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IntelliGrid - Program 161

Program Overview

Program Description

Utilities are increasingly deploying advanced monitoring, communications, computing, and information technologies to support smart grid applications such as wide area monitoring and control, integration of bulk or distributed renewable generation, distribution automation, and demand response. Companies face significant challenges when deploying these technologies, including: Selecting technologies that best meet current and future business needs and regulatory requirements,

while minimizing the risk of early obsolescence and vendor lock-in Creating an overall architecture that integrates the many intelligent devices, communications networks,

and enterprise systems to utilize resources and provide information to all users Managing the tremendous amount of data that is generated by the smart grid, converting data into

actionable information and effectively present the information to the people who need to take action Managing a growing network of intelligent devices that have different capabilities and that use different

protocols and data formats in a way that optimizes performance Ensuring that the workforce has the skills necessary to design, operate, and maintain equipment and

systems that use new technologies The IntelliGrid Program will address these challenges by: Tracking federal government and regulatory activities relating to standards, cyber security, and

communications and interpreting the impact that these actions will have on the utility industry Promoting interoperable systems by contributing to the development of key smart grid standards,

assessing emerging standards, conducting interoperability tests of products that implement key standards, and providing information to utilities on how to implement standards

Defining requirements for utility communications networks and assesses key communications technologies

Facilitating smart grid demonstration projects around the world to better understand and advance the use of distributed energy resources in smart grids

Research Value

With the knowledge acquired through this research program, members will have access to information that can help them with: Assistance in how to best 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 systems

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

An understanding of the impact that federal government and regulatory activities relating to standards and communications will have on the utility industry

Utility implementation approaches and results for smart grid technologies and systems Roadmaps for implementing a smart grid An understanding of communications and information system architecture requirements to support a

smart grid

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Electric Power Research Institute 2012 Research Portfolio

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: White papers on utility experience with adopting standards and migrating from one standard to another Reports on lessons learned and best practices when deploying applications Reports on interoperability testing of vendor products to standards such as the Common Information

Model (CIM) and Smart Energy Profile 2.0 (SEP 2.0) Contributions of technical reports to standards development organizations and industry groups

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: Concepts to Enable Advancement of Distributed Energy Resources (1020432) highlights a shift in

approach from using "command and control" to "inform and motivate," which would allow the customer and the grid to interoperate with full transparent, extensible, and scalable interoperability.

Methodological Approach for Estimating the Benefits and Costs of Smart Grid Demonstration Projects (1020342), completed with DOE, presents a framework for estimating the benefits and costs of smart grid demonstration projects and a step-by-step approach for making these estimates.

EPRI Smart Grid Demonstration Initiative: Two Year Update (1021497) describes the progress in EPRI's demonstration project of developing a foundation of tools and references, while performing research to support the advancement of distributed energy resources in large-scale demonstrations.

Accuracy of Digital Electricity Meters (1020908) provides a historical perspective of electromechanical meters and highlights the transition to solid-state models and the factors that influence the perceptions of them in the market today.

Smart Grid Interim Interoperability Roadmap Report: The National Institute of Standards and Technology (NIST) awarded EPRI a contract to engage smart grid stakeholders and develop a draft interim standards roadmap, which NIST has used as a starting point in developing an NIST interim roadmap for smart grid interoperability standards. EPRI technical experts compiled and distilled stakeholder inputs, including technical contributions made at two EPRI-facilitated two-day public workshops.

Current Year Activities

Research results will address near-term needs as well as make contributions that will advance the industry toward open, standards-based systems and devices that are interoperable and secure. Specific objectives include: Migration path for International Electrotechnical Commission (IEC) 61850 implementation and

coordination with CIM, Distributed Network Protocol (DNP), and MultiSpeak (a registered trademark of the National Rural Electric Cooperative Association) standards

Evaluation of open standards and testing of interoperability for end-load management, including SEP 2.0 Development of an open, standards-based platform for disseminating and visualizing operational data to

mobile devices Tracking and analysis of smart grid regulation and technology trends CIM training and 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

Estimated 2012 Program Funding

$3.9M

Program Manager

Donald Von Dollen, 650-855-2210, [email protected]

IntelliGrid - Program 161 p. 2


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 technology 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 toward an intelligent grid. Every activity is designed to enhance access to research results so that both continuing and new funders of the IntelliGrid Program will find value. IntelliGrid Program members include utilities, vendors, public organizations, and other research organizations. One of the important objectives of this project set is to enhance coordination across all the different research organizations and industry organizations (for example, the U.S. Department of Energy [DOE], the Institute of Electrical and Electronics Engineers [IEEE] Intelligent Systems Coordinating Committee, and European smart grid 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: Tracking activities relating to the smart grid at NIST, FERC, and

the FCC and providing an analysis of these activities Tracking communications technology developments Organizing a smart grid roadmap workshop for sharing

information related to roadmaps for smart grid implementation Conducting analytical studies on topics that will influence the

deployment of smart grids Reporting on industry-wide smart grid activities via an update to

previous reports Coordinating with international smart grid initiatives and reporting

lessons learned to members

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

Key Research Question

Utilities are increasingly deploying advanced monitoring, communications, computing, and information technologies to support smart grid applications such as wide area monitoring and control, integration of bulk or distributed renewable generation, distribution automation, and demand response. There are activities underway at the National Institute of Standards and Technology (NIST), the Federal Energy Regulatory Commission (FERC), the Federal Communications Commission (FCC), and various standards bodies that could have an impact on these deployments. Communications technology is advancing rapidly. These advances will impact current and future smart grid deployments. Utilities need to be aware of industry, regulatory, and technology trends and the impact that they may have on current and future smart grid deployments. The objectives of this project are to: Track industry and government activities, and provide an analysis on how these activities could impact

utilities and how they can best prepare. Track communications technology advances and their impact on utility applications.



Make contributions of EPRI results to relevant industry and government efforts, such as the NIST Smart Grid Interoperability Panel (SGIP), Open SG, and standards development activities.

Provide a forum for utilities that are developing or implementing smart grid roadmaps to share experiences and lessons learned.

Facilitate technology transfer of EPRI-developed R&D through webcasts and white papers.

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, DOE, various standards organizations, and internationally. This project tracks relevant activities at NIST, FERC, FCC, and standards bodies to provide funders with information and analysis. The project also 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

Many utilities do not have the resources to actively participate in industry activities. This project will provide tracking information on those activities. The analysis of the impact that these activities will have on utilities will help utilities in planning their smart grid deployments and will help minimize the risk when selecting technologies. The smart grid roadmap interest group and workshop will provide lessons learned and experiences from a large group of utilities.

