Grid Planning - Program 40

Transcription

1 Program Description Program Overview Traditional power system planning methods and tools are becoming less effective in today s power system environment. Transmission owners and operators not only need to plan for future demand growth and increasingly uncertain generation portfolios, but also to provide transmission services from the generation resources that include significant portions of variable generation (VG) technologies that are often remote from load centers and have significantly different dynamic behavior from synchronous generation. The challenge of meeting reliability requirements with the changing landscape and increasing levels of uncertainty may necessitate transmission planning to reassess planning criteria and methods. Resource planners are also increasingly challenged as environmental regulation forces the retirement of some conventional generation, supply resources become more variable and uncertain, and distributed and demandside resources become more viable. Resource adequacy may no longer be defined simply by ensuring sufficient capacity, but rather by ensuring capacity that exhibits sufficient flexibility to accommodate more variability and uncertainty from renewable and demand resources. The Electric Power Research Institute's (EPRI's) Grid Planning research program is designed to address the following strategic issues that grid planners must resolve: The increasing uncertainty of future generation and load Increased use of transmission assets and rights of way Evolving generation resource portfolio with non-traditional capabilities Higher reliability standards Increased interregional planning Research Value The mission of EPRI's Grid Planning research program is to support the development and validation of planning study models, planning processes, and frameworks that incorporate reliability and economics, as well as various reliability assessment analytics that will be required to build a reliable and economical transmission grid that integrates and uses an evolving generation mix to supply an increasingly complex load that can also act as a system resource. This is accomplished through a collaborative process in which EPRI works hand-in-hand with its utility and ISO members to identify existing research gaps and associated project needs that would provide value to EPRI members. Once identified, the EPRI Grid Planning team of technical and project management experts works with members and the world s foremost experts in related research areas to structure and conduct specific projects that create value by delivering a combination of products that provide value in the near-term, mid-term, and long-term. Finally, this value is transferred to members through collaborative advisory and task force interactions, workshops and webcasts, and company-specific applications and demonstrations of the developed methods and tools. Approach EPRI's Grid Planning research program delivers value by using the shared experiences and understanding of its utility and independent system operator (ISO) members, in conjunction with the expertise of EPRI's staff and network of top-level contractors, to conduct research projects that lead to innovative methods and tools used by system planners. EPRI's Grid Planning program also engages with external industry standards groups, regulatory agencies, and other research efforts to ensure that the EPRI research program is using broader industry efforts and advancing the state of the art. For research areas where the developed deliverables are of value to EPRI members only if embraced by the larger industry, as is the case for the development of new models that need to be adopted in commercial analysis packages, EPRI works to engage in the industry efforts and share research publicly to drive the 1

2 2 Electric Power Research Institute Portfolio 2014 industry to the desired path agreed on with members. The EPRI research program also strives to provide members with near-term, mid-term, and long-term value. For example, the 2013 Grid Planning research program will continue to develop and validate system component dynamic models already prevalent in the grid, while investigating ways in which resource adequacy planning processes need to change to ensure that the system of the future has enough capacity to meet system demand and has the right kinds of capacity to respond to increasing system variability and uncertainty. Accomplishments The Grid Planning program delivers valuable information that helps its members and the industry in numerous ways. Some examples: Models and Model Validation for Planning Studies: Technical Update ( ): This report documents the ongoing model development and model validation research efforts focusing on flexible ac transmission systems (FACTS) and high-voltage dc (HVDC) devices. Power Plant Parameter Derivation (PPPD) Version 5.0 ( ): The PPPD software uses measured synchronous generator responses to system disturbances to validate the generator, excitation system, and governor control system transient stability models. This tool allows transmission generation owners to perform ongoing model validation as system disturbances occur, and to comply with emerging North American Electric Reliability Corp. (NERC) requirements to periodically validate the generator models. This software is becoming the de facto standard for plant model validation. Comprehensive Load Modeling for System Planning Studies ( ): This technical report covers both measurement-based and component-based load modeling. It also contains a guide to comprehensive load modeling for planning studies and detailed laboratory test results of select load components, such as air conditioners, compact fluorescent lighting, and high-definition televisions. It also includes the results and insights of measurement-based load model parameter derivation modeling research. Transmission Contingency And Reliability Evaluation (TransCARE) ( ): This software provides a comprehensive framework for computing reliability indices for transmission networks, identifying worstcase contingencies and impacts of remedial action schemes, analyzing costs and benefits for various transmission upgrade options, studying the impacts of variable generation on system reliability, and analyzing extreme events, as well as performing NERC compliance studies. Current Year Activities EPRI's Grid Planning research program will focus research on following objectives: Develop and validate static, dynamic, and short-circuit models of system components such as static (VAR) systems and HVDC components that can be used in system planning studies. Develop probabilistic and risk-based planning methods and tools incorporating all sources of system uncertainty. Evaluate fault location algorithms to determine their suitability in estimating fault locations in networked transmission systems. In addition, work will be performed on assessing the potential of using Intelligent Electronic Device (IED) data to validate protection settings and system models. To develop a framework, indices and tools will be developed to determine the adequacy of flexibility in the system and understand their economics. Estimated 2014 Program Funding $2.5M Program Manager Daniel Brooks, , dbrooks@epri.com

