Modeling of a Radial Distribution Feeder with TCC-based Protective Devices

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1 1 Modeling of a Radial Distribution Feeder with TCC-based Protective Devices Jun Li, Student Member, IEEE, Karen L. Butler-Purry, Senior Member, IEEE, Carl Benner, Member, IEEE, B. Don Russell, Fellow, IEEE Abstract Accurate fault location is crucial to reduce outage time, operating cost and customer complaints. In order to accurately locate faults, the Power System Automation Lab (PSAL) at Texas A & M University has developed three modules to locate faults in radial distribution systems. In order to verify the validity of the three modules, fault current and voltage data are needed. Also system information such as equipment parameters, protective device settings and phase distribution of line sections must be known. Since this information is not publicly available from a real system, the authors simulated a radial distribution feeder with protective devices to generate the necessary data. This paper proposes a method to model a distribution feeder with TCC-based (Time Current Characteristic) protective devices. SIMULINK and SimPowerSystems (SPS) toolbox of MATLAB were used to model the system. The problems encountered during simulation and the solutions are discussed. A method to simulate different fault cases at different fault locations in a batch mode is also presented. Also several cases are performed to illustrate the method. Index Terms Fuses, Circuit Breakers, Relays, Modeling, Power Distribution Feeder. E I. INTRODUCTION LECTRICAL power distribution systems are that portion of electrical systems that connects customers to the source of bulk power (such as distribution substation). Radial distribution systems are characterized by having only one path for power to flow from the source to each customer. A typical distribution system consists of several substations which each includes one or more feeders. A three-phase primary feeder extends away from a substation, and there are many lateral feeders (three-phase, two-phase or single-phase) extending away from the primary feeder. There are loads, transformers, shunt capacitor banks, and protective devices in a distribution feeder. There are a large number of components in distribution systems and these components age over time. Further most distribution systems are overhead systems, which are easily affected by weather, animals, etc. These two reasons make faults in distribution systems inevitable. To reduce operating cost and outage time, fast and accurate fault location is necessary. Compared with transmission systems, distribution systems Karen L. Butler-Purry, Carl Benner and Jun Li are with the Department of Electrical Engineering, Texas A & M University, College Station, TX USA ( klbutler@ee.tamu.edu, benner@ee.tamu.edu, junli@ee.tamu.edu). have some unique characteristics: unbalanced loads, nonhomogeneity of lines, and frequent switching operations. Because of these characteristics, it is difficult to apply the fault location approaches developed for transmission systems to distribution systems. There are methods to locate faults in a distribution system based on impedance calculation [1-3], relay and CB operations [4-7], and knowledge-based techniques [8-9]. These methods only use one criterion to identify the possible fault location. Hence the accuracy of these methods is limited. A paper [10] proposed a method to locate faults according to fault distance calculations, and to prune down and rank several possible fault locations by integrating the information about protective device operations. The process of deciding the operated protective device was through observations and was not implemented automatically by a program. The method used probabilistic modeling method to deal with the uncertainties of fault location calculation, but it did not take into account of the uncertainty in the process of deciding the operated protective device. Fuzzy logic is a good tool to deal with the uncertainty and the inexactness. The Power System Automation Laboratory (PSAL) at Texas A&M University developed a fuzzy logicbased new approach to locate faults. The new approach locates faults according to fault currents and voltages recorded in substations. It consists of three modules [11-12]; each of them uses a different criterion to locate a fault. These three modules each assign a possibility value to each line section of a feeder respectively. These possibility values represent the possibility of a line section having a fault. To develop an aggregation method to aggregate the three modules outputs and verify the validity of these modules, a distribution system where all line parameters, phase distribution of line sections and protective settings are known is needed. Because this information is not publicly available from a real system, modeling a system with coordinated protective devices is a choice. The authors developed a model of a radial distribution feeder with protective devices based on IEEE 34 node test feeder [13] by using SIMULINK and SimPowerSystems toolbox of MATLAB [14-16], which provides a tool to simulate power systems. Section II will introduce background knowledge about protective devices used in power distribution systems. Section III will show the principles of protective device coordination. Section IV will present the modeling method of a distribution feeder with protective devices. Section V will discuss the problems encountered during simulations and the solutions.

