Power Systems Engineering Research Center PSERC Summer … · The typical project period will be July 1, 2016 to August 31, 2018. The funding will be provided once sufficient membership

Power Systems Engineering Research Center

PSERC Summer Planning Workshop Table of Contents

Mission (page i) Industry and Univ. Members (page ii) Personnel (page iii) 2015 Calendar (page iv) Draft Research Solicitation (page v)

Research Projects by Stem (page xxii) Project by Year (page xxix) CERTS (page xl) Presentation Handouts (page xli) Presentations (1-63) Login for materials at pserc.org (Members>Meetings)

Agenda Monday, July 13 7:00 – 9:00 p.m. Dinner reception for attendees and their guests Tuesday, July 14 7:30 – 8:00 a.m. Continental breakfast for workshop registrants 8:00 – 9:00 a.m. Research Ideas from the Executive Forum on Physical and Cyber Infrastructure

Supporting the Future Grid .................................................................................... p. 1 Forum Coordinating Committee, Mladen Kezunovic, Chair

9:00 – 12:00 noon T&D Stem Committee Working Session 12:00 – 1:00 p.m. Workshop group lunch for registrants 1:00 – 5:00 p.m. Systems Stem Committee Working Session 7:00 – 9:00 p.m. Workshop group dinner for registrants and their guests Wednesday, July 15 7:30 – 8:00 a.m. Continental breakfast for registrants 8:00 – 10:00 a.m. Markets Stem Committee Working Session 10:00 – 12:00 noon Technology and Policy Interactions: The Case of the EPA’s “Clean Power Plan”

Proposed Rule – A Dialog Between Industry Members and University Researchers (Panel) ...................................................................................................................... p. 21

12:00 – 1:00 p.m. Workshop group lunch for registrants 1:00 – 3:00 p.m. Invited Presentations

Grid Modernization Cross-Cut Initiative ............................................................ p. 31 Jeff Dagle, Chief Electrical Engineer and Team Lead, Electricity Infrastructure / Transmission System Resilience, Pacific Northwest National Lab Support of Grid Research by ARPA-E Timothy Heidel, Program Director, Advanced Research Projects Agency-Energy Value of the Integrated Grid ................................................................................. p. 43 Robin Manning, VP Transmission, EPRI Technology Innovation: Delivering Value to BPA ............................................ p. 53 Terry Oliver, Chief Technology Innovation Officer, Bonneville Power Administration

3:00 p.m. Workshop Adjourns for Participants 3:00 – 6:00 p.m. Executive Committee Meeting

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Power Systems Engineering Research Center

Our core purpose: Empowering minds to engineer the future electric energy system

What’s important to us: Pursuing, discovering and transferring knowledge

Producing highly qualified and trained engineers

Collaborating in all we do

What we’re working toward: An efficient, secure, resilient, adaptable, and economic

electric power infrastructure serving society

A new generation of educated technical professionals in electric power

Knowledgeable decision-makers on critical energy policy issues

Sustained, quality university programs in electric power engineering

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Industry Members in 2015

ABB ALSTOM Grid

American Electric Power American Transmission Company Arizona Public Service BC Hydro

Bonneville Power Administration California ISO CenterPoint Energy Dominion Virginia Power

Duke Energy Entergy EPRI Exelon

FirstEnergy Corporation GE Idaho Power Institut de Recherche d’Hydro-Quebec

ISO New England ITC Holdings Lawrence Livermore National Lab Midcontinent ISO (MISO)

National Renewal Energy Lab National Rural Electric Coop. Assn New York ISO New York Power Authority

Pacific Gas & Electric Company PJM Interconnection PowerWorld Corporation RTE-France

Salt River Project Southern California Edison Southern Company Southwest Power Pool

The Energy Authority Tri-State Generation and Transmission U.S. Department of Energy Western Area Power Administration

Collaborating Universities and Site Directors

Arizona State (Jerry Heydt)

Berkeley (Shmuel Oren)

Carnegie Mellon (Marija Ilic)

Colorado School of Mines (P.K. Sen)

Cornell (Lang Tong)

Georgia Tech (Sakis Meliopoulos)

Howard Univ. (James Momoh)

Illinois (Tom Overbye)

Iowa State (Venkataramana Ajjarapu)

Texas A&M (Mladen Kezunovic)

Washington State (Anjan Bose)

Wichita State (Ward Jewell)

Wisconsin (Chris DeMarco)

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PSERC Personnel Director: Vijay Vittal, Arizona State Univ. Founding Director: Robert J. Thomas, Cornell Univ. 2015 IAB Officers

• Flora Flygt, ATC, Chair • Jay Caspary, SPP, Vice-Chair

Deputy Director: Dennis Ray Facilitator: Frank Wayno, Cornell Univ. NSF I/UCRC Evaluator: Otto Doering, Purdue Univ. Stem Leadership

• Systems Stem • V. Ajjarapu, Iowa State University, Chair • Baj Agrawal, Arizona Public Service, Vice-Chair

• Transmission and Distribution Technologies Stem • Ward Jewell, Wichita State Univ., Chair • Jeff Fleeman, AEP, Vice-Chair

• Market Stem • Shmuel Oren, Univ. of California-Berkeley, Chair • Jim Price, California ISO, Vice-Chair

Adjunct and Junior Adjunct Researchers

Antonio Conejo, Ohio State Univ. Judy Cardell, Smith College Alberto Lamadrid, Lehigh Univ.

Administrative Specialist: Theresa Herr, Arizona State Univ. Business Operations Specialist: Laura DiPaolo, Arizona State Univ. Additional Information Website: http://www.pserc.org. Available email listservs: Faculty ([email protected]), Industry ([email protected]), Public ([email protected]), PSERC Students ([email protected]), HR Personnel ([email protected]). To subscribe, go to http://www.pserc.org/listserv.aspx. Contact Information:

Power Systems Engineering Research Center Arizona State University 527 Engineering Research Center PO Box 875706 Tempe, AZ 85287-5706 Phone: 480-965-1643 Fax: 480-965-0745 Email: [email protected]

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2015 PSERC Calendar of Events

2015 Events

Jan. 20

Hybrid Time Domain Simulation: Application to Fault Induced Delayed Voltage Recovery

Vijay Vittal, Arizona State University PSERC Webinar

Feb. 3 HVDC Transmission Systems Based on Modular Multilevel Converters

Maryam Saeedifard, Georgia Institute of Technology PSERC Webinar

Feb. 6-7 Executive Committee Management Retreat

Feb. 17

Applications of Software-Defined Networking (SDN) in Power System Communication Infrastructure: Benefits and Challenges Alex Sprintson, Texas A&M University

PSERC Webinar

March 3

Using Field Measurements, Numerical Simulation, and Visualization to Improve Utility-Scale Wind Farm Power Forecasts

Eugene Takle, Iowa State University PSERC Webinar

March 17 Visualization of Time-Varying Power System Information

Tom Overbye, University of Illinois at Urbana-Champaign PSERC Webinar

April 7 Control Strategies for Microgrids

Ali Mehrizi-Sani, Washington State University PSERC Webinar

April 21 Flexible Transmission Decision Support Kory Hedman, Arizona State University

PSERC Webinar

May 4-5 Executive Forum on Cyber and Physical Infrastructure

to Support the Future Grid (Day 1) Workshop on Research for Supporting the Future Grid (Day 2)

May 18-20

PSERC IAB Meeting Iowa State University, Ames, Iowa

July 14-15 PSERC Summer Planning Workshop Stevenson, WA

July 26-30 2015 IEEE Power & Engineering Society General Meeting Sheraton Denver Downtown Hotel, Denver, CO

Sept. 15 PSERC Webinar Sept. 16 Proposals Due for PSERC 2015 Research Solicitation Sept. 18 Proposals Distributed for Industry Member and Academic Reviews

Oct. 4-6 2015 North American Power Symposium (NAPS) Univ. of North Carolina at Charlotte

Oct. 6 PSERC Webinar Oct. 8 Industry and Academic Proposal Reviews Due for PSERC 2015 Research Solicitation

Oct. 20 PSERC Webinar Nov. 3 PSERC Webinar

Nov. 17 PSERC Webinar

Dec. 2-4 PSERC IAB Meeting Texas A&M University, College Station, Texas

Power Systems Engineering Research Center

DRAFT

Solicitation for New Projects Beginning in 2015

July 22, 2015

Proposal Submittal Deadline: Midnight Your Local Time on September 16, 2015

Confidential: For use by PSERC members only

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I. Overview

This solicitation is for project proposals from collaborative teams of PSERC researchers and industry members. Proposals are submitted by the PSERC researchers. The submitted proposals will follow the guidelines given in this solicitation. Proposals should be for work consistent with PSERC’s research plan as presented in this solicitation and should contribute to achieving PSERC’s mission of addressing significant challenges facing the electric power industry. PSERC is a collaboratory effort and its research projects should promote collaboration across universities and industry members. If a proposer has any questions about collaboration, the stem research areas, the evaluation criteria, or the solicitation in general, then the stem leaders should be contacted at: V. Ajjarapu, Chair; Baj Agrawal, Arizona Public Service, Vice Chair, Systems Stem

Ward Jewell, Chair; Jeff Fleeman, AEP, Vice Chair, T&D Technologies Stem

Shmuel Oren, Chair; Jim Price, California ISO, Vice Chair, Markets Stem Ideas for proposals are often identified and discussed at stem committee meetings that are held at the semi-annual IAB meetings, and at the PSERC summer workshop. Participation by industry is sought as project advisors. Industry members who provide project advisors are not required to contribute additional membership funds to do so.

II. Proposal Requirements

Submittal Deadline: September 16, 2015, by midnight local time of the listed project leader Eligibility: Proposals may be submitted by researchers at PSERC universities who are not on project teams that have a late PSERC final project report (unless otherwise approved by the Director). Adjunct researchers may be members of project teams, but they cannot be project team leaders. Number of Proposals: A researcher may only participate in two proposals per year either as the project leader or as a team member. Researchers on the high impact project are ineligible to participate in proposals until the project is completed. Researchers can be funded for at most three on-going projects. Conflict of Interest: Proposals that have any conflict of interest with the commercial interests of the project leader or research team members must contain a clearly written disclosure of that conflict of interest for the proposal to be considered for funding by the Director, IAB, and Executive Committee.

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Evaluation Criteria (from the PSERC Operations and Procedures Manual): The following criteria will be used by the Industry Advisory Board (IAB), the Executive Committee, and the Director to review, rank, and select proposals for funding.

1. Industrial issues: a. Does the project have at least two companies interested and the names of two industry people who will

devote time to work with PSERC on the project? b. Does the IAB rank the project high?

2. Center issues:

a. Does the project properly fit the solicitation? b. Are multiple universities involved?

3. Quality issues:

a. Is the project innovative and creative? b. Do the proposed investigators have good track records?

4. Budget and balance issues:

a. Does the project contribute to equitable university site funding distribution (that is, lead toward an average funding of $120K/site over a 3-year moving window)?

b. Does the project contribute to equitable investigator funding distribution? c. Does the project contribute to the balance of basic vs. applied research? d. Is the budget correct for the work proposed – typically $110K? e. Does the proposal advance PSERC’s education mission by budgeting support for students? f. Does the project have one leader, at least one researcher from another university, and two industry

participants? Regarding fit with the solicitation, submitters should review the research areas and topics identified by the stems. These areas and topics are given later in the solicitation. Project Duration: Project lengths should be one to two years. The typical project period will be July 1, 2016 to August 31, 2018. The funding will be provided once sufficient membership support has been received. Final project reports are due at the end of the project period (i.e., typically, August 31, 2018). Review by the industry advisors on the project team is required before the project report is submitted. Funding Period: The project begins as soon as funds are available, probably by July 1, 2016. Funding is on a calendar year basis. PSERC’s Research Budget for New Projects: Considering the funding of PSERC’s on-going projects, the approximate budget for new projects in 2016 is $675,000. This means that there is expected to be funding for the equivalent of about six new projects beginning in 2016. Projects per Researcher: Typically PSERC will fund one new project for a PSERC researcher as the project leader or as a project team member. If any researcher is on the research team of two or three selected proposals, the researcher should expect a $10K per year budget reduction for the second project and a $20K budget reduction per year for the third project. Project Budget: The maximum project budget is $110,000 year for the typical project. In keeping with PSERC’s education mission, support of students will be viewed favorably as the main component of proposal budgets. In general, a project team leader should be budgeted for no more than $40K per year. Each other project team member should be budgeted for no more than $35K.

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Research Stem: The proposal should designate one principal research stem to help industry members identify the appropriate person to review the proposal in their organization. The designated stem must reflect the principal subject matter of the proposal as related to the identified topics areas found later in this solicitation. The proposal should describe how the project relates to the research topics given in this solicitation no matter which stem the topics are categorized. Cross-Stem Projects: As noted above, only one principal research stem should be designated. Do not list multiple stems. This requirement should not be interpreted as a limit to the breadth of the research.

Obtaining Industry Advisors: In contacting industry members to invite them to provide project advisors, proposers are encouraged to send an email to the PSERC IAB listserv ([email protected]) to give all of PSERC’s industry members the opportunity to participate. It is suggested that email contain: (1) preliminary title of the proposal; (2) a preliminary summary (about one paragraph long); (3) preliminary research team members; and (4) contact information. Direct any questions about contacting PSERC’s industry members to Dennis Ray at [email protected] or 608-265-3808. Proposal Length: Not to exceed six pages, including references; however, the budget page can be the seventh page. Proposal Format: Proposals must be submitted using the current (i.e., 2015) PSERC project proposal template. The template will be provided from Dennis Ray. Submission Address: Send your Word file (not PDF) to Dennis Ray ([email protected]).

Continuing Lines of Research: Requests for continued funding of lines of research will be made in the form of new proposals. The same evaluation criteria will be applied to all new proposals. Descriptions of current research projects can be obtained from the PSERC website (http://www.pserc.org). Intention to Facilitate Additional Funding: The Executive Committee intends to review the submitted proposals to see if some proposals can be bundled along a logical theme and marketed for potential funding beyond base funding. Possible themes include smart grid technologies, renewable generation, and low carbon strategies. No a priori decision can be made about the best theme for doing the marketing.

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Proposal Submittal, Review, and Approval Schedule

Date Action By July 22 Distribute 2015 Solicitation

By midnight local time of proposal leader on September 16

Proposals sent to the Deputy Director at [email protected].

By September 18 Proposals forwarded to industry members of the research stems with a ranking/prioritization form for feedback and ranking. Each proposal also forwarded for at least one anonymous academic review by a PSERC faculty member.

By October 8 The industry and academic evaluation forms, along with comments, due to the Deputy Director.

By October 15 Director sends proposals, and compilation of industry and academic reviews to the Executive Committee.

By October 30 The Executive Committee provides recommendation to the Director.

By November 6 The Director decides which proposals will be presented at the December 2-4 IAB meeting, notifies proposers of any needed modifications to their proposals, and informs the researchers to prepare for presentations at the December IAB meeting.

By November 13 The Director sends proposals to the IAB members.

December 3 Presentations on selected proposals made by researchers. IAB members vote on projects to recommend to the Director. Recommendations given to the Director and Executive Committee.

By December 10 Any final input requested by the Director from the Executive Committee submitted.

By December 17 Director makes all final decisions about initiating new projects. Funding to begin when the funds are available (typically in June).

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III. Systems Stem Research

The work of the Systems Stem targets modeling, evaluation, decision, and control in power system operation, maintenance, and planning of generation, transmission, and distribution subsystems for more reliable and economic grid performance. The electric power industry is comprised of a large number of diverse organizations that together operate, maintain, and plan the infrastructure used to generate, transport, and distribute electric energy. These activities require continuous and intimate coordination among the various organizations while simultaneously satisfying information sharing needs and limitations associated with the economic systems (e.g., markets) used to facilitate energy trade. Regional coordinators for operations, reliability, and markets have needs driven by their functional complexity and by their large size. Capability to monitor and control power systems over increasingly wider areas is needed. Flexibility and interoperability of corresponding information systems is essential. Power electronic devices are being deployed at generation, transmission, and end-use levels. Small-scale, dispersed generation technologies are increasing their penetration in power systems. Environmental concerns have motivated diversification of power generation portfolios around the world, and the corresponding growth in different supply technologies (gas, nuclear, land-based and offshore wind, solar, biomass, etc.) drives changes in the de-livery system technologies on which they depend. The complexity of systems problems increases with system size, new technology options, operational requirements, and environmental constraints. Advances in information technology, communications and mathematics demand that systems problems be reexamined and new approaches formulated. The Systems Stem supports development of new frameworks, approaches, advanced algorithms, and computational methods that will effectively cope with the complexity and large scale issues of the future electric power industry. Representative areas of work include: • Operations, planning, optimization, system reliability/security, and risk management • Security, reliability and adequacy criteria • Real-time security assessment and preventive and corrective control • Interactions of complex systems • Communications, control, data management, system monitoring, self-healing, restoration, cyber security and

cyber infrastructure • Computational complexity arising in operation and control of power systems • Operation, control, and protection of distributed generation • Short-term scheduling of uncertain renewable resources • Component modeling and system identification • Simulation platforms and visualization tools. The Systems Stem has identified the following core areas in which we intend that the Stem will have impact in the coming years. These areas are listed below together with examples typical of each area.

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I. Control Center Technologies State estimation, phasor measurements, Visualization, Situational, awareness (preventive and corrective), Restoration, Control room architectures. II. Wide Area Control and Cascading Defense Adaptive islanding, Coordination of different control levels, Operational identification and simulation of high-risk contingencies, Use of phasor measurements in control and decision. Communication systems. III. Reliability and Planning (Operational and Long-Term) Reactive power planning, dynamic load models, standards, uncertainty, distributed generation, using condition data, losses, long-range planning. IV. Sustainability of Energy Supply and Transport Impact of renewables, wind integration, fuel and gas transport infrastructure, emissions and climate impacts, electrification of transportation. V. Cyber/Physical System Interaction and Interdependence Operations are becoming increasingly dependent on cyber assets and rely on the integrity of cyber systems to prepare for and respond to contingencies. These dependencies need to be considered in operations and planning for reliability. Additional Information Projects are also encouraged that have commitments from one or more member companies to supply additional funds to fund part of the project if it is selected. It is the responsibility of PIs to seek out and gain these commitments. The companies and the amount of additional funds should be specified in the proposal. The next section provides a list of topics identified by PSERC industry membership as being relevant to their research needs. In addition, specific project ideas were presented at the PSERC Summer Workshop. Slides from these presentations are available on the PSERC web site.

