Produção Nacional
Revisado por pares
Implementation and performance evaluation of a harmonic filter for use in adaptive single‐phase reclosing
2017; Institution of Engineering and Technology; Volume: 11; Issue: 9 Linguagem: Inglês
10.1049/iet-gtd.2016.1630
ISSN1751-8695
AutoresOzenir Dias, Maria Cristina Tavares,
Tópico(s)Power System Optimization and Stability
ResumoIET Generation, Transmission & DistributionVolume 11, Issue 9 p. 2261-2268 Research ArticleFree Access Implementation and performance evaluation of a harmonic filter for use in adaptive single-phase reclosing Ozenir Dias, Corresponding Author Ozenir Dias ozenirfd@dsce.fee.unicamp.br Department of Systems and Energy, School of Electrical and Computer Engineering, UNICAMP – University of Campinas, Campinas, São Paulo, BrazilSearch for more papers by this authorMaria Cristina Tavares, Maria Cristina Tavares orcid.org/0000-0001-9030-6764 Department of Systems and Energy, School of Electrical and Computer Engineering, UNICAMP – University of Campinas, Campinas, São Paulo, BrazilSearch for more papers by this author Ozenir Dias, Corresponding Author Ozenir Dias ozenirfd@dsce.fee.unicamp.br Department of Systems and Energy, School of Electrical and Computer Engineering, UNICAMP – University of Campinas, Campinas, São Paulo, BrazilSearch for more papers by this authorMaria Cristina Tavares, Maria Cristina Tavares orcid.org/0000-0001-9030-6764 Department of Systems and Energy, School of Electrical and Computer Engineering, UNICAMP – University of Campinas, Campinas, São Paulo, BrazilSearch for more papers by this author First published: 14 June 2017 https://doi.org/10.1049/iet-gtd.2016.1630Citations: 9AboutSectionsPDF ToolsRequest permissionExport citationAdd to favoritesTrack citation ShareShare Give accessShare full text accessShare full-text accessPlease review our Terms and Conditions of Use and check box below to share full-text version of article.I have read and accept the Wiley Online Library Terms and Conditions of UseShareable LinkUse the link below to share a full-text version of this article with your friends and colleagues. Learn more.Copy URL Share a linkShare onFacebookTwitterLinkedInRedditWechat Abstract This study presents an adaptive single-phase reclosing method based on voltage harmonic measurement implemented in a digital harmonic filter. This filter and the transmission system were modelled in a real-time digital simulator. A distance relay was used for protection and reclosing, responding as if it was in field operation. The studied system was based on an actual 500 kV Brazilian system. This study highlights the advantages of using the adaptive technique with a digital harmonic filter. 1 Introduction Most faults in electrical power systems occur in transmission lines, and the single-phase transient fault is more frequent among them. In Brazil, almost 80% of faults on 500 kV transmission lines are single-phase and transient, caused mostly by atmospheric discharges. In this case, the protection system should interfere and quickly remove this fault to maintain system stability, isolating a faulty section from the rest of the system and restoring power supply as quickly as possible. Single-phase manoeuvre is most suitable for cases of single-phase transient faults, since the fault is eliminated by opening only that specific phase (single-phase opening). After dead time has passed, reclosing completes the manoeuvre. During the manoeuvre, consisting of phase opening +dead time +reclosing, the other two phases of the transmission line remain delivering power, and this is one of the main advantages of this technique. It is also possible to improve system stability and reliability and reduce torsional impacts on turbo generator rotors [1] in this manoeuvre, since the system remains connected during the fault, however operating under unbalanced conditions. A very important benefit is the reduced overvoltage during phase tripping and reclosing when compared with the three-phase manoeuvre. The success of this manoeuvre depends mainly on the fault extinction. Traditional single-phase reclosing is made using a fixed single-phase reclosing time determined by studies, to ensure the manoeuvre success within preset dead time. Dead time limit is obtained from studies on system stability. Once time limit is determined, transient studies calculate the probabilities of fault extinction within dead time, i.e. the success of the manoeuvre. In these studies, devices and/or additional procedures required to enable the manoeuvre are applied. Normally, dead time lasts between 500 ms and 1 s to guarantee fault extinction. In some cases, this fixed time may be too long, resulting in excessive time to reclose the open phase or may not