3 3 Electric Power Research Institute Portfolio 2014 Summary of Projects Project Number Project Title Description P Model Development, Validation, and Management P Transmission Line Protection Support Tools This project helps system planners improve modeling accuracy and the model management process. The long-term goals of this project are to determine the most suitable algorithms for specifying fault location in networked transmission systems, determine what information can be gleaned from various data sources used in fault location (e.g., digital fault recorder (DFR) records, relay event reports, synchrophasors) to analyze and validate existing relay settings and system modeling parameters, and determine ways to apply IED data to post-mortem event analysis for NERC compliance. P Strategic and Flexible Planning P Reliability & Economic Evaluation of Transmission Alternatives P Incorporation of Risk Analysis into Planning Processes This project is expected to build an industry consensus framework for strategic planning to meet the reliability and economic needs of an increasingly dynamic power system where the need for flexibility to manage variability is important. This project seeks to develop an improved process for assessing interregional transmission projects on a bilateral basis in the timeframe. The project will help members incorporate risk-based planning approaches in the transmission planning process to deal with the challenges posed due to deregulation of energy markets as well as increasing penetration of variable generation and demand-side resources. P Model Development, Validation, and Management (070595) Description Computer simulations of power systems, using device and load models, are essential to the effective planning and reliable operations of the bulk power system. This project will continue previous years' research efforts to collaborate with other industry groups including WECC to develop generic models for HVDC and FACTS type system components, with an objective to complete the model development and the validation for HDVC-related components. Additionally, 2013 research on load model parameter derivation will continue with an update of the Load Model Parameter Derivation (LMPD) software tool. As with the previous models developed through this research project, the publicly available model results will be incorporated into commercially available planning tools such as GE PSLF and Siemens PTI PSS E Approach EPRI intends to reach these objectives through the following efforts: HVDC Model Development and Validation: Continue model developments, including collaboration with industry groups such as the WECC HVDC Task Force and HVDC vendors to develop planning-level models for HVDC. Finalize the stability model of VSC-HVDC, including validation and verification through testing, review and broad feedback.

