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Name Author Date Size Type
Security Enhancement through Direct Non-Disruptive Load Control: Part I (S-16 Report)
Description
Dynamic security enhancement is generally associated with improvements in the response of generation and transmission systems, with network controls provided by FACTS devices and special protection schemes gaining acceptance. Load control, on the other hand, has (rightly) been viewed as disruptive to customers and, therefore, as the response of last resort. However, significant enhancements in communications, metering and computer technologies have meant that coordinated control of massive numbers of diverse loads is becoming feasible. Issues arising from such a control strategy have been explored.
Our research has focused on the viability of load control for alleviating voltage collapse, and hence, for mitigating the possibility of cascading system failures. Many customer installations include loads that can be tripped with imperceptible consequences over the short-term. Consolidation of these numerous small loads provides a non-disruptive load control capability that can be used to enhance dynamic security, for example by alleviating voltage collapse. Our research has explored a hierarchical control structure consisting of a lower-level, substation-based controller that interacts with loads, together with a higher-level, wide-area controller that formulates coordinated responses to threats of voltage instability. Load availability information is passed from the substation controller up to the higher-level controller. The resulting control signals are passed back down to the lower level for communication to the actual loads.

This is Part I of the Final report for PSERC project "Security Enhancement through Direct Non-Disruptive Load Control" (S-16). Uploaded: January 22, 2005.
Author
Project Leader: Ian Hiskens, Wisconsin-Madison
Date
6/14/2016
Size
291.12 KB
Type
Document
Project Leader: Ian Hiskens, Wisconsin-Madison 6/14/2016 291.12 KB Document
Security Enhancement through Direct Non-Disruptive Load Control: Part II (S-16 Report)
Description
Direct, non-disruptive control of loads has the potential for enhancing preventative control of oscillatory instability in power systems. The efficacy and robustness of load control was demonstrated over a range of operating conditions on different test systems by optimal selection of load types and locations, and of control actions. The research conclusions confirm the potential of direct load control for stability enhancement from the perspectives of control effectiveness, robustness, and potential economic viability. In addition, modern sensor and communication technologies facilitate use of such geographically-targeted direct load control. Thus, loads can be a resource not only for supporting supply adequacy, but also for providing essential system reliability services.

This is Part II of the Final report for PSERC project "Security Enhancement through Direct Non-Disruptive Load Control" (S-16). Uploaded: January 22, 2005.
Author
Projec Leader: Vijay Vittal, Arizona State
Date
6/14/2016
Size
1.60 MB
Type
Document
Projec Leader: Vijay Vittal, Arizona State 6/14/2016 1.60 MB Document
Control and Design of Microgrid Components (T-18)
Description
Penetration of distributed generation across the US has not yet reached significant levels. However, that situation is changing rapidly and requires attention to issues related to high penetration of distributed generation within the distribution system. Indiscriminant application of individual distributed generators can cause as many problems as it may solve. A better way to realize the emerging potential of distributed generation is to take a system approach which views generation and associated loads as a subsystem or a "microgrid". This approach allows for local control of distributed generation thereby reducing or eliminating the need for central dispatch. During disturbances, the generation and corresponding loads can separate from the distribution system to isolate the microgrid's load from the disturbance (and thereby maintaining high level of service) without harming the transmission grid's integrity. Intentional islanding of generation and loads has the potential to provide a higher local reliability than that provided by the power system as a whole. The size of emerging generation technologies permits generators to be placed optimally in relation to heat loads allow for use of waste heat.
Such applications can more than double the overall efficiencies of the systems. Most current microgrid implementations combine loads with sources, allow for intentional islanding, and try to use the available waste heat. These solutions rely on complex communication and control, and are dependent on key components and require extensive site engineering. The objective of this work is to provide these features without a complex control system requiring detailed engineering for each application. Our approach is to provide generator-based controls that enable a plug-and-play model without communication or custom engineering for each site.

