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Fault Evaluation and Performance of an IEEE Bus 30 Power Distribution Network with Distributed Generation (DG) Angeles, C.J1, Mercader, E.J.2, Tan, G.E3, Pacis, M.C.4, Bersano Jr. R.F.5 4mikeinmars@yahoo.com School of Electrical, Electronics and Computer Engineering Mapua University1,2,3,4 Intramuros, Manila, Philippines Mindanao State University, Iligan Institute of Technology5 Iligan City, Philippines Abstract—Due to the penetration of Renewable energy to the power system which is inevitable, the power system will experience a drastic change, not only in its performance but also on the protective settings of relays. Thus, characterization of faults is necessary to determine the settings of the protective devices. In this paper, Fault Characterization studies are used to determine the performance and the fault values of all of the busses of the power system but with the impact of Distributed generation (DG). An IEEE Bus 30 system is a good selection of power system test case since it can be easily penetrated by a DG and can be connected as a mesh network. System performance during steady state and transient state is analyzed using the ETAP 6.0 software. A thorough investigation is needed so that the researchers can analyze the effect of DG's in the protection scheme of the relay settings, circuit breaker selection and protective device coordination. The simulation of results indicates that penetration of DG’s in the network affects the fault current nevertheless where fault current contribution depends on the location of the fault point to the penetrated DG in the system. Based from the graph of the DG contribution for different fault locations, the DG contributes the most fault current when the fault occurs connected at their respective busses. When the fault occurs at bus 29, DG 11 has the least contribution since it is far away from the fault point. In the summary of fault percentages, the researchers may say that the worst case of fault current occurs at Case 17 where Gen 2, Gen5 and Gen13 are removed in the system. Index Terms IEEE Bus 30 system, Distributed Generation, Fault Characterization, ETAP fault occurs. But the the I. INTRODUCTION Distributed generation plays a vast part in our power system. As the demand of electric energy demand goes 978-1-5386-0912-5/17/$31.00 ©2017 IEEE to these fulfill vague, there is a significant increase of distributed generation necessities. Interconnection of DG on power system will give a huge advantage on power generation on remote areas and will give additional benefits on the grid, distribution and to the supply. Due to carbon dioxide reduction goals, many of small sources of DG are renewable energy sources such as wind turbines, biomass, solar panels, micro turbines etc. Large scale integration of DG at MV and LV side of the system is presented to cover the supply of some loads. The problem to be solved in this study is the effect of the high penetration of DG’s in the performance of the protective devices in a distribution/sub transmission network connected as a mesh or loop. The performance of these relay settings plays a vital role in the selection of a new protective scheme of the power system with the inclusion of DG. The introduction of DG’s in the distribution of disadvantages on the operation, stability and protection. The change of fault current because of this additional source will create problems such as false tripping, out of synchronism problems and increase and decrease short circuit levels [1]. The penetration of DG will have a huge impact on controls, voltage collapse, and protection. The significance of this study will help to identify related problems in the power system and will minimize these issues using the proposed strategies from the results of this study. system will plenty have II. REVIEW OF RELATED LITERATURE I. Traditional Concepts of Power Systems Generation of electricity was a complex process, from power plants to transmission and utilization, these processes is a long way step for the production of [2,3]. Distribution electricity

in radial where Networks are usually connected majority of consumers are connected. In the radial connections, the flow of power will be in one direction, from the power source which is your source, to the transmission and to the distribution. The first process is the generation stage, these are your power plants located remotely from the city because of economics and environmental concerns. Through the second process, with the help of substations, transmission lines and cables, the transmission of electrical energy from longer distances was executed. The last process is the distribution systems, the links between the secondary transmission to primary distribution and where the power quality of the system takes place [3]. Due to increasing demand of electrical energy in the society, electrical source should also increase. Thus, penetration of distributed generation this economical problem. Nowadays, the technological evolution, environmental policies, the expansion of the finance and electrical markets, are promoting new conditions in the sector of the electricity generation. [4,5]. is a solution to III. METHODOLOGY The step by step procedure of the study