of transportable energy storage systems for grid asset management

applications • Case studies and testing of emerging energy storage systems

Energy Storage - Program 94 p. 1


Accomplishments In the past, the energy storage program has delivered valuable information that has helped its members and the industry in numerous ways. Some examples include:

• Quarterly strategic intelligence reports and trends to anticipate and plan new deployments of energy storage

• In-depth technology assessments of Li-ion, and other advanced battery systems • Quantification of the markets and value of energy storage systems along the entire electric utility

value chain • Identification of novel bulk energy storage cycles: e.g., second-generation compressed air systems

and nonfuel compressed air systems • Best practice guidelines for using NaS energy storage for grid support • Benchmarking the costs and GHG emissions of distributed generation options • Updated cost and performance of second-generation compressed air storage systems

Current Year Activities In the coming year, this research program expects to accomplish these objectives:

• Strategic intelligence reports on trends in the energy storage and distributed generation • Updated market, value, and gap analysis of energy storage systems for utility applications • In-depth technology assessments of Zn-Air and advanced lead acid batteries • Definition and specification of neighborhood energy storage systems and technology options • Specification of transportable energy storage systems and options for grid support • Online database updates on energy storage systems in www.disgen.epri.com • Regional case study of a compressed air storage system to assess value and GHG impacts under wind

penetration scenarios • Conceptual design and definition of nonfuel, advanced compressed air energy storage systems


Program Manager Daniel Rastler, 650-855-2521, [email protected]



Summary of Projects


P94.001 Strategic Intelligence, Technology Assessments and Green House Gas Analysis of Energy Storage and Distributed Generation

This project provides analysis and strategic planning information on energy storage and distributed energy resource systems through an online technology assessment database, annual technology assessments, and strategic intelligence reports. Analysis is undertaken to understand the cost, benefits, markets, and impacts of energy storage systems. Specific technology evaluations and assessments are prioritized by members. Industry white papers are prepared to inform stakeholders.

P94.002 Energy Storage and Distributed Generation Options for Grid Support and Reliability

This project area provides specific solutions, information, and guidelines for using distributed energy storage and distributed generation systems for grid support and peak management. To achieve this, the project conducts analyses, performs lab testing and field demonstrations, and prepares informative case studies of current and emerging energy storage systems. Technical results include empirical data on performance, lessons learned, risks, and costs of these systems for use in a utility environment. This project also translates laboratory tests and field demonstration lessons learned into best practices and guidelines for use by grid asset management managers, distribution planners, and energy managers.

P94.003 Bulk Power Energy Storage Solutions

This project area provides information and specific solutions based on non-fuel based compressed air energy storage (A-CAES) systems pumped hydro, and emerging large flow battery systems to improve the value of large-scale variable renewable generation This area also address energy storage based solutions from the ISO / RTO perspective in providing ancillary services.

P94.001 Strategic Intelligence, Technology Assessments and Green House Gas Analysis of Energy Storage and Distributed Generation (051547)

Key Research Question Utilities need strategic and objective information on current and emerging energy storage and distributed energy resource technologies that could have an impact on utility operations and may reduce carbon emissions.

This information includes technical characteristics, performance and cost information, as well as trends of energy storage and distributed generation options. Analysis is needed to improve the understanding and assess the costs/benefits of a distributed portfolio in a smart grid, including the associated GHG emission impacts of distributed generation and energy storage.

Approach This project provides analysis and strategic planning information on distributed energy resources (distributed generation and energy storage systems) through: an online technology assessment database; real-time web energy intelligence service; annual in-depth technology assessments; and strategic intelligence reports. Analysis is undertaken to understand the operational value, the costs and benefits, and impacts of energy storage systems. Specific technology evaluations and assessments are prioritized by members; technologies include novel distributed and bulk energy storage technology as well as novel flow battery systems.

Technology assessments of emerging energy storage systems will be performed, including zinc-bromine, new lithium–ion battery chemistries, fuel cells, and advanced ultra-capacitors. In addition, analysis will be



conducted to assess the value proposition of energy storage and distributed generation (DG) systems in current and future Smart Grid configurations. Also, databases will be developed that maintain the latest cost, performance, trends, and GHG footprint of distributed generation and energy storage systems.

This project tracks and benchmarks all distributed generation and energy storage technologies. It also monitors the status and development of all small to large energy storage options for transmission, generation, distribution, frequency regulation, and end-use peak load-shifting applications. Information on the value, role, and key markets for energy storage may also be transferred to external stakeholders via industry white papers, conferences, and collaboration with trade groups such as the Electricity Storage Association.

Impact Participants in this project could be affected in a number of ways including:

• Having access to timely information on the trends and developments in energy storage and distributed generation.

• Acquiring strategic intelligence on emerging technology that can affect utility business operations. • Gaining insight into carbon reduction impacts of energy storage and distributed generation systems. • Receiving objective information to support strategic corporate planning and answer regulatory inquiries. • Having access to analysis and an online database, and assessments to support corporate strategy and

decisions to invest in distributed generation and energy storage initiatives. • Learning about the quantification of the value of a distributed resource portfolio to utility business

operations. • Getting information to support win-win policies for deployment of energy storage systems.

How to Apply Results • Research findings will be used by corporate and resource planners as part of their strategic planning

function and will help them anticipate technology trends and apply solutions to business issues. Distribution system designers of “smart grids” may incorporate research findings and results into future grid expansion assessments. Results could also be used by regulatory policy and regulatory affairs managers to develop responses to state public commission inquiries related to distributed generation and energy storage costs/benefits and market integration; or inquires related to greenhouse gas emissions and impacts of decentralized generation. Corporate strategic planners may use results to: respond to senior management inquiries;

• evaluate the technology and investment risks of distributed generation and energy storage initiatives; • inform senior management on technologies that could affect or improve business operations; and • use EPRI research findings to inform policy makers.

2010 Products


Industry White Papers and Technical Briefs: This project will prepare one to three publically available industry white papers or industry technical briefs to better communicate the role and value of electric energy storage systems to the electric enterprise. Topics and key messages will be prioritized by members, but could include: Wind and Energy Storage Integration; Energy Storage in the Smart Grid; Neighborhood Energy Storage Systems and their Value; and Leveraging Energy Storage Technology being developed for Transportation Applications.

12/20/10 Peer Literature





Annual Technology Assessments: The program will conduct one or two in-depth energy storage technology assessments, with benchmarking and analysis based on staff recommendations and funder priorities. In 2009, updates were competed on advanced lead acid batteries, flow batteries, and Zn-Air batteries. In 2010, options may include supercapacitors using advanced materials, superconducting magnetic energy storage (SMES) using yttrium barium copper oxide (YBCO) wire; or novel bulk storage systems such as electrochemical production of methanol from renewable energy. Also, based on member needs, the project will conduct technology updates on emerging distributed generation systems.


Energy Storage Application Guide and On-line Data Base: This product provides members with a one-stop resource for objective EPRI information on the cost, performance, application, and integration of distributed generation and energy storage systems. It is the program's technology assessment guide, providing summary-level data on technology availability, costs, risks, GHG emission impacts, case studies, and applications. It also includes EPRI's Energy Voyager technology watch tool.


Strategic Intelligence Reports: Strategic intelligence reports provide objective information on current and emerging distributed generation and energy storage technologies that could affect or support utility business operations and reduce carbon emissions. Up to six reports are produced with a feature story and summaries of the latest information on the cost, performance, and trends of distributed generation and energy storage options that are available from credible sources in the literature.


High value stationary applications for primary and secondary use of PHEV batteries. : This project will examine and identify several high-value stationary market applications for Plug-in Hybrid Electric Vehicle (PHEV) batteries. The goal is to identify a large stationary market opportunity to increase the production volume and lower the cost of PHEV type batteries. Also as PHEV batteries may outlive the vehicle, research will be conducted to identify the most promising secondary-use applications and develop a utility roadmap and application plan for the realization of this opportunity.


P94.002 Energy Storage and Distributed Generation Options for Grid Support and Reliability (065556)

Key Research Question Aging grid infrastructure, the inability to install new lines, and requirements for higher reliability are prompting many utilities to consider energy storage and distributed generation options for capital deferral, grid support, distribution planning, and end-user energy management. The program’s portfolio of energy storage and distributed generation systems could be key essential assets in future smart grid configurations. To deploy and effectively utilize these assets in grid configurations, utilities need empirical information on costs, performance, operations characteristics, reliability, risks, and durability. Research is required to better understand the cost, performance and reliability of these options and how current and future grids can accommodate the use of distributed generation and energy storage assets.