4 4 Electric Power Research Institute Portfolio 2014 Load Model Development and Validation: Evaluate the feasibility of adding the air conditioning motor stalling features of the WECC complex load model (cmpldw) to the EPRI Load Model Parameter Derivation (LMPD) software tool and explore options for enhancing the LMPD optimization algorithm. Apply LMPD to new and expanded disturbance measurement data sets to develop regional and seasonal load composition trends and find the sensitivity of various model parameters to the initial estimates and bounds of the optimization algorithm. Evaluate the use Trajectory Sensitivity Analysis (TSA) to incorporate consideration of the uncertainty and variation of load characteristics in planning studies to gain a greater understanding of the impact of variations in load-model compositions and other critical parameters to the expected response of the power system. Impact Provide public models for new components and improve existing models that can be adopted by commercial software vendors and supported by equipment suppliers. Improve power system reliability through better modeling and simulation capabilities to more effectively plan the system. Increase the understanding of uncertainty and risk due to variations in load characteristics through applications of trajectory sensitivity analysis. How to Apply Results Similar to the previously developed SVS models, HVDC model development results are expected to be included in commercially available power system simulation software packages so that members can use the EPRI results as part of the standard model libraries of tools already used for planning studies. Load modeling research efforts will be included in the EPRI LMPD software tool so that members can utilize the tool with system-specific disturbance measurement data to determine load compositions for their systems Products Product Title & Description Planned Completion Date Product Type Technical Update of Planning Model Development and Management 12/31/14 Technical Report Load Model Parameter Derivation Tool Version /31/14 Software P Transmission Line Protection Support Tools (070597) Description Data from transmission protection relays and other substation intelligent electronics devices (IEDs) can be used for many applications related to transmission protection. Prior research in this project has focused on using relay data for determining fault location on transmission lines. In 2014, research will focus on using the data from relays and IEDs for validating relay settings and other protection-related models, and to perform post-mortem event analysis. Approach The 2014 research efforts will focus on the following: Develop applications for using relay and IED data for validating relay settings and line constant parameters used in protection models.

5 5 Electric Power Research Institute Portfolio 2014 Impact Identify any limitations of sequence models versus n-phase models and make recommendations accordingly. Evaluate options to use relay and IED data for post-mortem event analysis to meet the following NERC event analysis requirements: PRC Regional Procedure for Analysis of Misoperations of Transmission and Generation Protection Systems PRC-004-1a Analysis and Mitigation of Transmission and Generation Protection System Misoperations PRC-004-2a Analysis and Mitigation of Transmission and Generation Protection System Misoperations PRC-004-WECC-1 Protection System and Remedial Action Scheme Misoperation MOD Development of Interconnection-Specific Steady State System Models Improve reliability through faster restoration times and more accurate relay settings and system models. Reduce line crew search times and associated costs based on improved fault location capability. Apply event data to NERC event analysis and other NERC compliance efforts. How to Apply Results The algorithms developed for validating protection settings and line parameters will be fully described in an EPRI technical update, which can be used to provide insights for protection engineers verifying protection study results. Associated prototype tools will be developed (not delivered until future year) that can be used to automate this process and be applied through supplemental projects. Methods developed to support post-mortem event analysis will also be fully described in the technical update, which can be used to support internal disturbance investigations and NERC compliance Products Product Title & Description Planned Completion Date Use of Relay and Other IED Data for Advanced Protection Analyses 12/31/14 Product Type Technical Update P Strategic and Flexible Planning (070598) Description Flexibility the ability of a system to respond to changes in demand and variable generation (VG) output has become more important in recent years, primarily because of the growth in wind and solar generation as well as changes to the conventional generation mix in many regions. System planning will increasingly need to consider operational issues to ensure that sufficient resources exist to meet changes in net load (demand net of VG). In addition, resource and transmission planning are becoming more intertwined as the location of resources impacts system operation. Properly quantifying the needs and sources of flexibility for a system allows its inclusion into the planning process. In systems with high levels of production variability and uncertainty, flexibility will be required to meet reliability targets by enabling the system to respond effectively to load or generation changes and to reduce the cost impacts of integrating large amounts of VG. The need for flexibility must be balanced with the expensive nature of many highly flexible resources. The long-term objective of this project is to develop planning processes and tools to ensure that systems are designed to facilitate long-term strategic energy objectives in the most economical and reliable manner. Prior research in this project developed a flexibility assessment framework, including proposed new flexibility metrics, and quantified the level of flexibility to be expected from the traditional resource.