Systems Stem Research Topics from the 2014 Solicitation Topics of interest, as expressed by industry, are listed below. 1. Modeling

• Load modeling (static and dynamic) • Need to model entire interconnection; planning and operating models should be the same; need to use field

data to perform model validation 2. Environmental

• What environmental regulations should we have? Are there systematic ways to answer this question? • Perform CO2 reduction via electrification of vehicles • Need alternatives to SF6 due to 2017 restrictions

3. System performance – frequency and MW

• Frequency response of 3 interconnections is decreasing. How to provide regulation, AGC, operating reserves.

• Effects on frequency response of displacing coal units

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• Energy storage projects • Demand-side control • Broader regional dispatch • Ability to predict Under Frequency Load Shedding needs • Price responsive demand in markets and operation

4. System performance – voltage and Vars

• Dynamic voltage recovery: modeling loads and benchmarking • Dynamic models • Ability to predict Under Voltage Load Shedding locational needs

5. Variable generation

• Variability, relation to demand side • Dynamic thermal ratings and renewables • Converter models for wind and solar • Accuracy of aggregated wind models voltage/transient • Weather forecasting • Variable generation – induced uncertainty on system operating studies • Generic study of how best to integrate large-scale remote renewables into an interconnection.

6. Monitoring and control

• Vulnerability caused by interaction of two key infrastructures (power and communication) via PMUs; look at redundancy, security, stability

• What to do with all that PMU data? Need more mature tools. • Centralized remedial action schemes • Wide area protection and control • Use of RTDS • Next generation EMS • Dynamic State Estimation • Extended State Estimation to initialize Dynamic Security Assessment • Phasor Measurement Unit Based Stability Analysis of Power System

7. Planning

• How to predict where generation is going to be • How to measure value/worth of reliability • Need data mining on security results • Need tools to perform strategic planning to obtain sustainable generation mix • Transmission Expansion Plan Optimization based on economics – in other words, robustness testing of

transmission portfolio 8. Distribution and end-use

• How to address interaction between household appliances and grid? • Will have 2 million smart meters by 2013 • Power Quality at connection points to Transmission System • Distribution system V/VAr improvements and impact on transmission VAr requirements

9. Condition data

• Need data integration methods • Control centers need to utilized equipment condition data

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10. Cyber security

• Protecting assets and markets from intrusion and insider actions 11. Gas/Electric interaction and dependence

• Supply issues such as pipeline adequacy 12. Demand response in operations/AGC 13. Imbedded HVDC to assist HVAC 14. Other issues

• Bring training/education of new smart grid technologies • Atmospheric electromagnetic events, facility shielding • Bring standards to different technologies • How to use social media (Facebook) to benefit the grid • Impact of GIC on system operations • Learning from Smart Meter and PMU Data • HVDC VSC for Black Start - especially in view of the many fossil plant retire-ments that are expected

(which accelerate with EP "train wreck“ regulations) • Flowgate-driven limits – Angle across areas • Exploit time-zone differences.

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IV. T&D Technologies Stem Research

Industry Background While the T&D industry has experienced vast changes from its historic role, the underlying issues of safe, reliable, and economic operation remain. The scope of T&D Technologies Stem spans traditional transmission and distribution systems, and also microgrids, distributed generation and storage, and low-voltage customer systems. It includes:

• Application of new technologies to improve system performance • Design engineering, materials, maintenance and aging infrastructure • Components, protection, and communication • Asset management and condition assessment • Cybersecurity and physical security • Resiliency, hardening, and restoration

T&D Stem Research Topics from the 2014 Solicitation

Discussions at the T&D Technologies Stem meeting at the 2014 PSERC Planning Workshop identified research issues for this solicitation. While this is not an exhaustive list, and other proposals within the stem scope are welcome, it summarizes the thoughts of those attending this year’s workshop.

• Best practices, pitfalls, and protection for unique interconnection requests • Predictive reliability and decision support. • Transmission metrics and performance measures • Using PMU and other data to create validated NERC compliant models, especially load models • Distribution planning, forecasting, and net metering • Future feeder designs: Better and cheaper options than radial • Optimizing and automating load balancing and reconfiguration to improve distribution performance • New business models, revenue streams, and cost allocation as distributed generation grows • New organization models as lines are blurred among engineering, customer service, markets, and supply. • Reliability of distributed generation and its effect on system reliability. • Distribution design to maintain reliability with distributed generation. • With distributed resources, who is responsible for reliability? • Distribution markets • Education of regulators • Application of operating data • Microgrid design and coordination with distribution and transmission

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Another session devoted exclusively to distribution yielded these research needs:

• Interactions among distributed resources and voltage regulators • Design improvements for distributed resource power electronics interface • Islanding with distributed resources • Design for customer participation in markets • Distribution modeling and state estimation • Value of new technologies to distribution companies • Standardization of interconnecting components and communication • Distributed resource dispatch • Distributed resource response to transmission faults. • Distribution design for high distributed resource penetrations • Distributed resource and microgrid maintenance • Optimal distributed resource penetrations • Design with 100% distributed resources. • Distribution analysis tools that include multiple distribution systems linked at the subtransmission and

transmission levels • Collection of distribution data, communicating it to system operators • Bulk vs. distributed storage • Storage ownership • Distribution system architecture: automated/adaptive protection and control • Public education • Workforce for new distribution designs • Communication technologies • Fast evolution of communication technologies: depreciation and protection against stranded assets • Data privacy and security • New load shapes, effect on distribution planning and design • Distributed resources and resiliency • Real-time pricing – engineering and regulatory issues • Locational value of PV and other distributed resources. • Reactive power supply by distributed resources: design, control, and incentives • Distributed resources and new load effects on conservation voltage reduction. • Effects of restricted operator access to data • Coordination of industrial and commercial customers to respond to price signals? • Optimal location of distributed resources • Net load forecasting • Effect of non-connected solar on load shapes • Effect of location on price and operations • Optimal operation of storage: facilitating load and arbitrage. Optimal storage operation with renewables • Value of storage - quantify benefits • Design of distribution for electric vehicles • Conservation voltage reduction: Hardware implementation and quantification of impact • Cybersecurity for distribution: rural applications • Electronic tampering with smart meters • What data should be collected on distribution systems, considering limited data capacity and granularity? • Design with a mixture of 2-way and unidirectional feeders • Rules for power quality: minimum, location-based requirement for interconnection • Ride-through in an islanded network

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V. Markets Stem Research

The electric power industry in the US and worldwide is undergoing a major transformation. It is changing from a vertically integrated industry in which generation transmission and distribution system in a geographical region were owned by single entities with tight coordination of the planning, scheduling, and operations of these industry components. By contrast, the new industry paradigm is based on dispersed ownership, separation of the generation, transmission, and distribution, and on coordination through markets. This transition is propelled by social, political and economic forces and by technological developments, particularly the emergence of small scale generation, advances in power electronics, reliable and inexpensive communication, metering and computer technologies, and by the rapid growth in electronic commerce.

As new technologies emerge or become economically feasible we may see further evolution in the industry structure as well as in the planning, scheduling and operational paradigms. For example in the long term, mass deployment of FACTS devices may result in a switchable transmission system that will lead to different market organization. Similarly proliferation of distributed generation and storage technologies could lead to new operational paradigms, direct access at the distribution level, and new market structures. This emergence of new technologies has become sufficiently recognized that the term “Smart Grid” has become popular, which highlights the impacts that these developments will have on market structure.

In addition, markets are facing challenges of adapting to new state and federal regulatory requirements that address climate change and energy security. Requirements such as increasing the use of renewable energy to 20%, 33%, or more of total energy use within the 2020 to 2030 timeframe, and/or reducing the emissions of carbon dioxide into the atmosphere by 50-80% by 2050, will have profound implications for the electric utility industry. The likely effects on electricity production will be to increase the use of renewable sources of energy, increase the use of electricity for transportation with the introduction of Plug-in Hybrid Electric Vehicles (PHEV), and put a priority on developing new technologies for Carbon Capture and Sequestration (CCS) for traditional fossil power plants.

Unlike new initiatives like the Smart Grid, for example, many of these changes are being imposed on the industry from outside forces without having a clear understanding of the implications for system reliability or the financial viability of the current providers of electricity services. Examples include:

• Renewable Portfolio Standards (RPS) set by political processes,

• Net-metering and “feed-in” tariffs to accept energy from distributed sources as a way to subsidize customers who install solar panels or other on-site generation, and

• Putting a price on emissions of carbon in a cap-and-trade market.

Initial studies indicate that these developments may create challenges for markets including increased cycling of existing generation, ramping of system dispatch, and additional requirements for frequency regulation. New types of resources are anticipated to grow in their market size, including energy storage and price-responsive demand resources that are more flexible than traditional emergency response programs. Market mechanisms for carbon management such as cap-and-trade and carbon taxes are being debated, while early research results indicate that initial market results have not always accomplished their goals, making this a potentially fruitful area for further research to identify effective mechanisms. Hence, an important objective for new research in the Market Stem is to evaluate how these types of change will affect the industry and to identify preferred ways to make the transition to a low-carbon economy in a more orderly way.

Our primary research goal in this stem is to focus on short to medium term issues concerning the interaction between the technical and economic aspects of the restructured industry given the current technological landscape. In particular this stem focuses on a new market based paradigm that will replace the traditional functional timeline leading from years to cycles prior to real time, which includes long term demand forecasting, capacity planning and expansion, maintenance, short term forecasting, scheduling, dispatch, and real time control. The research under this stem emphasizes the design and analysis of market institutions, mechanisms and computational tools that will

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facilitate coordination, efficient investment, operational efficiency, and system reliability, while recognizing the economic and technical realities of the electric power industry.

The scope of work under this stem can be broken down by subject area and by methodological approach, recognizing the fact that some approaches may be better suited for certain problem areas. These general goals are pursued by means of the following methodological approaches that complement and support each other:

• Analytical methods that can be further classified into:

o Theoretical analysis focusing on conceptual abstract modeling and analysis, employing techniques of operations research, systems analysis, microeconomics, stochastic modeling, game theory, and auction theory.

o Empirical analysis focusing on interpretation of empirical data and on estimation and validation of theoretical models using econometric methods, financial engineering approaches, statistical analysis and data mining.

• Computational methods employing numerical methods and agent-based models to simulate and forecast market outcomes under realistic modeling of the electric power system in conjunction with behavioral models of economic agents that control various aspects of the system and interact in the marketplace.

• Experimental economic approaches employing controlled laboratory experiments with live and artificial agents in order to explore decision patterns under alternative rules and system conditions, and to test behavioral assumptions upon which such rules are founded.

Markets Stem Research Topics from the 2014 Solicitation

This year’s solicitation emphasizes devising market mechanisms and market products for coordinating the interfaces between the technological opportunities provided by the evolving Smart Grid, the new demands on the electric system that are result from the increased use of renewable energy and reductions in carbon release, and the more traditional network and public goods requirements of providing reliable, efficient and socially acceptable supplies. Four focus areas represent a continuation of the areas listed in previous years’ solicitations, in which proposals should recognize the new challenges and opportunities described above, and recognize the foundation established by previous research when focusing new proposals:

1. Developing Flexible Systems Using Technological Innovation and Integration,

2. New or Refined Market Products for System Operability and Reliability,

3. Financial Adequacy in Market Environments,

4. Gas-Electric Coordination.

1. Developing Flexible Systems Using Technological Innovation and Integration

As discussed above, both technological change and society demands are occurring at an accelerated pace in today’s electric utility industry, and new challenges are being posed for the industry by emerging government policies relating to climate change and energy security. In particular, industry interest in Smart Grid offers new opportunities for markets to leverage technological changes. A flexible infrastructure, market structure, and supporting systems are vital to ensure a smooth evolution of the industry. As "smart" transmission devices such as FACTS and HVDC provide more flexibility in the transmission grid, issues include how to model and price these smart devices in markets in conjunction with transmission switching, unit re-dispatch, and optimal power flow control.

Topics in the Market Stem related to Smart Grid include developing ways in which technological developments can create smart markets and smart customers. Characteristics of smart markets include:

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• Being sufficiently transparent and providing price, tariff and usage information, and providing pricing structures, sufficient to facilitate cost-effective demand response, distributed generation, and conservation responses needed to benefit customers,

• Having sufficient communication capabilities to enable participation of demand response and distributed generation,

• Creating pricing structures and market products that help integrate renewable resources into the grid, and

• Enabling fair competitive markets, and increasing grid reliability and resilience, in the presence of uncertainty in market behavior, stochastic resources and demand response, and network topology changes.

To be effective in a smart market, it is essential for entities that manage retail programs and pricing to maintain close coordination with entities (e.g., ISOs and RTOs) that manage wholesale markets to link wholesale market prices, which are explicitly designed to reflect temporal and locational grid conditions, to the retail-level response. The development of Smart Grid plans should address what technological capabilities will be needed to link grid conditions with signals to retail customers. The consideration of demand response should not be limited to traditional program designs for peak load reduction, but should also include commercial and industrial process control, flexible operation of programs involving small end users, and strategies for electric vehicle charging.

Development of smart customers (including owners of distributed generation) includes (1) fostering an evolution of the utility customer from a recipient of energy to a participant in the grid, through consideration of customer expectations about the Smart Grid, (2) formulating strategies for education on why energy issues matter to individual customers, how they can more efficiently use electricity, and how customer expectations align with the realities of technology, and (3) providing customers with meaningful and actionable information about real-time grid conditions, including easy-to-follow methods of understanding when grid stability and reliability depend on their immediate action. In particular, in connection with the integration of an increased quantity of variable energy resources, that immediate customer action may include increased consumption (such as during times of oversupply), as well as the more traditional notions of decreased consumption during periods of scarce supply.

Innovative solutions for adding flexibility to existing systems include energy storage and demand response. Knowledge of any real barriers to developing these as flexible resources is limited, and any barriers may not be initially apparent. For example, ISOs can facilitate resource development, but should not cross lines that would place ISOs in roles where they become market participants. The benefits of a flexible system for production and delivery are increased reliability, affordability, sustainability, and environmental quality.

2. New or Refined Market Products for System Operability and Reliability

The initial years of experience in restructured electric markets shows that markets have integrated multiple products, including energy, spinning and non-spinning reserve, and regulation, but have also shown that these markets are not complete. For example, day-ahead and real-time market horizons do not fully account for the range of generators’ start-up times, and assessments of extended unit commitment horizons may increase the optimality of dispatch. In addition, recently completed studies show that the operational challenges that the markets need to address are increasing in complexity with the increasing use of renewable resources, for example increases in regulation and load following requiring thousands of MW of storage or new conventional (fossil fuel or hydroelectric) generation that can respond quickly to the variable output of wind and solar resources. New markets are developing for optimal dispatch of real-time imbalance energy, crossing boundaries between central and bilateral market areas, in which design issues include bidding processes, seams issues including transmission rate design merging access charges of an organized market with bilateral contracts into single structure to support real-time dispatch, and integration of regulations such as greenhouse gas rules. Existing definitions of ancillary services ensure that designated amounts of committed and quick-start generation reserves are procured, but rapid system ramping can mean that the reserved capacity is not fully available to provide reserves. Also, existing definitions of ancillary services do not fully reflect the capacity value that storage and demand response can provide through rapid ramping but with limited time spans of delivering net energy. New requirements such as frequency response reserve are being defined, and through experience in existing markets, requirements for market products can

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become refined. Requirements also arise for competitive procurement of services such as black start capability and voltage support. Possible research topics include:

• How can the benefits and costs of existing market structures be compared, to inform new market entrants or existing markets that are considering market changes? The areas in which benefits can be considered include reliability, economic savings, operational benefits, and possibly other issues, and neglecting benefits in only some areas can cause decision-making to be incomplete.

• What issues arise as bilateral market areas begin participating in structures such as energy imbalance markets, and how can these issues be resolved? Examples of such issues include:

o In FERC's decision approving CAISO's proposal to extend its real-time market as an energy imbalance market extending beyond its balancing authority area, FERC supported the elimination of rate pancaking within the expanded market area as CAISO proposed. FERC found that such market transfers are sufficiently distinct from exports to justify different rate treatment from interchange transactions. As CAISO or other market operators further consider their transmission rate structures when markets cross balancing authority areas, are there superior alternatives from a market efficiency perspective?

o With different states using different approaches to resource adequacy (e.g., establishment of planning reserve margins), and a market operator not necessarily being a reliability coordinator, some form of resource sufficiency conditions are needed in the design of energy imbalance markets to avoid "leaning" among market participants. Have the most efficient resource sufficiency criteria been identified?

o Beyond settlements that apply directly to energy production and consumption, uplift and neutrality costs are inevitable. How can uplift cost allocation be designed to ensure market efficiency?

o Existing benefit studies of energy imbalance markets have quantified economic benefits, with studies of reliability benefits being more qualitative. How can the reliability benefits be quantified for comparison to economic benefits and costs?

• How can new products (e.g., ramping reserve, frequency response reserve, black start, voltage support, demand response) be integrated into existing markets? What are the best procurement methods for new products?

• Do different market environments require different products and/or reliability criteria?

• How can supply of these new products be qualified?

• What refinements in market products can be identified from experience in existing markets? For example, pricing algorithms for computing LMPs could consider marginal value limits rather than administratively-determined penalty prices when implementing constraint relaxation.

The evolution of new market products can also introduce new types of market participants, whose interactions in the market need to be understood and alternative business models explored. In particular, FERC issued Order 719 requiring RTOs and ISOs to allow Aggregators of Retail Customers that are not affiliated with load serving entities (i.e., a new type of market participant) to bid demand response on behalf of retail customers directly into the RTO’s or ISO’s organized markets, unless prohibited by the laws or regulations of the retail regulatory authority. The FERC order facilitates demand response by providing a commercial interface for procurement of retail demand response products that can be aggregated into wholesale load response resources, which can be offered into the ISO energy and ancillary service markets. The issues involved in this new type of market participant include:

• Defining the terminology, roles, and responsibilities of the demand response aggregator,

• Defining relationships between the DR aggregators and end-use customers, energy service providers, utility distribution companies, ISOs and RTOs, and wholesale scheduling coordinators, including registration and notification processes among the involved parties,

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• Identifying and resolving existing tariff impediments,

• Specifying metering and communication requirements,

• Determining performance measurement & verification approaches,

• Establishing financial settlement processes and credit requirements among DR aggregators, load serving entities, and other actors in the marketplace.

Research proposals for addressing these evolving needs for market products should recognize three primary areas that will affect the success of potential solutions: technology, economics, and the regulatory environment. Several examples of industry concerns that could be overcome if the supply infrastructure and market structure were more adaptable to such needs are:

Areas of Concern Examples

Reliable power delivery Economics of transmission enhancements and the associated costs, benefits, & risks

Scalability Computational ability of computers

Fuel mix diversity Dependency on natural gas generation

Environment and Global Climate Change Dispatch to environmental constraints and regulatory requirements

Adoption of new technology Incentives for demand response, distributed generation, etc.