be enough to the fault extinction. Due to these general characteristics, some smart single-phase reclosing are being discussed globally, and they are called adaptive single-phase reclosing (AdSPAR) [2–15]. These studies aim at estimating the arc extinction instant and distinguishing transient faults from permanent faults. Adaptive reclosing has advantages over the traditional technique: it increases the chances of a successful reclosing, improves system stability, and reduces impact when a permanent fault occurs [15]. AdSPAR successfully recloses the power line, reducing the period the faulted phase is not available and increasing the system security and reliability. Besides gains on power flow, uninterrupted supply helps the good functioning of the whole system and prevents systems separation due to loss of synchronism. The AdSPAR scheme proposed in this study is implemented by measuring the voltage harmonics in the open (faulted) phase at one of the transmission line terminals. Harmonics indicate whether the fault still persists, and their absence indicates, within certain pre-defined limits, that the fault is extinct. If there is no harmonics at the beginning of the fault, this means that the fault is not transient, but has a high probability of being a permanent fault, indicating that automatic reclosing must be blocked and the three-phase opening started. In this study, we developed and tested a fast digital filter to calculate harmonics in the faulted phase. The fast filter was implemented in real-time digital simulator (RTDS) and system protection was made using a line protection relay connected in closed loop with the RTDS. According to the control created, an order is given to block or reclose the open phase. The results obtained were satisfactory, both in performance and operation velocity of the proposed scheme. 2 Fast adaptive SPAR The protection scheme of fast AdSPAR proposed in this study is made by measuring the harmonic voltages at the faulted phase terminals. Voltage harmonic content has already been investigated by many researchers, among them [16–23]. In [23] long electrical arcs with various 60-Hz current magnitudes were artificially generated at Power Laboratory. The most significant voltage harmonic components are presented at Table 1, including the total harmonic distortion (THD). It can be observed that the harmonic content is very high. In [24] the harmonic content of open phase oscillography voltage in cases with secondary arc occurrence are presented. The 3rd, 5th and 7th harmonic components are present as seen on laboratory cases. Table 1. Voltage harmonic content of the secondary arc [22] Current class () 15 30 50 60 100 150 200 harmonics 3rd 26.5 22.5 22.9 25.0 27.6 26.8 25.4 5th 10.3 6.9 6.3 7.3 9.4 10.3 9.9 7th 4.7 2.6 2.3 1.8 3.7 4.1 4.0 THD (%) 28.8 23.6 23.8 26.1 29.4 29 27.5 In the article by [25], there is a comparison between traditional reclosing, using a dead time of 500 ms, and an adaptive reclosing by measuring total voltage harmonic distortion (THD) at the faulted phase. The article showed that the analysis of the voltage harmonic content allowed the determination of the fault extinction time in the case of transient faults or the blockage of the automatic manoeuvre in case of permanent faults. Based on the results presented in [23, 24], 5% minimum THD threshold was used to identify permanent fault. For transient fault, the extinction occurs when open phase voltage THD reduces to less than 5%, as presented in flowchart [25]. The method operates properly, but with a slow response because of the harmonic measurement device used, which was developed for time observation windows much larger than the ones required for the present methodology. In this study, we propose to replace the voltage harmonic measurement device by a fast digital filter implemented in RTDS, which responds in 2 to 3 cycles of the fundamental frequency. In the present paper the harmonic filter was implemented inside RTDS using RTDS components. An ongoing research is the development of a hardware with the proposed adaptive protection function. 