Approach This project area provides specific solutions, information, and guidelines for using energy storage and distributed generation systems for grid asset management and end-user load shifting—including applications for urban load pockets, radial feeders and substations, distribution networks, and communities. It also provides assessments of potential solutions for meeting end-user energy management needs in the areas of


load management and peak load shifting. To achieve this, the project conducts analyses and defines application requirements and specifications. It performs laboratory testing and field demonstrations, and prepares case studies of current and emerging distributed generation and energy storage systems. Technical results include empirical data on performance, lessons learned, risks, and costs of these systems for use in a utility environment. This project also translates laboratory tests and field demonstration lessons learned into best practices and guidelines for use by grid asset management managers, distribution planners, and energy managers. The overall goal of this project area is to advance applications for energy storage to support the grid and provide key information necessary to enable utilities to effectively integrate distributed systems that enhance grid management and reliability by 2012 in various smart grid configurations. In that regard, EPRI’s program will seek to engage, leverage, and help transfer energy storage demonstration data and information anticipated to be forthcoming from energy storage demonstration projects to be funded by the industry via the DOE Energy Storage Stimulus Funding Opportunity- Smart Grid Demonstration Recovery Act.

Impact Participants may be affected in a number of ways including:

• Obtaining demonstrated capability to use distributed energy storage for grid support • Procuring, installing, operating, or contracting for energy storage systems in a safe and reliable manner

by employing guidelines and best practices • Gaining risk assessment information—based on validated test data—on the performance, costs, and

operation of energy storage and selective emerging distributed energy resource options • Incorporating the optimal use of distributed energy storage solutions into T&D planning activities • Understanding the options for deferring T&D capital investments by applying storage solutions for peak

management • Making more informed purchase and deployment decisions of energy storage systems • Gaining information to support investor relations on green initiatives and corporate strategic planning

How to Apply Results Research findings may be used by distribution planners for grid operational solutions and by engineers and planners when developing a “smart grid” implementation. Distribution system designers of “smart grids” can incorporate research findings and results into future grid expansion plans. Results from case studies and evaluations can be used to assess the risks and value to utility business operations. Results can also be used to develop new energy management and demand response solutions for end-use customers.

2010 Products


Best Practices Guidelines for Transportable Storage Systems: The goal of this project is to advance the best practice use of transportable energy storage systems for grid support. The project will provide an update on the lessons learned from field trials of several 0.5 MW / 2 MWh ZnBr transportable energy storage systems, which were deployed in 2009. A best practices guideline will be prepared, which covers procurement, siting, permitting, integration, and operational considerations and use case(s) of such transportable energy storage systems.


Case Studies of Energy Storage in Grid Support Applications: NaS, and advanced lead acid batteries.: This project will provide updates and case studies on the most relevant energy storage demonstrations under way in the United States for Distribution Grid Support. Included will be updates on all the NaS battery demonstrations, as well as advanced lead acid demonstrations under way.






Case Study and testing of Li-ion battery systems integrated with Residential Photovoltaic systems.: This project will continue to test and evaluate emerging Li-ion energy storage systems that were started in 2009. 5 kW / 20 kWh modules and larger will be first tested at EPRI's Knoxville Living Lab and then migrated to the field for utility testing. Applications of interest are for integrated photovoltaics and also fast charging of PHEVs. We will also plan to test other emerging energy systems like new Zn-Air rechargeable systems.


Neighborhood Energy Storage Systems for Pad Mounted transformer and advanced IUT applications.: The goal of this project is to evaluate advanced distributed energy storage applications in a neighborhood or a community setting, where they are co-located with pad-mounted transformers. In 2009, the program developed a functional specification, requirements, and use case for such energy storage systems and collaborated with a utility stakeholder interest group. Initial technology mapping and screening were also conducted. This year's efforts will advance this application by conducting further technology screening, tests, and evaluations of candidate systems as well as advancing the future application with the Intelligent Universal Transformer (IUT). EPRI will work with members to test and evaluate selected systems and develop a field trial and demonstration / deployment program plan where these storage systems are part of a Smart Grid system.


Tests and evaluation of Emerging Energy Storage and DG Systems: This project will test and evaluate emerging energy storage and distributed energy resource options and characterize their performance and operating envelope and readiness for utility applications. Options will be recommended by EPRI staff and advisors and selected by funders. Activities may include tests of advanced batteries, micro-generation systems, and advanced distributed generation systems. EPRI will seek testing opportunities that leverage with awards provided from the U.S. DOE Smart Grid Demonstrations Recovery Act. The strategic intelligence activities and technology assessments conducted in the program will help identify promising options for possible evaluation. Examples may include:- 1 MW transportable fuel cell system for grid support and utility peak shaving- 3-5 kW residential energy storage system for back-up and demand response- 1-5 kW Honda fuel cell home appliance system- Zn / air modules and early prototype systems for beta testing.


P94.003 Bulk Power Energy Storage Solutions (065557)

Key Research Question The electric enterprise needs cost-effective and reliable bulk energy storage to help balance supply and demand and optimize the operation of bulk power resources — including nuclear, fossil, and renewable resources. State renewable portfolio standards (RPS) may result in a high penetration rate of variable renewable resources. Utilities need bulk power storage solutions to effectively manage the variability of wind and effectively reap the emissions reduction potential of wind and solar power and the ability to store base-load energy for use during peak times. Presently two technologies are available that may help to achieve these goals: Compressed Air Energy Storage and pumped hydro. Second-generation compressed air energy storage solutions are receiving serious consideration, but they still require use of fossil fuels. This project looks into the options of compressed air energy storage designs without the need to burn fossil fuels, and therefore, there is a need for nonfuel CAES cycles. The industry also needs to re-examine the potential for pumped hydro applications and assess new technology developments in pumped hydro technology. Also,


given new trends and developments in large flow-battery systems, the program will re-examine the use of vanadium, Zn / Br and Zn / Cl redox cycles for use in large bulk storage applications.

Approach This project area provides information and specific solutions based on nonfuel, advanced compressed air energy storage systems (CAES), pumped hydro, and large battery storage systems to improve the value of large-scale variable renewable generation. Research areas prioritized by members, will include:

• Advanced, nonfuel, compressed air energy storage (CAES) systems • Technical Update on pumped hydro storage: costs, resource potential, sizing, siting, permitting, and

historical operating experiences including an update on trends in new pumped hydro technologies • Large ( 100 MW) flow battery systems- update and cost assessment • Regional analysis of energy storage for renewable energy integration under upcoming state RPS

requirements • Energy storage for frequency regulation and ancillary services

Impact Participants may be affected by this project in a number of ways including:

• Improving the market penetration of variable wind power — improving cost-effectiveness and reducing the industry's GHG emissions profile

• Learning about assessments and timelines for advanced bulk energy storage systems • Improving the utilization and operation of transmission assets • Improving the understanding of the system- wide benefits of CAES and bulk energy storage • Improving the use of fossil assets and lowering GHG emissions when using storage for ancillary services

How to Apply Results Research findings could be used by corporate strategic planners, resource planners, and system planners as well as utility design engineering staff. Planners and operators of bulk power generators may use the results to plan new projects as well as increase the utilization of existing base-load or intermediate-duty generation assets. Independent system operators (ISOs) can apply findings into their planning and market development activities.

2010 Products


Advanced, non-fuel, Compressed Air Energy System Definition: This project will continue to advance the development of a nonfuel, advanced compressed air energy storage (A-CAES) system, with the goal of enabling a demonstration by 2013. In 2009, a concept design of an A-CAES system was developed, including trade-offs of thermal storage media/options. In 2010, the designs will be further optimized, refined, and updated with the focus on plant requirements for wind and renewable integration. Testing of the most optimal thermal media materials and containment will be undertaken to develop scale-up information. Modeling of the cycle will provide design information for transient operation inherent with thermal storage systems. The development plan and demonstration plan will be updated. A Project Task Force will guide efforts to conform with industry needs and requirements. The goal at the end of 2010 will be to have the design basis to proceed with more preliminary engineering and planning for technology demonstration and the value proposition for wind integration.As a separate effort and task, the cost and availability of large flow batteries will be re- examined and benchmarked against the non-fuel compressed air system for






application in wind integration.