2 2 Section VI will present the method to simulate several fault cases in a batch mode. Section VII will give two simple examples to illustrate the modeling method. Section VIII will give conclusions. II. BACKGROUND Protective devices are used in distribution systems to minimize the duration of a fault and isolate the affected areas of a fault. Commonly used protective devices in distribution systems are fuses, reclosers, and circuit breakers, which are usually controlled by relays. Their function will be discussed separately. A. Fuses Fuses are overcurrent protective devices and can operate only once. They use a metallic element that melts when overload current passes through them. The metallic element must be replaced before a fuse can be used again. A fuse is designed to blow within a specific time for a given value of overcurrent. It has two TCC curves: the minimum-melt (MM) curve and the total-clearing (TC) curve. MM curve represents the relationship between the overcurrent value and the minimum time needed to melt the fuse; TC curve is the relationship between the overcurrent value and the maximum time to melt the fuse. The advantage of fuses is their low cost. It only needs a small investment to install them. The disadvantage is that they are one-time operating devices. When a fault happens, even a temporary fault, they will blow and interrupt power supply. However, most faults (80-95%) on distribution and transmission lines are temporary faults [17]. Using too many fuses will jeopardize the continuity of power supply, hence reclosing devices like reclosers are used. B. Circuit breaker (CB)/ relay combination Usually CBs operation are controlled by relays and their characteristics are determined by overcurrent relays and reclosing relays. Overcurrent relays have two types: instantaneous trip relays, which operate instantaneously when currents are larger than the setting, and inverse time relays, which have inverse, very inverse, or extremely inverse timecurrent characteristics. Generally the relay used to open CBs is the second type [17]. CBs can operate once or reclose several times. C. Reclosers Reclosers are overcurrent devices that automatically trip and reclose a preset number of times to clear temporary faults and isolate permanent faults. Reclosers also have two types of TCC curves: instantaneous curve (also called fast curve) and time-delay curve (also called slow curve). The operation sequence of reclosers can vary. The sequence can be two instantaneous operations followed by two time-delay operations (2F+2S), one instantaneous operation plus three time-delay operations (1F+3S), one instantaneous operation and two time-delay operations (1F+2S), etc. Usually the number of operations is set at three or four (up to five times is typical) [17]. The advantage of reclosers is that they clear temporary faults before they lock out. This improves the continuity of power supply significantly. The shortcoming of reclsosers is they are more costly than fuses. III. COORDINATION One of the fault location modules developed at Texas A&M compares the overcurrent value and fault time duration with protective devices TCC curves to decide which device operates in response to a fault. The assumption of this method is that protective devices are coordinated correctly. The purpose of the simulation done by the authors is to generate the data to test these three modules so that the simulated feeder should include the correctly coordinated protective devices. The protective devices used in the distribution feeder model are fuses, reclosers and CBs. The coordination between them will be discussed. A. Fuses protecting reclosers There are two different situations when a fuse is used to protect a recloser [18-19]. One is the recloser clearing temporary faults and the fuse clearing permanent faults. The other one is the fuse clearing both temporary and permanent faults. Obviously the first one is better, because it reduces the outage rate of the distribution circuit and saves the time to exchange fuses. But when a lateral carrying a rather small current goes away from the primary feeder with a rather large current, the first kind of coordination is unrealistic. Then the second coordination method is needed. Two kinds of coordination are shown in figure 1. For the first situation shown in the left graph of figure 1, the correct coordination is achieved if the minimum fault current is larger than the intersection of the recloser s slow curve and the fuse s TC curve, and the maximum fault current is less than the intersection of the fuse s MM curve and the recloser s fast curve. For the second situation shown in the right graph of figure 2, the correct coordination is that the fuse s TC curve is always below the recloser s fast curve, which means the fuse always operates faster than the recloser. To achieve the correct coordination, factors such as preloading, ambient temperature, accumulated heating and cooling of the fuse should be taken into account. Fig. 1. Fuses protecting reclosers