is given on Figure 1. Figure 1. Flowchart of the study Test System the study framework of The conceptual is presented on Figure 1.Using the data from [13], the IEEE 30 bus system is designed using the ETAP software. The bus system is a prototype, and real time systems are designed and developed with reference to such prototype models. The prototypes are subjected to contingency analysis and results were obtained. The load flow analysis and transient stability for the standard IEEE-30 bus system are performed. The standard IEEE 30 bus system consists of 30 buses, 6 generators, 24 loads and 4 transformers. Generator1 is the swing bus and the other generators are in voltage control mode. The generators are rated 135kV, with speed 1800 rpm and with 4 poles. All of the loads in service are 3- phase and with rated voltage of 135kV. The unit of the lines have impedances in ohms per kilometer and the transformers are connected in 3-phase with rated voltage of 135 kV-140kV. Software Used The simulation software used here is the ETAP or Electrical Transient Stability Analysis Program by Operation Technology. There are different kinds of analysis that can be performed using this software such as Load flow analysis, Short Circuit Analysis, Arc Flash analysis, Harmonic Analysis and Transient stability analysis. The one line diagram for IEEE-30 bus system is drawn using the one line editor. ETAP is a user friendly graphical electrical analysis software that can be run on Windows XP and Microsoft Vista operating systems. The results of the analysis on the prototype models is used for real time simulation, optimization, advanced monitoring and intelligent load shedding at high speeds. ETAP allows to perform operations like varying the loads, allowing the system to contingency and study the characteristics of the faults. These virtual faults in the simulation model can be compared to the real time system faults [6]. The Single Line Diagram was constructed using the ETAP software. the user Load Flow Analysis and Short Circuit Analysis Load flow analysis also called as power flow analysis is an important tool for performance analysis of a power system. The basic knowledge required to perform load flow analysis of a system is to understand the one line diagram and the representation of the components of the power system in its per unit values.

Based on Table 1, 17 cases were presented with the results of load flow and comprehensive short circuit study. Fault Studies was limited to shunt faults only and the comparison for all the cases will be discussed on Section IV. Table 1. Power System Cases Case 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Configurations No DG DG 11 Out DG 12 Out DG 29 Out DG 30 Out Gen 13 Out Gen 11 Out Gen 5 Out Line 27 out Line 41 out No Swing Bus DG 11 and DG 12 Out DG 12 and Dg 29 Out DG 29 and DG 30 Out DG 30 and DG 11 Out Swing Bus and Gen 8 Out Gen 2, 5, and 13 Out Data Gathering: Computation of the DG’s rating. According to [7] Pmax = ….. (1) Qmax = x Pmax …… (2) It is assume that the maximum production gives the highest voltage rise. The reactive power at maximum production is a certain fraction of the active power as seen on eq (2). Based on the computation of the DG ratings, the researchers used a 1000m length with a cross sectional area of 50 square millimeters as their base length because the computed power rating was close to the ratings for the modeled IEEE Bus 30 system [8,9]. IV. RESULTS AND DISCUSSION After modeling the IEEE Bus 30 system, the researcher has to compare if the bus voltage result of the modeled power system is approximately equal to the IEEE bus 30 system. Using equation 3, the voltage error was computed and compared to the reference. %error = %diff = ……….(3) - ……(4) Based on Table 2, the Vref is the value of the reference while Vlf is the value of the voltage from the ETAP simulation. The load flow result of the modeled power system was reasonable because the voltage difference did not exceed the 5% marginal error. After obtaining the load flow data, the researcher performs the short circuit analysis. Using ETAP, the 3-Phase fault, MCR and KAIC ratings were obtained using 3-phase device duty (ANSI C37). MAX 1/2 cycle was used for getting the 3phase, SLG, LL, and DLG faults. The %difference formula was used in the fault average magnitude as well as the phase angle average with respect to Case I or NO DG. The 100% in the rows of Table 4 and 5 refers to the reference value or base case. Based on Table 3, shows the average fault current magnitude with respect to the base case. The maximum increase of the 3 Phase, Single Line to Ground Fault and Double Line to Ground Fault occurs at Case 17 where Gen 2, Gen5 and Gen13 are removed in the system. For the minimum decrease of 3 Phase fault, Single Line to Ground fault and Line to Line fault occurs at Case 2 where DG 11 is removed from the system, for the Double Line to Ground fault it occurs at Case 10 where Line 41 is out from the system. According to Table 5, shows the average fault current phase magnitude with respect to the base case. The 3 phase fault phase angle with highest percentage increase occurs at Case 9 where Line 27 is out in the system, it also occurs in Case 9 for the Single Line to Ground fault phase angle.