Pumped Hydro Resource Update: This project will provide an update on the current use and scale of pumped storage in the United States, including the value and GHG reduction impacts as a proxy for understanding the impacts of future bulk storage deployments. The update will provide information on how bulk storage is currently being used and deployed to gain insights into future storage system requirements. The update will also include a status report and information on trends in new pumped hydro facility deployments, planning studies, emerging new technologies, and issues. Based on member interest and funding, the opportunity will be examined for using municipal water systems as small pumped storage options.


Meeting Regional RPS Mandates with Energy Storage Systems: This project will continue work begun in 2009, examining the regional opportunities, role, and value of energy storage systems for improving renewable penetration and market integration, including the role that storage can play in reduction of the electric sector's carbon footprint. In 2009, the ERCOT region was examined for bulk compressed air energy storage systems. In 2010, we will conduct an analysis to: 1) better understand how much energy storage is needed by region to support high renewable generation scenarios; and 2) the trade-offs and needs for bulk vs. distributed energy storage systems. Regions to be examined may include CAISO, PJM, MISO, and NYISO, depending on available funding.


Energy Storage Systems for Frequency Regulation and Ancillary Services: This project will examine the needs of the independent system operators (ISOs) and the markets and energy storage systems capable of meeting and serving the ancillary services markets.It will include a review of ISO pilots, activities and trends for requesting the use of energy storage to serve these markets. In addition to the EPRI report, a public white paper will be prepared. Webcasts and a workshop may be considered based on member interests and funding.



Integration of Variable Generation and Controllable Loads - Program 173

Program Overview

Program Description A number of ongoing environmentally driven regulatory issues—including greenhouse gas reductions and climate change initiatives, the U.S. Clean Water Act: Cooling Water Intake Structures, and the U.S. Clean Air Act: Interstate and Mercury Rules—have increased implementation of renewable energy resources and adoption of distributed generation (DG) and demand-side resources.

Research Value EPRI research and development in integrating generation and controllable load area will produce knowledge and tools that will help system operators and planners:

• Understand the impacts of variable generation and controllable load on system reliability • Control variable generation and controllable load to minimize operational risks • Design robust transmission systems to integrate variable generation and controllable load.

Approach The Integration of Variable Generation and Controllable Load program offers members both short- and long-term value that can be realized in a number of ways:

• Anticipating future developments, creating new strategies, and outlining roadmaps • Developing methods and tools • Demonstrating and deploying technologies • Providing training and staff development • Sharing knowledge, information, and experience • Building networks and conducting outreach.

Accomplishments The Integration of Variable Generation and Controllable Load program was created in 2009. Program products in that year included:

• Technical update on transmission infrastructure to integrate renewable energy • Technical update on determining planning and operational reserve requirements for intermittent resource

integration, with case studies • Technical update on operational tools and methods for high-penetration wind systems.

Current Year Activities In 2010, this research program expects to accomplish these objectives:

• Understanding the state of the art, best practices, and gaps of existing tools • Preparing a set of requirement specifications for expanding the capabilities of tools to deal with the

variability of resources • Exploring new methodologies to deal with uncertainty of variable generation and controllable load • Business case studies to quantify financial benefits of controllable load and storage


Integration of Variable Generation and Controllable Loads - Program 173 p. 1



Summary of Projects


P173.003 Grid Performance and Modeling of Variable Generation and Evolving Power System Resources

This project aims to describe the technical performance requirements of variable generation and other emerging generation technologies, help develop generic non-proprietary models for modeling and planning the integration of such resources into the utility grid, and guide efforts in model validation.

P173.004 Determination of Optimal Reserve with Consideration of Variable Generation and Controllable Loads

Determine energy and reserve schedules with consideration of power system uncertainties arising from conventional and emerging energy technologies such as controllable loads, price-sensitive demand, energy storage, and PHEVs.

P173.005 Advanced Frequency Control for High Variable Generation Systems and Evolving System Resources

System operators presently depend on generating resources to supply frequency regulation through the load frequency control (LFC) portion of AGC. Present LFC algorithms may be tuned in a way that does not provide optimal or even adequate frequency control for high penetrations of variable generation. For example, recent EPRI studies performed on a small island system with high wind penetration showed that control tolerances had to be loosened to prevent hunting, or over-control, which degraded control performance. This project will evaluate potential changes to existing LFC functionality and maintenance for high variable generation scenarios. Additionally, the project will assess gaps in existing control algorithms, communications infrastructure, or any other barrier that would preclude new sources that provide system flexibility from participating in frequency control. This information will then be used to create a roadmap and possible demonstration efforts needed to take the concept to an implementation phase.

P173.006 Advanced Planning Tools to Study the Impact of Variable Generation and Controllable Loads

This project will investigate future load composition, system load shapes, business cases for energy storage, regulatory policy impacts and the value of ancillary services as affected by integrating high penetrations of renewable generation, controllable loads, PHEV, energy storage, and demand response. Information developed through this project will prove useful to members when planning their future transmission grids.

P173.003 Grid Performance and Modeling of Variable Generation and Evolving Power System Resources (067489)

Key Research Question Many states have passed renewable energy requirements, and the prospects for a federal requirement seem good. Many of these requirements include specific targets for wind and solar generation. As a result, there is an increasing effort to integrate solar photovoltaic (PV) panels in residential and commercial constructions. When connected to the distribution system in sufficient quantities, PV generation is capable of impacting power grid behavior during system disturbances. It is important to understand the characteristics of PV generation with respect to voltage and frequency variations in the power grid. PV, solar thermal, demand



response, plug-in hybrid electric vehicles (PHEVs), and other evolving system resources have performance characteristics that can differ from those of conventional generation. System planners and operators, as well as owners of the new system resources, need to understand the requirements for each of the technologies to supply services required by the system.

Approach This project will investigate and develop technical specifications for the dynamic performance of evolving power system resources. For example, should PV have fault ride-through, as is now accepted and implemented for wind power plants? This effort will build on work from a supplemental project begun in 2009 that provides for developing these technical specifications for wind generation technologies. The 2010 project will extend these specifications to other technologies such solar PV, solar thermal, energy storage, demand response, and PHEVs. The order of development will be prioritized with project members. In addition to furthering technical specifications for advanced resources to provide system performance needs, this project will also develop guidelines for representing such devices in bulk system planning studies. This effort will:

• Review available technical literature on inverter-based PV testing and modeling, and review any readily available field measurements for existing PV installations. This literature and data review will also be conducted for other advanced sources, such as PHEVs, to serve as the basis for developing bulk system modeling guidelines for these devices in future efforts.

• Identify gaps that may exist in the understanding of inverter-based PV generation that potentially limit the ability to develop representative bulk transmission system models. Determine whether further laboratory testing of certain units may provide a better understanding of such issues. If so, develop a plan for obtaining equipment, develop test plans, and conduct additional tests in the future. Similar gaps should be identified for other evolving resources.

• Develop a detailed scope for future project work to develop models for inverter-based solar generation and other evolving resources, and methods to include representation of these devices in commercially available bulk power system planning tools. Such models need to be non-proprietary and open for use by all, disseminated to the industry to allow their implementation in standards and widely used commercial power system analysis software. This effort would coordinate with ongoing efforts by IEEE, WECC, and other organizations developing models for variable generation resources. The project would also aim to develop ways to validate the models.

• Based on a literature search and experience with wind generation, provide a qualitative assessment of the potential impacts that a large proliferation of inverter-based distributed generation, such as PV, may have on the bulk transmission grid. Accordingly, make recommendations on what aspects of standards and future inverter-based PV and DG control strategies may need to be investigated and revised to address those issues. Such standards development is clearly outside the scope of EPRI's work, and the goal would be to make technical recommendations to standard organizations such as NERC.

Impact • This work is necessitated by the growing demand for renewable and distributed generation technologies.

On the system modeling and planning side, existing tools and models do not yet adequately represent the breadth of capabilities and performance of these emerging technologies. Being able to develop the models needed and technical performance guidelines for applying these new technologies will be a significant step in providing system planners with the tools they require to plan the power system in coming years. This research can help members by:Defining the control features and capabilities that emerging variable generation sources need to match existing generation technologies

• Providing models and guidance on the use of models of these new technologies for system planning studies

• Validating existing or in-development models.



How to Apply Results Provide workshops, tutorials and training webcasts. Also, disseminate key results and models through industry forums such as IEEE and CIGRE.