3 3 B. Fuses protecting fuses Because fuses are much cheaper than reclosers, some distribution systems use a large fuse (protected fuse) as the backup device of a small fuse (protecting fuse), instead of using a recloser. These two fuses should be coordinated appropriately, so that the outage areas would be as small as possible. To ensure these two fuses are coordinated correctly, the protecting fuse s TC curve should always be located lower than the protected fuse s MM curve during the fault current range [18]. To eliminate the effect of load current, ambient temperature, etc., usually an adjustment factor of 75% is used on the protected fuse. Correctly coordinated fuses curves are shown in figure 2. C. Reclosers protecting fuses Usually this kind of coordination is used at substation transformer primary side and secondary side. The fuse provides protection for the transformer against a fault in the transformer or at the transformer terminals and also provides backup protection for the recloser. The recloser should clear all kinds of downstream faults (temporary & permanent), and the fuse only protects the transformer [18]. The correct coordination is that the recloser s slow curve should be below the fuse MM curve. There is also an adjustment factor depending on the number of fast and slow trips and the reclosing time of the recloser. Figure 3 gives an example of this kind of coordination. Fig. 2. Fuses protecting fuses D. Reclosers protecting reclosers While downstream smaller reclosers protect upstream larger reclosers, the correct coordination is achieved by the requirement: the maximum fault current is less than the intersection of the upstream slow curve and the downstream slow curve plus several cycles (usually 12 cycles) [18-19]. This requirement is illustrated in figure 4. E. Coordination between fuses and CBs The coordination between a fuse and a CB (overcurrent relay) is somewhat similar to the coordination between a fuse and a recloser. The main difference is that the reclosing time of CBs is larger than that of reclosers, so that there is no need for heating and cooling adjustments. When the fuse is used as the protecting device, the coordination is achieved if the relay operating time is 150 percent of the total clearing time of the fuse. When the fuse is used as the protected device, the coordination is achieved if the minimum melting time of the fuse is 135 percent of the combined time of the CB and related relays [17]. Fig. 3. Reclosers protecting fuses F. Coordination between reclosers and CBs Fig. 4. Reclosers protecting reclosers A CB is the backup protective device of a recloser. The CB s TCCs should be higher than those of the recloser. A crucial factor to achieve the coordination is the reset time of overcurrent relays during the tripping and reclosing sequence. The coordination must ensure the relay cannot accumulate enough movement in the trip direction during recloser successive operations to trigger a false tripping. IV. MODELING THE MODIFIED IEEE-34 NODE FEEDER WITH TCC-BASED PROTECTIVE DEVICES MATLAB6.5 includes the SimPowerSystem (SPS) toolbox, which has many power system element models (e.g. line model, transformer model, etc.) and is fit for simulating power systems. The IEEE distribution system analysis subcommittee developed some radial test feeders that can be used to test the correctness of power system analysis programs [20]. However, the authors modeled a distribution feeder to generate fault currents, fault voltages, and protective device operating information. Hence the IEEE 34 node feeder was modified slightly to ease the modeling. A. Feeder model The transmission or subtransmission system that connects a substation transformer s primary side is treated as an ideal voltage source. The author used 3-phase voltage source to model both the transmission (or subtransmission) system and the substation transformer. The voltage magnitude was equal to the transformer s secondary side voltage; the source internal impedance was chosen as the substation transformer impedance. There are two transformers in the IEEE 34 node feeder model. The one in the substation was incorporated into the source. The other one was modeled using two-winding three-phase transformer model. One half of the transformer impedance was put on the primary side; the other half was put on the secondary side. The distributed line models were used to model most of the primary feeder and laterals except short lines. For short lines, the propagation time was negligible; the lumped PI models were used to model them. The definition of a short line depends on the simulation step. For example,

