Current Projects


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M-46: Toward Large-Scale DER Aggregation: Competitive Aggregation, Operation Support, and ISO-Aggregator-Utility Coordination (ending August 2025)

Summary This project focuses on the practical challenges of DER aggregations for wholesale market participation under FERC Order 2222. We propose a bottom-up approach to address key technological barriers at the interfaces between (a) a DER aggregator (DERA) and its customers where generation, storage, and flexible demand resources are aggregated;  (b) a DERA and a market operator (ISO) where DERAs participate in wholesale energy, reserve and regulation markets; (c)  a DERA and a distribution utility where the utility provides planning and operation support for delivering the aggreged DER; (d) a utility and an ISO where the ISO maximizes net benefits of market participants and mitigates risk subject to system constraints. In particular, this project investigates large-scale, competitive, and profit-maximizing aggregation technologies that benefit DERA customers more than the prevailing net energy metering-based retail tariffs. The project examines the impacts of DER aggregation uncertainties at all interfaces and develops risk mitigation strategies. The project investigates distribution system planning and operation solutions supporting DER aggregation, DERA bidding strategies in the wholesale markets, and ISO market clearing and settlement solutions. The project delivers technical assessments and comparative studies on the feasibility and cost/benefit analysis. 
Academic Team Members Project Leader: Lang Tong (Cornell,
Team members: Tim Mount (Cornell,, Subhonmesh Bose (UIUC,, and Meng Wu (Arizona State,
Industry Team Members Mike Swider (NYISO), Tongxin Zheng (ISO-NE), Jianzhong Tong (PJM), Hong Chen (PJM), Clyde Loutan (CAISO), Yonghong Chen (MISO), Anupam Thatte (MISO), Akshay Korad (MISO), Arezou Ghesmati (MISO), Patrick Dalton (MISO), Megan Pamperin (MISO), Patrick Panciatici (RTE) Ahmed Zamzam (NREL), Bo Yang (Hitachi), Yanzhu Ye (Hitachi), Ryan Fox (GE), Harvey Scribner (SPP), Nikita Singhal (EPRI), Ibrahim Krad (EPRI), Nitin Padmanabhan (EPRI), Arun Sukumaran Nair (Eaton)
Project Period July 1, 2023 to August 31, 2025

M-45G: Bidding Generation Tool (ending January 2024)

Summary The new FERC Order 2022 has paved the way for market participation of DERs through aggregators. Although these aggregators can now be market players, they are unlike the normal traditional generation participating in bulk power system services. These DERs can provide both distribution services as well as bulk system services. A new framework is being investigated and developed through this work where a bidding generation tool will be created to develop bids, optimizing distribution and wholesale market participation.
Academic Team Members Project Leader: Mojdeh Khorsand (Arizona State,
Industry Team Members Abrez Mondal (EPRI), Nikita Singhal (EPRI), Ahmed Saad (EPRI)
Project Period November 1, 2022 to January 31, 2024

M-44: The Future of Markets and DERs: Providing Essential Grid Services and Managing Performance Risk (ending August 2024)