Final report for PSERC project "Microgrid Protection and Control" (T-18). Uploaded: January 22, 2006.
Author
Project Leader: Robert Lasseter, Univ. of WI-Madison
Date
7/7/2016
Size
3.94 MB
Type
Document
Project Leader: Robert Lasseter, Univ. of WI-Madison 7/7/2016 3.94 MB Document
Automated Integration of Condition Monitoring with an Optimized Maintenance Scheduler for Circuit Breakers and Power Transformers (T-19 Report)
Description
The effectiveness of expending maintenance resources can vary dramatically depending on the target and timing of the maintenance activities. In this research project, we developed a comprehensive and cost-effective system-wide maintenance allocation and scheduling system based on automated integration of condition monitoring with an RCM-based optimized scheduler. The maintenance allocation and scheduling system can reduce maintenance costs while increasing equipment reliability.
It can also (1) extend equipment life; (2) cut costs for substation design, refurbishment and construction; and (3) ensure high levels of health and safety for operation and maintenance personnel, the public, and the environment. The research focused on transformer and circuit breaker maintenance, but the system is expandable to other equipment. We focused on circuit breakers and transformers because (1) expenditures for maintenance of this equipment represent a large percentage of maintenance budgets; (2) failures adversely affect system reliability; and (3) monitoring technologies presently exist within substations.

Final report for PSERC project "Automated Integration of Condition Monitoring with an Optimized Maintenance Scheduler for Circuit Breakers and Power Transformers" (T-19). Uploaded: February 10, 2006. Revised: May 2, 2006.
Author
Project Leader: Jim McCalley, Iowa State
Date
7/7/2016
Size
1.78 MB
Type
Document
Project Leader: Jim McCalley, Iowa State 7/7/2016 1.78 MB Document
Executive Forum on Solutions to Transmission Investment
Description
PSERC Executive Forum, April 21, 2006, in Chicago, IL. This Forum provided an opportunity for senior managers and PSERC experts to identify critical challenges and possible solutions to (1) transmission investment and pricing issues, and (2) issues related to enhancing grid reliability. The report summarizes participant ideas on the challenges to be overcome and the solutions for doing so.

PSERC Executive Forum on Solutions to Transmission Investment: Participant Ideas on Challenges, Solutions, and Steps to Improving and Expanding the Electric Transmission Grid, Chicago, IL, April 21, 2006.
Author
PSERC Executive Forum
Date
7/7/2016
Size
126.03 KB
Type
Document
PSERC Executive Forum 7/7/2016 126.03 KB Document
Consequences of Fault Currents Contributed by Distributed Generation (S-20 Supplemental Report)
Description
New generation capacity from distributed generation (DG) is growing in the over-all generation mix due in part to state and national initiatives to address global-warming concerns. Of concern in power system design and operation are the implications of high penetration of DG on fault currents and protection system coordination. Installation of DGs in the distribution system increases the fault current throughout the system. De-pending on the penetration level, locations, and type of DGs, the protection system may lose coordination with high numbers of DG units when the protection system is designed with conventional techniques. Circuit breaker capabilities and settings of protective re-lays that were previously designed for a system without DGs may not safely and appro-priately coordinate to manage faults in a system with DGs. And accurate fault analysis in systems with inverter-based generation may not be possible with conventional fault analysis tools and techniques. At low inverter-based DG penetration levels (e.g., below five percent of system capacity), conventional protection analysis methods may be quite adequate. However, at high penetration levels (e.g., ten percent or higher), new methods may be necessary. This report addresses those issues.

Supplemental report to PSERC project "New Implications of Power System Fault Current Limits" (S-20). Uploaded: June 16, 2006.
Author
Project Leader: Gerald Heydt, Arizona State
Date
6/15/2016
Size
2.42 MB
Type
Document
Project Leader: Gerald Heydt, Arizona State 6/15/2016 2.42 MB Document
Performance Assessment of Advanced Digital Measurement and Protection Systems: Part 2 (T-22 Report)
Description
Recently, optical voltage and current transducers, often called Optical Voltage Transformers (OVTs) and Optical Current Transformers (OCTs) respectively, have become readily available. The signals from OCTs and OVTs can be communicated to a control room through fiber optic cables. In the control room, the signals may supply a digital device, such as a relay, an energy metering system, or a power quality meter. This all-digital system may be more advantageous than conventional systems that use magnetic Current Transformers (CTs) and Potential Transformers (PTs). PTs include both Voltage Transformers and Coupling Capacitor Voltage Transformers. The optical transformers may provide improved transient response (due to a wider frequency band), improved dynamic range, and higher accuracy. This research project has sought to explore and quantify the advantages of an integrated measurement and protection system using OCTs and OVTs over a traditional system that uses conventional magnetic CTs and PTs.