4 4 when the simulation step is 25µs, the lines with the propagation time less than 25µs (shorter than ,000=7.5km) were treated as short lines. However, not all short lines are modeling using PI models. When a short line connected a switch, a T model was used instead of a PI model (the reason is explained later in section V). Shunt capacitor banks appearing in the feeder model are given by their capacity. Three single-phase capacitors were connected to form a star-connected capacitor bank. The value of these capacitors was calculated according to their capacities and rated voltage. There were three types of spot loads in the feeder model: constant PQ load, constant impedance load, and constant current load. Because the different types of loads express different characteristics during the steady state, their response during a fault may be different from their steady state characteristics. However, the purpose of the modeling was to generate fault current and voltages waveforms. Furthermore, only a constant impedance load model is available in SPS. Hence the authors modeled all loads as constant impedance loads. Like sport loads, there are three kinds of distributed loads. All distributed loads are treated as constant impedance load. A distributed load modeling is another issue. The exact lumped load model described in [21] was used to model distributed loads. In the exact lumped load model, 2/3 of a distributed load was put at the ¼ length of the line and the other 1/3 of the distributed load was put at the end of the line. This exact lumped line model will give correct computation results for the voltage drop and the power loss down the line. B. Protective devices model There is only one switch model in SPS (i.e. circuit breaker model) and it operates at a specific time or is controlled by an external signal. However the feeder model has many coordinated protective devices that operate according to their TCCs. To model different protective devices using the switch model in SPS, control logic modeling the operations of these protective devices was implemented. This logic determines the open time of a protective device according to its TCC curve and to sends the open signal to the switch that opens the circuit. If the protective device is a reclosing device, the control logic also sends the closing signal to the switch when the reclosing time is achieved. The authors developed two kinds of control logic. One was the single-phase control logic, which was used to simulate fuses and single-phase reclosers. The other one was the threephase control logic, which was for simulating three-phase reclosers. The details of the implementation of the control logic were presented in [22]. The structure of protective devices is shown in figure 5. In the figure, I in is a current passing through a protective device. To simulate TCC-based protective devices, the control logic to determine the control signal status is the key element. The TCC curves for all devices used in the feeder are stored in the control logic. I in Control Logic Switch I out Fig. 5. The structure of the protective device Figure 6 shows the structure of the control logic block shown in figure 5. It consists of six blocks: filter, A/D converter, Magnitude/Angle computation, comparator, RMS calculation and control signal determination. For each type of protective device, all blocks are the same except the control signal determination block. I in Filter A/D Converter Calculation of RMS Current Control Signal Determination Fig. 6. The structure of control logic Magnitude/ Angle Computation Indicator Comparator The IEEE 34-bus test feeder [23] was modeled using this modeling method. Reclosers were chosen to protect most parts of the primary feeder. Fuses were selected to protect all laterals except the lateral with the transformer. Using short circuit analysis, the minimum and maximum fault currents at each section were determined. Further, using load flow, the normal currents at each section were determined. Based on the normal and fault currents, the appropriate sizes of protective devices were chosen. A diagram of the feeder with protective devices is shown in figure 7. Table I shows the protective devices used in the model, their type, protected sections and the section numbers. V. SIMULATION ISSUES AND SOLUTIONS A. Simulation speed issues Originally the authors used the distributed line model to model all line sections in the distribution feeder but the simulation speed was very slow. The reason is MATLAB chooses the maximum simulation time step smaller than the propagation time of the shortest line in the system in order to get the accurate simulation result. Because the shortest line in the modeled system was very short (about 0.78km), assuming an aerial line with a 300,000 km/s propagation speed, the propagation time was 2.6 µs. The simulation time step would be less than 2.6µs to get accurate result. To increase the