Summary FERC Order 2222 mandates incorporation of distributed energy resources (DERs) in wholesale markets. With this new requirement, one main power systems change is the push towards not just DER integration but also the reliance on these resources to be able to provide essential grid services. Electricity markets, grid operations, and reliability requirements are designed for classical assets, not emerging assets with distinct characteristics, i.e., higher probability of failure, lower capacity firmness, and lower impact of failure. This project addresses the concern of DER integration from multiple fronts: a) effective aggregation and management of DERs to ensure their profitability and the quality of services provided by these aggregated resources, b) essential market and operational reform, and c) coordination of transmission and distribution services provided by DERs. This project will develop a virtual power plant DER aggregation strategy to demonstrate that, while DERs possess new challenges in comparison to conventional assets, they can be optimally managed such that they perform similar to conventional assets. An intra-day DER evaluator module will be developed to assess whether the aggregated DER will be able to satisfy their offering to ensure a high level of real-time performance during both normal and outlier/extreme events. Moreover, this project provides an effective transmission and distribution coordination strategy by leveraging untapped flexibilities such as optimal mode of operation and setpoint identification of smart inverters within the allowable range of IEEE 1547.  
Academic Team Members Project Leader: Kory W. Hedman (Arizona State,
Team members: Mojdeh Khorsand (Arizona State, and Shmuel Oren (UC Berkeley,
Industry Team Members Oluwaseyi Akinbode (MISO), Guillermo Bautista Alderete (CAISO), Sumit Bose (GE), Hong Chen (PJM), Yonghong Chen (MISO), Kwok Cheung (GE), Richard Dillon (SPP), Erik Ela (EPRI), Jesse Gantz, (GE), Anthony Giacomoni (PJM), Bo Gong (SRP) Majid Heidarifar (EPRI), Avnaesh Jayantilal (GE), Akshay Korad (MISO), Sobia Naqvi (APS), Dane Schiro (ISO-NE), Nikita Singhal (EPRI), Yohan Sutjandra (The Energy Authority), Arun Nair (Eaton), Clyde Loutan (CAISO)
Project Period July 1, 2022 to August 31, 2024

M-43: Integrating RTO and utility processes in planning and cost allocation (ending August 2024)

Summary We address resource and transmission (R&T) investment planning methods, focusing on four objectives: (1) Determine ways new software tools can facilitate long-term planning while exploring interdependencies within RTO interconnection queues, transmission expansion processes, capacity markets, and interregional transmission considerations; (2) Implement a reliability evaluation toll that coordinates with a long-term expansion planning application, explicitly accounting for utility-scale renewables, storage, and DER. (3) We will test an implementation of our tools using large-scale industry-size models, developing results to illustrate relationships between investment robustness, resource adequacy, and operational flexibility. (4) Develop a new cost allocation approach which incorporates investment robustness in identifying benefit.
Academic Team Members Project Leader: James McCalley (Iowa State,
Team members: Jacob Mays (Cornell,, Lizhi Wang (Iowa State,
Industry Team Members Wes Hall (GE), Eduardo Ibanez (GE), Yifan Li (MISO), Haifeng Liu (CAISO), Harvey Scribner (SPP), Casey Cathey (SPP), Greg Brinkman (NREL), Anthony Giacomoni (PJM), Patrick Panciatici (RTE), Anish Gaikwad (EPRI), Parag Mitra (EPRI), Miguel Ortega-Vazquez (EPRI), Mohamed Osman (NERC)
Project Period July 1, 2021 to August 31, 2024


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S-109G: Impact Analysis of Synchronous Generators and Inverter-Based Resources on System Modes (ending June 2025)

Summary With large-scale integrations of renewable energy sources, the dynamics of the power systems is becoming more complex in power grids all over the world. Fast dynamic controls and switches that are built into the newer power electronic-based energy interfaces are interacting with the traditional power grid controls in unpredictable ways. These complex and non-smooth dynamic mechanisms are impacting the small-signal stability properties of bulk power systems. This project will focus on the impact analysis of inverter-based resources (IBRs) and synchronous generators on the damping properties of system modes. The project will assess the overall contribution of the increased presence of IBRs in medium-scale power system models. The project will also develop novel signal theoretic algorithms for estimating the impact of synchronous machines and IBRs on the damping levels of interarea modes using ambient synchrophasor measurements.
Academic Team Members Project Leader: Vaithianathan (Mani) Venkatasubramanian (Washington State,
Industry Team Members Patrick Panciatici (RTE), Gilles Torresan (RTE), Adrien Guironnet (RTE)
Project Period June 16, 2023 to June 15, 2025

S-108G: Guidelines for Voltage Stability Assessment on Systems with Large Integrations of IBRs (ending August 2024)