6 6 Electric Power Research Institute Portfolio 2014 Approach In 2014, EPRI will seek to develop pragmatic processes to integrate resource and transmission evaluations in a long-term flexibility assessment tool that considers flexible resources such as distributed generation, demand response, and energy storage in future resource adequacy planning. Tools will be provided to allow system planners to define the flexibility needs of the system and verify how various options of generation and transmission resources can meet the requirement. The developed tools will be demonstrated and results will be documented in case studies. It is envisioned that the tool will be able to screen for flexibility using detailed flexibility metrics for generation, transmission, and demand-side resource, helping planners assess the overall flexibility of the system. Impact This project is expected to provide numerous benefits for developing the power system. In particular, it should inform better planning decisions to maximize the value of flexible resources on the grid. Among the key benefits: Metrics to determine the flexibility needs and resources in a system, considering new and existing flexibility resources as well as the transmission network in a system. Understanding of the various options and their economic impact using the flexibility metrics to compare their impact on reliability. Identification of the value of flexibility in system resource adequacy and resource expansion. A better comparative understanding of the flexibility offered by demand response and other possible sources of flexibility. A flexibility screening tool for use in long-term planning and the algorithms used which enable members to incorporate flexibility assessment into planning processes a meaningful way. How to Apply Results Building on the work completed to date, members can start to apply the methodologies developed in their own planning process. By co-planning for flexibility, capacity, and adequacy in their system planning, members should be able to define more optimized solutions for their systems. Existing planning tools can be altered using the proposed framework to incorporate reliability and economics into the planning process, together with metrics on flexibility needs and sources Products Product Title & Description System Flexibility Assessment Tool: The System Flexibility Assessment Tool will be used to apply the multi-level framework for assessing flexibility needs, resources and adequacy developed in the project. This tool will extend the System Flexibility Screening Tool by adding additional levels of detail. These additional levels of detail require more detailed information and produce results including Expected System Flexibility Deficiency and Insufficient Ramp Resource Expectation. The screening analysis previously performed will also be improved with demand response and storage added to the tool. Flexibility in transmission and resource planning: This technical update will describe the work done in the project in This includes consideration of how transmission planning can include flexibility metrics, how resource planning and resource adequacy can include flexibility metrics and description of existing and new market products or operational processes needed to ensure flexibility in power system operation. Case studies of one or more systems will illustrate the methods developed here. Planned Completion Date Product Type 12/31/14 Software 12/31/14 Technical Update

7 7 Electric Power Research Institute Portfolio 2014 P Reliability & Economic Evaluation of Transmission Alternatives (073569) Description The objective of this project is to develop and demonstrate technologies that facilitate the reliability and economic assessments that are part of interregional transmission planning, with consideration for alternative transmission technologies like FACTS and advanced conductors. Introducing long-distance transmission projects changes planning assumptions inside and around the new transmission path, with the added need to accurately describe any wide-area impacts on loop flows. Recent DOE projects on interconnection planning have identified key issues with expanding planning exercises beyond the current transmission planning boundaries, including the need for adjusting traditional planning and approval processes, modeling tools and analysis, consideration of gas-electric interdependencies, and integration of large-scale variable renewables. While these key issues identify technical needs and potential developments, increasing adoption of alternative transmission technologies must be evaluated for the purposes of integrating renewable generation, utilizing smart grid functionality, and developing new transmission components and control schemes. These schemes rely in alternative technologies such as voltage upgrades, dc conversions, high-voltage direct current (HVDC), flexible ac transmission systems (FACTS), and advanced high-temperature low-sag conductors, which can offer significant opportunities to increase transmission capability and should also be considered in system planning. Understanding the impact of incremental and major upgrades in system planning will help members make economic decisions while considering the costs and limitations of such upgrades. Further, these technologies are being adopted at an increasing rate that requires additional integration and training efforts for transmission planning staff. Approach Work in 2014 will examine how to incorporate lessons from earlier projects into a revised, more general framework that can be broadly applied for transmission planning. This project addresses planning issues related to incremental upgrades and enhanced technologies, such as dynamic ratings, as well as major upgrades including voltage upgrade, FACTS, and advanced high-temperature low-sag conductors. It also addresses power flow upgrades achieved by portfolios of different projects. The project will select different advanced technologies at various stages of maturity for evaluation in power flow management applications. It will also examine the economics of applying such technologies to develop a tool for informing 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. ISO/RTO/utility staff will participate in webcasts that review available materials to help them become familiar with the evaluation framework and the way that advanced technologies can be considered as additional project options, in comparison with traditional transmission planning options. Impact This project may help system planners and operators communicate and realize the economic benefits of advanced transmission technologies in these ways: Perform technical analysis to evaluate the use of advanced technology planning options to relieve transmission bottlenecks and increase operating efficiency. Communicate operational benefits, and translate them into reliability and economic benefits suitable for planning analyses and regulatory review. Provide a solid basis for strengthening grids and deferring investment in new transmission. Improve robustness of the transmission grid through the application of advanced technologies. Help quantify higher-quality maintenance, protection, and operation information to increase the robustness and integrity of transmission grids.