5 5 simulation speed, the authors changed the distributed line model to the PI model for short lines. The other reason for the slow speed was the modeled feeder had more than 400 states and more than 40 switches (non-linear elements). The continuous algorithm was originally chosen to do the simulation. The algorithm tries to get the best precision on every state, which slows down the simulation speed. Hence, the algorithm should only be used for small systems where extremely accuracy is needed. The solution was to discretize the system using a fixed step trapezoidal integration. To do that, a powergui model that provides graphical user interface (GUI) tools for the analysis of SPS models was put in the IEEE 34 node feeder model. The powergui model can digitize an electrical system by choosing the appropriate item. B. Numerical oscillation By using the PI model, the simulation speed problem was solved but another problem arose. There was a numerical oscillation in the currents of the switches that connected between two PI model line sections. The reason was that when the switch was closed, there were two capacitors in parallel through a small breaker resistance (typically 0.01 ohm) so that the two states (capacitors voltages) were almost the same. If they were exactly same, it was impossible to formulate the state equations. For the situation where a low resistance connected two PI models, it was possible to formulate state equations, but there would be a numerical oscillation in the currents passing through the switches. To solve the problem, PI models were changed to T models when a line was connected to a switch. VI. BATCH PROCESSING OF FAULT SIMULATION As mentioned before, this modeling method was used to model a distribution feeder with protective devices and generate fault currents and voltages. It needed a long time to simulate one fault case (about 15 minutes) and there were more than 200 cases to be simulated. If the simulation process cannot be implemented in a batch mode, a person is needed to set the fault type, the fault location, and restart the simulation case-by-case, which is a time-consuming task. Fortunately, SIMULINK provides commands to control a simulation. By using these commands, the authors developed a program to run a batch of simulations. This program simulated different kinds of faults at several fault locations. The procedure of the program is shown in figure 8. First the simulated model was opened using the command open_system. Second both the start time and the stop time of simulations were set by the command set_param. Third a list of fault locations and fault types were read. Next a status was checked to determine if all fault locations had been simulated. If all locations had been performed, the model was saved and closed by the commands save_system and close_system. Otherwise, the lines connecting the fault model with the previous fault location were deleted using the command delete_line, and the lines connecting the fault model with the new fault location were added using the command add_line. Thereafter, a status was checked to decide if all fault types had been simulated for the fault location. If all were performed, the fault location was changed to the next one. Otherwise, the fault type was changed, and a new type fault simulation was started. Then, the simulation status was checked using the command get_param to see if the previous simulation was finished. If it was running, the simulation status kept being checked. Fig. 7. IEEE 34-bus distribution feeder with protective devices VII. CASE STUDY After including the appropriate protective devices, setting their parameters in the IEEE 34-bus test feeder, and modeling the feeder, the authors performed several short circuit cases to verify the accuracy of the modeling method. A few cases are illustrated in this section.