Decentralized decision making Municipal energy systems

3. Financial Management in Market Environments

Responses to past years’ solicitations have resulted in beneficial information concerning financial aspects of market participation, and methods of facilitating market participation and investments that are guided by market outcomes. These topics remain of interest, but new proposals should build on the results of previous studies and further develop their integration into energy markets, or develop knowledge in areas that have not been explored previously.

• Risk Management in Different Markets: This research theme focuses on the design, pricing and analysis of instruments and contractual mechanisms that facilitate the management, diversification and allocation of risk in the electricity supply chain and other energy applications, associated with investment, production, consumption, and energy trading activities. Topics in this area also include the application of financial and real option approaches, portfolio optimization involving real and financial assets, and the interaction of risk management instruments with system operations and long-term investments.

• Investment Incentives and Resource Adequacy: This research theme focuses on identifying and analyzing barriers and solution approaches to planning and investment in power markets, including resource adequacy related issues in generation and transmission. With regard to transmission investment, projects may focus on market driven and regional planning approaches to transmission investment, economic assessment of transmission upgrades, long term transmission rights, the role of independent transmission companies, cost recovery approaches, coordination of transmission and generation investment, etc. With regard to generation adequacy and investment incentives in generation capacity, research projects may focus on identifying and analyzing incentive mechanisms and market based approaches to promoting and remuneration of adequate generation resource and demand side participation in determining and achieving adequacy objectives.

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4. Gas-Electric Coordination

In the past 10 years a combination of environmental restrictions, advancements in turbine technology and the success of hydraulic fracturing have caused natural gas to be the fuel of choice for nearly all new thermal generators. At current trends, in the next several years natural gas-fired generators will surpass coal generators as the largest source of electric supply in the United States. Natural gas is already the dominant fuel for power markets in New York, New England, Texas and California. While new gas turbines are reliable and flexible they rely on a fuel that it delivered just-in-time over a pipeline network with business practices, market rules and schedules that were not designed to synchronize with electric sector business practices, market rules and schedules. Some regions have mitigated gas-electric coordination issues by securing firm pipeline transportation, gas storage, backup fuel supplies, firm transmission delivery, resource diversity, and other options, which have increased the firmness of energy supplies, but there has been a cost for this mitigation. In other regions, issues include the following:

• Market Timing: The gas day and the electric day are not synchronized, and therefore base loaded and some intermediate loaded gas generators must schedule gas over two days to meet the schedule for a single electric day. Electric generators typically must submit next-day offers before the trading window opens for next day gas. Generators can either buy gas before submitting their electric schedule and take the risk that they will be dispatched, or wait and take the risk that they can purchase gas once their schedule is known. Gas is sold daily rather than hourly, with pipelines tariffs generally requiring gas to be consumed evenly over the day (a “ratable take” of 1/24th per hour), whereas electric generators must follow load, and may only be dispatched at peak. Gas markets are only liquid during regular business hours, whereas electric markets are 24/7. Pricing rules may not allow generators to reflect the true cost of intraday gas, and gas pipelines oppose rules that would encourage generators to consume gas at any cost, as they need non-firm customers to get off the system when demand from space-heating customers is high.

• Market Incentives: Arguably, there is a missing market signal for resources to maintain adequate fuel supply to ensure reliability. Most electric markets do not explicitly require gas-fired generators to purchase firm gas or pay for fuel assurance – the cost is assumed in the offer price. The system operator’s ability to secure emergency power can limit the financial exposure of gas generators and therefore may distort the incentive to purchase firm fuel supply. Electric markets with capacity requirements may financially penalize generators for derates and forced outages, but these penalties, and the associated planning processes, assume that derates and outages are random and uncorrelated, which may not be the case when gas-fired units derate or declare an outage for lack of fuel.

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Current and Past Systems Research Projects

Systems research concentrates on efficient and reliable operation of the increasingly complex and dynamic power system.

Current Projects (PDF version has titles linked to project summaries on the PSERC website)

Projects ending in 2017

• Advanced Cyber-Physical Analysis for Smart Grid Distributed ICT and IED Resources at RTE France (S-63G) • Monitoring and Maintaining Limits of Area Transfers with PMUs (S-64) • Real Time Synchrophasor Measurements Based Voltage Stability Monitoring and Control

(S-65) • Representation, Modeling, Data Development and Maintenance of Appropriate Protective Relaying Functions

in Large Scale Transient Stability Simulations (S-66)

Projects ending in 2016

• Hybrid Time Domain Simulation: Application to Fault Induced Delayed Voltage Recovery (S-58) • Sparse Sensing Methods for Model-Free Sensitivity Estimation and Topology Change Detection using

Synchro-Phasor Measurements (S-59) • Load Model Complexity Analysis and Real-Time Load Tracking (S-60)

Projects ending in 2015

• Towards a Privacy-Aware Information-Sharing Framework for Advanced Metering Infrastructures (S-54) • Toward Standards for Dynamics in Electric Energy Systems (S-55) • Stability, Protection and Control of Systems with High Penetration of Converter-Interfaced Generation (S-56) • Adaptive and Intelligent PMUs for Smarter Applications (S-57) • Day-ahead and Real-Time Models for Large-Scale Energy Storage (S-61G) • Seamless Grid Management (S-62G)

Completed Systems Stem Projects (Titles linked to the final reports on the PSERC website.)

• Seamless Energy Management Systems Part I: Assessment of Energy Management Systems and Key Technological Requirements (2014, S-53G – Part I)

• Seamless Energy Management Systems Part II: Development of Prototype Core Elements (2014, S-53G – Part II)

• Coordinated Aggregation of Distributed Demand-Side Resources (2014, S-52, full report currently available for PSERC member viewing only)

• The Application of Robust Optimization in Power Systems (2014, S-51) • Real Time PMU-Based Stability Monitoring (2014, S-50) • Exploiting Emerging Data for Enhanced Load Modeling (2014, S-49) • Testing and Validation of Phasor Measurement Based Devices and Algorithms (2013, S-45) • Data Mining to Characterize Signatures of Impending System Events or Performance from PMU

Measurements (2013, S-44) • Setting-less Protection Methods (2012, S-48G) • Integrated EMS for Seamless Power System Analytics (2012, S-47G)

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• Seamless Power System Analytics (2012, S-46G) • Low Frequency Transmission for Wind Farm Power (2012, S-42) • Tools and Techniques for Considering Transmission Corridor Options to Accommodate Large Scale

Renewable Energy Resources (2012, S-41) • Integration of Storage Devices into Power Systems with Renewable Energy Sources

(2012, S-40) • The Smart Grid Needs: Model and Data Interoperability, and Unified Generalized State Estimator (2012, S-39) • Toward a Systematic Framework for Deploying Synchrophasors and their Utilization for Improving

Performance of Future Electric Energy Systems (2012, S-37) • Validation and Accreditation of Transient Stability Results (2011, S-43G) • Next Generation On-Line Dynamic Security Assessment (2011, S-38) • Techniques for the Evaluation of Parametric Variation in Time-Step Simulations (2011, S-17) • Using PMU Data to Increase Situational Awareness (2010, S-36) • System Protection Schemes: Limitations, Risks, and Management (2010, S-35)

• Implementation Issues for Hierarchical, Distributed State Estimators (2010, S-33) • Fast Simulation, Monitoring, and Mitigation of Cascading Failures (2010, S-32) • Real-Time Security Assessment of Angle Stability and Voltage Stability Using Synchrophasors (2010, S-31) • Impact of Increased DFIG Wind Penetration on Power System Reliability and Consequent Market Adjustments

(2009, S-34) • Development and Evaluation of System Restoration Strategies from a Blackout (2009, S-30) • Detection, Prevention and Mitigation of Cascading Events – Prototype Implementations (2008, S-29) • Preventing Voltage Collapse with Protection Systems that Incorporate Optimal Reactive Power Control (2008,

S-28) • Decision Tree Based Online Voltage Security Assessment Using PMU Measurements (2008, S-27G) • Risk of Cascading Outages (2008, S-26) • Effective Power System Control Center Visualization (2008, S-25) • Optimal Allocation of Static and Dynamic VAR Resources (2008, S-24) • Enhanced State Estimators (2006, S-22) • Security Enhancement through Direct Non-Disruptive Load Control: Part I, Part II (2006, S-16)Both good

• Optimal Placement of Phasor Measurement Units for State Estimation (2005, S-23G) • On-Line Transient Stability Assessment Scoping Study (2005, S-21) • New Implications of Power System Fault Current Limits (2005, S-20) • Detection, Prevention and Mitigation of Cascading Events: Part I, Part II, Part III (2005, S-19) • Visualization of Power Systems and Components (2005, S-18) • Extended State Estimation for Synchronous Generator Parameters (2005, S-15) • Comprehensive Power System Reliability Assessment (2005, S-13) • New System Control Methodologies (2005, S-6) • Risk-Based Maintenance Allocation and Scheduling for Bulk Transmission System Equipment (2003, S-14) • Integrated Security Analysis (2003, S-7) • Robust Control of Large-Scale Power Systems (2002, S-12) • Steady State Voltage Security Margin Assessment (2002, S-11) • Power System State Estimation and Optimal Measurement Placement for Distributed Multi-Utility Operation

(2002, S-10) • Coordination of Transmission Line Transfer Capabilities (2002, S-8)

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• Voltage Collapse Margin Monitor (2002, S-2) • Identification and Tracking of Parameters for a Large Synchronous Generator (2002, S-1) • Automated Operating Procedures for Transfer Limits (2001, S-5) • Impact of Protection Systems on Reliability (2001, S-4) • Avoiding and Suppressing Oscillations (2000, S-3)

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Current and Past T&D Technologies Research Projects

T&D research improves transmission and distribution systems through use of technology innovations.

Current Projects (PDF version has linked to project summaries on the PSERC website.)

Projects ending in 2018

• Life-cycle Management of Mission-Critical Systems through Certification, Commissioning, In-Service Maintenance, Remote Testing, and Risk Assessment (T-57)

Projects ending in 2016

• Reliability Assessment and Modeling of Cyber Enabled Power Systems with Renewable Sources and Energy Storage (T-53)

• Setting-less Protection (2014 Plan Part I): Centralized Substation Protection (T-55G) • Setting-less Protection (2014 Plan Part II): Field Demonstrations (T-56G)

Projects ending in 2015

• Systematic Integration of Large Data Sets for Improved Decision-Making (T-51) • Establishing a Controls Laboratory for Training, Research and Development, and Experimentation (T-54G)

Completed T&D Projects (Titles linked to the final reports on the PSERC website)

• Setting-less Protection Methods: Laboratory Demonstrations (2014, T-52G) • The Electricity and Transportation Infrastructure Convergence Using EVs (2014, T-50G) • The Economic Case for Bulk Energy Storage in Transmission Systems with High Percentages of Renewable

Resources (2014, T-48) • Making the Economic Case for Innovative HTLS Overhead Conductors (2014, T-47) • Setting-less Protection (2013, T-49G) • The Next Generation EMS Design (2013, T-45) • Distribution System Analysis Tools for Studying High Penetration of PV with Grid Support Features (2013, T-

44) • Evaluation of RTV Coated Station Insulators (2012, T-46G) • Verifying Interoperability and Application Performance of PMUs and PMU-Enabled IEDs at the Device and

System Level (2012, T-43) • Micro and Nano Dielectrics for Utility Applications (2012, T-42) • Communication Requirements and Integration Options for Smart Grid Deployment (2012, T-39) • Implications of the Smart Grid Initiative on Distribution Engineering, Part 1, Part 2, Part 3, Part 4 (2011, T-41) • PHEVs as Dynamically Configurable Dispersed Energy Storage (2011, T-40) • Transformer Overloading and Assessment of Loss-of-Life for Liquid-Filled Transformers (2011, T-25) • Substation of the Future: A Feasibility Study (2010, T-38) • The 21st Century Substation Design (2010, T-37) • Comparative Characterization of Parallel Distribution Sensors Under Field Conditions (2010, T-35) • Integration of Asset and Outage Management Tasks for Distribution Applications (2009, T-36) • Power System Level Impacts of Plug-In Hybrid Vehicles (2009, T-34)

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• Characterization of Composite Cores for High Temperature-Low Sag Conductors (2009, T-33) • Integration of Substation IED Information into EMS Functionality (2008, T-32) • Massively Deployed Sensors (2008, T-31) • Transient Testing of Protective Relays: Study of Benefits and Methodology (2008, T-30) • Digital Protection System Using Optical Instrument Transformers and Digital Relays Interconnected by an IEC

61850-9.2 Digital Process Bus (2008, T-29) • Satellite Imagery for the Identification of Interference with Overhead Power Lines (2008, T-28) • Reliability-Based Vegetation Management Through Intelligent System Monitoring (2007, T-27) • Prediction of Flashover Voltage of Insulators Using Low Voltage Surface Resistance Measurement (2006, T-

26G) • Risk-Based Maintenance Resource Allocation for Distribution System Reliability Enhancement (2006, T-24) • Novel Approach for Prioritizing Maintenance of Underground Cables (2006, T-23) • Performance Assessment of Advanced Digital Measurement and Protection Systems: Part I, Part II (2006, T-

22) • Automated Integration of Condition Monitoring with an Optimized Maintenance Scheduler for Circuit Breakers

and Power Transformers (2006, T-19) • Control and Design of Microgrid Components (2006, T-18) • Enhanced Reliability of Power System Operation Using Advanced Algorithms and IEDs for On-Line

Monitoring: Part I, Part II (2005, T-17) • Voltage Sag Effect on Loads in Electric Power Systems (2005, T-16) • Distribution System Electromagnetic Modeling and Design for Enhanced Power Quality (2005, T-12) • Distributed Electric Energy Storage and Generation (2004, T-21) • Smart Sensor Development for Power Transmission and Distribution: Optical Sensor for Transformer

Monitoring (2004, T-20) • Evaluation of Critical Components of Non-Ceramic Insulators In-Service: Role of Seals and Interfaces (2004,

T-14) • Intelligent Substation (2004, T-5) • Personnel Grounding and Safety Issues / Solutions Related to Servicing Telecommunications Equipment

Connected to Fiber Optic Cables in Optical Ground Wire (OPGW) (2002, T-13) • Power System Monitoring Using Wireless Substation and System-Wide Communications: Part I, Part II

(2002, T-11) • Accurate Fault Location in Transmission and Distribution Networks Using Modeling, Simulation and Limited

Field-Recorded Data (2002, T-10) • Enhanced State Estimation via Advanced Substation Monitoring (2002, T-9) • Investigation of Fuel Cell Operation and Interaction within the Surrounding Network (2002, T-8) • Condition Monitoring and Maintenance Strategies for In-Service Non-ceramic Insulators, Underground Cables

and Transformers (2002, T-6) • Differential GPS Measurement of Overhead Conductor Sag and Software Implementation (2002, T-2) • Corona Discharge Caused Deterioration of All Dielectric Self-Supporting Fiber-Optic Cables (2002, T-1) • Redesign and New Interpretation of Power Acceptability Curves for Three Phase Loads (2001, T-7) • Electrical Transmission Line Insulator Flashover Predictor (2001, T-4) • On-Line Peak Loading of Substation Distribution Transformers Through Accurate Temperature Prediction

(2001, T-3)

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Current and Past Markets Research Projects

Markets research focuses on planning, design and operation of smart markets for a smart electric grid.

Current Projects (PDF version has linked to project summaries on the PSERC website.)

Projects ending in 2017

• Reliability Metrics for Renewable Resources and Self-Reserves (M-33) • Risk Assessment of Constraint Relaxation Practices (M-34)

Projects ending in 2016

• Markets for Ancillary Services in the Presence of Stochastic Resources (M-31) • New Operation Tools for Improving Flexibility and Reliability of Systems with Variable Resources and

Storage Devices (M-32)

Projects ending in 2015

• Constraint Relaxations: Analyzing the Impacts on System Reliability, Dynamics, and Markets (M-29) • A Framework for Transmission Planning Under Uncertainty (M-30)

Completed Projects (Titles linked to the final reports on the PSERC website.) • Analytical Methods for the Study of Investment Strategies in Compliance with Environmental Policy

Requirements (2013, M-28) • Impact of Bad Data and Cyber Data Attack on Electricity Market Operation (2013, M-27) • Quantifying Benefits of Demand Response and Look-ahead Dispatch in Support of Variable Resources (2013,

M-26) • The Development and Application of a Distribution Class LMP Index (2013, M-25) • Interactions of Multiple Market-based Energy and Environmental Policies in a Transmission-Constrained

Competitive National Electricity Market (2012, M-24) • Design and Valuation Design and Valuation of Demand Response Mechanisms and Instruments for Integrating

Renewable Generation Resources in a Smart Grid Environment (2012, M-23) • Coupling Wind Generation with Controllable Load and Storage: A Time-Series Application of the SuperOPF

(2012, M-22) • Integration of Storage Devices into Power Systems with Renewable Energy Sources

(2012, S-40) • PHEVs as Dynamically Configurable Dispersed Energy Storage (2011, T-40) • Technical and Economic Implications of Greenhouse Gas Regulation in a Transmission Constrained

Restructured Electricity Market (2010, M-21) • Improved Investment and Market Performance Resulting from Proper Integrated System Planning (2010, M-

18) • Optimal Electricity Market Structures to Reduce Seams and Enhance Investment (2010, M-9) • Facilitating Environmental Initiatives While Maintaining Efficient Markets and Electric System Reliability

(2009, M-20) • Integrated Financial and Operational Risk Management in Restructured Electricity Markets (2009, M-17)

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• Integrating Electric System Planning with Efficient Markets to Provide Adequate Investment (2009, M-16)

• Economic Impact Assessment of Transmission Enhancement Projects (2009, M-14) • Tools for Assessment of Bidding into Electricity Auctions (2008, M-15) • Agent Modeling for Integrated Power System, Power and Fuel Market Simulation (2008, M-13) • Reliability, Electric Power, and Public Vs. Private Goods: A New Look at the Role of Markets (2008, M-12) • Evaluation of Alternative Market Structure and Compensation Schemes for Incenting Transmission Reliability

and Adequacy Related Investments (2008, M-11) • Electric Power Industry and Climate Change – Discussion Paper (2007, M-19) • Uncertain Power Flows and Transmission Expansion Planning (2007, M-10) • Reliability Assessment Incorporating Operational Considerations and Economic Aspects for Large

Interconnected Grids (2007, M-8) • Modeling Market Signals for Transmission Adequacy Issues: Valuation of Transmission Facilities and Load

Participation Contracts in Restructured Electric Power Systems (2007, M-6) • Software Agents for Market Design and Analysis (2005, M-5) • Market Redesign: Incorporating the Lessons Learned from Actual Experiences for Enhancing Market Design

(2005, M-4) • Structuring Electricity Markets for Demand Responsiveness: Experiments on Efficiency and Operational

Consequences (2004, M-7) • Market Interactions and Market Power (2003, M-3) • Market Mechanisms for Competitive Electricity (2002, M-2) • Reactive Power Support Services in Electricity Markets (2000, M-1)

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Brief Descriptions of Current Projects Ending in 2015 (Final Reports Available in 2015)

Towards a Privacy-Aware Information-Sharing Framework for Advanced Metering Infrastructures (S-54)

Summary Advanced Metering Infrastructure (AMI) initiatives are a popular way for modernizing the electricity grid, reducing peak loads, and meeting energy-efficiency targets; however, privacy concerns have limited customer acceptance of these initiatives. This project’s research objective is to design appropriate architectures for information collection and dissemination with security and privacy guarantees. The project will also develop state-of-the-art algorithms and protocols for privacy-preserving communication and control that effectively exploit AMI for improved system operations and active customer participation.