Table 2. % Fault Current Average Magnitude with respect to NO DG Table 3. % Phase Angle Average with respect to NO DG % Phase Angle Average with respect to NO DG Configurations 3 Phase Cas e 1 2 3 4 5 6 7 8 9 12 13 14 15 16 17 % Fault Current Average Magnitude with respect to NO DG No DG Configurations Case 1 DG 11 Out 2 DG 12 Out 3 DG 29 Out 4 DG 30 Out 5 Gen 13 Out 6 Gen 11 Out 7 Gen 5 Out 8 Line 27 out 9 10 Line 41 out 11 No Swing Bus 3Phase 100 82.274 89.924 89.44 89.412 98.123 92.795 92.974 89.543 91.793 99.646 SLG 100 91.985 93.113 92.789 92.722 106.76 98.256 97.343 93.833 96.182 102.7 LL 100 88.276 89.922 89.443 89.415 98.34 92.799 92.977 89.543 91.794 99.631 DLG 100 89.376 90.9 90.694 90.684 100.149 94.548 94.382 90.906 80.757 101.191 DG 11 and DG 12 Out DG 12 and DG 29 Ou DG 29 and DG 30 Out DG 30 and DG 11 Out Swing Bus and Gen 8 Out Gen 2, 5, and 13 Out 12 13 14 15 16 17 91.287 94.042 91.29 92.055 92.443 94.839 92.446 93.365 95.382 112.72 95.385 96.111 90.683 93.383 90.715 91.789 108.57 114.08 108.57 109.773 112.67 117.93 112.534 114.306 Based on Figure 2, it shows that Bus 12 has the highest 3-phase fault currents followed by Bus 11. The 3-phase fault currents on Bus 11 and 12 were greatly affected by the DG connected to them. The graph shows that each selected bus increased their 3-phase fault current as the DG 11 was removed. Based on Figure 3, it is shown that busses without DG (remote bus) has the minimal fault current compare to busses with DG’s but Bus 12 was still greatly affected when DG11 was out. It also shows that Bus 29 and Bus 30 have almost the same fault current in all cases except for no DG connected to them. Based on Figure 4 and 5, it shows that the DLG Fault Currents in kA. DLG Fault currents have the highest fault currents among all other fault currents. Bus 12 still has the highest fault current when DG 11 was out but Bus 11 has the highest fault current when all DG was connected. The other busses remain at low fault kA. No DG DG 11 Out DG 12 Out DG 29 Out DG 30 Out Gen 13 Out Gen 11 Out Gen 5 Out Line 27 out SLG 100 100.48 2 100.20 2 100.37 3 100 100.54 7 100.12 1 100.47 8 100.49 100.37 100.09 100.13 3 6 5 4 6 8 4 7 100.62 3 100.54 1 100.45 97.94 100.47 9 100.5 5 100.97 100.89 100.74 100.64 100.22 9 100.12 2 100.03 100.53 6 100.25 100.20 100.08 5 1 10 Line 41 out 11 No Swing Bus DG 11 and DG DG 12 and Dg 12 Out 29 Out 30 Out DG 29 and DG 90.326 98.05 DG 30 and DG 11 Out 100.49 80.353 98.95 Swing Bus and Gen 8 Out 100.31 2 93.619 102.9 1 LL 100 99.28 100.7 1 99.34 99.15 99.88 98.23 98.4 103.3 2 100.5 1 100.8 2 DLG 100 - 34.8 6 - 29.2 6 - 11.3 4 - 12.0 2 -53.2 - 25.9 8 - 34.4 8 - 33.8 7 12.1 9 - 25.7 3 - 22.8 4 9.36 35.5 3 - 12.3 2 - 32.5 5 - 37.3 4 Gen 2, 5, and 13 Out 99.573 99.445 105.3 2 researchers used a Simple Linear The Regression as the statistical method for generating a function for base case and other configurations. Based on Figure 6, taking X axis as the base case (Case 1) and Y axis as test case for configuration (Case 2, 3, 4, and so on). The sample curve is for the 3 Phase Fault at case 2 where DG 11 is removed from the system. The importance of using Simple Linear Regression to generate equations for all types of fault current and will be vital in the speeding up the process in determining the relay settings for adaptive protection. the