Summary Large integration of renewable variable generation and inverter-based resources (IBR) alters the system’s response to contingencies and fault events, and consequently the ability of the system to preserve stable operation under critical conditions. Renewables and IBRs affect voltage stability in various ways, and consequently the methodologies and simulation tools used for the assessment of voltage stability and control. To address these challenges, this project will develop practical guidelines for power system operation and planning engineers to perform voltage stability assessment in transmission systems, especially in conditions where large penetration of IBRs (in the transmission and distribution grids) affects the behavior and response of the bulk power system. This project is intended to initiate the development and implementation of various improved methodologies and tools for voltage stability assessment.
Academic Team Members Project Leader: Amarsagar Reddy Ramapuram Matavalam (Arizona State,
Industry Team Members A.D. Rosso (EPRI)
Project Period July 1, 2023 to August 31, 2024

S-107: Adaptive Transmission and Distribution Modeling and Simulation Tools for Supporting Integration and Operation of High Penetration of DERs (ending August 2025)

Summary As the implementation of FERC Order 2222 is coming and DERs proliferate, it is imperative to (i) adequately model and efficiently analyze the dynamic impacts of DERs on transmission and distribution (T&D) systems, (ii) capture and leverage full capabilities of DER to facilitate large-scale DER integration and T&D system operation. This project 1) Develops adaptive, multi-fidelity modeling and AI-accelerated co-simulation approaches to improve the computational efficiency of dynamic simulation for large-scale T&D systems; 2) Builds an automated tool to create a multi-fidelity model library for adequately representing distribution systems and DERs while maintaining consistency for different dynamic and transient studies; 3) Derives aggregated reactive power capability curves at T&D interfaces by considering DER control capabilities and leverages them to provide reactive power ancillary services. The main outcomes will be open-source tools that help industry members efficiently plan and reliably operate their systems with high penetration of DERs. 
Academic Team Members Project Leader: Qiuhua Huang (Colorado School of Mines,
Team members: Venkataramana Ajjarapu (Iowa State,, Meng Wu (Arizona State,
Industry Team Members Kwok Cheung (GE), Panitarn (Joseph) Chongfuangprinya (Hitachi), Hung-Ming Chou (Dominion Energy), Bo Gong (SRP), Akshay Korad (MISO), Weijia Liu (NREL), Yi Liu (Eaton), Parag Mitra (EPRI), Alberto Del Rosso (EPRI), Deepak Ramasubramanian (EPRI), Harvey Scribner (SPP), Mohit Singh (ComEd), Sid Suryanarayanan (Eaton)
Project Period July 1, 2023 to August 31, 2025

S-106: Data-Driven Stability Analysis of IBR-rich Grids with hybrid EMT+Phasor models (ending August 2025)

Summary We propose to develop tools for stability analysis of inverter-based resources (IBR)-rich grids represented by hybrid electro-magnetic transient (EMT) and phasor models for planning and operations to (i) localize the cause of instabilities, and (ii) identify limits on transfer flows and IBR injection for secure grid operation. As a result, we directly address NERC recommendations that recognizes the importance of EMT modeling within stability studies. Conventional stability assessment tools currently used by the industry do not support hybrid multi-timescale models, necessitating this work. We will build upon our preliminary results that merge concepts from data-science and dynamical systems to perform transient-stability analysis purely from time-domain simulation results of the hybrid models. The analysis can be used to guide the development of a comprehensive stability assessment tool that will augment the intuition of the planner/operator in identifying critical grid assets. We will validate the proposed methods on network models developed by DOE/NREL.  
Academic Team Members Project Leader: Amarsagar Reddy Ramapuram Matavalam (Arizona State,
Team members: Vijay Vittal (Arizona State,, Subhonmesh Bose (UIUC,
Industry Team Members C. Mishra (Dominion Energy), J.D.L. Ree (Dominion Energy), P. Mitra (EPRI), D. Ramasubramanian (EPRI), W. Baker (EPRI), E. Farantatos (EPRI), S. Akinbode (MISO), R. Rajasekhar (MISO), M. Pamperin (MISO), P. Dalton (MISO), B. Gong (SRP), H. Scribner (SPP), M. Parashar (GE), K. Cheung (GE), M. Singh (ComEd), R. Jain (NREL)
Project Period July 1, 2023 to August 31, 2025

S-105: Integration of Protection and Control Systems in Dynamic Security Assessment Methods (ending August 2025)