Academic Team

Project Leader: Vinod Namboodiri (Wichita State Univ., [email protected]) Team members: Lalitha Sankar (Arizona State Univ., [email protected]); Visvakumar Aravinthan (Wichita State Univ., [email protected]); Murtuza Jadliwala (Wichita State Univ., [email protected])

Industry Advisors

Mirrasoul Mousavi (ABB); Slobodan Matic; (GE); Debbie Brodt-Giles (NREL)

Toward Standards for Dynamics in Electric Energy Systems (S-55)

Summary This project introduces systematic control and protection requirements based on wide-area measurement systems (WAMS) to avoid system-wide instabilities and large power/voltage swings. Test cases will be run to illustrate the stabilizing effects of fast control designed according to the proposed standards. A comparison of the new control designs to the effects of today’s Special Protection Schemes (SPS’s) will also be studied. The simulations will demonstrate how such control can prevent a dynamic system collapse. Estimates will be provided of reduced system-level dynamic reserve requirements when the proposed standards are enforced.

Academic Team

Project Leader: Marija Ilic (Carnegie Mellon; [email protected]) Team members: Vijay Vittal (Arizona State, [email protected]); Le Xie (Texas A&M Univ., [email protected])

Industry Advisors

Xiaoming Feng (ABB); Reynaldo Nuqui (ABB); Kip Morrison (BC Hydro); Michael Yao (BC Hydro); Khaled Abdul-Rahman (CAISO); Enamul Haq (CAISO); Mahendra Patel (EPRI); Erik Ela (EPRI); Nilanjan Chaudhuri (GE Global Research); Innocent Kamwa (IREQ); Eugene Litvinov (ISONE); Jason Ausmus (ITC Holdings); Kevin Harrison (ITC Holdings); Mark Westendorf (MISO); Ed Mujadi (NREL); Bruce Fardanesh (NYPA)

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Stability, Protection and Control of Systems with High Penetration of Converter-Interfaced Generation (S-56)

Summary If the power fed by converters reaches 100% penetration in a local area, and if that area is remote from synchronous machines, grid behavior might be very different than expected. Would it be possible to operate a power grid without synchronous machines? Are there requirements essential to allowing a system to operate correctly even if this operation is different than it is today? We will conduct exploratory research for defining and evaluating new approaches for stability, protection, balancing control, and voltage/VAr control of systems with high penetration of converter-interfaced generation.

Academic Team

Project Leader: Sakis Meliopoulos (Georgia Tech, [email protected]) Team members: Vijay Vittal (Arizona State Univ., [email protected]); Raja Ayyanar (Arizona State Univ., [email protected]); Maryam Saeedifard (Georgia Tech, [email protected])

Industry Advisors

Mirrasoul Mousavi (ABB); Reynaldo Nuqui (ABB); Baj Agrawal (APS); Wenyuan Li (BC Hydro); Steven Whisenant (Duke Energy); Yishan Zhao (Duke Energy); Sharma Kolluri (Entergy); Alan Engelmann (Exelon-ComEd); Evangelos Farantatos (EPRI); Mahendra Patel (EPRI); Joseph Waligorski (FirstEnergy); Naresh Acharya (GE Global Research); Bill Henson (ISONE); Kamwa Innocent (IREQ); Durgesh Manjure (MISO); Mark Westendorf (MISO); Bruce Fardanesh (NYPA); George Stefopoulos (NYPA); Mariko Shirazi (NREL); Mahendra Patel (EPRI); Patrick Panciatici (RTE France); Sebastien Henry (RTE France), Thibault Prevost (RTE France), Douglas Bowman (SPP), Harvey Scribner (SPP), Brian Keel (SRP), Bill Middaugh (Tri-State)

Adaptive and Intelligent PMUs for Smarter Applications (S-57)

Summary One PMU does not fit all applications and all operating conditions. PMU performance varies with operating conditions. Phasor based applications may use only some PMU measurements. Measurement accuracy depends on selected phasor estimation algorithms. Distributed applications may require some local PMU calculations and data manipulation. User-defined bits can be used to realize enhanced PMU capability for smarter applications. PMU interchangeability with changing applications is an important issue. This project considers these and other aspects of PMU use to develop an ‘adaptive’ and ‘intelligent’ PMU for smarter applications.

Academic Team

Project Leader: Anurag Srivastava (Washington State, [email protected]) Team Members: Vijay Vittal (Arizona State Univ, [email protected]); Sakis Meliopoulos (Georgia Tech, [email protected]); Pete Sauer (Univ. of Illinois at Urbana-Champaign, [email protected])

Industry Advisors

Xiaoming Feng (ABB); Reynaldo Nuqui (ABB); William Kouam Kamwa (AEP); James Kleitsch (ATC); Giuseppe Stanciulescu (BC Hydro); Mahendra Patel (EPRI); Evangelos Farantatos (EPRI); Innocent Kamwa (IREQ); Qiang Zhang (ISONE); Farrokh “Frank” Habibiashrafi (SCE)

xxxi

Day-ahead and Real-Time Models for Large-Scale Energy Storage (S-61G)

Summary As renewable penetrations increase, the uncertainty and variability of wind and solar may be alleviated with bulk energy storage technologies. This project develops new models and algorithms to effectively integrate energy storage technologies within existing energy management systems and market management systems.

Academic Team

Project leader: Kory W. Hedman (Arizona State Univ., [email protected]) Team member: Ward T. Jewell (Wichita State Univ., [email protected])

Industry Advisors

Xiaoming Feng (ABB); Khosrow Moslehi (ABB); Xing Wang (Alstom Grid); Aftab Alam (CAISO); Rudy Bombien (Duke Energy); Erik Ela (EPRI [was with NREL]); Sean Wright (EPRI); Hussam Sehwail (ITC Holdings); Zheng Zhou (MISO); Vikas Dawar (NYISO); Bruce Fardanesh (NYPA); Deepak Maragal (NYPA); Alva Svoboda (PG&E); Hong Chen (PJM); Charlton Clark (U.S. DOE)

Seamless Grid Management (S-62G)

Summary For analyzing ideas for EMS and associated analytics, a flexible platform is needed that can simulate the layers of high voltage hardware, the IT hardware, and the various software packages that run applications for operating the grid. Such a simulation platform is needed to test ideas involving individual components (e.g., a new electronic controller) to operational procedures (e.g., fast wide-area control schemes). In this project we will build a simple platform to determine the feasibility and complexity of building a simulation platform that mimics a real continent-wide grid interconnection.

Academic Team

Project Leader: Anjan Bose (Washington State Univ., [email protected]) Team Members: Santiago Grijalva (Georgia Tech, [email protected]); Tom Overbye (Univ. of Illinois at Urbana-Champaign, [email protected])

Industry Advisors

Jay Giri (Alstom Grid); Paul Myrda (EPRI); Eugene Litvinov (ISONE); Patrick Panciatici (RTE-France)

Systematic Integration of Large Data Sets for Improved Decision-Making (T-51)

Summary The power industry is facing the challenge of how to manage and utilize large data sets (often called “Big Data”) made available by smart grid technologies. The key unresolved issue is the systematic integration and pre-processing of these large datasets for decision-making. This project offers a solution for data integration through correlating data in time and space, and through assuring that the data syntax and semantic needed for decision-making data analytics are consistent and interoperable. This is achieved through referencing all big data to a unified and generalized system model.

Academic Team

Project Leader: Mladen Kezunovic (Texas A&M, [email protected]) Team members: Le Xie (Texas A&M, [email protected]); Polo Chau (Georgia Tech, [email protected]); Santiago Grijalva (Georgia Tech, [email protected])

Industry Advisors

Mirrasoul Mousavi (ABB); William Kouam Kamwa (AEP); Jay Giri (Alstom Grid); Mahendra Patel (EPRI); Eugene Litvinov (ISONE); Aaron Beach (NREL); David Martinez (SCE); Bill Timmons (WAPA)

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Establishing a Software-Based Real-Time Simulation Laboratory for Training, Research and Development, and Experimentation (T-54G)

Summary This project aims to comprehensively design and provide a list of components required for a functional software-based real-time simulation platform for SCE based on the SCE's needs, facilities, and goals for hardware-in-the-loop setup using the existing units. Availability of such a setup additionally helps SCE, and potentially other companies, in seamless transfer of employees from one department, in which they are experienced, to another in which they are new. This work has broader applications for other companies with similar needs who can benefit from the results of this work.

Academic Team

Project Leader: Ali Mehrizi-Sani (Washington State University, [email protected])

Industry Advisors

Andy Paylan (SCE)

Constraint Relaxations: Analyzing the Impacts on System Reliability, Dynamics, and Markets (M-29)

Summary When appropriate, system operators allow constraints in power flow models to be relaxed. This is done to: 1) limit shadow prices in markets and 2) reduce infeasible solutions. This project team will: 1) develop models to assess the impact of constraint relaxations on reliability and on system dynamics; 2) conduct economic and reliability studies to determine the appropriate price cap on shadow prices and compare these findings to the currently implemented caps; and 3) analyze market implications of using price caps on shadow prices, and propose alternative mechanisms.

Academic Team

Project Leader: Kory Hedman (Arizona State Univ., [email protected]) Team Members: Vijay Vittal (Arizona State Univ., [email protected]); Jim McCalley (Iowa State Univ., [email protected])

Industry Advisors

Chien-Ning Yu (ABB); Khosrow Moslehi (ABB); Xing Wang (Alstom Grid); David Gray (Alstom Grid); Jim Price (CAISO); Mahendra Patel (EPRI); Robert Entriken (EPRI); Erik Ela (EPRI); Feng Zhao (ISONE); Li Zhang (MISO); Marissa Hummon (NREL); Michael Swider (New York ISO); Muhammad Marwali (New York ISO); Alva Svoboda (PG&E); Hong Chen (PJM); Jay Liu (PJM); Juan Castaneda (SCE)

A Framework for Transmission Planning Under Uncertainty (M-30)

Summary Currently transmission planning in practice primarily uses deterministic techniques. However, transmission planning confronts a wide range of sources of uncertainty that may be difficult to characterize analytically. In this project, we will develop a new framework for transmission planning that explicitly considers uncertainty. We will collect a representative set of transmission planning requirements and investigate the construction of an appropriate framework that supports decision-making through analytical expression of the underlying uncertainties.

Academic Team

Project Leader: Lizhi Wang (Iowa State Univ., [email protected]) Team members: George Gross (Univ. of Illinois at Urbana-Champaign, [email protected]); Sakis Meliopoulos (Georgia Institute of Technology, [email protected])

Industry Advisors

Lan Trinh (ABB); Anil Jampala (Alstom Grid); Flora Flygt (ATC); Kip Morison (BC Hydro); Aftab Alam (CAISO); Jim Price (CAISO); Anish Gaikwad (EPRI); Feng Zhao (ISONE); David Mindham (ITC Holdings); Hussam Sehwail (ITC Holdings); Aditya Jayam Prabhakar (MISO); Michael Swider (New York ISO); Juan Castaneda (SCE); Robert Sherick (SCE); Shih-Min Hsu (Southern Company); Murali Kumbale (Southern Company); Harvey Scribner (SPP)

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Brief Descriptions of Current Projects Ending in 2016 (Final Reports Available in 2016)

Hybrid Time Domain Simulation: Application to Fault Induced Delayed Voltage Recovery (S-58)

Summary This project develops an approach for hybrid time domain simulation that represents desired portions of the system in variable detail and that can analyze phenomena requiring attention to unbalance in phases, unsymmetrical faults, and devices represented on a single phase basis. The proposed method is applicable to a number of problems, such as Geomagnetically Induced Currents, HV ACDC systems, and inverter interfaced generation. The hybrid simulation will be demonstrated in a study of Fault Induced Delayed Voltage Recovery phenomena. More generally, it enables electromagnetic transient analysis at the required locations.

Academic Team

Project Leader: Vijay Vittal (Arizona State Univ., [email protected]) Team member: Sakis Meliopoulos (Georgia Tech, [email protected])

Industry Advisors

Bajarang Agrawal (APS); Evangelos Farantatos (EPRI); Anish Gaikwad (EPRI); Mahendra Patel (EPRI); Bruce Fardanesh (NYPA); Patrick Panciatici (RTE-France); Brian Keel (SRP); Juan Castaneda (SCE)

Sparse Sensing Methods for Model-Free Sensitivity Estimation and Topology Change Detection using Synchro-Phasor Measurements (S-59)

Summary Conventional model-based applications used for real-time monitoring and control are not ideal since the results depend on an accurate model with up-to-date network topology which may not be available. This project will pursue “model-free” estimation of the power flow Jacobian and related sensitivity matrices in near real time. By leveraging voltage magnitude and phase angle time series data provided by PMUs, the project will also develop similarly fast time-scale (i.e., second or sub-second update rates – much faster than standard state estimation rates) filters for detection and identification of topology changes.

Academic Team

Project Leader: Alejandro D. Domínguez-García (Univ. of Illinois at Urbana-Champaign, [email protected]) Team members: Pete Sauer (Univ. of Illinois at Urbana-Champaign, [email protected]); Chris DeMarco (Univ. of Wisconsin-Madison, [email protected]); Steve Wright (Univ. of Wisconsin-Madison, [email protected])

Industry Advisors

Mirrasoul Mousavi (ABB); Prashant Kansal (AEP); Jim Kleitsch (ATC); Evangelos Farantatos (EPRI); Mahendra Patel (EPRI); Alan Engelmann (Exelon-ComEd); Slava Maslennikov (ISONE); George Stefopoulos (NYPA); Angel A. Aquino-Lugo (PowerWorld); Jay Caspary (SPP)

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Load Model Complexity Analysis and Real-Time Load Tracking (S-60)

Summary Power system dynamic simulations and transient stability studies depend on load model accuracy. However, load data have not been investigated fully, and the adequacy or necessity of existing load model structures is in question. This project aims to analyze load models at different system levels and for specific disturbance events. Real-time and non-intrusive load model estimation is pursued using emerging load monitoring capabilities, especially high-bandwidth data along the distribution feeders. The ultimate goal is to equip system operators with the right load models for operations and control tasks.

Academic Team

Project Leader: Hao Zhu (Univ. of Illinois at Urbana-Champaign, [email protected]) Team Members: Tom Overbye (Univ. of Illinois at Urbana-Champaign, [email protected]); Bernie Lesieutre (Univ. of Wisconsin-Madison, [email protected])

Industry Advisors

Mirrasoul Mousavi (ABB); Robert O’Keefe (AEP); William Kouam Kamwa (AEP); Curtis Roe (ATC); Damien Sommer (ATC); Aftab Alam (CAISO); Anish Gaikwad (EPRI); Alan Engelmann (Exelon/ComEd); Chaitanya Baone (GE Global Research); Slawek Szymanowski (ISONE); Marissa Hummon (NREL); George Stefopoulos (NYPA); Scott Jordan (SPP)

Reliability Assessment and Modeling of Cyber Enabled Power Systems with Renewable Sources and Energy Storage (T-53)

Summary Smart grid technologies have motivated work on improved system control, on renewables integration, and on communication and security. Investigation is needed on the impacts on the system reliability of intermittent energy sources, of dynamic loads, and of the interdependency between cyber and current-carrying elements. The proposed work will develop a methodology for evaluation of power system reliability in a holistic manner. Our methodology will enable utilities to analyze the power system reliability implications advanced monitoring and control systems, of renewables, and of energy storage.

Academic Team

Project Leader: Chanan Singh (Texas A&M Univ., [email protected]) Team members: Visvakumar Aravinthan (Wichita State Univ., [email protected]); Alex Sprintson (Texas A&M Univ., [email protected])

Industry Advisors

Mirrasoul Mousavi (ABB); Jeff Fleeman (AEP); Kyle Phillips (AEP); Wenyuan Li (BC Hydro); Adam Wigington (EPRI); Miaolei Shao (GE Energy Management); Daniel Arjona (Idaho Power); Xiaochuan Luo (ISONE); Liang Min (LLNL)

Setting-less Protection (2014 Plan Part I): Centralized Substation Protection (T-55G)

Summary In the past few years, Georgia Tech and EPRI have been developing the setting-less protection technology. This technology has been demonstrated in the laboratory. The next steps are: (a) to demonstrate the technology in the field, and (b) to extend this technology towards the development of centralized substation protection systems. This proposal is for the purpose of developing the foundations towards the development of a centralized substation protection.

Academic Team

Project Leader: Sakis Meliopoulos (Georgia Tech, [email protected])

Industry Advisors

Paul Myrda (EPRI); Bruce Fardanesh (NYPA); George Stefopoulos (NYPA); Feliks Karchemskiy (PG&E); James Hudson (SRP); Manish Patel (Southern Company)

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Setting-less Protection (2014 Plan Part II): Field Demonstrations (T-56G)

Summary In the past few years, Georgia Tech and EPRI have been developing the setting-less protection technology. This technology has been demonstrated in the laboratory. The next steps are: (a) to demonstrate the technology in the field, and (b) to extend this technology towards the development of centralized substation protection systems. With respect to (a), this project will support the field demonstration of the setting-less protection to the NYPA system.