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 information, analysis, and lessons learned that will come out of this project. Results will be presented through webcasts, workshops, and white papers.

2012 Products

Product Title & Description Planned

Completion Date Product Type

NIST Smart Grid Standards Tracking, Analysis and Contribution: Monthly webcasts will focus on the analysis of the NIST SGIP activities. Specifically, how the Priority Action Plans (PAP) activities will impact utilities. A different PAP will be addressed each month. White papers will be developed on the topic of adoption of standards by the industry.

12/31/12 Technical Update

Smart Grid Informational Webcasts: Monthly webcasts on topics of interest relating to smart grid policy, deployment, technology, and business cases

12/31/12 Technical Resource

Smart Grid Roadmap Interest Group and Workshop: The smart grid roadmap interest group and workshop brings together the people who have the responsibility for developing their company’s smart grid roadmap to share lessons learned and experiences.

12/31/12 Workshop, Training, or Conference

Analytical Studies on Topics that Impact the Deployment of Smart Grid Applications: A series of white papers on topics that are selected by the members at the beginning of the year. These papers will address urgent topics that will impact the deployment of smart grid applications.


Communications Technology Tracking and Analysis: Regular research updates on the development of communications technology to support smart grid applications




PS161B Infrastructure for Intelligent Transmission Systems (063437)


The Infrastructure for Intelligent Transmission Systems project set focuses on the communications and information technology (IT) infrastructure needed to close technology gaps and achieve the interoperability required to support the transmission system of the future. It also addresses the migration strategies that will be essential to the successful transition from the systems of today to the systems of the future. The transmission system is already using extensive and sophisticated instrumentation and applications. This project set will assess additional possible communications needs for real-time applications and will 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 Applying the Common Information Model (CIM) for Information Integration of Transmission Applications

This project develops requirements for integrating Smarter Transmission applications within industry-defined areas of interest. These requirements serve as the basis for the development of data and device models for demonstration solutions such as The Standards-Based Integration Specification and Network Model Manager and Repository. This, in turn, validates the readiness of the CIM and IEC61850 standards and contributes to standards activities within key industry organizations such as IEC, IEEE, NIST and others. Additionally, this project provides educational resources to utilities interested in applying the CIM.

P161.015 Smarter Transmission System Implementation Strategies

This project will create strategies to assist utilities in migrating existing legacy transmission communications technologies to an IEC 61850 based communications infrastructure. The project will include Smart Grid Substation Lab simulations and lessons learned from real migrations if available.

P161.003 Applying the Common Information Model (CIM) for Information Integration of Transmission Applications (063286)


Robust and highly integrated communications and computing infrastructures will be needed to create a smarter transmission grid. These infrastructures need to facilitate interoperability across vendor equipment and applications deployed throughout 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) represented by IEC 61968 and IEC 61970 provides a common language for integrating applications across the enterprise and is a foundation standard for smart grids. IEC 61850 and the Internet Protocol (IP) also are key standards.

Approach

This project will develop requirements and explore solutions for integrating applications that are key to the deployment of smarter transmission technologies. Examples of these applications include the Asset Health Center, the Network Model Manager and Repository, Substation Intelligent Electronic Device (IED) Data Utilities, or other industry-suggested applications that align with the smarter transmission direction. This project will be utility driven and will move beyond the theoretical world into the practical world, focusing on supporting successful deployments of the CIM and IEC 61850 standards. Any identified issues will be presented to the appropriate standards body for consideration during their review cycle. A central part of this project is the application of the existing portions of the standards and demonstration of the value to the business enterprise that will create the necessary momentum to continue the path forward.



In addition to the focus on the practical application of standards development, this project will also provide information and education on the CIM to utilities considering deployment of a CIM-based solution.

Impact

This project could have the following impacts: Demonstrate true interoperability, and enable integration of applications across the enterprise via systems

built to open standards. Verify standards that enable open enterprise applications, and utilize this openness across utilities. Enable improved life-cycle savings by demonstrating the value of “end-to-end” business process

streamlining of data management.


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. Results from this project will help members plan for future requirements involving upgrades to their energy management systems, substation data managers, etc., and for the procurement of next-generation transmission operations equipment such as relays and protection equipment.

2012 Products



The Standards Based Integration Specification: This product brings together work from several areas to demonstrate the potential value of correlating multiple sources of asset-related information so that intelligent decisions regarding the operation and maintenance of assets can be made. For example, EPRI has developed algorithms to assess the health of large power transformers. This assessment, while effective, is somewhat static in its application. Through the efforts of this product, a real-time assessment process will be demonstrated that integrates necessary information from applicable systems and provides the appropriate information to utility staff across the enterprise. Additionally, there are data from various asset health sensors typically installed to remotely collect data from major pieces of equipment across the transmission system. This sensor data, translated into IEC 61850, could be integrated into a CIM-based integration environment and provided on a near real-time basis to appropriate field personnel, equipment experts, and asset managers to perform forensic analysis and enhance their asset-management strategies (such as repair or replace, life extension, sparing strategies, maintenance strategies, and specification for replacement equipment) and to grid operators to enhance their decision making. The CIM and 61850 standard interfaces required by this product are substantially complete in their design, but have not yet been field tested. Any identified issues will be presented to the appropriate standards body for consideration during their review cycle.


Network Model Manager and Repository: The duplication of effort in maintaining multiple transmission system network models in disparate applications is a challenge facing utilities that will grow more complex as the number of applications dealing with network models increases. Applications supporting substation automation configuration, protection scheme definitions, and interfaces to distribution system models will be added to the current planning applications and EMS systems that contain transmission system network models. This product focuses on the definition of requirements and a solution demonstration for a Network Model Manager and Repository that will support the life cycle of the transmission network (from planning through construction, configuration, and commissioning to reconfiguration and







retirement). A Network Model Manager and Repository would be used to maintain transmission models used by all other applications in EPRI’s Smart Grid Substation Lab. Data export would use CIM (61970 and 61968) defined interfaces and would utilize both “flat file XML” and integration bus approaches. Any identified issues will be presented to the appropriate standards body for consideration during their review cycle.

CIM Education: This product will provide support for a variety of CIM users group (CIMug) activities including meeting summaries and training materials. It also provides a venue for complementary CIM training; for access to reference information about the CIM standards; and for learning about CIM deployment experiences, CIM-based products, and implementation resources.