Summary The protection and control (P&C) system has been the top contributor to system disturbances as consistently shown in the annual NERC reports. This reality is expected to continue and worsen as the penetration level of inverter based resources (IBRs) increases. Specifically, IBRs change the characteristics of the system response during faults and disturbances: reduced fault currents, reduced negative and zero sequence components of fault currents and faster transients. The performance of many legacy protection schemes will deteriorate and mis-operations will increase. We propose to develop a framework for assessing the impact of P&C schemes on the security of the system as the presence of IBRs increases. An effective tool for this purpose, is our proposed co-model of the power system and the P&C system that will enable quantification of the interactions between these two systems. By necessity, the co-model will be a three-phase, breaker-oriented, physically-based, P&C inclusive system for analysis of system response during fault conditions. For post fault DSA, we propose the automatic extraction of the RMS-EMT co-model  from the above described model. The approach will enable to assess the vulnerability of the system to common mode outages, cascading events, effects from circuit breaker failures, effects of hidden failures and cyber-attacks on the P&C system. Two novel dynamic security assessment methods are proposed based on the co-model: (a) a stability assessment method based on identification of the center of oscillations and the energy method and (b) Artificial Intelligent (AI) based approach to selectively identify critical outage scenarios for further analyses. The proposed work will also provide the framework for power system resiliency analysis by developing effective quantifiable resiliency metrics. 
Academic Team Members Project Leader: A. P. Meliopoulos (Georgia Tech,
Team members: Mojdeh Khorsand Hedman (Arizona State,
Industry Team Members Evangelos Farantatos (EPRI), Paul Myrda (EPRI), Bruce Fardanesh (NYPA), Kumaraguru Prabakar (NREL), Bo Gong (SRP), Akshay Korad (MISO), Yonghong Chen (MISO), Jianzhong Tong (PJM), Cheung Kwok (GE), Harvey Scribner (SPP), David Till (NERC)
Project Period July 1, 2023 to August 31, 2025

S-104G: Data Development & Composite Probabilistic Adequacy Evaluation (ending December 2024)

Summary The objective of this project is to develop and illustrate a functional system of data development and probabilistic adequacy assessment to enable planners in organizations such as the New York Power Authority to evaluate the adequacy of their generation and transmission systems and use this evaluation to inform planning-related decision-making.
Academic Team Members Project Leader: James McCalley (Iowa State University,
Industry Team Members Shayan Behzadirafi (NYPA)
Project Period January 1, 2023 to December 31, 2024

S-103G: Oscillation Analysis with SCADA using Inferential Statistics (OASIS) (ending August 2024)

Summary This project will develop rigorous statistical methods that can use widely available SCADA measurements for the detection and analysis of power system oscillations. Even though millions of SCADA measurements are available in a typical power utility company, they are used mostly for quasi-steady-state analysis in the present-day power system owing to their slow sampling rate. In this project, we propose the use of SCADA for detecting problematic dynamic oscillations in the power grid.  This is accomplished by exploiting the asynchronous sampling inherent in SCADA technology. While the oscillation period cannot be determined from SCADA data as implied by the sampling Theorem, the inferential statistical formulation will enable estimating the oscillation amplitude at a specified confidence level. In this project, we will develop the statistical algorithms for SCADA-based oscillation detection and analysis by estimating the amplitude of oscillations in power plant outputs and transmission line power flows and test the methodology using simulations and archived SCADA data from RTE France.
Academic Team Members Project Leader: Vaithianathan (Mani) Venkatasubramanian (Washington State University,
Industry Team Members Patrick Panciatici (RTE), Gilles Torresan (RTE), Marie-Sophie Devry (RTE)
Project Period September 1, 2022 to August 31, 2024

S-102G: Second Stage in Feasibility Assessment of Synchronous Operations of the North American Eastern and Western Interconnections (ending January 2024)