Part 2 of the Final report for PSERC project "Performance Assessment of Advanced Digital Measurement and Protection Systems" (T-22). Uploaded: July 3, 2006.
Author
Project Leader: Mladen Kezunovic, TAMU
Date
7/7/2016
Size
1.08 MB
Type
Document
Project Leader: Mladen Kezunovic, TAMU 7/7/2016 1.08 MB Document
Performance Assessment of Advanced Digital Measurement and Protection Systems: Part 1 (T-22 Report)
Description
The suggested advantages of optical systems over traditional magnetic systems include improved safety, smaller size, immunity from electromagnetic interferences, better transient response (wider frequency band), a broader dynamic range, and higher accuracy. It is expected that the optical and digital system will provide advantages in relaying and metering applications. The wider frequency band and improved dynamic performance should make the relaying applications less prone to misoperation as a result of transformer saturation or input signal distortions. The higher accuracy should result in more reliable revenue metering. The wider frequency bandwidth should also improve accuracy of harmonic monitoring, which would enable improved assessment of power quality. The immunity from electromagnetic disturbances should increase reliability.
These suggested benefits of optical instrument transformers motivated a systematic quantitative comparison of an integrated measurement and protection system based on optical CTs and PTs with a system using magnetic CTs and PTs in this research project. At Arizona State University, a high-current generator was developed to produce up to 1,200 A. It was used in the High-Voltage Laboratory for laboratory comparison of instrument transformer performance. Field testing using installed conventional and optical CTs and PTs for protection and metering was done at AEP's Corridor substation. The instrument transformer outputs were observed and recorded by a Tesla event recorder. In general, the results show that the performance of the optical instrument transformers is quite comparable to the magnetic instrument transformers. Differences found in the field and laboratory measurements were within acceptable levels of the test and data acquisition equipment used.

This is Part 1 of the Final report for PSERC project "Performance Assessment of Advanced Digital Measurement and Protection Systems" (T-22). Uploaded: August 24, 2006.
Author
Project Leader: George Karady, Arizona State
Date
7/7/2016
Size
4.49 MB
Type
Document
Project Leader: George Karady, Arizona State 7/7/2016 4.49 MB Document
Risk-Based Resource Allocation for Distribution System Maintenance (T-24 Report)
Description
In this project, we have developed a comprehensive and cost-effective maintenance allocation and scheduling system, and have implemented it in software tools. These tools assist in answering three concerns commonly faced by an asset manager:
* How to identify and justify the resources needed for managing the assets of the entire system.
* How to allocate the available resources to different maintenance programs.
* How to select a set of maintenance tasks to be performed within each maintenance program.
Our system allocates resources and schedules maintenance tasks to optimize system reliability by maximizing risk-reduction achieved from those tasks. It uses information obtained from inspection and monitoring to determine the state of the system. Available maintenance tasks are identified, and the risk reduction provided by each is computed. The risk reduction for each task is based on the condition of the component being serviced, the task's effect on improving the component's condition of equipment, and the resulting improvement in reliability indices. The tasks are prioritized, subject to constraints on available resources, using an optimization technique combining integer programming, Lagrange relaxation, and dynamic programming.