16.00 14.00 12.00 10.00 8.00 6.00 4.00 2.00 0.00 NO DG DG 11 OUT DG ALL NO SWING DG 11 & 12 out GEN 2,5 and 13 OUT Bus 4 Bus 6 Bus 11 Bus 12 Bus 15 Bus 28 Bus 29 Bus 30 Figure 4. Single Line to Ground Fault Currents on Every Node in KA 16.00 14.00 12.00 10.00 8.00 6.00 4.00 2.00 0.00 NO DG DG 11 OUT DG ALL NO SWING DG 11 & 12 out GEN 2,5 and 13 OUT Bus 4 Bus 6 Bus 11 Bus 12 Bus 15 Bus 28 Bus 29 Bus 30 Figure 5. Double Line to Ground Fault Currents on Every Node in KA Figure 7 shows the contribution of the four DGs in the 3 phase fault current of the system. It shows that the DG contributes the most fault current when the fault occurs at their respective busses. When faulted at bus 29, DG 11 has the least contribution of fault current because the bus where DG 11 was connected is far away from the fault point. 16.00 14.00 12.00 10.00 8.00 6.00 4.00 2.00 0.00 Bus 4 Bus 6 Bus 11 Bus 12 Bus 15 Bus 28 Bus 29 Bus 30 NO DG DG 11 OUT DG ALL NO SWING DG 11 & 12 out GEN 2,5 and 13 OUT Figure 2. 3 Phase Fault Currents on Every Node in KA 14.00 12.00 10.00 8.00 6.00 4.00 2.00 0.00 NO DG DG 11 OUT DG ALL NO SWING DG 11 & 12 out GEN 2,5 and 13 OUT Bus 4 Bus 6 Bus 11 Bus 12 Bus 15 Bus 28 Bus 29 Bus 30 Figure 3. Line to Line Fault Currents on Every Node in KA Figure 6. Simple Linear Regression

VI. REFERENCES [1] Yuping Lu, L. H. (2007). A Study on Effect of Dispersed Generator Capacity on Power System Protection. IEEE [2] Angel Fernandez Sarabia, “Impact of distributed generation on distributied system”, Aalborg University - Department of Energy Technology Pontoppidanstraede 101 9220 Aalborg East, Denmark Printed in Denmark by Aalborg University [3] Mario Vignolo, R. Z. (2002). Transmission Networks or Distributed Generation?. Montevideo, Uruguay [4] Philip P. Barker, R. W. (2000). Determining the Impact of Distributed Generation on Power Systems: Part 1 - Radial Distribution Systems. 12. IEEE. Retrieved 02 16, 2011, from IEEE. [5] Edward Coster, Stedin, Johanna Myrzik and Wil Kling Eindhoven University of Technology The Netherlands “Effect of DG on distribution grid protection” [6] Stanley Horowitz and Arun Phadke “Power System Relaying” 3rd Edition, John Wiley and Sons Ltd. 2008 [7] Math H. Bollen,Fainan Hassan.(2011), Integration of Distributed Generation in the Power System [8] William Rosehart , Ed Nowicki (24-28 June 2002). Optical Placement of Distributed Generation, University of Calgary [9] R.M. Kamel1 and B. Kermanshahi, Optimal Size and Location of Distributed Generations for Minimizing Power Losses in a Primary Distribution Network, December 2009, Sharif University of Technology 30 29 28 15 12 11 6 4 DG 30 DG 29 DG 12 DG 11 0 0.5 1 1.5 2 2.5 3 Figure 7. DG Contribution For Different Fault Locations [3 phase DG ALL] V. CONCLUSIONS In this study, the system was modeled by the computer design software called ETAP. After modeling the IEEE Bus 30 system, the researcher compares the bus voltage results of the modeled power system to the IEEE bus 30 system. Based on the results, the load flow result of the modeled power system was reasonable because the voltage difference did not exceed the 5% marginal error. There were 17 different cases that were developed in this study and based on the simulation results, the penetration of DG’s in a system affects the fault current nevertheless where the fault occurs. But the fault current contribution depends on the location of the fault point to the penetrated DG in the system. Based on the graph of DG contribution for different fault locations, the DG contributes the most fault current when the fault occurs connected at their respective busses. When the fault occurs at bus 29, DG’s 11 has the least contribution since it is far away from the fault point. The graphs and curves of different cases show the performance of the system given that case 1 as base. In the summary of fault percentages, the researchers conclude that the worst case of fault current occurs at Case 17 where Gen 2, Gen5 and Gen13 are removed in the system and the best case for the 3 phase fault, single line to ground fault, line to line fault it occurs at Case 2 where DG 11 is removed from the system, for the double line to ground fault it occurs at Case 10 where Line 41 is out from the system. the drastic change of

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