Summary This project will focus on the second stage in considering the feasibility of synchronous operations of the actual North American Eastern and Western Interconnections, along with an analysis using the synthetic versions of each of these interconnects. The idea is to build on the work of the previous SPP funded PSERC project (S-92G) with a greater focus in this project on the economic benefits of such an interconnection.
Academic Team Members Project Leader: Thomas J. Overbye (Texas A&M University,
Team members: Farnaz Safdarian (Texas A&M University,, Jonathan Snodgrass (Texas A&M University,
Industry Team Members Harvey Scribner (SPP), Casey Cathey (SPP)
Project Period August 15, 2022 to January 31, 2024

S-101G: Comparison of Positive-Sequence Simulation Versus Three-Phase Simulation of IBRs and Rotating Loads in Time Domain Simulation (ending August 2024)

Summary This project compares positive-sequence time domain simulation of IBRs in power systems versus three-phase simulation of IBRs.
Academic Team Members Project Leader: Vijay Vittal (Arizona State,
Team members: Mojdeh Hedman (Arizona State,
Industry Team Members Deepak Ramasubramanian (EPRI), Parag Mitra (EPRI), Jens Boemer (EPRI), Anish Gaikwad (EPRI)
Project Period July 1, 2022 to August 31, 2024

S-100: Detection, Characterization, and Mitigation of Disruptive Events (DECODE) by Combining Machine Learning/Artificial Intelligence on Synchrophasors and Physics-based Analysis (ending August 2024)

Summary To leverage over 20 years of research that used physics-based analysis to correlate synchrophasor data to disruptive events, we propose to develop the automated tools by combining various data-based and physics-based solutions in real-time to help system operators detect and classify faults, oscillations, impending instability, and other events that may lead to system emergencies. To achieve this goal, the project:  1) Offers data wrangling techniques for collecting large synchrophasor historical datasets to improve bad data detection, feature engineering, and event label assignment for automated ML/AI solutions; 2) Defines the most effective ML/AI techniques for unsupervised, supervised, semisupervised, and transfer learning solutions, and 3) Combines ML/AI-based and physics-based solutions for cost-effective and computationally efficient automated event characterization, 4) Implements the tool that ranks operator actions to mitigate the events as needed. 
Academic Team Members Project Leader: Mladen Kezunovic (Texas A&M,
Team members: Vijay Vittal (Arizona State,, Mani Venkatasubramanian (Washington State,, Anamitra Pal (Arizona State,
Industry Team Members Casey Cathey (SPP), David Riekel (Hubbell), Bajarang Agrawal (APS), Bo Yang (Hitachi), Jianzhong Tong (PJM), Evangelos Farantatos (EPRI), Tongxin Zheng (ISO-NE), Ben Kroposki (NREL), Bo Gang (SRP), Gilles Torresan (RTE), Arun Nair (Eaton)
Project Period July 1, 2022 to August 31, 2024

S-99: Incorporating climate impacts into electricity system planning models: review and case study (ending August 2024)

Summary The impacts of climate change on the U.S. electricity system are increasingly tangible, but current electricity system models are not well equipped to analyze the new types of common mode events driven by a changing climate. This project seeks to comprehensively survey climate-change-related extreme events and identify common mode impacts on the grid, as well as how these integrate into electricity system planning models. After identifying knowledge gaps and the current state of the art, we will select a case study (type of extreme event and regional extent) and create scenarios for use in grid modeling. Focusing on this case study, we will extend current electricity modeling capabilities to incorporate the relevant climate change scenario and address questions across time scales ranging from real-time operation to long-term planning. The outcomes will be open source tools and publications that seek to advance modeling capabilities for understanding climate-forced extreme event impacts on power systems.
Academic Team Members Project Leader: Ana Dyreson (Michigan Tech,
Team members: Line Roald (Univ. of Wisconsin-Madison,, Thomas Overbye (Texas A&M,, Hao Zhu (Univ. of Texas,
Industry Team Members Aftab Alam (CAISO), Don Lynd (CMS), Laura Fischer (EPRI), Eknath Vittal (EPRI), Xiaochuan Luo (ISO-NE), Jinye Zhao (ISO-NE), Akshay Korad (MISO), Felicia Ruiz (MISO), Barry Mather (NREL), Mike Swider (NYISO), Laurent Dubus (RTE), Bo Gong (SRP), Stanley Palmer (WAPA), Stacy Russ (WAPA), Ron Horstman (WAPA)
Project Period July 1, 2022 to August 31, 2024