3 Conventional harmonic measurement Devices used to measure electrical quantities are often used to measure harmonic content. Such devices follow the IEC 61000-4-7 : 2009-2010 standard, intended for measuring spectral components in the frequency range up to 9 kHz, which are superimposed on the fundamental frequency at 50 or 60 Hz [26]. For practical considerations, this standard distinguishes between harmonics, inter-harmonics, and other components above the harmonic frequency range up to 9 kHz. There are four main components of a measurement device that complies with IEC 61000-4-7: Input circuit with Anti-Aliasing filter; A/D converter with Sample-and-Hold; Main synchronisation, e.g. phase-locked loop; Discrete Fourier Transform (DFT), which provides Fourier coefficients. The general structure of harmonics measurement devices is represented in Fig. 1, taken from [26]. Fig. 1Open in figure viewerPowerPoint Simplified structure of a measurement device [26] One of the main aspects of this standard is the setting of the time windows to be used to sample the waveform before starting the analysis with Fourier Transform. For measurement devices to operate both at 50 and 60 Hz, it is determined a window with a length of 10 cycles in a 50 Hz system and 12 cycles in a 60 Hz system. In both cases, the window length is 200 ms, and applying discrete Fourier algorithms results in frequency resolution of 5 Hz for both systems (50 and 60 Hz). The greater the length of this window, the more accurate the frequency, but the lower the precision of harmonics in time. In the case of commercial measuring devices, inter-harmonic measurements are necessary, thus a 5 Hz resolution (200 ms windows) is desirable. In practical results, commercial measuring devices may have a 200 ms delay over time. For quality analysis, such delay is irrelevant, since large time intervals, much higher than the delay, are monitored. In this study, a good response is required from voltage harmonics over time, and, for power system protection, this delay could affect the performance of the proposed scheme, delaying the detection of permanent faults and the single-phase reclosing. As commercial measuring devices have this limiting factor, we proposed the use of a harmonic filter to calculate voltage harmonics. 4 Harmonic filter The harmonic filter was implemented in RTDS [27]. The filter is used to calculate first, third, fifth, and seventh voltage harmonics. As filtering is done only for componentś block diagram (harmonic filter) multiple of the fundamental frequency, we used a window of 16.67 ms for 60 Hz and frequency resolution of 60 Hz. Calculation of harmonic voltages can be seen in Fig. 2. Built-in RTDS components were used to implement the filter. The PB5 RTDS card necessary to model the filter can be drastically reduced if the filter is written in C language using RTDS Cbuilder component. Fig. 2Open in figure viewerPowerPoint Harmonic filter block diagram The filter implemented consists of: A low-pass filter, to attenuate high-frequency signals. We used a second-order Butterworth filter with cut off frequency of 646 Hz. A sampler for conversion of continuous analogue signals to discrete signals. We used a sampling at 1920 Hz, being generated 32 samples per cycle (60 Hz). An analogue-to-digital converter for the conversion of the analogue signal to digital signal. A 12-bit analogue-to-digital converter with 4096 steps, i.e. it can define a scale of 4096 different values, making conversion precise. Low-pass filters to reject unwanted frequencies. We used four cosine low-pass filters. They have been configured for 60, 180, 300, and 420 Hz. After extraction by the cosine filter, each component phasor is calculated. With the measurements of each component, we can calculate the THD, using the following equation: (1) where, Vh1 – fundamental frequency voltage value; Vh3 – third harmonic voltage value; Vh5 – fifth harmonic voltage value and Vh7 – seventh harmonic voltage value. The new scheme tested is represented by the block diagram of Fig. 3. The entire power system and the harmonic filter were modelled in the RTDS, whereas system protection and reclosing are made by SEL421 relay. Fig. 3Open in figure viewerPowerPoint Scheme of the proposed protection 5 Electric power system analysed The transmission system used is based on the Northeast–Southeast interconnection Brazilian transmission trunk. The 500 kV system has a power generation unit, the step-up transformer, and a 350 km long transmission line using shunt compensation, as shown in Fig. 4. Transmission line parameters for fundamental frequency (60 Hz) are in Table 2. The line was modelled as ideally transposed (balanced line). Fig. 4Open in figure viewerPowerPoint Transmission system analysed Table 2. Transmission line parameters calculated for 60 Hz Sequence Series, Ώ/km Shunt, μS/km positive/negative 0.0161 + j 0.2739 j 6.0417 zero 0.4352 + j 1.4427 j 3.5227 As the transmission line is very long, reactive shunt compensation is necessary to reduce power overload permanently at no-load or light load. Such compensation is made by reactors installed at both line terminals, which will compensate positive sequence shunt admittance. The reactor has been calculated so that voltage gain between terminals at no-load was 1.05, with 188 Mvar of power, and quality factor of 400 (typical Brazilian value). A