6 6 Start Input a model's name Open the model Set the start time and the stop time of a simulation In figure 9, F6T control signal output for each phase and F15T_T0.8 control signal output for each phase (a control signal output equal to zero means the protective device is open) are shown. From this figure, it is seen that phase A of F6T opens at about 0.24s and F15T_T0.8 remains closed. The fault duration is equal to 0.073s. From the current value passing through F6T in figure 10, it is observed that the phase A current s peak value is about 200A. The RMS value of the current is about 141A. From the MM curve of F6T, the operation time is 0.073s. This agreement confirms the proper operation and coordination of these two protective devices. Input a list of fault locations and fault types Change the fault location All fault locations have been simulated? No Delete the lines connecting the fault model with the previous fault location, and then add the lines connecting it with the present fault location Yes Save the model and close it End Fig. 9. The control signal outputs of F6T and F15T_T0.8 Yes All fault types have been simulated? No Change fault type Yes Start a simulation No No The simulation is stopped? Fig. 8. The procedure of a batch of simulation A. Phase A to ground fault at node 840 A phase A-to-ground fault was staged on section 13 at 0.167s. This section was protected by F6T, and F15T_T0.8 was the backup protective device. According to the coordination principles, F6T should burn before F15T_T0.8 is damaged if faults are at section 13. Fig. 10. The currents flowing through F6T and F15T_T0.8 B. Phase AB fault at node 836 A phase A-to-B fault was staged on section 12 at 0.167s. F15T_T0.8 protected this section and R35H_T3 was the backup protective device. The reclosing operation sequence setting of R35H_T3 was [FFSS], which meant it opened on fast curve twice and then on slow curve twice. The reclosing time setting of the recloser was [1 1 1]. Based on the coordination, the recloser should open before the fuse to clear the temporary fault if faults are in section 12. Only after the recloser s two fast operations, the fuse will burn. Since the recloser is a three-phase device, it only has one control signal

7 7 output. The control signal outputs of the fuses and of the recloser are shown in figure11. Form this figure it is seen that R35H_T3 will operate twice before F15T_T0.8 burns. The open interval between the two fast operations is 1s, which is the same as the recloser s setting. The fault current s peak value is about 230A, which is shown in figure 12, and the RMS value is about A. The fault duration is about 17 cycles (about 0.283s). Based on the recloser s fast curve, the recloser s operating time should be 0.282s when the current value is equal to A. The fuse opened after the fault occurred about 17.5 cycles (0.458s), and the operating time should be 0.457s according to its TCC curve. This example shows the protective devices operate correctly according to their TCC curves and their operating sequence satisfies the coordination requirement. Fig. 11. The currents flowing through F15T_T0.8 and R35H_T3 Fig. 12. The currents flowing through F15T_T0.8 and R35H_T3 VIII. CONCLUSION To verify fault location modules developed at Texas A&M, a distribution feeder was modeled to generate data such as fault currents, voltages, equipment parameters, protective device settings and phase distribution of line sections. A modeling method for a distribution feeder with TCCbased protective devices has been introduced. The problems encountered during the simulation and the solutions were discussed. A method to simulate fault cases in a batch mode was also presented. The IEEE 34-bus test feeder modified to include protective devices was simulated and tested. Two cases were presented to illustrate the modeling method was accurate. IX. REFERENCES [1] M. Lehtonen, S. Pettissalo, J. Etula, Calculational fault location for electrical distribution networks, Third International Conference on Power System Monitoring and Control, Jun 1991, pp [2] R. Das, M. S. Sachdev, T. S. Sidhu, A technique for estimating locations of shunt faults on distribution lines, IEEE WESCANEX 95 proceedings, Vol. 1, May 1995, pp [3] Girgis, A.A, Fallon, and C.M, Lubkeman, D.L., A fault location technique for rural distribution feeders, IEEE Trans. on Industry Applications, Vol. 29, NO. 6, Nov. - Dec. 1993, pp [4] H. T. Yang, W. Y. Chang, C. L. Huang, A new neural network approach to on-line fault section estimation using information of protection relays and circuit breakers, IEEE Trans. on Power Delivery, Vol. 9, NO. 1, Jan. 1994, pp [5] F. Elckhoff, E. Handschin, W. Hoffmann, Knowledge based alarm handling and fault location in distribution networks,, IEEE Trans. on Power Systems, Vol. 7, NO. 2, May 1992, pp [6] C. Y. Teo, Automation of knowledge acquisition and representation for fault diagnosis in power distribution networks, Electrical Power Systems Research, NO. 27, 1993, pp [7] T. Genji, M. Shimamoto, K. Kishida, Development of a high-speed switching system for distribution network, IEEE Trans. on Power Delivery, Vol. 13, NO. 1, Jan. 1998, pp [8] A. A. Girgis, M. B. Johns, A Hybrid Expert System for Faulted Section Identification, Fault Type Classification and Selection