Academic Team

Project Leader: Sakis Meliopoulos (Georgia Tech, [email protected])

Industry Advisors

Paul Myrda (EPRI); Bruce Fardanesh (NYPA); George Stefopoulos (NYPA); Feliks Karchemskiy (PG&E); James Hudson (SRP); Manish Patel (Southern Company)

Markets for Ancillary Services in the Presence of Stochastic Resources (M-31)

Summary As market structures change to improve the management of stochastic resources such as wind and solar generation, advances are needed in the design and pricing of energy and ancillary services markets. This project focuses on designing new tools for ancillary services markets, new dynamic reserve policies and reliability criteria, and new pricing mechanisms taking into consideration stochastic resources. The proposed changes are anticipated to result in improved pricing mechanisms that reward stakeholders when they provide higher quality of ancillary services made possible by the advances in dynamic reserve policies.

Academic Team

Project Leader: Kory Hedman (Arizona State Univ., [email protected]) Team Members: Muhong Zhang (Arizona State Univ., [email protected]), (CY 2014 only. Kory Hedman took over Zhang’s tasks beginning in 2015 because Zhang left ASU) Marija Ilic (Carnegie Mellon Univ., [email protected])

Industry Advisors

Xing Wang (Alstom Grid); Jim Price (CAISO); Eamonn Lannoye (EPRI); Evangelos Farantatos (EPRI); Aidan Tuohy (EPRI); Bahman Daryanian (GE); Nikhil Kumar (GE); Feng Zhao (ISONE); William Henson (ISONE); Liang Min (LLNL); Thomas Edmunds (LLNL); Yonghong Chen (MISO); Marissa Hummon, (NREL); Andy Tillery (Southern Company)

New Operation Tools for Improving Flexibility and Reliability of Systems with Variable Resources and Storage Devices (M-32)

Summary This project explores new operational tools to improve system flexibility and reliability in systems with variable resources and storage. The new dispatch models will integrate storage devices of various types (e.g., distributed batteries, pumped hydro etc.) as well as flexible demand control, and assess their impact on system flexibility. The SPP 2020 planning study model (with (16,000 buses, 90 GW wind capacity) will provide a simulation platform for realistic evaluation of the proposed models in real-world, large-scale systems.

Academic Team

Project Leader: Andy Sun (Georgia Tech, [email protected]) Team Members: Le Xie (Texas A&M, [email protected]); Sakis Meliopoulos (Georgia Tech, [email protected])

Industry Advisors

Feng Gao (ABB-Ventyx); Prashant Kansal (AEP); Zhenhua Wang (AEP); Xing Wang (Alstom Grid); Aftab Alam (CAISO); Jim Price (CAISO); Robert Entriken (EPRI); Evangelos Farantatos (EPRI); Eamonn Lannoye (EPRI); Nikhil Kumar (GE Energy Management); Eugene Litvinov (ISONE); Tongxin Zheng (ISONE); Li Zhang (MISO); Hong Chen (PJM); Harvey Scribner (SPP); Phil Markham (Southern Company)

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Brief Descriptions of Current Projects Ending in 2017 (Final Reports Available in 2017)

Advanced Cyber-Physical Analysis for Smart Grid Distributed ICT and IED Resources at RTE France (S-63G)

Summary The availability of a vast number of substation IEDs and distributed computational resources offers great potential for enhancing the smart grid. However, the distributed computing infrastructures in utilities today are nowhere near adequate to exploit this potential, being decades behind those in other industries. This project will lead to several technologies and tools, and analyze others, to help utilities and vendors to develop next-generation cyber-physical infrastructure using distributed ICT and IED resources. The problems addressed by this project, as well as the software released, will be widely applicable to utilities, ISOs, and vendors.

Academic Team

Project Leader: Dave Bakken (Washington State Univ., [email protected]) Team members: Anurag Srivastava (Washington State Univ.)

Industry Advisors

Daniel Arjona (Idaho Power); Patrick Panciatici (RTE France); Juan Castaneda (SCE)

Monitoring and Maintaining Limits of Area Transfers with PMUs (S-64)

Summary We will develop practical methods based on PMUs to detect and act on conditions in which transfer of power through areas of the power system should be curtailed to satisfy thermal line limits and small signal stability limits. Closed loop controls for robust stability will also be developed. The larger objective is to combine measurements with physical network models to turn PMU data into actionable advice for operators to improve the management of bulk power transfers and control instabilities.

Academic Team

Project Leader: Ian Dobson (Iowa State Univ., [email protected]) Team members: Marija Ilic (Carnegie Mellon Univ., [email protected])

Industry Advisors

Guru Pai (Alstom Grid); Anil Jampala (Alstom Grid); Baj Agrawal (APS); Giuseppe Stanciulescu (BC Hydro); Evangelos Farantatos (EPRI); Navin Bhatt (EPRI); Mahendra Patel (EPRI); Dave Schooley (Exelon/ComEd); Alan Engelmann (Exelon/ComEd); Santosh Veda (GE Global Research); Naresh Acharya (GE Global Research); Chaitanya Baone (GE Global Research); Orlando Ciniglio (Idaho Power); Milorad Papic (Idaho Power); Slava Maslennikov (ISONE); Ed Muljadi (NREL); Saman Babaei (NYPA); Paul Runana (WAPA)

xxxvii

Real Time Synchrophasor Measurements Based Voltage Stability Monitoring and Control (S-65)

Summary This project’s objective is improve situational awareness of the power grid by assessing the short-term and long-term voltage stability in real-time using synchrophasor measurements. We have developed a systematic PMU measurement-based model free approach for short-term voltage stability assessment which will be tested on a real system (~ 10,000 buses). A computationally efficient, long-term voltage stability assessment approach will be developed that uses PMU data and local network information to calculate voltage stability indices at all load buses in real time. These algorithms will be integrated and implemented on a real time test bed.

Academic Team

Project Leader: Venkataramana Ajjarapu (Iowa State Univ., [email protected]) Team members: Umesh Vaidyam (Iowa State Univ., [email protected]); Chen-Ching Liu (Washington State Univ., [email protected])

Industry Advisors

Reynaldo Nuqui (ABB); Prasant Kansal (AEP); Jay Giri (Alstom Grid); Aftab Alam (CAISO); Navin Bhatt (EPRI); Evangelos Farantatos (EPRI); Mahendra Patel (EPRI); Erik Ela (EPRI); Alan Englemann (Exelon/ComEd); David Schooley (Exelon/ComEd); Robert Daquila (GE Energy Management); Liang Min (LLNL); Eduard Muljadi (NREL); George Stefopoulos (NYPA); Jianzhong Tong (PJM); Juan Castaneda (SCE)

Representation, Modeling, Data Development and Maintenance of Appropriate Protective Relaying Functions in Large Scale Transient Stability Simulations (S-66)

Summary Questions have been raised about the appropriate representation of the relaying function in planning and operating studies. This project aims to systematically examine and identify the appropriate relaying functions that are critical for transient stability. The project will (1) develop systematic techniques to represent the relaying functions, and develop settings, (2) identify steps for maintaining data accuracy of data and for updating data as the system evolves, and 3) develop a systematic framework to ascertain the viability and accuracy of representing critical protection functions in commercial transient stability packages.

Academic Team

Project Leader: Vijay Vittal (Arizona State University, [email protected]) Team members: Anjan Bose (Washington State University, [email protected]); Saeed Lotififard (Washington State University, [email protected])

Industry Advisors

Jay Giri (Alstom Grid); Rene Rosales (Alstom Grid); Daniel Houghton (APS); Brant Werts (Duke Energy); Mahendra Patel (EPRI); Anish Gaikwad (EPRI); Evangelos Farantatos (EPRI); Sean McGuinness (EPRI); Alan Engelmann (Exelon/ComEd); Mike Koly (Exelon/PECO); Jianzhong Tong (PJM); Bruce Fardanesh (NYPA); Brian Keel (SRP)

xxxviii

Reliability Metrics for Renewable Resources and Self-Reserves (M-33)

Summary New reliability metrics are necessary to evaluate (a) the impact of non-dispatchable renewables on reserve requirements, and (b) future technologies that enable renewable resources to provide self-reserves. This project will develop improved stochastic models of renewables, techniques to determine the optimal level of self-reserve for these resources to provide, new reliability metrics to determine the impact on system reserve requirements, and quantify the value proposition of renewable self-reserve. The focus will be wind generation, but the work can be generalized to other uncertain resources.

Academic Team

Project Leader: Kory Hedman (Arizona State Univ., [email protected]) Team members: Junshan Zhang (Arizona State Univ., [email protected]); Shmuel Oren (Univ. of California, Berkeley, [email protected]); Alberto Lamadrid (Lehigh Univ., [email protected])

Industry Advisors

Jim Price (CAISO); Bob Entriken (EPRI); Evangelos Farantatos (EPRI); Eamonn Lannoye (EPRI); Aidan Tuohy (EPRI); Erik Ela (EPRI); Khaled Bahei-eldin (GE); Nikhil Kumar (GE); Tongxin Zheng (ISONE); Dejan Sobajic (NYISO); Hong Chen (PJM)

Risk Assessment of Constraint Relaxation Practices (M-34)

Summary System operators allow various constraints within market models to be relaxed, but correct the relaxations in operations. This proposed project is an extension of PSERC Project M-29. Its goal is to analyze the following concerns: 1) should we treat pre-contingency limit relaxations differently than post-contingency limit relaxations; 2) how does the duration of the violation impact reliability and what risk are we exposed to; 3) how should we incorporate probabilities of contingencies within this practice; 4) what is the impact on stability; and 5) how does this practice relate to a risk-based optimal power flow dispatch.

Academic Team

Project Leader: Kory Hedman (Arizona State University, [email protected]) Team members: Vijay Vittal (Arizona State University, [email protected]); James McCalley (Iowa State University, [email protected])

Industry Advisors

Jim Price (CAISO); Bob Entriken (EPRI); Mahendra Patel (EPRI); Erik Ela (EPRI); Jinan Huang (IREQ); Feng Zhao (ISONE); Muhammad Marwali (NYISO); Hong Chen (PJM); Doug Bowman (SPP); Thomas Burns (SPP); Jay Caspary (SPP); Melanie Hill (SPP); Harvey Scribner (SPP)

xxxix

Brief Descriptions of Current Projects Ending in 2018 (Final Report Available in 2018)

Life-cycle Management of Mission-Critical Systems through Certification, Commissioning, In-Service Maintenance, Remote Testing, and Risk Assessment (T-57)

Summary

The life-cycle management of mission critical systems requires tools and methodologies that are not readily available. For example, no standard tools for certification, commissioning, in-service maintenance, and risk assessment are available for synchrophasors used for Wide Area Protection, Monitoring and Control; and Special Protection Schemes. This project will deliver such tools for:

• Device and system testing of synchrophasor systems, substation measurement equipment, etc.

• Calibration and field testing equipment for in-service maintenance • Remote testing and detection of device failures and data management

architecture problems • Visualization to track the state of mission-critical systems and to help with

maintenance and repair. Academic Team

Project Leader: Mladen Kezunovic (Texas A&M University, [email protected]) Team Members: Sakis Meliopoulos (Georgia Institute of Technology, [email protected] ); Thomas Overbye (University of Illinois-Urbana Champaign, [email protected]); David Bakken (Washington State University, [email protected]); Anurag Srivastava (Washington State University, [email protected])

Industry Advisors

Floyd Galvan (Entergy); Alberto Del Rosso (EPRI); Eugene Litvinov (ISONE); Mark Westendorf (MISO); Michael Swider (NYISO); Bruce Fardanesh (NYPA); Jianzhong Tong (PJM); Mark Laufenberg (PowerWorld); Patrick Panciatici (RTE France); Juan Castaneda (SCE)

xl

Consortium for Electric Reliability Technology Solutions (CERTS): FY 2015 Funded Projects Led by PSERC Researchers

The Consortium for Electric Reliability Technology Solutions (CERTS) was formed in 1999 to research, develop, and disseminate new methods, tools, and technologies to protect and enhance the reliability of the U.S. electric power system and efficiency of competitive electricity markets. DOE-funded, the research program is described at certs.lbl.gov. The work below is funded through a cooperative agreement with the National Energy Technology Lab. Advanced Applications Research and Development

• Pre-and Post-disturbance Grid Reliability Monitoring and Model-less Approach Validation, Prototype and Field Test

Research Area: Reliability and Markets

Stochastic Planning, Optimization, and Markets Analysis • Benchmarking and Integrating Chance-Constrained Stochastic Unit Commitment Solution for

Optimal Management of Uncertainty • Virtual Bids and Flexible Bids: Risk Mitigation and Congestion Relief • Probabilistic Forecast of Congestion and Real-Time Locational Marginal Prices • Mapping Energy Futures: The SuperOPF Planning Tool • Attribute-Preserving Optimal Network Reductions

Demand-side Markets and Reliability • A Business Model for Retail Aggregation of Responsive Load to Produce Wholesale Demand Side

Resources

xli

Presentation Handouts

xlii

Intentionally Blank

Executive Forum/Workshop on Physical and Cyber Infrastructure

Supporting the Future Grid

Summary

PSERC Summer WorkshopJuly 14-15, 2015

• The forum/workshop was held in the WaterviewConference Center in Arlington VA May 4-5, 2015.

• The PSERC planning committee included, Mladen Kezunovic, Ward Jewell, George Gross, Flora Flygt, Jay Caspary, Mirrasoul Mousavi, Dennis Ray, and Cara Lee Mahany Braithwait

• The discussion addressed key research problems with a 10 year window for solution

• The emphasis was on use-inspired research

2

Background

1

Panels (Day I)

• H. B. “Trip” Doggett, CEO, ERCOT• Bob Mitchell, CEO, AWC&TDC• Tony Montoya, CEO, WAPA• A. Wade Smith, CEO, AEP Texas• V. Emesih, VP, CNP• J. Gallagher, Executive Director,

NYS Smart Grid Consortium• M. Wakefield, Director, EPRI • David Mohre, Executive Director,

NRECA• J. Bebic, Managing Director, GE

Energy Consulting• J. Giri, Director, ALSTOM Grid• R. Masiello, Innovation Director and

Senior VP, DNV GL

• D. Voda, Smart Grid Segment Leader, ABB Inc.

• C. Greer, Senior Executive, NIST • T. Heidel, Program Director,

ARPA-E • P. Khargonekar, Assistant

Director, NSF• J. Mapar, Director, DHL• D. Ortiz, Deputy Assistant

Secretary, DOE• J. Dagle, Chief Electrical Engineer

and Team Lead, PNNL• I. Husain, Director, FREEDM• M. O’Malley, Director, UC Dublin• K. Tomsovic, Director, CURENT• V. Vittal, Director, PSERC

3

Discussions (Day II)

• Breakout Session I:- Topic: Modeling andAnalysis

- Moderators, V. Vittaland J. Caspary

- Participants: over 25- Goal: define researchproblems

- Outcome: first five andthe entire list

• Breakout Session II- Topic: Technology andSupplementary

- Moderators: M.Kezunovic, W. Jewell

- Participants: over 30- Goal: define researchproblems

- Outcome: first five andthe entire list

4

2

Forum Registration

• Total registration: 95• Breakdown by category:

- Industry: 33- Government:17- Academia: 45

• Other statistics: - PSERC affiliated: 42- Non-PSERC affiliated: 53- Speakers/panelists: 21

5

Executive Perspectives: Areas of Concern(Flora Flygt, Moderator)

• HVDC• How to create business case which will lead to

appropriate cost allocation (some form of socializing)• Where is it best deployed? How should it be

implemented• How to convince regulators to use it?

• Planning/Forecasting – Need:• Longer-term, more strategic approach to planning out

the system• Better wind and solar forecasting in real-time and day

ahead• To address uncertainties in the planning process

6

3

Executive Perspectives: Areas of Concern

• Demand Response – Need:• Visibility into the distribution system• Better forecasting tools• More defined ancillary services

• Renewables/Distributed Generation• How to deal with the ramp rates that are created• Increased visibility • More defined ancillary services• Is storage a solution and do we need a new market

construct to accommodate development of storage?

7

Technology Application Perspectives(Mladen Kezunovic, Moderator)

• Opening statements (issues of concern)- Grid resiliency, real-time customer interaction- Cost-effective demand response- Distribution visibility and automation- Integration of renewables and DGs- Role of Distribution Service Providers (DSP)- Granular pricing of DSM: hourly, sub-hourly- Resiliency of ICT and enabling technologies- Standardization for decoupled functionalities- Cyberphysical security and privacy

8

4

Technology Application Perspectives

• Research needs (Q/A)- Centralized vs. decentralize and who decides- How to justify the grid expansion investments- How much distributed generation is justified- The need for large scale testbeds- Market efficiency: centralized vs. decentralized- Use of water heathers as a thermal storage- Understanding of weather impacts in real-time- Market design for participation of DSP- How to policy implications of technology

9

Technology and Solution Provider Perspectives (George Gross, Moderator)

Towards a comprehensive load model improved composite load models to represent the flexibility of loads

as loads change from passive to activemodel of consumer behavior including the impacts of policies and

incentives operational needs on load visibility at each point in time and its

flexibility characterizationEnergy storage modeling, management and

solution methodologiesmodels for effective participation of storage in markets for provision

of commodity and ancillary services assessment of the economic value of storage for investment formulation of operational paradigms new schemes to manage inventory overcoming scalability issues in mixed integer programming

5

Technology and Solution Provider Perspectives

PMU deployment and data utilization PMU deployment for enhanced protection assurance of fidelity and security of PMU data PMU data verification with operational models usage of PMU data for inertial response estimation for control of

storage devices address how far synchronized sampling rate of PMU needs to be

pushed PMU data use beyond monitoring: formulation of control actions to

ensure the health of the system and eventual decision making; transition from local to wide area control

Assessment of cyber security technology to meet the requirements of standards

Government Perspectives (Jay Caspary, Moderator)

• Scalable hybrid data-driven control strategies• Integrated risk management tools • Enhanced modeling / simulation capabilities • Composable, reconfigurable test beds to address

interoperability challenges• Increased capabilities for demonstration and

testing/assessment of new technologies• Address barriers to entry, i.e, open models• Better understanding of complex systems • Newer risk methodologies • Education of policy makers regarding critical need for

R&D12

6

University and National Lab Perspectives (Ward Jewell, Moderator)

• Controls technology• Integration of planning, operations, and markets• Integrating Transmission and Distribution

Systems• Integrate electricity with other energy systems• Simulating power grid and other supporting

infrastructure, including communications systems

• Power electronics• Communications• Consumer behavior

13

Modeling and Analysis High Priority Research Ideas (Vijay Vittal and Jay Caspary)

• How can we better account for uncertainty in operations and planning, especially in the presence of renewable resources – Looks at need for characterizing uncertainty and developing analytical tools which incorporate uncertainty

• Develop methods for scheduling all available resources including traditional generation, intermittent energy resources – Need to develop better short term forecast methods in order to enable better scheduling of variable generation 14

7

Modeling and Analysis High Priority Research Ideas

• Develop control algorithms based on real time measurements such as synchrophasorsfor enhanced grid operation and control –Incorporation of PMU and other real time measurements in control

• Measure system inertia including centralized and distributed energy resources in real-time, determine inertia limits, and mitigate low inertia effects – Need to determine impact of reduced inertia

15

• Improve wind/solar forecast accuracy for system operation – Need for improved short term wind and solar forecast

• High-resolution identification of the load composition, especially with respect to quantifying its flexibility potential, and in what ways it can be provided – Load composition identification to aid DSM

16

Modeling and Analysis High Priority Research Ideas

8

Technology and Supplemental High Priority Research Ideas

(Mladen Kezunovic and Ward Jewell)

• Testing and evaluation of future solutions:- Need to create real-time simulation-based testbeds shared between multiple universities

- Create scalable and reconfigurable large scaletest beds based on multiple hardware-in-the-loop(HIL) technologies

- Simulation and testing tools for architectureand device large-scale testing.