2010 Products


Workshop on Variable Generation Performance and Modeling 12/31/10 Workshop, Training, or Conference

Technical Report on Variable Generation Performance and Modeling 12/31/10 Technical Report

P173.004 Determination of Optimal Reserve with Consideration of Variable Generation and Controllable Loads (067490)

Key Research Question New NERC requirements for Operational and Planning Reserve (BAL-002-RFC-02, RES-001-1) recognize the need for improved methodologies and algorithms beyond the traditional contingency analysis to accommodate increasing levels of uncertainty in the behavior of intermittent resources and demand response. This research is new and compelling, due to the introduction of renewable portfolio standards and the use of demand response for mitigating the impacts of high-priced energy sources.Unlike conventional generation from fossil fuels, nuclear, and hydropower energy sources, emerging generation technologies such as wind, solar, and demand-side energy sources offer new uncertainties and are not easily controlled. Specifically, their variability makes it more difficult for system operators to determine reserve requirements. Current practice, which uses a deterministic approach, is no longer sufficient. A new approach is needed for determining reserve requirements.

Approach This project will apply a stochastic model to determine robust energy and reserve schedules. The model minimizes the overall cost of energy and establishes reserve schedules and post-contingency correction controls, while maintaining the reliability of power system operation under both normal and contingent scenarios. The methodology determines energy and reserve schedules with consideration of power system uncertainties arising from conventional and emerging technologies. Such technologies include intermittent generation, controllable and price-sensitive loads, energy storage, and plug-in hybrid electric vehicles (PHEVs). The project team proposes to use a stochastic optimal power flow (SOPF) model with reserve determination under different types of uncertainties. This model formulation forms the core of a new approach to network modeling for describing and simulating new behaviors of network resources. It can be applied to planning and operations studies, and can also help determine long-term system capacity requirements. In a market context, the model formulation forms the basis for understanding system performance under uncertainty. It can be used to help market operators, market monitors, and regulators determine sufficient capacity requirements for short- and long-term needs. Through models and case studies, this project will provide examples of a detailed analytical method for determining planning and operational reserve requirements. The project will proceed as follows:

• Review existing capacity evaluation methods utilized in various jurisdictions (statistical analysis of capacity in worst hours versus probabilistic-based simulations)

• Review empirical data (including CA 2006, ERCOT, Denmark, and Germany) • Evaluate new approaches, such as stochastic optimal power flow and others.



Impact Power system operators and planners will have new capabilities for determining reserve requirements that balance the installation of emerging energy technologies with system reliability. This capability can be used to determine short-term reserve and long-term capacity requirements.

• Determine reserve requirements subject to new demand-side and renewable resource uncertainties. • Quickly compute stochastic optimal power flows. • Use a new approach to network modeling, incorporating components with uncertain behavior.

How to Apply Results EPRI offers project status updates, training webcasts, and reporting exercises to communicate the strengths and applications of the reserve determination under uncertainty. Training and workshops will help users become familiar with the detailed aspects of the technology and the variety of options and experience. Members will develop the capability to utilize stochastic model formulations with commercial simulation tools, as well as handle emerging energy technologies in operational and planning studies.

2010 Products


Technique for Reserve Determination with Consideration for Conventional and Emerging Technologies 12/31/10 Technical Report

Model for Reserve Determination with Consideration for Conventional and Emerging Technologies 12/31/10 Software

P173.005 Advanced Frequency Control for High Variable Generation Systems and Evolving System Resources (069255)

Key Research Question The variability and uncertainty associated with variable renewable generation such as wind and solar PV can have a significant impact on system performance and market operation as penetration levels increase. How does the availability of demand response and distributed energy storage impact existing operational planning and control strategies and implementation to ensure sufficient balancing and frequency regulation?

Approach EPRI will draw on studies from small islanded systems with high wind penetrations and engage operators from other systems with increasing variable generation penetration to identify potential performance impacts and needs. This project may also engage automated generation control (AGC) vendors for one or more systems on which new algorithms might be tested.

Impact This project will provide system operators with insights concerning the potential impacts of variable generation on frequency control, as well as new methods for minimizing any negative impacts on system frequency performance.

How to Apply Results • Read the technical report and implement recommendations for existing AGC system. • Work with associated vendors to develop and test identified algorithms in a modified AGC system.



2010 Products


Advanced Frequency Control for High Variable Generation Systems and Evolving System Resources 12/31/10 Technical Report

P173.006 Advanced Planning Tools to Study the Impact of Variable Generation and Controllable Loads (069256)

Key Research Question Global climate concerns are influencing the ever-increasing role that renewable and highly variable generation will play as future energy sources. At the same time, interest in the smart grid has accelerated in the United States and the rest of world. To date, smart grid implementation ideas have been largely limited to the development of smart meters, whose availability will likely precede that of other technologies on the bulk power grid level. Deployment of smart meters connected to customers with controllable loads will require grid planning to model them effectively, thereby improving grid reliability and reducing system operating costs. In addition, energy storage will be urgently needed to complement renewable generation and customer demand. Research is needed to develop advanced planning tools that integrate the planning and operation of customer demand, energy storage, and renewable generation. In the absence of such tools, blackouts are more likely to happen. This project is needed by system planners modeling planning studies and evaluating the impact of variable generation and controllable loads on transmission capacity requirements and grid reliability.

Approach This project is new. It will continue for three years and be completed at the end of 2012. In 2010, the project includes the following activities:

• Model the uncertainties associated with renewables, including wind and solar. Usually, wind farms and solar collection points are combined or treated as a single entity in steady-state power flow models; such simplifications result in low accuracy simulation. A complete treatment of the random outage and production distribution of renewable generation will be developed. This work will incorporate research results by EPRI and others on modeling the intermittent nature of renewable generation.

• Develop system renewable generation outage probabilities and production distributions with various assumptions on penetration scenarios (15%, 20% and even 33%).

• Develop system load shapes and load factors with various assumptions on penetration scenarios of controllable loads, before and after applying control.

• Develop advanced planning tools to perform reliability assessments for comparing alternative transmission expansion plans to accommodate a high penetration of renewables and controllable loads. The impact of renewable resources and controllable loads on capacity requirements will also be evaluated.

Impact The value and benefits this project will delivery to its members include:

• Understanding of the technical and financial benefits of controllable loads—including energy storage, PHEVs and demand response—if holistic planning is applied to the entire power supply and delivery chain. Improvements in reliability and reduction in system operating costs may be direct benefits.

• Ability to use project results to assess the impact of controllable loads on future transmission capacity requirements. Members will find that tremendous savings in transmission investments can be achieved if a holistic planning approach is taken to optimally control and complement all the resources and demands over the entire power supply and delivery chain, instead of using disjointed criteria to plan the transmission grid.




How to Apply Results The project report will help members understand how to conduct advanced planning for the entire power supply and delivery chain. Members will be able to use the best available data and information about load composition and load models that recognize all resources and demands. Typical system load shapes will be available for members to use for system studies. Business cases for applying energy storage will be excellent sources of information for members planning a possible role for energy storage in their future systems. Survey results and summaries of regulatory impacts as well as the value of ancillary services will also be valuable. Webcasts will be held regularly to engage members in research effort and for information transfer.

2010 Products


Technical update on the issues and methods for assessing and planning for customer demand and energy storage for regional transmission grid: Technical update on the issues and methods for assessing and planning for customer demand and energy storage for regional transmission grid.



Enabling Integration of Distributed Renewables - Program 174

Program Overview

Program Description The integration of distributed renewable generation sources into the electricity grid poses a number of challenges for the industry. Utilities will be faced with issues of enabling high penetration of distributed generation into both existing and future distribution systems. This program will address these issues with a variety of projects that cover interface devices, analytics, system studies, special applications and assessment of new technology for effective interconnection and integration of renewable and other distributed generation. The program also includes lab and field tests, demonstrations, and use-case reference library. A primary objective is to expand utility hands-on knowledge and capability to use, leverage, and monetize the value of renewable generation deployments without reducing distribution safety, reliability, or asset utilization effectiveness. A second focus is to evaluate end-user level intertie equipment both grid-tied and direct photovoltaic (PV) energy-to-appliance applications.


• Maintaining distribution network reliability and safety • Strategies for responding to customer-sited renewable generation • New business models, economic analysis of ownership options and potential to rate base distributed

assets • Proactive response to state and federal renewable portfolio standards (RPS) • Planning for renewable deployment and advanced distribution automation • Utilizing the value of the utility distribution system to support renewable distributed generation

Approach

• This was a new program in 2009, and will build on previous work related to distributed resource integration. It will also utilize EPRI experience with the advanced distribution automation, Green Circuits, and Intelligrid programs, as well as the smart grid demonstrations.