Final report for PSERC project "Risk-Based Resource Allocation for Distribution System Maintenance Reliability Enhancement" (T-24). Uploaded: September 1, 2006.
Author
Project Leader: Ward Jewell, Wichita State
Date
7/7/2016
Size
1.37 MB
Type
Document
Project Leader: Ward Jewell, Wichita State 7/7/2016 1.37 MB Document
A Novel Approach for Prioritizing Maintenance of Underground Cables (T-23 Report)
Description
Distribution businesses serving urban areas are increasingly using underground cable for distributing power to their customers. Extruded cross linked polyethylene (XLPE) insulated cables are employed extensively in the industry. Premature failure of these cables can occur due to aging from exposure to multiple stresses, such as electrical, heat, and chemicals (water). Furthermore, degraded cables are more susceptible to failure during "dig-ins". To help distribution businesses save on maintenance costs while maintaining reliable service, in this study we have developed a method for assessing cable condition so that cable replacement need only occur when the cable approaches the end of its useful life.
For this study we characterized the extent of cable degradation occurring in 15kV cross linked polyethylene (XLPE) insulated distribution cables in hot and dry climates. The extent of degradation was quantified using two parameters: the area of Fourier Transform Infra Red (FTIR) spectrum and the electrical breakdown strength using needle plane geometry. Degradation occurring in a hot and dry climate can be reproduced in a laboratory by accelerated thermal aging testing. The Arrhenius equation for the temperature dependence of a chemical reaction rate was used to establish the accelerated aging test parameters. Using the FTIR technique, we demonstrated that the reduction of the CH2 bond yielded a good correlation with reduction in electrical performance after accelerated aging. Hence, the reduction of the bond can be used to assess the condition of field aged cables.

Final report for PSERC project "A Novel Approach for Prioritizing Maintenance of Underground Cables" (T-23). Uploaded: October 23, 2006.
Author
Project Leader: Ravi Gorur, Arizona State
Date
7/7/2016
Size
660.74 KB
Type
Document
Project Leader: Ravi Gorur, Arizona State 7/7/2016 660.74 KB Document
Prediction of Flashover Voltage of Insulators Using Low Voltage Surface Resistance Measurement (T-26G Report)
Description
Failures of high voltage insulators on transmission lines can lead to transmission line outages, thereby reducing system reliability. One form of insulator failure is flashover, the unintended disruptive electric discharge over or around the insulator. Contamination on the surface of the insulators, such as from salts for de-icing streets and sidewalks, enhances the chances of flashover. Currently there are no standardized tests for understanding the contamination flashover performance of polymeric insulators. This research project developed models by which the flashover voltage can be predicted and flashover dynamics explained for contaminated polymeric insulators. The model developed can be applied to contaminates such as sea salt, road salt, and industrial pollution found in many locations. The results from this work are useful for selecting the appropriate insulator design (including dimensions and material) for different system voltages. This work finds applications in distribution class insulators and can be extended to higher voltage classes. An important next step in this line of research is the development of a low voltage tool for measuring surface resistance. That this is the next step resulted from this research demonstrating the validity of assessing insulator performance by measuring surface resistance for ceramic and non-ceramic insulators.

Final report for PSERC project "Prediction of Flashover Voltage of Insulators Using Low Voltage Surface Resistance Measurement" (T-26G). Uploaded: November 15, 2006.
Author
Project Leader: Ravi Gorur, Arizona State
Date
7/7/2016
Size
445.20 KB
Type
Document
Project Leader: Ravi Gorur, Arizona State 7/7/2016 445.20 KB Document
Enhanced State Estimators (S-22 Report)
Description
Power system operators need to be confident in the results from state estimators before they will use the information for making critical decisions. Our research sought to understand challenges for achieving that confidence, and to propose and assess possible state estimator enhancements to address those challenges. The enhancements from this research address challenges of:
    1. efficient detection and identification of network parameter errors (that is, errors in representing the electrical characteristics of the underlying transmission system);
    2. efficient state estimation in multi-area, regional systems;
    3. effective placement of phasor measurement units to improve confidence in state estimator results; and
    4. modeling assumptions about the physical electric power system that introduce inaccuracies and computational problems in state estimation.
These challenges are becoming more relevant as grid and market operation responsibilities expand to cover much greater geographic areas than experienced in the industry's history. At the same time, grids are becoming more congested with rapidly changing power flow patterns responding to market conditions. The research project final report has four parts covering the proposed and tested state estimator enhancements.

Final report for PSERC project "Enhanced State Estimators" (S-22). Uploaded: November 28, 2006.
Intermediate Project Report was uploaded on April 2005.
Author
Project Leader: Ali Abur, Northeastern Univ.
Date
6/15/2016
Size
1.71 MB
Type
Document
Project Leader: Ali Abur, Northeastern Univ. 6/15/2016 1.71 MB Document

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