Future Year Products



The Standards Based Integration Specification: This product will continue to refine the efforts of bringing together work from several areas to demonstrate the potential value of correlating multiple sources of asset-related information so that intelligent decisions regarding the operation and maintenance of assets can be made. For example, EPRI has developed algorithms to assess the health of large power transformers. This assessment, while effective, is somewhat static in its application. Through the efforts of this project, a real-time assessment process will be demonstrated that integrates necessary information from applicable systems and provides the appropriate information to utility staff across the enterprise. Additionally, there are data from various asset health sensors typically installed to remotely collect data from major pieces of equipment across the transmission system. This sensor data, translated into IEC 61850, could be integrated into a CIM-based integration environment and provided on a near real-time basis to appropriate field personnel, equipment experts, and asset managers to perform forensic analysis and to enhance their asset-management strategies (such as repair or replace, life extension, sparing strategies, maintenance strategies, and specification for replacement equipment) and to grid operators to enhance their decision making. The CIM and 61850 standard interfaces required by this project are substantially complete in their design, but have not yet been field tested. Any identified issues will be presented to the appropriate standards body for consideration during their review cycle.


Network Model Manager and Repository: The product will continue the effort started in 2012 to reduce the duplication of effort in maintaining multiple transmission system network models in disparate applications. This is a challenge facing utilities that will grow more complex as the number of applications dealing with network models increases. Applications supporting substation automation configuration, protection scheme definitions, and interfaces to distribution system models will be added to the current planning applications and energy management systems that contain transmission system network models. This product focuses on the definition of requirements and a solution demonstration for a Network Model Manager and Repository that will support the life cycle of the transmission network (from planning through construction, configuration, and commissioning to reconfiguration and retirement). A Network Model Manager and Repository would be used to maintain transmission models used by all other applications in EPRI’s Smart Grid Substation Lab. Data export would use CIM (61970 and 61968) defined






interfaces and would utilize both “flat file XML” and integration bus approaches. Any identified issues will be presented to the appropriate standards body for consideration during their review cycle.

CIM Education: This product will continue to provide support for a variety of CIM users group (CIMug) activities including meeting summaries and training materials. It also provides a venue for complementary CIM training; for access to reference information about the CIM standards; and for learning about CIM deployment experiences, CIM-based products, and implementation resources.


P161.015 Smarter Transmission System Implementation Strategies (069294)


The recent acceleration of the implementation toward a smarter transmission grid 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 technology will not be easy. 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, the benefits and disadvantages to different implementation strategies are uncertain. For example, should a company implement by voltage class, geographic region, or some other approach What are the pros and cons of the various approaches

Approach

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

Impact

This project could have these impacts: Members will be able to better understand the pros and cons of various implementation methods and the

challenges associated with each. Members will be able to plan, design, develop, and execute a better smart grid implementation strategy

for their companies and better understand the benefits achieved using different approaches.


Members will be able to apply the knowledge gained from the project products to designing and implementing smart grid technologies effectively through the transition from legacy environments to smart grid.

2012 Products



Synchrophasor Communication Infrastructure: This project will continue the process started in 2011 to evaluate the benefits of various approaches to wide-area communications used for the transport of synchrophasor measurements. This will include both transport within the utility as well as outside the utility to external entities such as RTOs and ISOs. The project will also assess the NASPInet concept developed by the North American Synchrophasors Initiative's Data and Network Management Task Team being implemented by the American Recovery and Reinvestment Act (ARRA) award winners. This






may include demonstration of the NASPInet concepts within EPRI's Smart Grid Laboratory as appropriate and evaluation of the tactical development of the various components.

IEC 61850 Implementation: Implementing IEC 61850 within a utility is not necessarily easy or straightforward. While transitioning electromechanical relays to microprocessors is a relatively straightforward process, taking advantage of the entire suite of benefits enabled by IEC 61850 enabled devices is another matter altogether. What approach to the transition is most beneficial At what point should a utility consider adoption of the process bus, object models data, communication protocol transition, and more Each of these features brings benefits that need to be carefully considered within the context of the rest of the substation, control center, and enterprise. In this project, EPRI will evaluate and assess various implementation strategies from the perspective of "how to deal with all the IED data" and the benefits and drawbacks of various approaches applied in the field. The project will also look at what tools exist to assist in the management of the data.


Transition from Legacy Protocols to IEC61850: Implementation of IEC 61850 within a utility is not necessarily easy or straightforward. During the transition, it is usually necessary to operate with both legacy protocols and the new IEC protocol simultaneously within a substation environment. This project will look at the implication of this dual-protocol mode and offer guidance as to successful approaches to consider during the transition.


Future Year Products



Synchrophasor Communication Infrastructure: This project will wrap up the process started in 2011 to evaluate the benefits of various approaches to wide-area communications used for the transport of synchrophasor measurements. This will include both transport within the utility as well as outside the utility to external entities such as regional transmission organizations (RTOs) and independent system operators (ISOs). The project will perform a final assessment of the NASPInet concept developed by the North American Synchrophasors Initiative's Data and Network Management Task Team as implemented by the ARRA award winners.


IEC 61850 Implementation: Implementing IEC 61850 within a utility is not necessarily easy or straightforward. While transitioning electromechanical relays to microprocessors is a relatively straightforward process, taking advantage of the entire suite of benefits enabled by IEC 61850 enabled devices is another matter altogether. What approach to the transition is most beneficial must be considered. At what point should a utility consider adoption of the process bus, object models data, communication protocol transition, and more Each of these features brings benefits that need to be carefully considered within the context of the rest of the substation, control center, and enterprise. In this project, EPRI will evaluate and assess various implementation strategies from the perspective of "how to deal with all the networked IEDs" and the benefits and drawbacks to various approaches applied in the field. The project will also look at what tools exist to assist in the management of the IEDs.






Transition from Legacy Protocols to IEC61850: Implementation of IEC 61850 within a utility is not necessarily easy or straightforward. During the transition, it is usually necessary to operate with both legacy protocols and the new IEC 61850 protocol simultaneously within a substation environment. This project will look at the implication of this dual-protocol mode and offer guidance as to successful approaches to consider to actually phase out the legacy protocol at the substation.


PS161C Infrastructure for Intelligent Distribution Systems (063438)


The Infrastructure for Intelligent Distribution Systems project set focuses on the communications and IT infrastructure necessary to achieve fully integrated distribution operations. The research is focused on obtaining, sharing, using, and updating information that is critical for distribution applications. The standards for back-office application integration and communications are evolving rapidly. This project set seeks to track this evolution and provide value to the participating members with analysis and ancillary information in the form of training, tools, and media. The project set further seeks to utilize back-office standards and communications protocols to provide near-term value to utilities in the form of tools and techniques for using information.


P161.005 Enterprise Information Sharing for Smart Distribution Applications

This project supports cost-effective utility integration of distribution applications by advancing CIM-based design, implementation, and interoperability testing. The project will focus on tracking CIM development progress and developing guidelines for the application of the standards to real back-office integration.