S-98G: Model reduction and translation for coordinated expansion planning studies (ending August 2024)

Summary The objective of this project is to develop an integrated grid reduction/translation package to facilitate application of expansion planning software on large industry-grade planning models, where reduction provides a reduced-order network, together with economic data and line limits, and translation identifies investments made on the reduced model in terms of the original large planning model.
Academic Team Members Project Leader: James McCalley (Iowa State University,
Team members: Ali Jahanbani Ardakani (Iowa State University,
Industry Team Members Xavier Florent (RTE), Patrick Panciatici (RTE)
Project Period September 1, 2021 to August 31, 2024

S-96: Data driven control of DERs & hybrid PV plants for enhancing voltage stability with TSO-DSO interactions over multiple timescales (ending August 2023)

Summary This project addresses control & coordination of distribution system assets like DERs and hybrid PV plants with storage to provide real-time active/reactive power support to mitigate voltage instability in transmission systems over multiple timescales. A novel controller for hybrid PV plants will be developed that delivers the requested P/Q/V to the bulk grid. The control is robust to PV variability and disturbances in the grid and exploits the capabilities of DERs like storage. We will utilize physics-based data driven techniques to develop the control scheme of DERs and hybrid PV plants for mitigating the voltage instability in real-time using message-passing machine learning architecture. The control strategies will mitigate/contain inverter tip cascading during delayed voltage recovery events (seconds timeframe) and ensure a safe stability margin for credible Transmission-Distribution (TD) co-simulation platform (PSSE/GridLab-D [1] & OpenDSS) to implement proposed methodologies demonstrating their ability to mitigate voltage instability on practical systems while capturing TSO-DSO interactions. Further (HIL) real-time T&D test bed to ensure that controls are effective under noisy measurements & communication delay.
Academic Team Members Project Leader: V. Ajjarapu (Iowa State University,
Team members: Hugo N. Villegas-Pico (Iowa State University,, Anurag K.Srivastava (Washington State University,, and Anjan Bose (Washington State University,
Industry Team Members B. Leonardi (EPRI), F. Eladi (NRECA), C. Mishra (Dominion Energy), D. Ramasubramanian (EPRI), A.D. Rosso (EPRI), Y. Zhang (NREL), H. Scribner (SPP), K. Zhu (MISO), J. Tong (PJM), V. Krishnan (NREL), B. Kroposki (NREL), P. Chongfuangprinya (Hitachi), W. Qiu (NERC), M. Parashar (GE), Bo Gong (SRP)
Project Period July 1, 2021 to August 31, 2023

S-95: Reliable fault-ride through and protection of converter-dominated power systems under unbalanced conditions (ending August 2023)

Summary Power electronics interfacing renewables, storage, and novel transmission technologies are envisioned to be the cornerstone of tomorrow’s resilient and sustainable power systems. While state-of-the-art power converter control can replace grid-forming and grid-supporting functionalities of synchronous machines, their design typically neglects crucial aspects such as unbalanced faults and the interaction between converter protections (e.g., current limiting) and system-level protection. This jeopardizes system reliability and resilience and has already resulted in large-scale system outages and explicitly accounts for current limits, unbalanced conditions, and protection in the control design. The proposed approach will enable reliable and predictable fault-ride through capabilities that do not rely on heuristics, avoid adverse interactions with system protection, and retain the positive impact of grid-forming control on system-level stability when feasible.
Academic Team Members Project Leader: Dominic Gross (University of Wisconsin-Madison,
Team members: Maryam Saeedifard (Georgia Tech,
Industry Team Members David Till (NERC), Hongtao Ma (NERC), Ben Kroposki (NREL), Kumaraguru Prabkar (NREL), Hung-Ming Chou (Dominion Energy), Aditya Korad (MISO), Evangelos Farantatos (EPRI), Deepak Ramasubramanian (EPRI), Wenzong Wang (EPRI), Harvey Scribner (SPP), Thibault Prevost (RTE), Guillaume Denis (RTE), Bo Gong (SRP)
Project Period July 1, 2021 to August 31, 2023