• Votes = 1217

Technology and Supplemental High Priority Research Ideas

• Resiliency modeling and metrics- Model power system resilience with multipleweighted indicators based on electrical,economical, and social aspects

- Create metric(s) for resilience and rate ofreturn for resilience improvements.

- Study possible use: investment analysis or toprovide incentives to operators for adoption ofresiliency measures. Votes = 11

• Increase resiliency of the grid through smart control and smart protection. Votes = 10

18

9

Technology and Supplemental High Priority Research Ideas

• Various ideas with same number of votes= 8- Centralized data, large dynamic data sets,model validation and operations

- No regrets and best best transmission systemconfigurations

- How should we reconfigure the electric powergrid to rely more on microgrids

- Redefine the technical interface between T&Dsystems to coordinate both systems and integrate DERs efficiently; Design the neededinformation architecture for integrated T&D oper.

19

Suggested Research by Area(Mirrasoul Mousavi and Dennis Ray)

• Control and Situational Awareness Using Real-time Measurements• Enhanced grid operation and control

• Resiliency: managing extreme events and security risks• Physical and cybersecurity, metrics for assessment/valuation• How to increase resiliency?

• Electricity Markets• Simulation test bed/platform for assessing market mechanisms• Future of ancillary services: models and frameworks

• T&D System Modeling, Simulation, and Test Beds• Collaborative test beds for testing new strategies, hardware,

business services, controls, reliability and resiliency actions

20

Note: The second bulleted items are only examples of research under each category.See the full list of ideas for a comprehensive view.

10

• Integrated T&D Operations and Control• Accounting for uncertainty in operations and planning• Designs for operating/coordinating an integrated transmission

and distribution system

• Information and Computational Technology Needs and Architectures• Framework for secure/efficient communication of smart grid data

• DER Modeling and Integration• Improve wind/solar forecast accuracy (including ramping)

• Distribution Systems and Microgrids• How to reconfigure the grid for more microgrids?• Expand uses of PMU data

21

Suggested Research by Area

Suggested Research by Area

• Power Electronics/FACTS/HVDC/Grid Hardware• Advance hardware development• Improve modeling such as for power flow control

• Business/Research Models and Technical-Economic Analysis• Create incentives for resilience improvement

22

11

PSERC Workshop Participants

DISCUSSION

23

12

Categorized Research Ideas from PSERC/NSF Future Grid Workshop Breakout Groups Prepared by Mirrasoul Mousavi, ABB, and Dennis Ray, PSERC

Research ideas provided by university participants in the PSERC/NSF Forum on Physical and Cyber Infrastructure to Support the Future Grid (May 4, 2015) were selected and edited for use in two breakout sessions at the Workshop on Research to Support Development of the Future Grid (May 5, 2015). Breakout session attendees from industry, universities, and government added research ideas to the list of research ideas that they were given for their particular breakout session. Then attendees in each breakout session used their list of research ideas to identify high priority ideas. Each attendee was invited to vote for up to five “high priority” research ideas that were likely to produce a useful solution within ten years that would be of high value whether to industry or society at-large due to cost savings, new services, reliability improvement, higher system flexibility and resilience, greater profitability, operational improvements, environmental improvements, or any other measure of value that the participant preferred to use. There were approximately 30 people in each breakout session. The final list of research ideas and prioritization votes are given below. Ideas were numbered as follows: M for Modeling and Analysis Ideas (in Breakout Session 1), and T for Technology and S for Supplementary Ideas (in Breakout Session 2). Note: Research ideas may appear in multiple categories. Control and Situational Awareness Using Real-time Measurements

Research Idea or Issue No. High Priority Votes

Develop control algorithms based on real time measurements such as synchrophasors for enhanced grid operation and control

M105 10

Develop cheaper (much cheaper) PMU technology to be deployed in the distribution level for cost-effective and fast linear state estimation on the distribution level, line impedance identification, time-domain load modeling, adverse event identification (such as faults), DER coordination, etc.

T309 7

Centralized data: large dynamic data sets (e.g., of normal operation and of abnormal operation) for model validation and modeling of realistic operations

T338 8

Measure system inertia including centralized and distributed energy resources in real-time, determine inertia limits, and mitigate low inertia effects (inertia)

M109 10

Develop early warning methods and situational awareness tools based on PMU data along with mitigation strategies based on such information

M103 6

Develop big data driven methods for better controlling and operating the power grid (big data)

M106 4

Specify how much inertia is needed M113 0 Large area situational awareness (related to M123) on an interconnection and/or national scale with real-time visualization, real-time analytics, and real-time reporting

T339 2

Develop methodologies for the use of real time PMU data to help system operators to go beyond monitoring of grid to actual decision-making and control

M123 0

Investigate grid operator control center tools that reduce operator decision-making when appropriate to maintain grid reliability

M139 0

What are the research issues, challenges, and value proposition for the application of big data analytics to smart grid? What is the specification of “big data”?

S218 0

Develop scalable hybrid (electric power, weather, traffic, etc.) data-driven control strategies that enable new infrastructures

S219 0

13

Resiliency: Managing Extreme Events and Security Risks How should we manage extreme risks so as to minimize their adverse system wide impact?

M101 4

Model power system resilience with multiple weighted indicators based on electrical, economical, and social aspects

S220 (w/ S221) 11

Create metric(s) for resilience and rate of return for resilience improvements. Possible use: investment analysis or to provide incentives to operators for adoption of resiliency measures.

S221 (w/ S220) 11

Increase resiliency of the grid through smart control and smart protection T307 10 No regrets and best bets transmission system configurations. Useful for creating a grid road map/development plan.

T342 8

Model coupling of infrastructures in reliability studies M119 5 How to harden the grid against extreme weather conditions T327 (w/ T333) 7 Harden grid (resiliency) vs. redundancy, which is more appropriate? T333 (w/T327) 7 Smarter security in the grid, advanced heuristics and analytics. Next generation technical standards.

T337 (w/ S202,S210)

6

Cybersecurity: Identify security risks such as digital relays, control center firewalls, etc.

S202 (w/ T337,S210)

6

Investigate methods for quantifying the impact of cybersecurity investments S210 (w/ T337,S202)

6

Framework/model for secure and efficient communication of smart grid data M154 5 Formal methods to analyze/verify behavior of power system as cyber/physical system/designs

M149 1

Explore system vulnerability to interdiction and develop ways to make the grid more resilient to such attacks

T302 0

Physical security: Identify weak links in the grid T304 0 Develop standards related to the use and implementation of cyber security technologies

S217 0

Create risk models that also capture the inter-dependencies of subsystems S222 0 Electricity Markets

A new simulation testbed or platform for modeling, simulating, quantifying new markets, market mechanisms, that provides valuable information on a unified system all the way from the ISO-level to end-user distributed assets

M117 8

What is the potential expanded portfolio of ancillary services? S212 4 Forecast ramping requirements M145 2 Market constructs for variable energy resources to compete with conventional producers and loads

M148 2

Assess revenue sufficiency viability of low capacity factor resources M146 1 Framework for valuation of grid support services M151 2 Evaluate flexible resource adequacy M153 2 Model/framework for establishing the value of DER M152 1 Develop a new mathematical paradigm that will enable participation of thousands of smaller resources in wholesale markets, including stochastic effects

M120 0

What is the right mix of fast and conventional frequency response? M121 0 Develop stochastic-based optimization strategies with the incorporation of storage and distributed resources in retail market and various sources of system uncertainties

M124 0

Change markets to have inertia based service to provide incentives for renewables to then provide synthetic inertia

S205 0

Improve cost-effective demand response (i.e., pool pumps, air conditioning) S200 0

14

T&D System Modeling, Simulation, and Test Beds

Need to create real-time simulation-based test beds shared between multiple universities

T317 (w/ T318,T341)

12

Create scalable and reconfigurable large scale test beds based on multiple hardware-in-the-loop (HIL) technologies

T318 (w/ T317,T341)

12

Simulation and testing tools of new architecture and devices for testing new strategies, hardware, business services, controls, reliability and resiliency assessment, etc.

T341 (w/T317,T318)

12

Improve real-time power system models, particularly by expanding use of AC models, to allow expanded utilization of the grid

M140 3

Create cross discipline simulation models (physics, economics, society studies) for power system analysis

M125 2

Create an open source full scale simulation model for transmission/distribution systems

M126 3

Create models that integrate transmission and distribution as one entity for flexible coordination and control

M127 1

Models for integrated analysis of transmission and distribution systems M135 1 Create and solve models that capture the cascading effects due to inter-dependencies of subsystems

M129 3

Power system dynamics with fast-acting and single-phase components – hybrid simulation and analysis

M133 2

Research already proven and tested models used by other industry to see if there is applicability to power systems analyses

M128 0

Robust stochastic models and algorithms for power flow, stability, etc. M136 0 Develop hybrid models, analytics, and simulation tools for new devices M137 0 Modeling demand response for operational decision-making and situation awareness

M138 0

Develop enhanced models of power system operations to incorporate diverse demand, generation and storage resources

M141 0

Apparatus libraries with operational data and validated models M143 1 Models for evaluating dynamic stability consequences of dispatcher actions M144 1 Load Modeling and Demand Response High-resolution identification of the load composition, especially with respect to quantifying its flexibility potential, and in what ways it can be provided

M118 (merge M122,M132)

9 (alone)

Develop a high fidelity load model with specific flexibility for the effective implementation of demand response technologies

M122 (merge M118,M132)

6 (alone)

Load modeling and uncertainty bounding from historic data M132 (merge M118,M122)

1 (alone)

Develop techniques to dynamically extract load data S216 4 Modeling demand response for operational decision-making and situation awareness

M138 0

15

Integrated T&D Operations and Control Develop methods for scheduling all available resources including traditional generation, intermittent energy resources

M104 18

Redefine the technical interface between transmission and the distribution systems to coordinate both systems and integrate DERs efficiently

S201 (w/ T328

8

Design the information architecture needed to support integrated transmission and distribution operations

T328 (w/ S201)

8

How restrictive do operating standards have to be in power systems? How much flexibility can be permitted?

M116 2

How much competitive vs. cooperative efforts should be within an integrated system? S207 0 To achieve better coordination across transmission and distribution systems, explore how to coordinate EMS – DMS

S224 0

In response to new asset classes in the system, including those behind the load, how can the power system be converted to a better fly-by-wire system?

T320 0

Integrated controls as an alternative to hardware redundancy T324 0 Closed loop control technologies that are implemented on physical apparatus based on high dimensional data

T344 0

Transactive controls at various levels of aggregration through price and bid flows. T332 0 Model the interaction between microprocessor controlled equipment and develop control strategies to ensure cooperation

S203 0

New control paradigms that will achieve the same goals (in terms of stabilization, variability mitigation, etc.) as transmission assets that are too expensive (and time intensive) to build

S227 0

System Operations Under Uncertainty How can we better account for uncertainty in operations and planning, especially in the presence of renewable resources

M100 22

Stochastic control algorithms with approximation guarantees M147 3 Include uncertainty into basic tools – power flow, OPF M131 0 Explore ways to incorporate detailed weather model data into power system operations T329 0 System Operations with No/Less Inertia Measure system inertia including centralized and distributed energy resources in real-time, determine inertia limits, and mitigate low inertia effects (inertia)

M109 10

Specify how much inertia is needed M113 0 Investigate power system operations in systems with no synchronous inertia at all M130 0 What control paradigms will allow newer power electronic devices to make up for the relative reduction of inertial response with increased penetration of variable resources?

S226 0

16

Information and Computational Technology Needs and Architectures Framework/model for secure and efficient communication of smart grid data M154 5 Approaches to model the communication and computation of information and platforms (e.g., networks, processes)

T336 3

How to design the information architecture and supporting communications system to achieve a fault-tolerant grid management system? What should the information architecture be for the future grid?

T311 0

Design the information architecture needed to support integrated transmission and distribution operations

T328 0

What information is needed between different layers of industry in order for the system to balance objectives of reliability, resiliency and efficiency?

S206 0

What are the better ways of handling, storing, and protecting data? S213 0 Develop efficient approaches such as parallel computing to take advantage of supercomputers/clusters for tackling power system problems

M107 1

Address architectural issues: (1) design goals (such as distributed management) and (2) design principles that enable the system to achieve these goals (e.g., the division of functionality, the placement of intelligence, etc.)

T347 0

DER Modeling and Integration

Develop a new dynamic underfrequency load shedding scheme that accounts for the contribution of power generation at the distribution feeder level and how this varies over time.

T334 4

Evaluate flexible resource adequacy M153 2 Change IEEE 1547 for integration of DERs M150 2 Model voltage sources behind inverters and develop closed and open loop control strategies to improve the security and reliability of the grid

M110 0

Analyze and compare the economic consequences of local storage versus system upgrades for the integration of PV at the residential and commercial level

M112 0

How should we integrate EV’s into the grid so as to exploit their flexibility in managing the system

T301

How many DERS under 10MWs would it take to require new distribution grid management?

T312 1

How can distributed resources assist grid operators? T314 0 Design of new topology (ring-based) for distributed resources, distributed optimization and controls

T343 0

What control paradigms will allow newer power electronic devices to make up for the relative reduction of inertial response with increased penetration of variable resources?

S226 0

Wind and solar forecast accuracy Improve wind/solar forecast accuracy for system operation M108 (w/

M145) 9

Forecast ramping requirements M145 (include

w/ M108)

2 (alone)

Need for improved wind forecasting and forecasting of ramp rates M115 0 Exploit Renewables and Storage Explore how to exploit complementarity between renewables and storage in operations and market structure

M102 1

Develop higher energy storage density technologies and batteries T313 0 Investigate the lifecycle of energy storage T316 0

17

Distribution Systems and Microgrids

How should we reconfigure the electric power grid to rely more on microgrids? T300 8 Develop cheaper (much cheaper) PMU technology to be deployed in the distribution level for cost-effective and fast linear state estimation on the distribution level, line impedance identification, time-domain load modeling, adverse even identification such as faults, DER coordination, etc.

T309 7

Develop real-time black start algorithms for dynamic restoration of the distribution system with DER in order to close the control loop for secure and adequate restoration

S204 (w/ S212)

4

What is the potential expanded portfolio of ancillary services? S212 (w/ S204)

4

Optimal location and sizing of switching devices in distribution systems T326 2 New distribution sensors to address DER altered power flows – for planning and design T340 0 What information should be required to be provided by users for a distribution system operator to be able to maintain reliability and efficiency?

S209 1

Is decentralized control in distribution systems “good” or “bad” from the perspective of a system operator?

S215 0

Model power quality, particularly at the distribution level. Improve modeling of power flows and harmonics between generation and end-use customers instead of stopping at the substation

M111 0

How do we ensure that power quality is maintained, particularly with DER T308 0 Develop a home energy system to collect and visualize data. Develop pricing, timing or other curtailment strategies for more efficient residential end use

T310 0

Power Electronics/FACTS/HVDC/Grid Hardware

Design the next generation of power electronic based solid state generators and transformers via an integrated hardware and software approach

T319 (w/ T321)

3

Build, demonstrate, and use high power electronics models capitalizing on recent material advances, and create algorithms that work with real data (this applies to all areas).

T321 (w/ T319)

3

Fast-acting electronic and mechanical switches T323 2 Develop high performance power electronics based on new material such as diamond T303 0 HVDC active control devices are at the end of their service life. What’s next? T306 0 Develop UPFC & substation automation controls that are enabled from PMU data T315 0 Load, generation, and storage with power electronics – creating a plug and play operating environment

T322 0

Can HVDC systems and other fast-acting power electronics help with mitigation of variability from renewables?

T325 0

What control paradigms will allow newer power electronic devices to make up for the relative reduction of inertial response with increased penetration of variable resources?

S226 0

Power Flow Controllers Models and coordination algorithms are needed for advanced power flow control devices recently developed

M134 3

Flexible power flow control assets must be integrated into software M114 0 Explore methods for allowing operator control actions with SVCs, FACTs devices, and new flow control technologies without adversely affecting neighboring systems.

M142 0

Magnetic amplifiers for controlling power systems S225 0

18

Business and Research Models, and Technical-Economic Analysis Create metric(s) for resilience and rate of return for resilience improvements. Possible use: investment analysis or to provide incentives to operators for adoption of resiliency measures.

S221 5

Long-term financial justification of important/critical projects. Technical justification can take a lesser role than financial implications. How can large projects requiring significant financial resources be justified when decision-makers are incentivized to make short-term/least-cost solutions?

T330 0

Value of distributed resources to the system. How to incorporate consumer behavior into traditional grid operations.

T335 0

Development of complex analysis tools for technology, policy, societal, and public perspectives in development of resilient power systems

T345 0

What is a systematic method for evaluating cost-effective investments in distribution lines and comparison with investing in local DERs?

S208 0

Develop detailed business model for energy storage that will enable large scale deployment

S211 0

How can we transition to a generation-following model (instead of the conventional load-following mode), where load is more flexible than generation?

S214 0

Explore opportunities to improve gas-electric coordination for reliable grid operations S228 0 Assess revenue sufficiency viability of low capacity factor resources M146 1 Research and Education Collaboratives Establish a consortium of stakeholders (policy, government, academic, utility) to define obstacles/barriers to implementation of research and potential solutions to remove those roadblocks.

T331 0

Design and run competitions similar to “DARPA” challenge to drive large-scale engagement of students. Use artificial but representative data to set it up.