P161.018 Geospatial Information System (GIS) Data Quality Improvement

The project intends to provide utilities with an adaptable template and set of tools that can be used to assess, improve, and ensure ongoing GIS data quality.

P161.019 Field Force Data Visualization of Operational Data

This project is to develop a polished mobile data access application using modern web standards (for example, HTML5) in conjunction with modern mobile operating systems (for example, Apple iOS4 or Google Android) to create an application to merge data from disparate systems with real-time video to create a user interface for the visualization and dissemination of operational data.

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


Utilities need Common Information Model- (CIM-) based architecture, infrastructure, applications, and interoperability testing to support efficient cost-effective enterprise integration of distribution applications. This project focuses on tracking CIM development progress and developing guidelines for the application of the standards to real back-office integration.

Approach

This project will continue to support interoperability tests of the CIM for distribution messages and report on the results. The project will also monitor the progress of the CIM for distribution standards as a whole, and will assess the progress and convey to the funders the impact of the CIM development on their day-to-day business


functions. This project will survey the state of the industry of CIM integration and will provide guidance as to the viability of implementing parts of the CIM or CIM-like semantic models.

Impact

IT and operations personnel can expect to gain a deeper knowledge of the problems they may face in implementing CIM or any other back-office standard. These individuals will gain knowledge of solutions to problems that they may face by learning from other efforts.


Distribution system architects, application developers, and information technology managers can use the knowledge and products produced in this project for designing, developing, testing, and maintaining distribution applications.

2012 Products



Update on CIM for Distribution Development and Testing Activities for 2012: A compendium of the activities involved in the development and testing of IEC 61968 and MultiSpeak®.


Application of the CIM in Distribution Enterprise Applications: Case studies and training in the use of the CIM, using the experience gained by members in overcoming real problems.

12/31/12 Technical Report

P161.018 Geospatial Information System (GIS) Data Quality Improvement (072073)


Utilities continuously struggle with the quality of geospatial information system (GIS) data. With the advent of the smart grid and advanced metering infrastructure, utilities are facing increased pressure to resolve data quality issues. GIS quality issues are primarily related to: Gaps. For example, certain key data are missing. Redundancies with other systems. For example, data are captured in many systems, and they are

inconsistent or require duplicate data entry to update. Lack of currency with system “as-built.” For example, there is untimely work order completion/backlog. Inaccuracies with the field. For example, The GIS has data, but does not represent the actual system in

the field. Inaccurate or unavailable land base. For example, there are varying degrees of accuracy of land-based

data based on the source. Customer to transformer connectivity by phase is in doubt. The GIS model itself allows for “bad” data.

The project intends to provide utilities with an adaptable template and set of tools that can be used to assess, improve, and ensure ongoing GIS data quality.

Approach

With the advent of advanced metering infrastructure (AMI), distribution management systems (DMS), distributed energy resources (DERs), and the smart grid, distribution companies can no longer ignore poor data quality. In many cases, utilities are finding that their capital-intensive smart grid investments are not yielding anticipated benefits simply because the utility does not have an adequately accurate representation of the distribution



system. In more extreme cases, the safety of employees and the public has been compromised due to misrepresented facilities in the GIS. Utilities need a robust and reliable model from customer to transformer through protective devices to substation by phase that is accurate and timely. This project will do the following for participants: Provide a means of performing a self-assessment of data quality, what is needed, how accurate it should

be, and where they are in comparison to peers. Identify processes, strategies, tactics, and tools to resolve existing data challenges. Provide processes and methods to ensure that data quality continues to improve. Offer software tools specific to key utility GISs to assess, correct, and ensure ongoing data quality.

The project intends to provide utilities with an adaptable template and set of tools that can be used to assess, improve, and ensure ongoing data quality. The project will serve as a seminal reference to data quality for utilities. Following the recommendations of the report and using the associated tools will provide utilities with a strong foundation to ensure data quality on an ongoing basis.

Impact

The GIS acts as the “hub” around which the engineering and operations applications revolve. In an ideal world, the GIS feeds critical information to the other applications in the distribution environment. This ideal has been hampered by the lack of complete and accurate data. By cleaning up the data in the GIS, a utility that relies on that data could expect immediate improvement in the accuracy of the Outage Management System (OMS), power systems modeling, DMS, and other mission-critical applications.


IT and engineering departments will be able to take the findings of this work and apply them to their business processes. The results of this research will be written as a series of actionable steps that, taken individually or collectively should be able to mitigate the GIS data issues that utilities actually face.

2012 Products



Geospatial Information System (GIS) Data Improvement: Processes, strategies, tactics, and tools to resolve existing GIS data challenges and help prevent future issues.

12/31/12 Technical Report

P161.019 Field Force Data Visualization of Operational Data (072074)


Utilities continuously struggle to justify their investment in information technology. Inaccurate data, lack of standards, and vendor “lock-in” all prevent the cost-effective use of their technology investment. Data exist in disparate systems, inaccessible to the operations center and field personnel. Mobile computer power is wasted, displaying out of date or irrelevant data. Data are not used because they are not available in the vendor-specific software that is loaded on the mobile computing device. In short, the investment made in IT by utilities has yet to reach its full potential. To fully realize the promised potential, a standards-based IT architecture is needed for the visualization of data and the use of visual data in the decision-making process. In that respect, what is needed is: A generic data viewer that can work with any data, but that can be easily customized/configured for

particular types of data



Seamless integration of data systems so the user is not aware that they are pulling data from multiple systems

The ability to add new systems on the fly to increase the available data A polished, modern smart user interface (UI) that utilizes all the advances made in graphical user

interfaces that have been developed in other industries A standard graphics format so the user has access to a graphical editor that works for multiple types of

data Multi-platform functionality so that it works on a computer, phone, tablet, etc.

This project is to develop a polished mobile data-access application using modern web standards (for example, HTML5) in conjunction with modern mobile operating systems (for example, Apple iOS4 or Google Android) to create an application to merge data from disparate systems with real-time video to create a user interface for the visualization and dissemination of operational data.

Approach

As utilities begin to integrate systems that previously operated with little or no data interconnection, it becomes easier to link together related data. This can result in powerful diagnostic and management tools that use this interconnected data so that engineers can better understand the network and the context of any unexpected behavior. To show the power of data integration and modern human-computer interfaces, it is proposed that emerging technologies from the mobile computing field be used to create a Mobile Integrated Data Access Platform. A key use-case is to allow a lineman or engineer out in the field to be able to identify all relevant data for the network at their current location. From this interface they could navigate through all the data for a transformer; identify its location in the GIS and a single-line diagram; be shown the down-stream circuit on a map; and trace into its asset history, maintenance history, manufacturer information and catalogue, etc. Upon arriving in a street, the GIS and magnetometer (compass) built into a tablet would identify the crew’s location, and holding up the tablet would allow them to see in real time a video of the area with data on the view, on a single line diagram, and on the map. The lineman could query as to the state of a switch, identify premises with outages, automatically tag devices, etc. This would all be possible with a properly integrated data environment and accurate GIS data.