S-90: Grid Supporting Controllers for Enabling 100% Penetration of Inverter Based Resources (ending August 2023)

Summary Future power systems are envisioned to transition to significant amount of renewable energy. For example, California has mandated 100% renewable energy supply by 2045 and Minnesota has passed laws to move to full renewable energy supply by 2050. New technologies such as HVDC systems will be also integrated into the conventional AC systems forging hybrid AC-DC systems. To assure reliable integration of such a massive amount of renewable inverter-based resources (IBRs), the IBRs should be augmented with grid support capabilities and compatibility features. To this end, this project proposes a multi-pronged research effort as follows: i) Grid Firming Converters: proposing methods to achieve desired voltage and frequency supports from IBRs such as wind and PV farms in the future grid, ii) Grid Forming Converters: developing controls to enable cold start capability of a system with high penetration of renewables, and iii) Resilient Converters: Designing fault ride through capability and post-fault recovery control strategies to avoid massive dropouts of renewables following a disturbance such as what happened in the Western system.
Academic Team Members Project Leader: Maryam Saeedifard (Georgia Tech,
Team members: Sakis Meliopoulos (Georgia Tech,, Saeed Lotfifard (Washington State,
Industry Team Members Deepak Konka (GE), Harvey Scribner (SPP), Kwok Cheung (GE), Mehmet Cintuglu (ABB), Miaolei Shao (GE), Evangelos Farantatos (EPRI), Deepak Ramasubramanian (EPRI), Wenzong Wang (EPRI), Doug Bowman (SPP), Mahesh Morjaria (First Solar), Alan Engelmann (Exelon), Mohit Singh (ComEd)
Project Period July 1, 2020 to August 31, 2023

Transmission and Distribution Technologies (T&D):

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T-67: Smart Meter-Driven Distribution Grid Visibility and Control (ending August 2025)

Summary To unlock the capabilities of smart meters for distribution system applications, this project will develop data-driven models for distribution systems and associated algorithms for real-time state estimation and control applications. The project will use actual smart meter data from Hubble and consider practical limitations on communication bandwidth in both developing and validating the proposed models and algorithms. 
Academic Team Members Project Leader: Daniel Molzahn (Georgia Tech,
Team members: Line Roald (UW Madison,, Dan Fuhrmann (Michigan Tech,
Industry Team Members David Rieken (Hubbell), Kurt LaFrance (CMS Energy), Venkat Banunarayanan (NRECA), Bo Gong (SRP), Dongbo Zhao (Eaton), Shakil Hossan (Eaton), Arun Sukumaran Nair (Eaton), Benjamin Kroposki (NREL), Jouni Peppanenlectric (EPRI), Mohit Singh (ComEd)
Project Period July 1, 2023 to August 31, 2025

T-66: Modeling, Characterization and Suppression of Temporary Overvoltages in Power Grids with High Share of Inverter-Based Resources (ending August 2024)