Accomplishments The integration of renewables program has delivered valuable information that has helped its members and the industry. Some examples include:

• Members are better positioned to deploy and to connect to renewable generation, realizing the critical role, and value, of their existing distribution and substation assets.

• Research results identify best practices and opportunities for grid modernization while helping justify needed investments.

• Evaluating new applications and hardware will support members’ planning considerations and help avoid investment mistakes.

• Preparing for increased penetration levels and offering new ways to connect and use renewable generation can help members retain leadership in the production and delivery of electric energy.

Enabling Integration of Distributed Renewables - Program 174 p. 1


Current Year Activities • Develop screening tools, criteria, and guidelines for increasing penetration of renewable generation in

existing radial and network distribution, as well as future circuit functional requirements. • Plan and conduct a member's workshop to share current practices and identify future need for planning

and integration tools, as well as assessment of advanced circuits design concepts. • Survey current AMI deployment with distributed generation and explore ways that advanced metering

systems help enable, integration, including a comparison of current and expected future performance. • Identify and provide application and design data for promising direct current use of photovoltaic energy by

end users. • Develop performance criteria, design, test, and set up laboratory test stand to evaluate available intertie

hardware, systems, and configurations.


Program Manager Tom Key, 865-218-8082, [email protected]

Summary of Projects

PS174A Integrating Renewables into Distribution (067431)

Project Set Description This project set focuses on the distribution system’s readiness for high penetration of renewable and distributed generation. The first project is related to incremental increases of distributed generation into today’s existing distribution, both radial and network. The second project will assess future distribution system designs and related options for integrating anticipated high penetration of renewable and distributed generation. There are aligned with EPRI's Green Circuits, Smart Grid and Intelligrid programs.


P174.001 Planning and Design for Integrating Renewables into Existing Distribution

Continues 2009 activities engaging utility personnel in applying screening tools, developing planning and application guidelines.

P174.002 Accessing Future Distribution Options for Integration of Distributed Renewable Generation

The project will access future distribution options for integration of distributed renewable generation.

P174.001 Planning and Design for Integrating Renewables into Existing Distribution (067492)

Key Research Question Existing radial and network distribution systems are not designed for a significant penetration of distributed generation. The key issues are lineman and public safety, circuit protection, voltage control, and reliability. Circuit limits on the penetration of distributed generation are expected due to output variability and two-way power flows. Specific problems to be addressed are planning and design for adaptability of relays, interactive voltage control, fault detection, phase-to-ground overvoltage and islanding detection, and service restoration methods.


mailto:[email protected]


Approach This project looks at making incremental renewable generation additions in today’s existing radial and network distribution systems without sacrificing safety, reliability, or effectiveness. Starting with prior EPRI R&D, this project focuses on changes needed in planning, design, and operating criteria for high penetration of distributed and variable generation. It will provide guidelines, impact analysis, and assessment methods to determine the limits and analyze the expansion options and potential system value.

Impact • Enhance ability to conduct resource planning, improve on interconnection screening and requirements,

and maintain circuit performance and reliability. • Gain access to and exchange up-to-date information. Share best practices, state-of-the-art

developments, and related information from other distribution companies. • Benefit from collaborative R&D activities and sharing applications, experiences, lessons learned, and

solutions related to integrating distributed renewable generation. • Address current renewable power generation issues via analytical studies, developing planning methods,

applying screening tools, and evaluating specific interconnection case studies.

How to Apply Results Utilities faced with planning or integrating new renewable generation will utilize the results of this project to ensure that the full implications of safety, reliability, and electrical performance are considered. Findings can be used to work with developers wanting to connect green buildings, construct zero-energy homes, and implement sustainable community strategies.

2010 Products


Guideline on applications of adaptive relaying to accommodate high penetration: Technical update includes sample case studies and provides guidelines on applying adaptive relaying to accommodate high penetration of DG.


Planning methodology to determine practical circuit limits for distributed generation: Technical report presents planning fundamentals to help users determine the practical substation and circuit limits for DG integration in distribution systems.


Guideline on voltage control strategies for high penetration of distributed generation: Technical update includes sample case studies and provides guidelines on voltage control strategies for high penetration of DG.


P174.002 Accessing Future Distribution Options for Integration of Distributed Renewable Generation (067493)

Key Research Question Decisions on replacing or upgrading aging distribution systems will require considering the potential for high levels of distributed renewable generation. Utilities would like to plan for and build in capability to support higher penetration levels of distributed renewable generation while maintaining safety, protection, and reliability. A key issue this project will address is new distribution system designs that will allow greater penetration of distributed resources.



Approach This project addresses future distribution options for planning, design, and operation with new integration devices, advanced distribution system configurations, and practices capable of supporting wide-scale integration of renewable generation. It also assesses new concepts, methods, and tools along with the related cost and timing for accommodating high levels of variable distributed generation.

Impact • Knowledge, perspective, and new ideas about what future distribution systems with significant levels of

distributed generation, related communication, and automation will need to look like. • Collaboration with other members to develop criteria, apply planning methods, and share design concepts

for the distribution systems of the future. • Results from analytical studies, modeling and simulations, case studies and demonstration of new

distribution designs with high penetration of renewable generation.

How to Apply Results The criteria, configurations, and designs for accommodating high levels of renewable generation will help distribution system planners think through and incorporate needed changes in system plans. Distribution engineers and operators will use results that describe future options to frame recommendations and consider new operating procedures that will be required to accommodate high penetration of distributed resources.

2010 Products


Report on circuit functionality and requirements for future grid integration: Required new functionalities for future distribution systems to incorporate high penetration of distributed generation will be reported. Topics include the role of ADA, interface with communications architectures, and microgrids. Relative cost and timing for these deployments will also be covered.


Development of Advanced Circuit Guidelines (Initial Chapters for future EPRI Color Book document): Initiate process of developing recommended guidelines for advanced circuits needed to integrate higher levels of renewables and distributed generation, and to evolve into an EPRI Color Book. Proposed initial chapters are: • Overview of Impacts on Planning Tools • Communication Infrastructure Needs for Integration of Renewables and

DG (in coordination with Intelligrid) • Protection Systems to Integrate Renewables and DG • Voltage and Var Control with Renewables and DG


Workshop on Advanced Design Concepts for future grid Integration: This workshop will focus on advanced design concepts and options, such as the SCE Avanti circuit, microgrid results from Europe and the United States, and integrating renewables and DG with automation schemes. It will be scheduled in parallel with the workshop in 174.001 on existing circuits and current practices for high penetration of DG.






Workshop on Advanced Circuit concepts for Integration of Distributed Generation: This workshop will be a follow-on from 2010 and will address advanced circuit concepts for the integration of distributed generation.


Assessment of Cases that Demonstrate Deployment of Advanced Distribution Circuits with DG: This will be an update/assessment of actual case studies showing the planning, design and implementation of advanced circuits that demonstrate future configurations and hardware needs for high penetration of DG.


PS174B PV & Metering Integration into Distribution (067432)

Project Set Description This project set focuses on end-user level, distributed renewable interface technologies. Both grid-tied and direct PV energy-to-appliance applications, as well as related hardware, will be covered. For grid-connected applications, advanced metering systems, inverters, controllers and other related intertie equipment will be evaluated. The direct use of dc from photovoltaic generators into drives, lighting, battery, PHEV and other electronic end uses will be investigated and tested.


P174.003 Advanced Metering Infrastructure (AMI) Applications for Distributed Renewable Integration

This project continues from 2009, moving from a survey of utility engagement level and requirements assessment to more hands on and field applications. AMI evaluations in the laboratory continues.

P174.004 DC Applications for Direct Use of Distributed Photovoltaic Generation

The project will continue surveying and reporting on PV-DC devices and applications. Where practical laboratory and/or field evaluation will be conducted.

P174.005 Evaluation of Distributed Renewable Grid Interface Systems

Laboratory and field evaluation of distributed renewable grid-interface systems.

P174.003 Advanced Metering Infrastructure (AMI) Applications for Distributed Renewable Integration (067494)

Key Research Question With deployment of advanced metering infrastructure, many utilities are making a financial investment in AMI technology. Timing is critical for AMI designs to take into account future requirements for integrating distributed resources. Although data capture may not be a problem, integrating data into billing and accounting software can be. To the extent that future PV system designs can employ AMI capabilities, the economics of both will be enhanced.