Impact

This project is a first step in utilizing the power of the Common Information Model (CIM) with a lightweight graphical interface. A utility will be able to combine the field force functionality of GIS, OMS, Asset Management, and Work Management. The field device of the future could provide the lineman with one interface on an inexpensive platform to perform all their necessary functions. Operational efficiencies could be expected along with the potential for lower IT hardware costs, fewer application seat licenses, and an overall lower cost of ownership of the field force platform.


Distribution system architects, applications developers, and information technology managers can have a powerful new tool to deploy to the field force to enhance capability and lower costs.

2012 Products



Mobile Integrated Data Access Platform: Software proof of concept to leverage CIM messaging and combine multi-application functionality in the field.

12/31/12 Software




PS161D Infrastructure and Technology for Customer Integration, Including Metering and Demand Response (063439)


This project set addresses the communication integration of customers with the utility, including advanced metering, load management, distributed energy resources (DERs) such as photovoltaic (PV) and battery storage, and other general information exchange. In the past, the customer interface was primarily limited to monthly metering, but advances in communication, measurement, and control technologies have transformed the landscape of customer integration, bringing many new possibilities but also many challenges. This project set addresses these challenges by evaluating technologies and architectures, identifying standards gaps and accelerating development, identifying lessons learned and best practices, and demonstrating capabilities in both laboratory and field environments.


P161.016 Advanced Metering Systems: Technologies, Architectures, and Life Cycle Management

The project will conduct research to advance the state of the technology for metering communication systems, including functionality, performance, and employment of open standards. Ancillary uses, such as DER management and distribution controls, will also be evaluated. Best practices for life cycle management will be tracked and reported.

P161.017 Load Management and DER Integration Systems: Technologies, Architectures, and Life Cycle Management

This project will conduct research regarding the communication systems and protocols used for end-load and DER monitoring and management, including residential, commercial and industrial domains. Emphasis areas will include acceleration and evaluation of open standards, and testing for interoperability.

P161.016 Advanced Metering Systems: Technologies, Architectures, and Life Cycle Management (072075)


Utilities are deploying advanced metering infrastructure (AMI) in their service territories, creating two-way communication networks reaching customer premises. Although metering is the primary application of AMI, the systems are generally viewed as being multi-purpose, sometimes supporting demand response, distribution controls, and renewables integration. Presently, there are many of providers of AMI systems, employing a wide range of technologies that include power-line communication, wireless, and wired broadband. Due to a lack of standards at many levels, these systems are mostly proprietary, and utilities are locked in to a particular vendor once they begin to deploy. AMI is evolving rapidly, with providers working to stay in step with changing utility needs and the availability of existing public infrastructure expanding. For most utilities, their next AMI system may bear little resemblance to their present system. Objective evaluation of these systems is needed, understanding the potential for the different architectures to support the range of applications. Acceleration of standards development is also needed in order to improve the interoperability of systems and to foster competition by enabling multiple sources of supply. The project will conduct research to advance the state of the technology for metering communication systems, including functionality, performance, and employment of open standards. Ancillary uses, such as distributed energy resources (DER) management and distribution controls, will also be evaluated. Best practices for life cycle management will be tracked and reported.


Approach

This project will closely coordinate with others within EPRI and throughout the utility industry. New applications and requirements identified in application areas, such as electric transportation, storage and renewables integration, advanced distribution, and demand response, will feed into the work of this project. Specific demonstration projects will be collaboratively conducted and results shared. This project will work with participating utilities to perform evaluations and to conduct testing of AMI architectures and protocols and will document the results in EPRI technical reports. Industry contributions will be made with the goal of stimulating or accelerating the development of open standards by identifying gaps and recommending solutions. The project will seek to identify best practices for life cycle management of AMI technologies, studying the design, deployment, operation and end-of-life issues to reduce the total cost of ownership for utilities and to maximize the benefits to customers.

Impact

Members will contribute to establishing a long-term industry vision for AMI, providing valuable input to system providers as to the nature of next-generation products that will be needed and contributions to standards bodies regarding gaps and needs for the future. An understanding of outside influences in the 10-year horizon, including technology advancements, infrastructure availability, third-party applications, and evolving customer expectations, will help to shape the vision. This vision will serve as a foundation for a strategic plan that will help guide research in the IntelliGrid rogram going forward. Standards organizations (for example, IEC, ISO, ANSI, and NIST) may benefit from the results of this project.


Members will gain insight into the range of advanced metering technologies being offered, the capabilities afforded by each, and the system uses being considered by other utilities. These insights will help members in executing their own assessment of various communication networks and in planning what uses, in addition to metering, might be supported by their AMI. Sharing of lessons learned will aid member utilities in developing their own processes and will enable the compilation of best practices regarding system architecture, ancillary system uses, deployment, operations, upgradeability, and transition to next-generation systems.

2012 Products



Secure and Cost Effective Sub Metering: Driven by the sub-metering needs of electric transportation and distributed photovoltaics, this project will assess options for secure and cost-effective sub-metering. This will be a multi-phase undertaking.


Open Systems-Based Advanced Metering: Building on supplemental activity started in 2011, this multi-year project will work to identify methods, standards, and specifications leading to AMI systems free of vendor lock-in. Phase 1 will include an analysis of existing and emerging standards on which open systems can be built. The work will include extensive coordination with industry organizations, including NIST and UCAI OpenSG.




P161.017 Load Management and DER Integration Systems: Technologies, Architectures, and Life Cycle Management (072076)


With challenges in bringing new generation online, both load management and distributed generation resources have become increasingly important to utilities. Load management exists in many forms, including variable pricing programs and direct load control; and it serves many uses, including load shifting for economic purposes and fast curtailment for emergency reserves. Distributed generation includes both utility- and customer-owned PV and battery storage systems. Utilities are employing a wide range of communication architectures to facilitate their load management needs. All systems involve some form of a wide-area communication system used to reach customer premises. These include systems that may be one-way or two-way, public or private, wired or wireless. Some systems also include a secondary in-premise network, such as a building automation system or home area network, and may or may not involve an energy management console. At all levels, load management systems employ diverse technologies, many of which are evolving rapidly, both in terms of the physical communication devices and the protocols they transport. Different architectures have different capabilities and, as a result, may be more or less suited for a given use. Research is needed to better understand the capabilities and limitations of various communication architectures. Standards are needed to simplify and reduce the cost of establishing connectivity with end devices. At the furthest reach or “edge” of the utility’s communication system, interoperability with end devices and the ability to accommodate evolution of customer equipment is critical. Improved understanding of customer preferences regarding connectivity and control is crucial to increasing enrollment and continuance in load management programs going forward. This project will conduct research regarding the communication systems and protocols used for end-load management, including residential, commercial, and industrial domains. Emphasis areas will include acceleration and evaluation of open standards and testing for interoperability.