Summary The recent power outage incidents in power grids with high share of inverter-based resources (IBRs) reveal temporary overvoltages, which may follow fault clearing events, could contribute to major power outages. Motivated by the real-world need for the modeling, characterization and suppression of temporary overvoltages in IBR dominated power grids, as identified by several event analysis reports, this project aims to develop the followings: (1) Proper representation of IBRs in dynamic models for realistic assessments of temporary voltage excursions (2) Defining proper system performance indicators associated with temporary voltage excursions in IBR-dominated power grids with different control strategies, (3) Identifying key influential factors on the dynamics of temporary overvoltages in IBR-dominated power grids by using analytical methods such as state space analysis and impedance-based analysis, and (4) Proposing controllers for IBRs to tolerate and suppress the temporary overvoltages subsequent to disturbances, for both grid forming and grid following converters. The proposed methodologies will be implemented and evaluated in large power grids such as WECC transmission systems and large power distribution systems. Different types of IRBs such as HVDC systems, battery energy storage systems (BESS), and wind and solar power plants will be considered. 
Academic Team Members Project Leader: Saeed Lotfifard (Washington State University,
Team members: Sakis Meliopoulos (Georgia Tech,
Industry Team Members Aftab Alam (CAISO), Ran Xu (CAISO), Alan Engelmann (ComEd), Shikhar Pandey (ComEd), Mohit Singh (ComEd), Kurt Lafrance (CMS), Dennis R. Woycehoski (CMS), Evangelos Farantatos (EPRI), Aboutaleb Haddidi (EPRI), Alberto Del Rosso (EPRI), Deepak Ramasubramanian (EPRI), Kwok Cheung (GE), Deepak Konka (GE), Miaolei Shao (GE), Bishnu Sapkota (GE), Rijesh Akkanusery (GE), Panitarn Chongfuangprinya (Hitachi), Bo Yang (Hitachi) Mingguo Hong (ISO-NE), David Rieken (Hubbell), Xiaochuan Luo (ISO-NE), Yonghong Chen (MISO), Akshay Korad (MISO), Kun Zhu (MISO), David Till (NERC), Hongtao Ma (NERC), Fathalla Eldali (NRECA), Benjamin Kroposki (NREL), Kumaraguru Prabakar (NREL), Gab-Su Seo (NREL), Jianzhong Tong (PJM), Casey Cathey (SPP), Harvey Scribner (SPP), Bo Gong (SRP), Wisam Al Sudani (WAPA)
Project Period July 1, 2022 to August 31, 2024

T-65: Identification and Mitigation of T&D Operational Security Vulnerabilities in Inverter Dominated Power Systems (ending August 2023)

Summary This project seeks to identify operational security vulnerabilities in T&D assets that grid integration of massive amounts of inverter-based resources (e.g. wind and solar generations, HVDC systems and inverter-interfaced energy storages) creates. We will investigate how the likely cascading outages in inverter-dominated power systems will look like as the result of new dynamics and fault response of inverter-based resources (IBRs). The project will focus on the following three main factors (1) Stability of inverters: we will analyze grid synchronization instability of IBRs and identify conditions tat controllers of IBRs negatively affect the stability of the power systems and different operating modes of IBRs (i.e. grid following, grid supporting, and grid forming modes). (2) Protection systems response: we will identify the root cause of protection system vulnerabilities versus penetration levels of IBRs and develop mitigation methods, (3) Dynamic response of loads: we will identify impacts of distinct dynamics of active power distribution systems on transmission systems as the result of large integration of IBRs in distribution systems. According to the identified vulnerabilities, we will propose mitigation strategies. Investigations and mitigation methods will be verified using commercial software such as PSS/E, CAPE, ETAP, PSCAD and realistic power system models.
Academic Team Members Project Leader: Saeed Lotfifard (Washington State University,
Team members: Venkataramana Ajjarapu (Iowa State University, and Sakis Meliopoulos (Georgia Tech,
Industry Team Members Evangelos Farantatos (EPRI), Deepak Ramasubramanian (EPRI), Parag Mitra (EPRI), Aboutaleb Haddadi (EPRI), Masoud Abbaszadeh (GE), Kwok Cheung (GE), Deepak Konka (GE), Miaolei Shao (GE), Bishnu Sapkota (GE), Doug Bowman (SPP), Harvey Scribner (SPP), Wisam Alsudani (WAPA), Jianzhong Tong (PJM), Yonghong Chen (MISO), Felicia Ruiz (MISO), Aftab Alam (CAISO), Adarsh Nagarajan (NREL), Venkat Krishnan (NREL), Murali Baggu (NREL), Ben Kroposki (NREL), Yingchen Zhang (NREL), Mehmet Cintuglu (Hitachi), Bo Yang (Hitachi), Panitarn Chongfuangprinya (Hitachi), Yohan Sutjandra (The Energy Authority), Atena Darvishi (NYPA), Mingguo Hong (ISO-NE)
Project Period July 1, 2021 to August 31, 2023