Approach AMI devices will be evaluated for use with PV inverter controller systems to determine synergies in functions and capabilities. For example, AMI should be confirmed as net-metering-compatible both functionally and with data acquisition. New data streams from AMI should consider what updates, upgrades, or overhauls will be



needed to existing billing and accounting software. Customer-sited distributed generation (DG) will be considered as part of this process. Interfacing methods will be explored, and where possible tested in the laboratory and demonstrated in the field.

Impact • Helps members specify AMI systems that will handle future requirements for distributed renewable

integration. • Provides insight in how future AMI and DG will interface with billing and accounting. • Identifies AMI systems that provide flexibility and functionality for future DG integration. • Avoids going back and patching later, which would incur otherwise avoidable costs.

How to Apply Results Using the field experience and lessons learned reported in this program, members can refine plans and adjust implementations in their own AMI deployments. The AMI criteria, new configurations, and future design concepts identified in this R&D program can be incorporated into specifications for major distribution system and customer interface upgrades or new circuits accommodating high levels of renewable generation.

2010 Products


Expanded Web Based Library of AMI Use Case Experiences: This activity provides continued management of a use case and requirements library, with appropriate updates and new case lessons learned. These results will be combined and summarized for easier use by members and to be provided in a straw-man document for future industry standards AMI development activities.


Field Performance Assessments for AMI used with Renewable Resources: These field performance assessments will be carried out at locations where AMI is being applied with the integration of distributed resources. Attributes of these cases and future needs will be identified.


AMI System Laboratory Evaluations: Lab evaluations will be conducted for selected AMI configurations and architectures based on the interest of participating members.


P174.004 DC Applications for Direct Use of Distributed Photovoltaic Generation (067495)

Key Research Question Utilities must take proactive technical leadership in advancing new ways to use PV produced electricity at end-use customer sites. Trends toward adding power electronics to improve efficiency in many appliances, adding dc electric energy storage as in PHEV applications, and installing rooftop PV will bring new opportunities for the dc-direct applications.

Approach This project will conduct scoping studies, define new applications, and develop conceptual designs for integrating PV generation via DC applications, including adjustable-speed drives, lighting, battery storage and plug-in electric hybrid vehicles (PHEVs). Results will be provided via paper studies, hardware demonstration partnerships, and lab evaluations as well as lab and field deployment demonstrations.



Impact • DC-direct applications can greatly simplify interconnection issues for PV, increase the efficiency of PV

systems, and reduce the cost of integration and interconnection. • By getting ahead of customers in identifying and understanding new applications, members leverage

other emerging end-use programs and may identify new business opportunities to provide end-use electric energy.

• Results from laboratory evaluation and field demonstrations will help define integration and performance requirements for these applications.

How to Apply Results Members with active programs in end-use energy efficiency and demand management can apply these results to extend such programs to include integration of on-site solar power. As deployment of distributed PV becomes more widespread, results from this program will help shape utilities’ future roles and identify new business options for end-use energy systems.

2010 Products


Performance assessment and aggregation of Lessons-learned from PV-DC Installations: This technical update will assemble performance information from site demonstrations of PV dc systems in addition to product information and evaluations. Overall knowledge acquired regarding both issues and opportunities for future utility involvement in PV-dc system deployment will be addressed.


Laboratory evaluations of PV-DC devices and applications: Obtain and evaluate PV-DC devices based on member interest and most likely future impacts on electric energy use.


EPRI Solar Electric Interest Group: Solar Electric Interest Group (SEIG) includes participation in all meetings, webcasts, technical tours and workshops. Results include future plans, findings from site visits, discussions of biomass R&D topics, deployment issues, and project developments, and summary materials from any workshops.


P174.005 Evaluation of Distributed Renewable Grid Interface Systems (067496)

Key Research Question Utilities need to take proactive technical leadership in understanding and advancing new grid interface systems for future high penetration of renewable resources. Developing performance criteria, and evaluating and demonstrating new interface hardware and systems, will position members to more effectively work with developers and customers wanting to deploy distributed renewable generation.

Approach This project looks at system compatibility (immunity, emission and energy performance) profiles, protection settings, communication and control interface, specifications, availability, performance, and the cost of existing inverter systems and other distributed renewable generation grid interface hardware. It will identify new options, including related performance criteria, and will include lab testing and field demonstration of new configurations, systems, and devices with options for the utility’s point of common coupling either on the AC or the DC side of the device or inverter. Project efforts are expected to evolve from concepts, prototypes, and first-adapter applications to industry best practices, guidelines, and proposed standards.




Impact • Hands-on evaluation of new interface hardware and systems will position members to more effectively

deal with interconnection requests. • Benefit from collaborative evaluation activities and the shared results of field experiences, lessons

learned, and solutions related to integrating distributed renewable generation. • Address current and growing interest in the deployment of distributed renewable power generation, with

results on available interface systems and their performance.

How to Apply Results Utilities faced with planning or integrating new renewable generation will use the results of this project to ensure that the full implications of safety, reliability, and electrical performance are considered. Findings can be used to work with developers wanting to connect green buildings, construct zero-energy homes, and implement sustainable community strategies.

2010 Products


Develop performance criteria and related test plans for renewable generation interface systems: This project will build on prior grid interface research, performance requirements, and related test protocols in the DER area. It will develop performance criteria for different configurations and point-of-connection and design tests that address current and future utility practices for mating meters, inverters, and related intertie equipment.


Design laboratory test stand, plan performance and compatibility testing: This project will build on prior grid interface test equipment, methods and related test protocols developed by EPRI for DER evaluations. It will develop the needed laboratory test stands as well as plans for performance and compatibility testing, including immunity, emission, and energy performance.




Database resource on interface system configurations, functions and specifications: This project provides a database for comparing different system configurations and functions that could be used for the interface/integration of renewable generation, including meters, inverters and other interconnection equipment.


Lab evaluation reports of selected grid interface systems: Selected equipment and interface systems will be set up and tested in the lab. Results are available to the manufacturer and project participants. In some cases, testing will be accomplished in the field at host utility sites.



End-Use Energy Efficiency and Demand Response in a Low-Carbon Future - Program 170 p. 1

PS170B Demand Response Systems (65571)

Project Set Description The projects in this set assess, test, and demonstrate the application of technological advances in integrated energy management control systems, linking smart thermostats, lighting controls, and other load control technology with smart end-use devices to enable more sophisticated and effective demand response, such as dynamic energy management, in homes and buildings. The project set also examines technological advances in thermal storage and its integration into demand response systems for load shaping and peak load management. Finally, it provides participants with a unique opportunity to work collaboratively with other utilities, government agencies, and manufacturers to define the requirements of end-use devices that are designed to participate in demand response programs “out of the box,” which carries the potential for dramatic operational and cost benefits to members.


P170.006 Enabling DR-Ready Appliances

This project continues the activities started in 2009 to develop use cases for DR-ready functionality for selected end-use devices. An EPRI-facilitated workshop will bring together diverse stakeholders—including DOE, EPA, utilities, equipment manufacturers, policy makers, and regulators—to define the attributes that will define DR-ready for the most applicable categories of end-use appliances. A report will document the developments of this workshop and other supporting activities conducted during the year.

P170.007 Advances in Thermal Energy Storage Technology

This project assesses and demonstrates the state-of-the-art in TES technologies.

P170.018 Intelligent Homes and Buildings

This is a third-party examination of lighting control systems identifying realistic performance, market potential, energy impact, and improved quality of light combined with the use of intelligent lighting control. The project also integrates demand response gateways into existing building energy management systems that have interoperable and open standards communication technologies.

P170.006 Enabling DR-Ready Appliances (067473)

Key Research Question Despite its well-documented and demonstrated benefits to society, utilities, and consumers, demand response (DR) remains a critically underutilized resource in the United States. One of the key barriers to greater participation is the cost to utilities of installing equipment in buildings and homes to enable load control and demand responsiveness, such as programmable communicating thermostats and sensors on air conditioners, appliances, water heaters, pool pumps, lighting, and other large end uses that contribute to peak demand. Experience also suggests that customer reluctance to have unknown controls installed in their homes or businesses represents another barrier to more widespread participation in utility DR programs. However, these barriers would be overcome if major energy consuming appliances came ready to participate in DR programs out-of-the-box (“DR-ready”).