Approach

The project will perform evaluation and testing of communication architectures, technologies, and protocols employed for load management and integration of distributed energy resources. Activities will be carried -out in coordination with other industry activities, including those of NIST, IEEE, and Open SG, avoiding overlap and making contributions where possible. Analysis and interoperability testing of emerging protocols, such as smart energy profile (SEP) and OpenADR will be conducted and results contributed to the appropriate organizations to help accelerate and mature their work. Forward-looking research elements will identify and demonstrate new applications, including integration of intermittent renewables, charging support of electric vehicles, and value-adding ancillary services such as dynamic grid stabilization and voltage regulation.

Impact

Participants will benefit from neutral evaluations of the architectures, technologies, and protocols involved with load management in the industrial, commercial, and residential domains. Findings will be used to provide valuable input to various end-device manufacturing groups such as American Household Appliance Manufacturers (AHAM), Air Conditioning, Heating and Refrigeration Institute (AHRI) and American Society of Heating, Refrigeration and Air Conditioning (ASHRAE). This relationship will foster improved understanding of utility demand-response needs and end-device capabilities. Where applicable, research results will be contributed to standards organizations to help improve, expand, and mature the standards that are critical to load management and the general utility/customer interface.





Members will have access to assessments, guidelines, and evaluation tools to aid in their load management and distributed resource systems design and technology selection processes. Understanding of the state of present and planned standards will assist members in working with product providers, leading to more open, interoperable systems.

2012 Products



Modular Communication Interface for Residential Devices: Industry Assessment: This project will perform an assessment of global efforts to define standard modular interfaces for residential devices. It will gauge standards progress, maturity, and stakeholder support to provide insight into this architectural possibility, its limitations, and potential benefits.


Standard Interfaces for Smart Building Integration: This project will investigate the methods and standards by which utilities may integrate smart buildings into their distribution systems. The work will include a summary of related activities, NIST PAPs, and current activities in standards groups in addition to an assessment of the market penetration of various protocols, and will provide an overall reference guide to smart building integration.


Smart Energy Profile 2.0 Device Compliance: This project will build upon supplemental project activity started in 2011. It will expand the capabilities of the software test harness to allow remote evaluation of products against a reference SEP 2.0 implementation. Results will be provided to SEP 2.0 protocol developers as well as to product manufacturers to aid in finding ambiguities in the specification and to accelerate its overall development.

12/30/12 Technical Resource



Supplemental Projects

Smart Grid Roadmap Development (072077)

Background, Objectives, and New Learnings

A smart grid merges communications and information technology with the power system infrastructure to achieve objectives such as: Extracting additional capacity from the existing infrastructure through peak load management Reducing costs through advanced metering infrastructure Maximizing transmission throughput through wide area measurement and control using phasor

measurement techniques Increasing reliability through on-line health monitoring of key components

Smart grid development is usually different for each utility. Approaches are influenced by regulatory policy and business drivers and the mix of technologies that a company has currently installed. Therefore, it becomes necessary for each utility to develop a Smart Grid Roadmap that defines the applications, technologies, policies, practices, and priorities that they should implement. EPRI has been helping utilities determine their path through the smart grid by applying a disciplined methodology developed early in the IntelliGrid program. This process, when applied to the task of uncovering which smart grid applications should be implemented by a utility over time to maximize their value, is the core of EPRI’s Smart Grid Roadmap program. A roadmap developed in this project as the final deliverable will be specific to the requirements and existing infrastructure, but will also contribute to more general industry infrastructure and technology requirements. Generic versions of selected use cases and roadmap development procedures will be available for the collaborative effort. The knowledge is being incorporated into the EPRI R&D programs. The roadmap for migration to an intelligent grid is an integral part of the Intelligrid Program (P161) and the results of the project will contribute to the use case library that is part of this program. In addition to publication of project results in EPRI research reports, important summaries of the project results will be made available through appropriate industry publications (for example, IEEE journals, IEEE meeting panel sessions, international conferences, etc.).

Project Approach and Summary

The project will produce a customized smart grid roadmap document for the funder that is focused on specific needs, which may be technology or policy related, and priorities and incorporates lessons learned from other roadmap development projects. The resulting roadmap will help the utility accelerate the deployment of projects and system components that, when leveraged as a whole, constitute a smart grid. It also will help the collaboration by sharing another set of lessons learned on the road to the smart grid. The roadmap development project is broken into several tasks, some performed in workshop settings and others carried out by performing analysis and mapping requirements and technologies as necessary. The key activities include information gathering and review as well as an initial project kickoff meeting and workshop with the utility’s smart grid team to familiarize the EPRI team with key personnel and documents provided to the EPRI team. At the core of the roadmap development is the use case preparation and requirements specifications development. Use cases may be retrieved from repositories prepared previously with other utilities or may be



uniquely developed for new participants. Requirements and use cases cover both functional and system management requirements. Once the requirements are set, a range of technologies will be identified that can meet the requirements, and existing technology will be assessed regarding how it can support the utility's strategy, followed by a cost-benefit analysis. The final tasks focus on synthesizing all of the information gathered in order to prepare a draft roadmap document. This will be done in close cooperation with utility personnel. Key elements include priorities and migration options for existing infrastructure as well as technology demonstrations to confirm technology assessment when necessary and definition of an overall implementation plan. This project will benefit the public by providing guidelines and best practices for implementing smart grid applications. This information will optimize the cost and benefit for building the smart grid and reduce the risk of early obsolescence.

Benefits

The activities of this project are intended to deliver the following value for the project participants: Clarity on options available and the impact they may have Understanding of the key smart grid applications and their requirements that will utilize the

communications architecture, and how the applications support the utility's vision and impact existing projects

Possible buy-in throughout the utility for the roadmap through inclusion of key personnel during its creation

Understanding the possible role of existing infrastructure and technologies The public will benefit through the increased understanding of what are the key contributing factors when implementing smart grid applications, as well as their impact on costs and benefits.