T346 1

19

20

Clean Power Plan Section 111(d) Panel BackgroundPSERC Summer Workshop 

July 2015

Overview

• Legal Underpinnings

• Overview of Rule

– Timeline

– Targets

How developed

States’ interim and 2030 targets

• Legal Challenges / Responses 

• Public Analyses and Impacts

2

21

Legal Underpinnings

• June 2013 President released Climate Action Plan

• Called for EPA to propose “carbon pollution” standards by June 2014

– To be finalized by June 2015

• Proposal relies on authority given EPA by Congress in Section 111(d) of the Clean Air Act (CAA)

• EPA has proposed “guideline document” with emission rate targets by state

– Interim targets (2020s) and final target (2030)

• Policies to reach the goals determined by the states

3

Overview of the 111(d) Rule

• Proposes state‐specific emission rate‐based CO2 goals with various options for compliance

• Offers guidelines for the development, submission and implementation of state plans to address greenhouse gas (GHG) emissions from existing fossil‐fired power plants

• Reflects emissions reductions that can be achieved by the application of the Best System of Emission Reduction (BSER)….adequately demonstrated.

• Initial proposed rule sets state goals for emission rates – as pounds of CO2 emissions per megawatt‐hour of electricity produced – not absolute emissions

• “30% reduction in CO2 emissions by 2030” is estimated impact, not the rule 4

22

5

Clean Power Plan Milestones

June 2,

2014

Draft rule issued

Dec 1,

2014

Comments due to EPA

June

2015

Final rule expected

June

2016

State Plans due

June

2017

State plans due (with one‐year extension)

June

2018

Multi‐state plans due (with two‐year extension)

January

2020‐29

Interim goals in effect

January

2030

Final goals in effect

Over 4 million comments received

Now expected in August

Due one year after final rule 

issued

How Targets Were Developed

6

• EPA used four “ building blocks” to develop emissions reduction targets

23

State Targets

7

Additional Approaches to Meeting CO2 Targets

• Co‐firing/switching to natural gas, or other lower carbon fuels

• “Flip the Stack” and/or operate coal during peak load periods 

• New natural gas combined cycle generation (NGCC)

• Heat rate improvements for fossil generators

• Transmission efficiency improvements

• Energy storage technology

• Retirements

• Emission trading programs 8

24

Challenges to CPP

By the fall of 2014, 18 state legislatures had passed either legislation or resolutions that negated the EPA’s CO2

Emission Guidelines.  See http://www.wbklaw.com/uploads/file/Articles‐%20News/EPA's%20CO2%20Rules%20and%2018%20States'%20Resolutions%20and%20Legislation.pdf. 

US Court of Appeals for the DC Circuit ruled June 9th that an appeal regarding the legality of the CPP by a dozen AGs and Murray Energy was premature, since it wasn’t a final rule.  Stay tuned…

9

NERC’s Reliability Assessment

• The proposed CPP is expected to accelerate a fundamental changes in electricity generation mix and transform grid‐level reliability services, diversity, and flexibility

• Industry needs more time to develop coordinated plans to address shifts in generation and corresponding transmission reinforcements to address proposed CPP CO2 interim and other emission targets

• Implementation plans may change the use of remaining coal‐fired generating fleet from baseload to seasonal peaking, potentially eroding plant economics and operating flexibility

10

25

SPP Analyses

• Reliability (October 2014): system intact and N‐1

• Assumptions: 

– Retirement of approximately 9,000 MW of coal and gas fired units (6,000 MW more than currently planned)

– Transfers from SPP and MISO to AR and LA

– Part 1: retired capacity replaced by existing unused capacity

– Part 2: retired capacity replaced by new gas and wind

• Results

– Part 1: voltage collapse until addition of 5,200 MVars reactive capability

– Part 2: 38 overloaded elements under N‐1; voltage collapse in some areas

11

SPP Analyses

• Economic analysis of Regional implementation (April 2015)

• Approach: 

– Use PROMOD production cost model

– Develop 2030 reference case, assumed “copper sheet”

– Evaluate range of carbon‐reduction measures for SPP

• Results – to meet compliance goal, needed:

– $45/ton CO2 price; 2,200 MW additional coal retirements; 5,600 MW of wind added; 3,600 MW CCs assumed to be CTs instead

– Incremental production and generation capital costs = $2.9 billion/year 

12

26

PJM Analyses

• Economic analysis (November 2014)

– 17 scenarios evaluated using range of assumptions including:

Gas prices

Fossil and nuclear resources

Renewable resources

Energy efficiency

– Results

Coal generation retired gradually

Increases in Load Energy Payments vary depending on levels of renewables, energy efficiency, new combined‐cycle gas, and price of natural gas

Adding more energy efficiency, renewable energy and retaining more nuclear generation would lead to lower CO2 prices

13

MISO Analysis

• Phase 1: Regional approach more cost‐effective

• Phase 2: Resource Mix Analysis (no infrastructure)

– 1,296 cases analyzed

– Results: lowest compliance costs meeting the target includes

Carbon price $25

Additional 14 GW of coal retirements

Energy efficiency of 0.75% of sales

Current renewable policies14

27

MISO Analysis

• Phase 3 (partially complete)

– Analysis of transmission and gas infrastructure needed under several Clean Power Plan Scenarios

Business as Usual

Business as Usual with Clean Power Plan constraints

Coal‐to‐Gas Conversions

Gas Build‐Out

Gas, Wind and Solar Build‐Out

Energy Efficiency, Wind and Solar

– Results 

Production costs lower with retirements and regional approach

Congestion increases under all compliance approaches

15

Recent Developments

• Final rule to White House as part of interagency review in early June

• Expect Final CPP Rule to be released this summer

• EISPC/NARUC issued “Multistate Coordination Resources for Clean Power Plan Compliance: Sample Documents for Consideration” in June

• At MARC on June 8th, EPA staff indicated final rule to include relaxed interim goals and informal ways for state to collaborate to ease compliance.  

• Options create uncertainties, which are good and bad.  

• New news everyday.  Stay tuned…16

28

Jay CasparyDirector – Research, Development & Special [email protected]

17

29

30

Grid Modernization Cross-cut Initiative

Bill ParksKevin LynnCarl Imhoff

Bryan Hannegan

Grid Modernization

Lab Consortium

Context for Grid Modernization 

• Time of transition

– System observability and controllability transitioning rapidly

– Growth in intelligent devices at systems edge challenging traditional paradigms

– Complexity increasing due to variable generation, transition from coal to gas, intelligent loads, natural phenomena, increased human risk

• Public / private partnership viewed as fundamental to grid modernization

– Industry increasingly challenged regarding R&D and long‐term focus

– Regulators challenged to innovate the traditional regulatory utility model

– National Labs able to aim mid and long‐term;  support DOE leadership in fundamental policy considerations

• Utilities / Vendors are key stakeholders for guiding the translation from discovery to commercial implementation

– Important to DOE and Lab advisory groups to guide strategy

– Vendors key partners in regional demonstrations and channel for national benefit

2

31

The future grid provides a critical platform for U.S. prosperity, competitiveness, and innovation in a global clean energy economy.  It must deliver reliable, affordable, andclean electricity to consumers where they want it, when they want it, how they want it.

Enhance the Security of the Nation

• Extreme weather• Cyber threats• Physical attacks• Natural disasters• Fuel and supply 

diversity• Aging infrastructure

Sustain Economic Growth and Innovation

• New energy products and services 

• Efficient markets• Reduce barriers for 

new technologies• Clean energy jobs

Achieve Public Policy Objectives

• 80% clean electricity by 2035

• State RPS and EEPS mandates

• Access to reliable, affordable electricity

• Climate adaptation and resilience

Grid Modernization Vision

3

OtherGov’t

An aggressive five‐year grid modernization strategy that includes

• Alignment of the existing base 

activities among the Offices

• An integrated Multi‐Year 

Program Plan (MYPP)

• New activities to fill major gaps 

in existing base 

• Development of a laboratory 

consortium with core scientific 

abilities and regional outreach

Grid Modernization Initiative

TechnologyStakeholdersInstitutional

Stakeholders

EPSA

FE EERE

OES1

CFO

SC

ARPA‐E

NE

4

32

Connectivity to Other DOE Activities

DOE Grid Modernization Multi‐Year Program Plan

Design and Planning Tools

Sensing and Measurement

System Control and Operations

Devices and Integrated Systems

Security and Resilience

Institutional Support

Stake Holder Inputs

60+ Workshops and Peer Reviews since 2012

Integrated Lab Call –Grid Modernization Lab Consortia (GMLC)

Industry and Academic Solicitations – HQ Program Offices

Cooperative Research Agreements – HQ Program Offices

Technical Assistance –HQ Program Offices and National Labs

QER – Policy Options

QTR – Technology Options

Key Attributes of a Modernized Grid

6

Grid Modernization

Reliable

AffordableClean

How do we keep the lights on and protect against threats?

How do we reduce our environmental impact?

How do we keep costs reasonable for consumers?

33

National Goals and Outcomes

• This new crosscutting effort will build on past successes and current activities to help the nationachieve at least three key outcomes within the next ten years: 

> Reliability: 10% reduction in the economic costs of power outages

> Affordability: 33% decrease in cost of reserve margins while maintaining reliability

> Clean: 50% cut in the costs of Distributed Energy Resources integration

• If achieved, these three key outcomes would yield more than $7 billion in annual benefit to the U.S. economy

• In addition, our efforts will ensure the future modernized grid is a flexible platform for innovation by entrepreneurs and others who can develop tools and services to empower consumers and help them make informed energy decisions.

7

DOE Major Achievements

• Major Achievement #1 – Lean Bulk Power Systems

– Reliable: Maintain reliable operations with <=10% reserve margin; 

– Clean: Systems include >33% variable energy resources;

– Affordable: New capability for grid operators to leverage and manage distribution‐level grid services will require less generation reserve

• Major Achievement #2 – Clean Distribution Systems

– Clean, Reliable: Demonstrate reliable and affordable feeder operations with >50% DER penetration

– Reliable: Coordinated microgrid(s) control for resilience (20% fewer outages, 50% shorter recovery time)

– Affordable: Distributed, hierarchical control for clean energy and new customer‐level innovation for asset utilization 

• Major Achievement #3 – Grid Planning and Analytics 

– Reliable: Use coupled T&D grid planning models with 500x speed‐up to address specific grid issues

– Clean: Develop with stakeholders new data‐driven approaches to DER valuation and market design

– Affordable: Work with States to more rapidly evaluate new business models, impacts of policy decisions

8

34

•Evaluate regulatory and policy options and implications of various grid ownership and operations models – support utility and regulatory reform through technical assitance

Institutional Alignment

•Develop planning tools that integrate transmission and distribution and system dynamics and can use high performance computing platforms -deliver 500x speed-up

Design and Planning Tools

•Increase ability to coordinate and control up to millions of devices and integrate with energy management systems – coordinate millions of devices; enable one-minute contingency analysis at the interconnect scale

System Control and Power Flow

•Develop sensors, analytics, and visualizations that enable 100% observability of generation, loads and system dynamics across the electric system – develop low cost sensors at all scales, handle 1000x data volumes, visualization tools, dynamic accuracy

Sensing and Measurements

•Develop advanced grid control and integration devices and validate integrated systems that can optimize operations at high variable RE penetrations and provide high reliable service – validate 50-100% DG penetration scenarios on feeders

Devices and Integrated Testing

•Develop advanced security (cyber and physical) solutions and real-time incident response capabilities – capable of identifying cyber events in real-time and analyzing within 12 hours.

Security and Emergency Response

•Develop megawatt-scale demonstrations that show transfer of the technologies developed through R&D activities into the field linked to policy and market decision tools

Risk Mitigation through Multi-scale Pilots

Technology Innovation

9

Building on our integrated technical thrusts

System Operations, Power Flow, and Control

Expected Outcomes

• By 2020 deliver an architecture, framework, and algorithms for controlling a clean, resilient and secure power grid

– leveraging advanced concepts, high performance computing, and more real‐time data than existing control paradigms

– Involving distributed energy resources as additional control elements

• Develop software platforms for decision support, predictive operations & real‐time adaptive control

• Deploy through demonstration projects new classes of power flow control device hardware and concepts 

• Advance fundamental knowledge for new control paradigms (e.g., robustness uncompromised by uncertainty)

Federal Role

• Convening authority to shape vision of advanced grid architecture, including new control paradigms for emerging grid to support industry transformation

• Deliver system engineering and other supporting capabilities from the National Laboratory System to research & develop integrated faster‐than‐real‐time software platforms and power electronics controls

Advanced control technologies to enhance reliability and resilience, increase asset utilization, and enable greater flexibility of transmission and distribution systems

Conventional controls

Distributed controls

35

Activities and Technical Achievements

11

Activity Technical Achievements by 2020

1. Develop Architecture and 

Control Theory

Comprehensive architectural model, associated control theory, and control 

algorithms to support a variety of applications to improve grid flexibility, future 

adaptability, and resilience while not compromising operational reliability or 

security.

Wide‐area control strategies to improve reliability, resilience, and asset 

utilization.

2. Develop Coordinated 

System Controls

New control grid operating system designs reflecting emerging system control 

methodologies.

Framework(s) for integrating the next generation energy management system 

(EMS), distribution management system (DMS), and building management 

system (BMS) platforms.

3. Improve Analytics and 

Computation for Grid 

Operations and Control

Future and real‐time operating conditions with short decision time frames and a 

high degree of uncertainty in system inputs can be evaluated.

Automation with predictive capabilities, advanced computational solvers, and 

parallel computing. This includes non‐linear optimization of highly stochastic 

processes.

Decision support to operators in control rooms through pinpoint visualization 

and cognitive technologies.

4. Develop Enhanced Power 

Flow Control Device 

Hardware

Low‐cost, efficient and reliable power flow control devices that enable improved 

controllability and flexibility of the grid.

• Develop devices & integrated systems

• Coordinates integration standards & test procedures

• Evaluates characteristics of both individual devices & integrated systems to provide energy services at a variety of scales

Device and Integrated Systems Testing

• Devices: individual technologies that connect to the grid including: PV, CSP, wind, EVs, electricity & thermal storage, building loads, appliances, HVAC systems, lighting, fuel cells, electrolyzers, CHP/BCHP, engines, microturbines, wires, cables, switches, transformers, etc. Device local controllers (DER controllers, building EMS) are covered in this area. Sensors are covered in Sensor area. Power flow controllers are covered in System Operations area.

• Integrated Systems: Integrated systems contain multiple devices/technologies integrated to achieve an energy goal. Examples: buildings, aggregated fleets, microgrids, campus energy systems, subdivisions, distribution circuits, multiple distribution circuits, regional electric grids that include sub transmission & transmission systems.

• Energy services: value‐added services & transactions for device & system owners include both energy services & ancillary services (e.g. frequency & voltage support, spinning reserves, etc.) with the electric grid & with other parties.

36

Device and Integrated Systems Testing

Reducing Customer Outages

• Developing cost effective energy storage that can provide local area backup power

• Testing & evaluating microgrid concepts that provide improved customer reliability

13

Helping meet high‐level GMLC Goals

Decreasing Operating Reserves

• Developing renewable generation, distributed generation, storage & controllable loads that can provide reserves to bulk power system at economic cost

• Developing interconnection & interoperability standards & test procedures to characterize devices’ ability to provide reserves

• Validating that renewable generation, distributed generation, storage & controllable loads can provide reserves for bulk power system

Reducing Integration Costs

• Developing smart interfaces to renewable generation, distributed generation, storage & controllable loads that can reduce interconnection costs

• Develop interconnection & interoperability standards that streamline processes & reduce renewable energy integration costs 

• Advanced components & key materials critical for enabling next generation of devices (capacitors, packaging materials, magnetic materials, etc.)

Security and Resilience

Expected Outcomes

• Holistic grid security and resilience, from devices to systems

• Inherent security designed into components and systems vs security as an afterthought

• Security and resilience addressed throughout system lifecycle and covering the spectrum of legacy and emerging technologies

Federal Role

• Lead and establish security and resilience research programs to develop technology solutions and best practice guidance

• Improve adoption of security and resiliency practices, and provide technology‐neutral guidance

• Inform stakeholders of emerging threats and help address threats appropriate for government response

Providing a pathway to holistic and comprehensive security and resilience for the nation’s power grid

37

Security and Resilience Activities & 2020 Achievement Targets

Activity Technical Achievements by 2020

6.1. Improve Ability 

to Identify Threats 

and Hazards

• An all hazards approach for threat identification and emergency response, which is 

accepted and implemented by the energy sector.

6.2. Increase Ability 

to Protect Against 

Threats and Hazards

• Standards, methods, testing and evaluation procedures for physical and cyber security enabled designs.

• Development, demonstration and field validation of novel energy, communication and control system models and logistical optimization techniques.

• Grid components which are inherently protective of grid services to all‐hazards.

6.3. Increase Ability 

to Detect Potential 

Threats and Hazards

• Advanced cyber‐physical data analytics and cognitive learning, spanning time scales and data sources across the system lifecycle, to enable proactive and real‐time information flow by the end of FY20.

6.4. Improve Ability 

to Respond to 

Incidents

• Methodologies and architectures frameworks which assess system degradation to all hazards, provide diverse attack recognition and mixed‐initiative response on multiple timescales, and optimize operational efficiencies/priorities for the power grid.

6.5. Improve 

Recovery 

Capacity/Time

• Advanced substation and transformer designs and standards that facilitate improved transformer portability and rapid substation recovery.

• Hardened fail‐safe and wireless communications capabilities and devices for grid control systems that resist impacts from cyber, geomagnetic disturbance, and electromagnetic pulse events.

Design and Planning Tools

Expected Outcomes by FY20• Coupling grid transmission, 

distribution, and communications models to understand cross‐domain effects  

• Computational tools, methods and libraries that enable 1000X improvements in performance for electric production cost simulation

• Incorporate uncertainty and system dynamics into reliability planning tools to accurately capture effects of renewable generations

Federal Role• Apply Natl. Lab advanced computing 

capabilities to develop next gen tools 

• Facilitate stakeholder engagement in R&D and transition to practice

Drive next generation of tools to accurately perform cost‐benefit trade‐offs and improve reliability of design for deployment new smart grid and renewables

Interconnect Feeder

38

Planning and Design Tools Activities & 2020 Achievement Targets

Vision: Grid Sensing & Measurement

System Visibility for Enhanced Resiliency and Control

• Expected Outcomes  

– Demonstrate novel, low‐cost sensors (e.g. under $10/sensor in buildings) to provide nearly 100% observability across the entire electric delivery system by 2020

– Develop real‐time data management and data exchange framework that enables analytics to improve prediction and reduce uncertainty by 2020 

– Develop next generation sensors that are accurate through disturbances to enable closed‐loop controls and improved system resiliency by 2020

• Federal Role

– Accelerate the development and deployment of  low‐cost sensors and a data analytics framework    for the next generation grid

– Ability to transfer data interoperably, securely including frequency coordination with the FCC

39

Grid Sensing & Measurement Activities & Technical Achievements

Activities Technical Achievements by 20203.1. Improve Sensing for Buildings & End-users

Develop low cost sensors (under $10 per sensor) for enhanced controls of smart building loads and distributed energy resources to be “grid friendly” in provision of ancillary services such as regulation and spinning reserve while helping consumers understand benefits of energy options.