Approach The focus of this project is to continue the effort commenced in 2009 to specify functional requirements for selected categories of end-use devices and building energy management systems to be deemed “DR-ready” and to develop a roadmap for industry migration towards ubiquitous demand response. DR-ready is the capability of end-use devices to receive signals from a utility, such as price information or other instructions, and respond automatically by modulating operation to reduce or shift demand.

The project builds on Electric Power Research Institute (EPRI) collaboration with the U.S. Environmental Protection Agency (EPA) and Department of Energy (DOE) in 2008 and 2009 to identify opportunities to make DR-ready a labeled attribute—possibly under the ENERGY STAR® brand—for selected categories of end-use devices going forward. This project will seek to establish consensus for DR-ready functional requirements for selected end-use devices, principally residential air conditioners, programmable communicating thermostats, water heaters, clothes washers, dishwashers, and pool pumps. This effort will take into account continuing developments in communications protocols and common information models that may provide standardized syntax for price signals and other utility-to-device communications. Building on DR-ready progress in 2009, this project will include lab testing and field demonstration of emerging DR-ready equipment to gauge functionality, reliability, and responsiveness to utility signals. EPRI will be open to assess both physical layer connection architectures as well as integrated circuit-based communication architectures based on emerging application layer protocols.

Impact • Have first-hand influence in shaping the utility industry's functional requirements for DR-ready end-use

technologies to ensure alignment with members' current and future DR objectives • Work through utility collaborative to influence EPA and DOE ENERGY STAR® standards to include DR-

ready functionality • Work through utility collaborative to influence equipment manufacturers to develop DR-ready equipment • Improve the cost-effectiveness of future DR programs by avoiding the expense of installing on-site

equipment for participating customers through DR-ready end-use devices • Increase DR capability and expand the potential market of DR program participants through the market

entry of DR-ready end-use devices

How to Apply Results Members will have first-hand access to influence the utility industry’s functional requirements defining what constitutes a “DR-ready” end-use device. Utility staff involved in the planning and design of DR programs and advanced metering infrastructure (AMI)/Smart Grid systems can apply the project findings and deliverables to match DR program requirements to desired end-use equipment attributes that would allow for “out-of-the-box” program compatibility. Equipment manufacturers will apply the functionality guidelines established through this project to develop prototype DR-ready technologies, which can, in turn, be tested in EPRI’s Living Laboratory and could be deployed in field trials in members’ service territories in conjunction with their DR programs. The eventual advent of DR-ready devices into the marketplace can expand members’ DR potential, increase dispatchability and reliability, and lower program operating costs.

2010 Products


Enabling DR-Ready Appliances: Volume 2: Continuation of 2009 project to assess, test, and demonstrate the capability of early-development demand response (DR)-ready devices.




P170.007 Advances in Thermal Energy Storage Technology (067474)

Key Research Question Thermal Energy Storage (TES), an established technology for shifting cooling and heating demand from on-peak to off-peak periods, is an often-overlooked means of responding to peak demand crises. It also is an option that can efficiently enhance the productivity of cooling, heating, and refrigeration systems. Many experts agree that TES technology is poised to become a more important part of heating, ventilating, and air conditioning (HVAC) markets. However, TES remains an underutilized technology, in spite of the fact that cool storage is an appropriate technology in approximately 60–80% of new commercial installations. With the rising importance of demand response (DR) and peak load reduction, adoption of TES technologies is expected to accelerate in the next few years.

Approach This technology is used to shift load from peak periods to on-peak periods. Since most U.S. utilities are summer peaking, cool storage has been of most interest to utilities and will be the main subject of this project. In cool storage, a vapor compression system cools a storage medium during off-peak hours. During peak periods, a heat transfer fluid or the storage medium itself is pumped through the delivery system, discharging the storage medium while avoiding compressor operation. Many different approaches have been taken to develop a cool storage system with the most attractive combination of cost, performance, and size, including water storage, ice storage and eutectics.

This project is a continuation of 2008 and 2009 activities. TES technology will be examined with the goals of identifying the features of available units, testing the most promising systems, publicizing the results, and acting on any improvement opportunities that are uncovered in the evaluation. Also included in the 2010 activities is an update to the Electric Power Research Institute (EPRI) software tool COOLAID, which computes cost-benefit evaluation of cool storage for utilities and customers.

Impact • Benefit from unbiased technical assessments of new TES technologies with the potential to reduce

demand and shift substantial load to off-peak hours • Assess state-of-the-art TES technologies for DR applications • Increase understanding of how TES technologies function in actual applications • Establish capability to transfer new TES technologies to utility customers, building operators, and

commercial customers • Enhance customer confidence by demonstrating a member’s value as an energy management partner

How to Apply Results Project findings and products will be employed by utility account representatives, marketing staff, and energy efficiency specialists as they work closely with customers in key residential, commercial, and industrial market segments and transfer new technology that can help utilities shift/lower peak demand. Members also can help customers improve energy efficiency, reduce pollution, enhance indoor air quality, and improve productivity.



2010 Products


Demonstrations of state-of-the-art TES technologies in the Living Lab and member utility service territories: Continuation of field demonstrations of the state-of-the-art thermal energy storage (TES) technologies that will lead to large-scale deployment by members.


Update to the EPRI COOLAID Tool: Beta version of a web-based tool, which is an update to the Electric Power Research Institute (EPRI) COOLAID tool that was developed in the 1990s.

12/31/10 Software

P170.018 Intelligent Homes and Buildings (069237)

Key Research Question An intelligent building can be defined as one that has the capacity to provide a safe and comfortable environment for its occupants, improve operational efficiencies for its owners, while at the same time respond to grid conditions to help utilities manage demand. Moreover, the level of intelligence can be determined by the capability of the building to deliver the maximum benefit to all three user groups: occupants, owners, and utilities. There are two main enabling components of intelligent homes and buildings:

• Building control systems • Lighting control systems Due to the inherent flexibility of building and lighting control systems, efforts must be made to evaluate their performance using basic customer requirements and, in turn, the results could be used to improve their performance. Such research may foster their widespread use in residential, commercial, and industrial buildings, helping to meet the needs of future energy requirements. Control systems used in intelligent buildings should support configurable control strategies whereby users are able to program or select subroutines to optimal performance levels based on a variety of parameters, such as external ambient conditions, time of year, consumer habits and preferences. These systems also need to be able to execute subroutines automatically upon the receipt of external signals including Real-time Pricing (RTP), time-of-use (TOU), and reliability-driven demand response events.

Approach This project consists of two subsets:

Building Control Systems: This activity is a continuation of 2007, 2008, and 2009 projects that build upon the technical assessment and demonstration of building automation and control systems for demand response applications. The 2010 activity will integrate demand response gateways into building energy management and control systems. The activity will pursue open standards and interoperable communication technologies.

Lighting Control Systems: The identification of lighting control systems is carried out by conducting extensive product searches, attending lighting control fairs and conferences, demand response expos, and engaging with existing and new manufacturers of lighting controls. New technologies will be procured for testing and evaluation in the Electric Power Research Institute's (EPRI’s) Living Laboratory in Knoxville. Lighting control research engineers also will be engaged to understand the direction of standards efforts and the requirements to support emerging lighting control technologies.



Impact Comprehensive evaluations of building and lighting control systems can be used by energy, lighting, and control engineers to aid in the decision process before lighting control technologies are considered for listing for energy efficiency and rebate/incentive programs. Additional value can be realized through

• providing opportunities for utilities to demonstrate leadership in environmental stewardship through deployment of vetted lighting control systems,

• understanding the impact of allowing lighting control systems to manage lighting loads in facility power systems,

• providing opportunities for utilities to integrate pricing gateways into smart building management systems, • gaining knowledge regarding the use of more intelligent yet easy-to-operate building management and

lighting controls, • understanding which technologies are more favorable for use with future demand response systems, and • helping ensure realistic performance that can be matched with product warranty expectations.

How to Apply Results Project findings and products will be employed by utility account representatives, marketing staff, and energy efficiency and demand response specialists as they work closely with their customers in key residential and commercial market segments to transfer new technologies and implement dynamic pricing models that can help customers by reducing peak demand, energy costs, and directly address their comfort and business needs. Comparison of electrical, efficiency, and photometric performance among traditional non-controlled light sources and lighting systems and those that are controlled in various commercial environments will allow members to determine expected energy reduction for system planning purposes. Project results will allow members to determine future energy and power quality requirements for supporting these technologies and the benefits of using lighting control systems combined with line-based building control and demand response systems. Project data will provide a foundation for members to compare field data from future installations with project and demonstration data.