Common Information Model (CIM) for Distribution Development (072078)


EPRI has a long history of assisting in the development of the Common Information Model (CIM). The model for development has been for volunteer labor to develop and test the model and resulting messages between systems. The vast scope of the CIM has taxed this method of development to the limit, and it is now time to organize and fund an effort to rapidly develop the standard for broad dissemination. In previously funded EPRI research, standard test procedures were developed for conformity and interoperability. This was done to prepare for this effort, which is a full-scale project to develop standard messages for CIM. This project is part of an EPRI strategy to remove the barriers to vendors providing CIM-compliant applications to the industry. New learnings that will be brought about from this work include the service definitions (messages) needed to achieve basic interoperability for most back-office utility applications. New additions and extensions to the CIM will also be researched and added to the model as warranted.


This project is part of a multi-year strategy to eliminate the barriers for widespread CIM implementation across the entire enterprise. Other projects in this multi-year strategy include developing standard testing procedures for conformity and interoperability testing, developing a CIM primer to reduce the learning curve with the standard and harmonization projects with other standards such as IEC 61850 and MultiSpeak®. The project intends to develop model improvements to IEC 61968 and to create and test new service definitions (messages). The project will coordinate with existing groups, such as OpenSG and IEC TC 57 WG 14 to accomplish this. While developing the model for IEC 61968, the project team will harmonize the new results with IEC 61850, MultiSpeak®, SEP 2.0 and other applicable standards. This project will consist of engaging a team of CIM professionals, dedicated to developing the use cases, messages, and additions to the CIM model to achieve a well-defined set of functionality that will encompass the entire breadth of the CIM.

Benefits

Smart Grid implementations are being hampered by a lack of standards to achieve the necessary level of back-office integration, reduce the cost of application ownership, and achieve the targeted effectiveness. This project will be an organized, funded approach to CIM development following an agreed-upon project plan. The benefits to the public will include: Greater reliability of the electric grid because the development of these standard messages will enable

the back-office integration necessary for the smart grid Lower rates from the utility being able to reduce the cost of application integrations, typically half to three-

quarters of the cost of an application implementation The benefits to the utility include: The distribution back-office applications acting in concert as if they were one system The ability to choose best-of-breed solutions and avoid vendor lock-in

The benefits promised by the smart grid will accrue to the public more rapidly and with less risk with the use of integration standards.



Automated Demand Response and Ancillary Services Demonstration (072079)


This demonstration project will perform research associated with emerging energy price and product messaging-protocol standards to take advantage of ubiquitous low-cost communication infrastructures that may be able to reliably perform automated demand response (DR) and ancillary services or fast DR functions. Internationally recognized standards for DR and ancillary services are a key enabler for the development of commercially available products that have largely been proprietary over the last 30 years. Emerging standards development in this area from the Lawrence Berkeley National Lab, the Organization for the Advancement of Structured Information Standards (OASIS) and the National Institute of Standards and Technology (NIST) have advanced sufficiently so that demonstrations are feasible and products are beginning to become commercially available, but research questions remain about the level of quality of service, reliability, security, and scalability. Other issues include the level of measurement and verification required and an understanding of the load characteristics and how it can meet the ancillary services requirements. In support of the research and advancement of this industry effort, EPRI will contribute to open source versions of Open Automated Demand Response (OpenADR) servers and clients that can be also be used by members of this project.


As a part of a path toward realizing the benefits of OpenADR, this project will focus on the interactions between the utility and a facility while validating OpenADR platforms and systems. Standardized DR automation is an important component of the smart grid to deliver dynamic price signals to achieve economic or reliability objectives. Via a standardized communications data model, utilities and independent system operators (ISOs) can directly interface with building and energy management systems. This project will synchronize with the aforementioned groups to continue progress to automate DR programs and acceptance by a wide range of building and industrial controls manufacturers and device manufacturers. OpenADR is currently defining/developing “Fast DR” capabilities for utilization where shorter cycle times are required to qualify for participating in ancillary service markets. The project seeks to validate fast DR technologies to qualify specific loads for regulating reserve, load following, and spinning reserves by field testing and demonstrations. The intent is to include demonstrations where commercial and industrial (C&I) customers can reduce power usage automatically and quickly to meet the desired target responses reliably and explore how residential products may participate in this market. Year one (2012) will focus on educating members on the “state of the industry” and developing research plans and demonstration protocols for host sites and contributing to open source developments of a Demand Response Automation Server (DRAS) and clients. In Year two (2013) utilities will deploy OpenADR servers and clients, operate the system, and assemble the data that will serve as the basis to analyze the performance and benefit. Small demonstrations for non-host sites will use an EPRI DRAS and clients installed remotely at utility-designated loads and resources. In Year three (2014), EPRI will complete performance and benefit assessment and report results with all project deliverables consolidated in a final “Reference Guide deliverable.

Benefits

This project may help to accelerate development of standards that automatically manage loads and distributed energy resources (DER) for DR and ancillary services requiring faster response. The use of standardized communication protocols for these functions will benefit the public by enabling the use of multiple types of low-



cost ubiquitous communication networks, crossing many utility boundaries from distributor to ISOs and facilitating access to ancillary markets. In just the short development time of OpenADR v1.0, there are now over 60 energy management and control system vendors that offer OpenADR products (clients). This work is expected to increase market participation in the development of devices, eventually, with this functionality directly built in. Electric utilities are expected to gain an understanding of the performance capabilities load types, infrastructure requirements, product availability, and market opportunities associated with the advancement of this smart grid application.



Field Area Network Demonstration Project (072080)


The field area network (FAN) is an essential layer of a utility’s smart grid communications infrastructure. The FAN concept is emerging to be a ubiquitous, high-per-formance, secure, reliable network providing "last mile" backhaul service for distribution supervisory control and data acquisition (SCADA)and advanced metering infrastructure (AMI) systems, as well as network access services for advanced distribution management and automation, distributed energy resources, and any future smart grid applications requiring connectivity from within and beyond the distribution substation. FAN implementation may involve a range of technologies -- from next-generation AMI networks (standards-based narrowband wireless mesh) to broadband options including Industrial Wi-Fi (a registered trademark of the Wi-Fi Alliance) and 3G/4G cellular infrastructure to wired (copper and fiber) networks for connecting major grid nodes, such as substations or wind farms, to the utility’s corporate network or to providing backhaul for wireless infrastructure. These heterogeneous networks will constitute a critical layer in the utility's smart grid network, supporting new applications and eventually migrating legacy operational applications such as distribution SCADA onto the FAN. Yet their reliability. among other characteristics, is not well understood. Therefore, one objective of the project is to establish methods and metrics for assessing the reliability of FAN technologies. A second objective is to work with utilities to incorporate the evaluation of FAN reliability into their FAN field trials, using the metrics and methods established in the project. A third objective is to raise the level of industry knowledge and practice around FAN reliability by publishing the results of FAN trials that the project will support. In particular, research will be published on high-reliability FAN architecture, design principles, and guidelines for implementation and operation. The new knowledge generated by this project is expected to include a reference communications architecture featuring the FAN as a common infrastructure for operational and smart grid applications; and a practical understanding of utility FAN characteristics, with a particular emphasis on models and empirical measures of reliability.