8 8 Electric Power Research Institute Portfolio 2014 How to Apply Results Materials developed through this project incorporate incremental and major improvements, including advanced transmission technologies, as planning options for enhancing the transmission grid. By understanding how to apply the technology options, members can enhance the robustness and flexibility of their system planning, resulting in a reliable and highly utilized system Products Product Title & Description Advanced Technology Transmission Project Assessment Technologies: This report describes how to utilize advanced transmission technologies for increased power flow and integration of renewable generation and smart grid technology. It contains methods for prioritizing portfolios of transmission projects to achieve specific business goals and draws in experience from a survey of industry practices and a continuing case study analysis. Planned Completion Date 12/31/14 Product Type Technical Update P Incorporation of Risk Analysis into Planning Processes (105387) Description The electric industry in the United States is experiencing rapid physical, institutional, and regulatory changes that are increasing uncertainty that may have ramifications for reliability and the cost of providing reliable electric service. The main drivers of these changes are the advent of open transmission access and deregulated energy markets across wider geographic regions, the growing prominence of remote variable generation resources such as wind and solar photovoltaic, and demand-side resources such as demand response, residential/commercial PV, and electric vehicles. These factors are significantly increasing the uncertainty in specific generation dispatch and associated power flows such that it is difficult, if not impossible to evaluate all near- and long-term reliability considerations when considering reliability projects. The existing planning processes and tools, which are mostly deterministic, may not be adequate to address these challenges in future. Therefore, there is a need to research a new framework for transmission planning with explicit consideration of uncertainties. Probabilistic risk assessment (PRA) methodologies, also referred as risk-based planning or probabilistic planning, have the potential to provide such a framework. Risk-based planning processes enable planners to evaluate various transmission investment options to deliver energy from generation resources to anticipated loads. However, there are institutional challenges in incorporating risk-based planning in transmission due to lack of standard methodologies, lack of widespread knowledge among practicing engineers, and lack of data and tools, among other factors. The long-term objectives of this new multi-year project are: Understand the role of risk in transmission planning, load growth uncertainty, weather related load variation, fuel cost uncertainty, hydro generation availability, etc. Develop probabilistic analytical techniques, tools, and understanding that utility planners can use in their existing planning processes. These efforts will address system reliability risks as well as financial risks. Approach This will be a multi-year research project focused on risk-based transmission planning, including the five areas related to risk-based planning described as follows: Assess existing methods and criteria for performing risk-based planning. Identify possible gaps, develop new methods, and recommend criteria if necessary. Define data sources required to support risk-based planning, and sources and methods for assembling the data.

9 9 Electric Power Research Institute Portfolio 2014 Enhance/develop simulation tools for performing risk-based analysis. Assess the resulting planning requirements due to regulatory changes. Transfer knowledge to the industry via case studies, workshops, and collaboration with national labs, IEEE, PSERC, CIGRE and other research entities. These activities will be conducted to address uncertainties that create both financial (economic) and reliability risk. Consequently, transmission system planning efforts need to assess both levels of uncertainty to identify the system plan that provides adequate reliability at the lowest cost. To this end, existing transmission processes need to be examined to evaluate the potential for improvement in both of the broad planning decision-making aspects: (Probabilistic) Economic Assessment: a more rigorous treatment of the uncertainties impacting the economic viability of a given transmission investment. (Probabilistic) Reliability Assessment: a more rigorous treatment of the uncertainties impacting the reliability and security of the operation of the grid with the new transmission components. Impact The main benefits of these research activities will be as follows: A clear understanding of criteria and indices that can be used for risk-based planning. Risk-based planning-level tools and techniques that members can incorporate to evaluate reliability and economic risks for different transmission plans. A platform to share information and knowledge on risk-based planning. Ultimately, appropriate implementation of risk-based planning that will enable members to meet reliability requirements in the most economical manner in an evolving environment of uncertainty. How to Apply Results Utility planners will be able to use the tools and methodologies developed through this project to assess the impacts of long-term and short-term uncertainties. Case studies developed as part of this project will help members understand the advantages and disadvantages of risk-based approaches compared to deterministic methods Products Product Title & Description Planned Completion Date Product Type Incorporation of Risk Analysis into Planning Processes 12/31/14 Technical Report