2010 Products


Integration of demand response gateways into building energy management and control systems: Comparison between demand response gateways and energy management and control system (EMCS) capabilities to identify commonalities that may result in the integration of the gateways into the EMCS.


Assessment of modern lighting control systems: Examination of lighting control systems identifying realistic performance, market potential, energy and demand impact, and improved quality of light associated with the use of intelligent lighting control.



Electric Transportation - Program 18 p. 1

PS18D Advanced Infrastructure Development for Plug-In Hybrid Electric Vehicles (056057)

Project Set Description This project set addresses issues surrounding electric vehicle (EV) infrastructure and impacts on the utility grid as electric-drive systems enter the marketplace. Special attention is paid to the potential of plug-in hybrid and fuel cell vehicles to provide power to homes, commercial sites, and potentially the grid itself.


P18.010 Infrastructure Working Council

This project will provide support to IWC for the execution of infrastructure analysis that affects the commercialization of plug-in hybrid electric vehicles (PHEVs) and battery electric vehicles (BEVs) in the automotive and truck industries.

P18.011 Identification of PHEV Infrastructure Requirements

This project will compile the knowledge accumulated from infrastructure technology demonstrations and will update recommendations for plug-in hybrid electric vehicle (PHEV) charging infrastructures.

P18.012 Vehicle and Infrastructure Connectivity and Communication

This project will provide the technical analysis and development work to support a single standard communication protocol and physical media for vehicle-to-grid communications.

P18.013 Infrastructure Technology Demonstrations

This project will focus on development and testing of the vehicle, battery, and on-board communication systems to maximize potential benefits when PHEVs are connected to the grid

P18.010 Infrastructure Working Council (065239)

Key Research Question The Infrastructure Working Council (IWC) was established to provide a forum for utilities, automotive manufacturers, suppliers, and other stakeholders to address issues regarding electric infrastructure for plug-in hybrid and electric vehicles. The IWC focuses on ensuring intercompatibility, safety, and simplicity of grid infrastructure as electrically powered vehicles enter the marketplace. The Electric Power Research Institute (EPRI) is well-positioned to represent its members through support of the IWC and its activities to foster continued adoption of electric transportation technologies.

Approach The IWC will continue to serve the industry as the facilitator of infrastructure review, analysis, and standardization. Project 18.010 will provide support to IWC for the execution of infrastructure analysis that positively affects the commercialization of plug-in hybrid electric vehicles (PHEVs) and battery electric vehicles (BEVs) in the automotive and truck industries. This project also will conduct a representative sample audit of airports and seaports across the United States and prepare a report with recommendations on airport and seaport infrastructure issues that should be addressed by the IWC. The scope of work is as follows:

• Lead utility industry participation in SAE J2293 standards development. • Review related U.S. and international standards (IEEE 1547 and others) and participate in these efforts

on an as-needed basis. • Continue to identify and execute infrastructure projects that address issues, concerns, and standards that

impact PHEV and BEV commercialization.



Impact This project may have the following impacts:

• Standardization of vehicle and stationary charging connection, equipment, and infrastructure to ensure interoperability and the safety of vehicle recharging

• Ensure that new standards facilitate communication between vehicle and grid to support industry needs for off-peak charging and electricity billing and tracking

• Minimize connectivity costs from both the grid and vehicle perspectives

How to Apply Results Results from the IWC analysis will enable clean vehicle technology management teams at funding utilities and their customers to implement connectivity between the grid and electric vehicle (EV) systems. The reports developed will be used by members to ensure that connections are achievable and cost-effective.

2010 Products


Infrastructure Working Council Annual Report: 12/31/10 Technical Report

P18.011 Identification of PHEV Infrastructure Requirements (065240)

Key Research Question Plug-in hybrid vehicle technology development is accelerating within the automotive industry. Existing and new standards are in the process of being updated. Technology is changing rapidly—including the proposed methods of interfacing these vehicles to the grid.

Approach This project will compile the knowledge accumulated from these technology demonstrations into a single document and will update recommendations for plug-in hybrid electric vehicle (PHEV) charging infrastructures. The scope of work is as follows:

• Review and catalogue the PHEV infrastructure issues and concerns regarding grid connectivity • Establish and prioritize a list of actions and recommendations for PHEV infrastructure standards • Develop a scope of work to initiate projects required to address specific PHEV infrastructure actions

Impact • Enable simple and safe connectivity between PHEV systems and the grid • Enable intelligent communication between electric vehicles (EVs) and the grid • Provide guidance to members in preparation for programs to implement EV market penetration

How to Apply Results Utility distribution management will use work papers and planning documents based on PHEV knowledge and prior supplemental infrastructure projects to execute a review of their own infrastructure and to implement a plan for PHEV market penetration.



2010 Products


Requirements of PHEV Infrastructure: 12/31/10 Technical Update

P18.012 Vehicle and Infrastructure Connectivity and Communication (067434)

Key Research Question Communication between plug-in hybrid electric vehicles (PHEVs) and grid infrastructure is the key element to maximizing the value of PHEVs as a connected load. As the market adopts PHEVs, utilities will need a means of communicating with these vehicles to incentivize off-peak charging, tracking, and billing the consumption of electricity as a transportation fuel and to optimize their use as distributed storage devices. There are a number of communication protocols and physical media—both wired and wireless—and their integration in advanced metering and other Smart Grid applications must be well understood.

Approach This project will provide the technical analysis and development work to support a single communication protocol and physical media that can be adopted as a standard by the automotive industry for vehicle-to-grid communication. The technical results of this project will support ongoing standards efforts in Project 18.010 and physical demonstrations in Project 18.013.

Impact • A technical specification for vehicle-to-grid communication • Understanding of technical issues regarding vehicles communicating to grid infrastructure • Development of a viable approach to create a single communication methodology applicable to plug-in

hybrid vehicles from all automotive manufacturers

How to Apply Results Results will be used in advanced planning for the integration of PHEVs into distribution systems. Utilities will receive a technical specification document that can be used to clearly designate requirements to advanced metering infrastructure suppliers, regulators, and other stakeholders.

2010 Products


Infrastructure Communication and Connectivity Requirements for Plug-in Vehicles: 12/31/10 Technical

Update

P18.013 Infrastructure Technology Demonstrations (065241)

Key Research Question This project will conduct field demonstrations of advanced infrastructure connected to prototype plug-in hybrid electric vehicles (PHEVs) to address the issues, concerns, and technologies required to maximize the benefits of PHEV technology as it connects to the utility grid. The project is focused on four major objectives:

• Determining the feasibility of PHEVs as distributed resources for generating electrical power to improve the security and reliability of electrical power distribution



• Defining and testing a communication protocol that would enable PHEVs to communicate with tomorrow’s intelligent grid and smart home

• Validating interoperability between PHEVs and charging stations, charging stations and building emergency medical services (EMS), and building EMS and energy service providers

• Analyzing current urban and rural distribution systems to understand the impacts of PHEV/battery electric vehicle (BEV) charging on the current infrastructure, with recommendations on near-, mid-, and long-term modifications needed to support the merging of transportation and electricity

Approach This project will focus on continued development and testing of the vehicle, battery, and on-board communication systems to ensure potential benefits are maximized when PHEVs are connected to the grid. The scope of work is as follows:

• Review of findings from the 2007 advanced infrastructure connectivity supplemental projects to identify the vehicle-specific issues and concerns to be addressed

• Prepare a project plan that addresses the identified issues and concerns • Establish alliances within the automotive and utility industries to address the issues and concerns • Develop a project plan for 2009 to evaluate the systems required as part of a vehicle and intelligent grid

system

Impact • Increase knowledge about advanced issues of PHEV-grid connectivity • Provide planning information for mid- and long-term conversion to PHEV commercialization • Enable necessary modifications to infrastructure to support anticipated consumer demand

How to Apply Results Distribution managers and fleet operators will receive detailed information on infrastructure impacts, enabling mid- and long-term planning to accommodate PHEV charging and support consumer demand. The knowledge resulting from this project will enable distribution and communication planners to ensure the linkage of electric-drive vehicles to the intelligent grid and smart home through advanced metering systems.

2010 Products


Preliminary Test Protocol for Vehicle-to-Grid Power Systems Testing: 12/31/10 Technical Report

Smart Grid Virtual Program - EPRImydocs.epri.com/docs/Portfolio/PDF/2010_PDU-VP3.pdf · Electric...

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