The project approach is modeled on and is very similar to EPRI's Smart Grid Demonstration Initiative. We plan to help utilities design their FAN projects and trials to include a reliability focus and will provide expert assistance in trial or pilot design, execution, and evaluation. The project will include quarterly meetings among project participants for the dissemination of information, experience, and results. We plan to visit host sites to gain hands-on experience in high-reliability FAN design, implementation, and operation. We plan to model the expansion of trials and pilots in to full-scale deployments across project member service territories. In summary, participating utilities will be assisted at every stage of the research, design, piloting, evaluation, and planning of a highly reliable FAN as the centerpiece of their next-generation smart grid infrastructure.

Benefits

Utilities may benefit by collaborating with others, thereby gaining knowledge and experience with a wide variety of approaches to high-reliability FAN design. They may also benefit from the ubiquity, performance, security, extensibility, and reliability of a FAN designed according to the architectures, principles, methods, and metrics that are explored or established in the project. These project features may drive risk and cost out of the utility's FAN planning and deployment process. Society may benefit from higher reliability of energy supply, especially due to a distribution system benefiting from the advanced applications that a FAN can support.



Using Standards to Disperse Field Data Across The Enterprise (072081)


In the 2011 "A Smarter Transmission Grid" white paper that EPRI published, three technology pillars were identified as key to a smarter transmission grid -- grid development and operation, asset lifecycle management, and information and communication technologies (ICT). Specifically, smart grid technologies will demand more analytical horsepower and data-handling capabilities. These data will be large in volume and scattered through the interconnected network. The data sources will be diverse, including equipment health sensors, phasor measurement units (PMUs), intelligent electronic devices (IEDs), and weather sensors, among many other types. Some of these data will be harvested in real time; others will be stored in a historian database. The challenge will be to deliver the information to end users and end-use applications with the specified accuracy, security, and speed. Robust and highly integrated communications and computing infrastructures will be needed to create a smarter transmission grid. These infrastructures need to be interoperable across vendor equipment and throughout 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 and the Internet Protocol (IP) also are key standards. The objective of this work will be to establish a diverse set of data sources that are representative of what may exist within a smarter transmission grid and apply a standards-based integration methodology to determine where the gaps are. Work in 2011 targeted transformer health and was demonstrated within the EPRI Smart Grid Substation Lab using data extracts from utilities and buffered near-real-time data. This work will be continued and expanded through this supplemental project. This approach will provide very specific learning with respect to practical utility-centric integration of a variety of data sources and determine within the established scope the limitations of the current IEC 61850, 61968 and 61970 (CIM) standards from a data object perspective.


This project will continue the work started in 2011, which was related to transformer health data, into the control room. In that project, utility data, both static, such as nameplate, and near real time, such as transformer loadings, were brought into the EPRI Lab, transformed into the applicable standards models, analyzed, and reported back out to the utility. Interest areas may include other substation assets such as circuit breakers, potential transformers, etc., or other well-monitored field assets. In this project, the specific requirements for a utility-specified topic area from the applications specified with the white paper will be developed -- applications such as Asset Health Center, Substation IED Data Utilities, or other industry-suggested applications that align with the smarter transmission grid direction. Through these various utility-specific supplemental projects, an overall data and integration strategy will emerge to provide utilities with an integrated approach to transmission smart grid information management. Unlike previous CIM and IEC 61850 interoperability tests that tended to be bulk data exchange-centric, this project will be utility driven and focus on supporting successful deployments of the CIM and IEC 61850 standards. Any identified issues will be presented to the appropriate standards body for consideration during their review cycle.

Benefits

This project could have the following impacts:

Facilitate true interoperability, and enable integration of applications across the enterprise via systems built to open standards.

Facilitate standards that enable open enterprise applications and leverage this openness across utilities. Provide benefit to the public through higher reliability by including more relevant information in the decisions

process.



Onsite Characterization of RF Exposure from Smart Meters (072509)

Background, Objectives, and New Learnings Deployment of Advanced Metering Infrastructure (AMI) is a core part of many utilities’ investment in the Smart Grid. These systems provide many potential benefits, including reduced meter reading costs, the ability to offer customers a variety of rate options, and remote service connect/disconnect. Some utility customers have expressed concerns regarding the possible exposure levels of Radio Frequency (RF) emissions from wireless AMI systems. This project will perform extensive measurement and characterization of AMI systems in field environments and expects to provide an overall understanding of the operational modes, communications usage, and resulting emissions from smart meters in general. Some AMI systems are highly adaptive, optimizing their behavior through the selection of specific frequencies, power levels, and data routing approaches. In addition, some metering devices may serve as a gateway or access point to upload information from a variety of metering devices. These characteristics make it necessary to assess and characterize these systems in a diversity of field environments in order to understand the range of resulting exposure levels. This project seeks significant new learnings, to provide insights for future systems and research programs. The non-proprietary learnings from this work will be incorporated into the EPRI IntelliGrid program 161.

Project Approach and Summary A detailed characterization of meter function and emissions requires coordination with participating utilities, and possibly manufacturers, performing detailed analysis of the communications and onsite measurements of RF emissions. For each participating utility, the number of residences necessary to provide statistical reliability depends on the expected home-to-home variability in emissions levels, duty cycles, etc. In prior research, EPRI developed an RF field measurement methodology and protocol that will be applied in this project to provide consistent and repeatable results. This protocol makes it possible to conduct comparison among systems of various designs and configurations. It also allows repeat measurements over time to assess stability of findings. The automated assessment process was designed to reduce potential inconvenience to homeowners by reducing the time and complexity needed to perform full-site analysis.

Benefits RF characterizations of multiple systems in multiple home settings will be performed through this project to provide an overall understanding of the characteristics of smart meters, while also providing each participating utility with precise understanding of the RF characteristics of their particular system, including any local settings, configurations or custom use-cases that may affect emissions. With utility approval, EPRI will coordinate with AMI vendors to understand radio transmission details and to access the diagnostic modes of operation that may be needed to support the field measurements.

intelligrid - program 161 - eprimydocs.epri.com/docs/portfolio/pdf/2012_p161.pdf · ·...

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