3.2. Enhance Sensing for Distribution System

Develop low cost sensors (under $100 per sensor) and ability to effectively deploy these technologies to operate in normal and off-normal operations

Develop visualization techniques and tools for visibility strategy to help define sensor type, number, location, and data management. Optimize sensor allocation for up to 1,000 non-meter sensing points per feeder.

3.3. Enhance Sensing for the Transmission System: Develop Agile Prognostics and Diagnostics for Reliability & Asset Management

Develop advanced synchrophasor technology that is reliable during transient events as well as steady state measurement.

Develop low cost sensors to monitor real-time condition of electric grid components.

3.4. Develop Data Analytic and Visualization Techniques

Provide real-time data management for the ultra-high velocities and volumes of grid data from T&D systems.

Enable 100% visibility of generation, loads and system dynamics across the electric system through the development of visualization techniques and software tools

Develop measurement and modeling techniques for estimating and forecasting renewable generation both for centralized and distributed generation for optimizing buildings, transmission, storage and distribution systems.

3.5. Demonstrate unified grid-communications network

Create a secure, scalable communication framework with a coherent IT-friendly architecture that serves as a backbone for information and data exchange between stakeholders and decision makers.

Expected Technical Achievements by 2020

• Accelerated state & federal policy innovation due to enhanced State and Regional technical assistance 

• Methods for valuation of DER technologies and services are defined and clearly understood by stakeholders and enable informed decisions on grid investments and operations

• 3‐5 states have adopted fundamental changes and 8‐10 states have adopted incremental changes to their regulatory structure that better aligns utility interests with grid modernization and clean energy policy goals

Federal Role

• Provide independent, unbiased technical assistance (e.g., information and analysis tools)that address key grid‐related policy, regulatory, and market issues

• Create an over‐arching stream of grid‐related “institutional” analysis, workshops, and dialogues to raise awareness of the need for grid modernization

Institutional Support

Enable regulators and utility/grid operators to make more informed decisions and reduce risks on key issues that influence the future of the electric grid/power sector

40

Institutional Support Activities & 2020 Achievement Targets

Activity Technical Achievements by 2020Provide Technical 

Assistance (TA) to 

States and Tribal 

Governments

TA to all states and tribes to inform their electricity policy decision making and accelerate 

state policy innovation.

Technical support to at least 10 states that allows them to establish formal processes to 

review utility distribution system plans, including guidance on consideration of non‐wires 

alternatives, DER, and advanced grid systems.

At least 10 other states have developed comprehensive energy system plans.

Support Regional 

Planning and 

Reliability 

Organizations

Facilitated long‐term regional planning in each U.S. interconnection.

Assisted regional planning organizations in developing institutional frameworks, standards, 

and protocols for integrating emerging technologies.

Coordinated regional long‐term planning process that uses standardized, publicly available 

databases of transmission and regional resource data and planning assumptions.

Develop Methods and 

Resources for 

Assessing Grid 

Modernization:  

Emerging 

Technologies,  

Valuation, and 

Markets

New methods for valuation of DER technologies and services that are defined and clearly 

understood by stakeholders and enable informed decisions on grid investments and 

operations.

Analysis tools and methods that facilitate states/tribes’ integration of emerging grid 

technologies into decision‐making, planning, and technology deployment.

New Grid Modernization performance and impact metrics and data collection methods, 

which are used by states to track progress.

Conduct Research on 

Future Electric Utility 

Regulations

3‐5 states have adopted fundamental changes and 8‐10 states have adopted incremental 

changes to their regulatory structure that better aligns utility interests with grid 

modernization and clean energy goals.

Engaging with Stakeholders

22

41

Stakeholder Engagement

23

• FY15 regional dialogues regarding MYPP 

• Gather regional input on grid modernization interests and priorities (FY15 and FY16)

• Future call for regional grid modernization partnerships for demonstrations

• Annual Grid Modernization summits, MYPP updates, solicitations to provide technical assistance

Developing Regional Partnerships using the National Laboratory Complex

What’s Next?

• Advisory groups for each of six technical areas formed summer 2015

• Regional discussions held with stakeholders thru October 2015

– Strategy input

– Frame regional priorities for grid modernization 

• Welcome industry input on how best to accelerate ecosystem of innovation between labs, vendors and early adopter utilities

Next year will see energy policy legislation drafted, Grid Modernization Initiative launched and regional discussions regarding grid mod priorities initiated.  Utilities and vendors have important role in contributing to the planning and execution of 

grid modernization!

24

42

Robin E ManningVice President - Transmission, EPRI

PSERC Summer Workshop July 15, 2015

Value of theIntegrated Grid

Utility Integrated Distributed Resource Deployment

2

EPRI’s Integrated Grid Concept

Extensive Electricity Sector Stakeholders in All Phases

Phase 1

Integrated Grid (IG) Paper

FEB 2014

Phase 2

Benefit/Cost Assessment

OCT 2014

Phase 1

IG Pilots

NOW

43

3

Action Plan

Inform Stakeholders on Key Concept &

Challenges

Benefit/Cost Framework for

Different Designs

Global Demonstrations

Data, Information and Tools

Global Collaboration to Establish the Science, Engineering and Economics

4

EPRI Whitepapers Aligned with the Integrated Grid

Phase 1

Integrated Grid (IG) Paper

FEB 2014 Grid Modernization

– Power System Resiliency– Physical Security, EMP, GMD, Sensors, UAV, Advanced Structures

Communication Standards and Interconnection Rules– Recommended Settings for Voltage and Frequency Ride-Through of Distributed

Energy Resources – Are Current Unintentional Islanding Prevention Practices Sufficient for Future

Needs

Integrated Planning and Operations – Contributions of Supply and Demand Resources to Required Power System

Reliability Services– Distribution Feeder Hosting Capacity: What Matters When Planning for DER

Informed Policy and Regulation– Power System Flexibility (PS Connectivity pending)– Importance of Capacity and Energy in Supply and Demand

44

5

Integrated Grid - Benefit Cost Framework Phase 2

Benefit/Cost Assessment

OCT 2014

6

Utility Scale PV

Utility Scale PV + Storage

Distributed Storage

Microgrids

EV Charging Infrastructure

Customer Side Technologies

EPRI Integrated Grid Pilots: Building an Industry Repository of Integration Approaches, Benefit-Cost and Business Models

45

7

Why Integrated Grid Pilots and EPRI?

An Integrated Approach

Uses consistent, transparent methodology intended to be broadly applicable

Goes considerably beyond technology demonstrations– Performance, costs,

environmental and operational impacts and business models

Assesses societal and grid benefits that far outweigh technology benefits alone

Requirements and approaches for integration at much larger scales

EPRI’s Role

Develop requirements for integrated approach

Help implement approach– For planned or existing technology

deployments Collect and analyze data to

assess costs and benefits

Inform and benefit industry research programs to enhance industry platforms and standards for integration

8

Integrated Approach to Deploying Distributed Energy Resources (DER)

The integrated approach allows

Local Energy Optimization to become part of Global Energy

Optimization

Discussion Topics

DER technology outlook

Value of Integrated Grid

Examples of Integrated approach for DER

TheIntegrated

Grid

46

9

Value of the Grid to DER

16

14

12

10

8

6

4

2

00 2 4 6 8 10 12 14 16 18 20 22 24

Hour

PV Output

Residential Load

Power (kW)

10

Grid Connectivity Reduces Harmonic Impact

47

11

Mon Tue Wed Thu Fri Sat Sun

5

4

3

2

1

0

-1

-2

-3

Site

Dem

and

(kW

)

Value of Grid for a Net Zero Energy Home

Capacity

Capacity

Need to Value Both Capacity and Energy

12

Outlook of Residential and Commercial PV

Factoids1

Residential system prices fell 7%, from $4.91/W (1Q13) to $4.56/W (1Q14)

Non-residential system prices fell 5.7% year-over-year, from $3.95/W to $3.72/W

Supply Chain, Overhead and Margins – largest cost category (40%)

Other significant include the PV module (20% of total pricing) and direct installation labor (13%) of total pricing).

TrendsResidential PV installations exceeded non-residential More than 1/3 of residential PV installations came on-line without any state incentiveSchool, government, and nonprofit PV installations increasingFuture price decline will depend on addressing soft costs

2009

$8.00

2014

$4.56

Residential PV System Price PV Module Price Trend

1SEIA/GTM Research 1Q2014 PV

43% decline in 5 years

$6.00

$5.00

$4.00

$3.00

$2.00

$1.00

$0.001990 1995 2000 2005 2010 2015

PV Module Price per Watt

Key contributor to price reduction

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13

Lithium Ion Technology Outlook

$180-$225

$100-$120

$1000-$1200

$500-$600

$400-$500

$200-$250

Projected Cost (in $/kWh) 2015 2020

Cell

Battery Pack

ResidentialES System

$800-$1000

$400-$500

Utility Scale ES System

Costs can differ significantly at the cell, battery pack, and complete system levels

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0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0

4.5

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 240.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0

4.5

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Controlled Water Heater (kWh)Uncontrolled Water Heater (kWh)

Smart Appliance as a Grid ResourceWater Heater – Passive Energy Storage

Average energy draw profile of an electric water heaterIntelligent set point control, charging and discharging decoupledIntelligent set point control to provide grid benefits

Hours

kW

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SubstationLine Regulators

1.10

1.05

1.00

0.95540480420360300240180120600 600

Time (sec)

Voltage (pu)

No Control

Voltage at END of Feeder

Value of an Integrated Approach: Smart Inverter Assisted Voltage Control

Volt/Var Control

Simulation results indicate use of smart inverters can mitigate many of the voltage issues resulting from PV

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Multiple Applications for Distributed Storage

Key long-term need: distribution communication/control platform to integrate and optimize

DistributionSubstation

SubstationStorage

Community Storage

ResidentialStorage

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17

0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100%

Total Fixed Total Variable

Utility #1

Utility #2

Utility #3

Utility #4

Utility #5

Utility #6

Utility #7

Utility #8

Utility #9

Utility #10

Analysis of cost for 10 representative US utilities

Cost Composition of Residential Bills(approximated from public data)

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Key Research Challenges: Enable Integration of Customer Resources

Grid Ops & Planning Integration Unproven Reliable forecasts of availability and dispatch-ability of customer resources needed for ops and planning

Integration Platforms Early EvolutionPlatforms to link and aggregate devices (controls, inverters, appliances) at the customer premises

Customer Adoption and Use Not ModeledNo robust model to estimate customer adoption and use of technology and resultant grid impacts

Load Impacts Highly UncertainNew technologies are altering load shapes in ways we are only beginning to comprehend

Measurement & Verification NeededMethods to characterize benefits and impacts attributable to customer resource interventions

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Together…Shaping the Future of Electricity

Electric Power Research Institute

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B O N N E V I L L E P O W E R A D M I N I S T R A T I O N

Technology InnovationDelivering Value to BPA

Organized, Disciplined, Focused

Keeping the Lights on for the Long Term

The Basics Bonneville Power Administration

(BPA) markets power from 31 Federal dams, the Columbia Generating Station Nuclear Plant, and several small non-Federal power plants

About 80% of the power BPA sells is hydroelectric.

BPA accounts for about 30% of the electric power consumed within the region.

3,100 Federal FTE employees

2

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15,000 Miles of Transmission System

3

Transmission System

Operating voltage Circuit miles1,000 kV……………………........... 264*500 kV ………………......... 4,735345 kV ………………………. 570287 kV ………………………. 229230 kV …………………….. 5,324161 kV ………………………. 119138 kV ………………………… 50115 kV …………………….. 3,556below 115 kV ………………...368Total 15,215

*BPA’s portion of the Pac NW / Pac SW direct-current intertie. The total length of this line from The Dalles, OR to Los Angeles, CA is 846 miles.

4

Direct LinksAgency

Strategy

Technology Innovation

Strategy

RoadmapBusinessLinkage

BusinessTechnology Linkage

TechnologyPortfolioLinkage

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Investing in Technology

5

BPA’s technology innovation agenda is guided by a strict logic and framework that links the agency’s research goals to current business challenges and technology gaps facing the agency.

This agenda supports three of the agency’s strategic priorities: Preserve and enhance generation and

transmission system assets and value; Advance energy efficiency; and Expand balancing capabilities and resources.

Since 2005, BPA’s Technology Innovation Office has pioneered an approach that ensures the agency is making shrewd investments in technology research.

BPA’s R&D Program

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Budget: >$18M Projects: >50

– Tx: Operations and Planning

– Demand Response– Hydro Optimization– Energy Efficiency

Well articulated Technology Roadmaps serve as the basis for R&D portfolio

BPA Technology InnovationAnnual Cycle

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Highlights of FY15 Completing Projects

Title Sponsor LeadInter-Area Oscillation Damping Controls Dmitry Kosterev BPA

Response-Based Voltage Stability Controls Dmitry Kosterev BPA

Verification and Validation of Transient Stability Models and Results Meg Albright University of Illinois

Impacts Due to Dynamic Transfers Meg Albright BPA

Data Integrity and Situational Awareness Tools (DISAT) Dmitry Kosterev PNNL

Real-Time Load Composition Estimation Dmitry Kosterev Oregon State University

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Transmission Planning and Operations

Success: Oscillation Damping Control

Address oscillation damping risks:– Improved understanding and

analysis of power oscillations– Development and deployment of

situational awareness tools for detection and analysis of power oscillations

– Research controls to dampen inter-area power oscillations

Current status:– WECC paper is published on modes of inter-area power oscillations in the

Western Interconnection– Engineering tools for oscillation analysis are developed and deployed– Supported deployment of Oscillation Detection and Mode Meter applications in

BPA control room, provided dispatcher training sessions– Quantified the effectiveness of various control methods to dampen inter-area

power oscillations, proceed with demonstration of PDCI modulation controller

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This is what we are trying to prevent

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Oscillation Detection Application was developed under BPA capital investment, TIP 50 helped with evaluation and dispatcher training

9

Success: Oscillation Damping Control

Synchrophasor Success! Platts Global Energy Award, 2014

– BPA’s synchrophasor program was nominated in the Industry Leadership Award category for Grid Optimization

Annual budget > $1.6M on big data projects

Projects address issues identified in the Transmission Technology Roadmap

> 150 phasor measurement units (PMUs) installed

It was a “…fall on your knees moment…”

BPA VP of Transmission ServicesLarry Bekkedahl, 2014

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Success: Response-Based Voltage Stability Controls

Assess voltage stability risks:– Dynamic voltage stability risks

due to motor stalling– Controls to enable reliable wind

integration– Synchrophasor-based voltage

stability controls

Current status:– Composite load model is developed and implemented in WECC,

fault-induced delayed voltage recovery risks are assessed for Portland Metro area

– Best practices for wind power plant voltage control are developed and implemented, held nation-wide voltage control conference

– Synchrophasor-based remedial action scheme (RAS) is researched, developed, prototyped, approved by WECC, and scheduled for energization in October 2015

Fault-induced delayed voltage

recovery

11

Synchrophasor remedial action scheme (RAS) development display12

Success: Response-Based Voltage Stability Controls

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Success: Power Plant Performance Monitoring and Compliance with NERC Modeling Standards

BPA PMU monitoring power plants: Conventional –

– 12 plants – 130 generators – 21,145 MW of generation

Wind –– 11 plants– 1,200 MW of generation

Review model performance annually

Cost-effective method of compliance with NERC MOD-026 and -027 Reliability Standards

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14

Before (2014) After (2015)

Actual Model

Success: Power Plant Performance Monitoring and Compliance with NERC Modeling Standards

Actual Model

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Synchrophasor Lab Promotes R&D related to

PMU data 10 servers used for:

• Event detection• Data validation• R/T trending and displays

200,000+ measurements are processed every second

Current status– Developing a centralized

Synchrophasor Event Analysis and Retrieval System (SPEARS)

15

Research partner: Portland State University Objectives:

– Improve data mining and analysis capabilities using Synchrophasor data

– Process raw PMU directly, distribute processes among nodes in cluster, combine results

– Release package as Open Source, with flexibility for multiple data formats

16

Open Source Platform for Accelerating Synchrophasor Analysis

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Synchrophasor Event Analysis and Retrieval System (SPEARS)– Retrieve logs from detection tool– Analyze and stores raw data from events– Generates automated event reports

Functional evaluation– BPA Lab with real-time PMU data

Case study analysis

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Synchrophasor Event Analysis and Retrieval System (SPEARS)

Synchrophasor Linear State Estimator and PMU Data Validation/Calibration

Explores development and implementation of data mining and validation tools for the incoming synchrophasor data via two research paths

Current Activities:– Software developed to track synchrophasor issues that are flagged at the PMU level

• Includes processing flags in the data streams and providing a daily count of “bad” data, along with data availability from each PMU.

• S/W expanded to analyze all model-less “suspect” data, including data that is stale, out of a reasonable range, etc.

– Work with EPG to develop Linear State Estimator; beta testing on historical data planned for May

– Begin developing a frequency event detection tool, including initial trigger definitions, assessing past test cases, and research into leading techniques employed nationally; beta testing on live PMU data by July.

PMU-based linear state estimator for data prediction, validation, calibration, and robust state estimation of the 500kV power system

Data mining techniques including base-lining, event detection, oscillation monitoring and detection, and bad data correction

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Hydro Optimization

Research partners:– Oregon State University (10/2012–9/2015)– Deltares (10/2012–4/2015)

Objectives: – Produce fast, stable, high resolution results – Quantification of operational flexibility– Effective and efficient ways to visualize large

amounts of data to support decision making– Supports real-time and Planning decisions

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Climate Change Impact Assessment Research partners:

– Portland State University (10/2013–9/2015)– Washington State University (10/2013–9/2016)

Objectives: – Updates/Enhances existing climate change

streamflow data sets to more accurately characterize the uncertainties in streamflow modeling

• Multiple hydrologic models.• Explicit representation of glaciers.• Use of advanced methods of parameter estimation to

resolve “cliffs” in certain fluxes and state variables at sub-basin boundaries.

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Resources and ContactsTo Learn More:

www.bpa.gov/[email protected]

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Energy Efficiency

Terry OliverChief Technology Innovation [email protected] | 503.230.5853

Transmission Power Generation Asset Management

Demand Response

BPA’s Technology Roadmaps

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