10 10 Electric Power Research Institute Portfolio 2014 Supplemental Projects Users Group for the Power Plant Parameter Derivation (PPPD) Software Tool (073978) Background, Objectives, and New Learning For more than a decade, the U.S. Western Electricity Coordinating Council (WECC) has required that all generating stations be periodically tested for model validation. Similar model validation requirements are going to be put in place nationwide by the North American Electric Reliability Corporation (NERC). After several years of research and development (R&D), the Electric Power Research Institute (EPRI) has developed the Power Plant Parameter Derivation (PPPD) software tool. The PPPD Software Tool provides an automated platform for deriving and validating power plant models using either staged field test data or recorded on-line disturbance monitoring data. This tool has now been used successfully by many utilities for the past three years. Since 2010 a PPPD user's group has been in place, and several utilities have been successfully applying the tool to meet the necessary model validation requirements for their generation fleet. This users group has the objective of being a forum for utilities that intend to use the tool to share learning and to better understand its application for meeting WECC and NERC requirements for generator model validation. It is a continuation of the existing users group. Project Approach and Summary This project will hold group webcasts and one annual face-to-face meeting. These forums will be an ideal setting for the following: To discuss enhancements and develop additional model requirements to be added to the tool To maintain the software and release future versions of the tool with new models ( bug fixes ) To share experience of various users with the tool To provide further training sessions Benefits This tool has two key values: It provides an automated algorithm to assist the engineer in the model validation process, significantly reducing engineering time. It provides a way to use on-line recorded data for model revalidation on a routine basis, eliminating the need to take units off-line for staged model validation testing. This project will provide a forum to help utilities with the application of PPPD, through workshops, users group meetings, webcasts, and software support. It also provides a way to continue to enhance the tool by adding more models or features to it, as appropriate.

11 11 Electric Power Research Institute Portfolio 2014 Load Modeling for Power System Stability Studies (073496) Background, Objectives, and New Learning Considerable progress has been made in the area of load modeling for system planning studies in the last few years. Work performed by various entities, including Electric Power Research Institute (EPRI) and the Western Electricity Coordinating Council (WECC) have led to better understanding of end-use loads, improvements in load-modeling techniques, and the development of standard composite load models for use in commercial power system software tools. In spite of these efforts, load modeling is still the most difficult aspect of component modeling for power systems in planning studies. The most significant challenge with load modeling is the variability and uncertainty associated with loads at any given time. Furthermore, the load characteristics change (mainly in composition) as a function of geographic location due to the difference in the climate of various regions. The main questions that need to be addressed are: How do we aggregate the system loads to capture all the dynamic behavior of the system for planning studies? What are the factors that determine the system behavior with respect to system characteristics and nature of disturbance in addition to load composition following a transmission fault? This project's objectives are to further investigate these questions and help utility planners to gain a greater understanding of load modeling for their systems. The work in this project will be built upon EPRI's research in this area for the recent past and will be closely linked with the base research work being performed in the area of load modeling from Project Approach and Summary The project has two main components as described below: 1. A process of developing percentage composition (i.e. percentages of static loads and induction motor loads) for the composite load model [1] will be developed. Utility planners can use the process to develop and update the percentage compositions of their system loads for performing system studies in commercially available software such as GE PSLF and Siemens PTI PSS/E. The process will be developed based on the following; Latest version of Load Model Data Tool available from Western Electricity Coordination Council (WECC). This tool will be publicly available soon and can be used by utilities outside of WECC as well. Information about load demand by components (e.g. % HVAC, % lighting etc.) for summer and winter peak hours. This information will be collected from the R&D efforts in EPRI's distribution program. 2. A comprehensive test system representing a realistic full three-phase distribution feeder model will be developed. The comprehensive test system developed could provide a significant insight into different factors in addition to load composition that determine the aggregate behavior of loads for a variety of system conditions and disturbances. [1] The composite load model is available as a standard library load model in GE PSLF and Siemens PTI PSS/E.