of Fault Location Algorithms, IEEE Trans. on Power Delivery, Vol. 4, NO. 2, April 1989, pp [9] Yuan-Yih Hsu, F. C. Lu, Y. Chien, J. P. Liu, J. T. Lin, H. S. Yu, R. T. Kuo, An Expert System for Locating Distribution System Faults, IEEE Trans. on Power Delivery, Vol. 6, NO. 1, Jan. 1991, pp [10] Jun Zhu, David L. Lubkeman, Adly A. Girgis, Automated Fault Location and Diagnosis on Electric Power Distribution Feeders, IEEE Trans. on Power Delivery, Vol. 12, NO. 2, April 1997, pp [11] K.S. Andoh, A fault location approach for fuzzy fault section estimation on radial distribution feeders, Masters thesis, Dept. of Electr. Eng., Texas A&M Univ., College Station, [12] K.M. Manivannan, Fuzzy logic based operated device identification in power distribution systems, Masters thesis, Dept. of Electr. Eng., Texas A&M Univ. College Station, [13] IEEE 34-bus test feeder. Available: [14] Using MATLAB (version 6), The MathWorks Inc., Nov [15] Using SIMULINK (version 4), The MathWorks Inc., Nov [16] Writing S-Function (version 6), The MathWorks Inc., Nov [17] Luces M. Faulkenberry, Walter Coffer, Electrical Power Distribution and Transmission, Prentice Hall, [18] Turan Gonen, Electric Power Distribution System Engineering, New York: McGraw-Hill, 1986 [19] WindMil Users Guide (version 5.0), Milsoft Integrated Solutions, Inc., 2001 [20] Distribution System Analysis Subcommittee Report, Radial Distribution Test Feeders, Proceedings of 2001 PES winter meeting, Vol. 2, 2001, pp [21] William H. Kersting, Distribution system modeling and analysis, CRC press, July [22] Jun Li, Karen L. Butler-Purry, Carl Benner, Modeling of TCC-based protective devices, Proceeding of 2003 T&D conference, September, X. BIOGRAPHIES Jun Li (S 01) received the B.S. and M.S. degrees from Xi an Jiaotong University, Xi an, China, in 1993 and 1996, respectively. He is currently working towards a Ph.D. degree in the Electrical Engineering Department at Texas A&M University, College Station.

8 8 Karen L. Butler-Purry (M 90 SM 01) is an associate professor in the department of electrical engineering at Texas A&M University. In , Dr. Butler-Purry was a Member of Technical Staff at Hughes Aircraft Co. in Culver City, California. Her research focuses on the areas of computer and intelligent systems applications in power, power distribution automation, and modeling and simulation of power systems and vehicles. Dr. Butler-Purry is a senior member of IEEE and IEEE Power Engineering Society (PES), and a member of the Louisiana Engineering Society. She is a registered professional engineer in the states of Louisiana, Texas, and Mississippi. Carl L. Benner (S 84 M 86) received the B.S. and M.S. degrees from Texas A&M University, College Station, TX, in 1986 and 1988, respectively. Since 1988, he has managed the Power System Automation Laboratory, Department of Electrical Engineering at Texas A&M University. His research interests include a wide variety of intelligent digital monitoring, control, and protection applications for power systems. Much of his work has focused on the detection of high-impedance faults, an area in which he holds several patents. Mr. Benner is a member of the IEEE Power Engineering Society and a Registered Professional Engineer in the State of Texas. B. Don Russell (F 92) received the B.Sc. and M.E. degrees in electrical engineering from Texas A&M University, College Station, and the Ph.D. degree in power system engineering from the University of Oklahoma, Norman. Dr. Russell is Associate Vice Chancellor and Associate Dean of Engineering, Professor of Electrical Engineering, and Director of the Power System Automation Laboratory of the Electric Power Institute at TexasA&MUniversity, College Station. His research interests include the use of advanced technologies to solve problems in power system control, protection, and monitoring. Dr. Russell is Division VII Director of the IEEE and Past President of the IEEE Power Engineering Society. He chairs the annual TAMU Conference for Protective Relay Engineers and the Substation Automation Conference. He holds several awards and patents for advanced digital technology applications. TABLE I PROTECTIVE DEVICES AND THE PROTECTED SECTION Name Type Protected Section R70-4H_T6.5 3-phase recloser From 800 to 816 F2T Fuse From 808 to 810 F20T_T0.8 Fuse From 816 to 820 F15T_T0.4 Fuse From 820 to 822 R50H_T5 3-phase recloser From 816 to 832 F6T Fuse From 824 to 826 F1T Fuse From 854 to 856 R15H R35H_T3 3-phase recloser 3-phase recloser From 832 to 890 From 832 to 834 F1T Fuse From 858 to 864 F20T_T0.5 Fuse From 834 to 848 F15T_T0.8 Fuse From 834 to 836 F6T Fuse From 836 to 840 F6T Fuse From 836 to 838 Section # Current Rating (A) Time Multiplier

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