12 12 Electric Power Research Institute Portfolio 2014 Benefits The potential benefits of this project are as follows: The work performed to develop percentage composition is especially relevant in terms of the NERC TPL standard TPL , section which requires system peak and off-peak load studies to represent the expected behavior of Loads that could impact the study area, considering the behavior of induction motor Loads. An aggregate System Load model which represents the overall dynamic behavior of the Load is acceptable. The tools used for this task will be publicly available and easy to use. Default data will be used for this work based on geographical location. This data will provide a base line for the utilities. The data can be improved if more accurate data is available to the utilities. Utility planners can use the knowledge gained from the full three-phase distribution feeder model to better understand the sensitivities of the system voltage recovery to various system conditions and disturbances. In addition, this work can help utilities to adequately model the load such that the study results properly reflect actual system performance, leading to greater reliability. Transmission Modernization Demonstration (074508) Background, Objectives, and New Learning The Transmission Modernization Demonstration is addressing the R&D smart grid challenges identified by over 1400 industry and public advisors along with the EPRI board of directors over a two year period. The project will employ learning-by-doing by demonstrating data management and analytics to support transmission operations, planning and asset management applications. As electric utilities are implementing or planning to implement advanced transmission applications to improve system reliability, efficiency, and performance, a vast amount of data is being generated from sensors, devices and systems. There is a gap to fully take advantage of turning this vast amount of data into actionable information with industry standard methods and tools. As just one example, installed phasor measurement units (PMUs) have doubled in 2012 while Synchrophasor applications have yet to reach a maturity where operators and engineers are relying on them for normal operations. The Transmission Modernization Demonstration objectives include identification of new and existing transmission applications that have value to utilities, creation of an application inventory, and assessment of these applications in the laboratory environment and in field demonstrations. Examples of these advanced applications might include continuous planning model validation using data from PMU s & IEDs, improving system operations by real-time system awareness enhancements, and derive new asset condition information from operational and historic usage information. This industry-led demonstration initiative will develop the requirements and demonstrate the emerging applications in a practical approach, preserving legacy systems as appropriate while also developing an architecture that leverages emerging standards such as the Common Information Model (CIM). Project Approach and Summary This project is a collaborative demonstration project with an opportunity for members to demonstrate hostadvanced transmission applications. EPRI support efforts include evaluation of applications, development of research roadmap, and preparation of cost benefit analysis. Lessons learned will be shared through a combination of meetings, media and reports. Specific activities include: One-on-one utility immersion/roadmap to share existing industry beneficial applications and develop a roadmap transmission applications and supporting architecture. The resulting opportunity matrix may support prioritizing applications, architectures and implementation strategies.

13 13 Electric Power Research Institute Portfolio 2014 Development of a collaborative vision statement for the future functionality of grid operations, including advanced transmission applications and integration points with other systems. Creation of member-defined deliverables such as reports, web casts, training and other media content to add value to the participant s own efforts. Benefits This project may help utilities to manage and benefit from increasing data generated from transmission system assets. When standardized analytical methods and tools are developed in a collaborative manner, it helps to reduce the total cost to procure, implement, and sustain advanced transmission applications. The development of common analytical methods that can be applied across the utility industry will accelerate the ability to process large data sets and translate into actionable information for common transmission applications. The public and members can expect to benefit from improved grid reliability through the application of advanced transmission applications and the improved ability to detect and respond to equipment failures. It is expected that anticipated increased situational awareness will enable system operators to focus on actionable information, and empowering them to make informed decisions with greater speed and reliability. A second public benefit may include the ability to maintain electricity affordable by helping utilities to reduce costs of customization and development efforts through the use of standardized functional specifications and enterprise integration methods, tools and algorithms. This may also lead to lower anticipated integration costs, lower information technology operational costs, and lower risk of integration implementation.