fourth reactor was connected between ground and neutral, called neutral grounding reactor, leading to the minimisation of phase mutual admittance. The main source that keeps the secondary arc current (SAC) flowing is provided by capacitive coupling between healthy energised phases and the faulty phase. This reactor can also be used to displace any possible resonances due to high compensation level. In this study, we considered faults with three levels of SAC. These values were chosen to test the scheme for compensated lines with high value for the neutral reactor (15 Arms compensated), compensated lines with low value for the neutral reactor (60 Arms compensated), and for a non-compensated line (short line – 15 Arms non-compensated). Table 3 shows the values of reactors used for each test. Table 3. Neutral reactor parameters Shunt compensation – neutral reactor Test Resistance, Ω Reactance, Ω 15 Arms compensated 10.3675 414.7 60 Arms 1.97925 79.17 For the 15 Arms non-compensated test, we reduced the transmission line length to 70 km to obtain a 15 Arms SAC. 6 Secondary arc model RTDS electrical arc model was used according to [27, 28] to represent the transient fault. Both the primary and the secondary arcs were modelled in the same way, with only one time constant, that was changed for each case. The arc characteristic is described in (2): (2) where g is the arc conductance, which varies in time, G is the stationary arc conductance and T is the time constant. T is calculated every half cycle, since it depends on the current peak value in the previous half cycle () and the arc length (l), as shown in the following equation: (3) For primary arcs, α is set at 28.5 µs [27]. For secondary arcs T is calculated according to the following equation: (4) β is set at 2.51 ms [27]. The configuration menu of this component is presented in Fig. 5. It is worth mentioning the following adjustments: secondary current (isec) threshold and off-state current (ioff) extinction threshold. These adjustments define the beginning and the end of the secondary arc, i.e. if the current is lower than isec, the secondary arc starts, and, if the current drops below ioff, the arc is extinguished. Fig. 5Open in figure viewerPowerPoint RTDS arc model adjustment The primary arc length (arcl) is set equal to the insulation distance where the arc is formed, whereas in the increase of the secondary arc length (alsec) is adjusted to model secondary arc's elongation speed. For alsec, it is possible to set a fixed value for elongation speed or to create an external control in the option secondary arc length external control on the configuration tab. Using external control, the input parameter becomes the secondary arc length by the elaborated control scheme and not the elongation speed. Primary arc length was set in 4 m due to the insulator string length of the 500 kV transmission line (4.05 m). The secondary arc growth rate has been defined by the transient fault duration. Initial tests were conducted to reach a duration of approximately 1 s. The following settings (Fig. 5) were used for each test performed. It is important to emphasise that the RTDS arc model is simplified and should be understood as an approximation, as the open phase voltage is not a perfect match when compared with real oscillographies [29]). Some researches in progress [30] contribute for a better arc modelling, but they are not yet completed. One of the important aspects in arc modelling is the correct definition of time constants and transition from primary (power) arc to secondary arc, which has much lower currents. Imposing a limit on the current to start RTDS secondary arc modelling may be a non-optimal approximation. Furthermore, as the harmonic signature of the electric arc, either of high or low arc currents, does not varies substantially, the proposed algorithm will properly operate, despite the approximations of the RTDS arc model. The arcs characteristics are described in Table 4. These data were used to generate 1 s arc duration. The minimum resistance fault value (fault on minimum resistance) was varied as shown: 1, 10, 20 and 100 Ω. Table 4. Arc elongation data RTDS arc model length Test Primary arc length, m Secondary arc length increase, m/s 15 Arms 4 43 15 Arms compensated 4 60 60 Arms 4 80 7 Performed simulations The tests consist in the implementation of single line to ground (SLG) fault in the transmission system, varying the line length and the neutral reactor value as described in the previous section. Permanent and transient SLG faults were applied to evaluate the proposed scheme. The simulated manoeuvre consists in energising the no-load line with subsequent application of the single-phase fault in phase A. For permanent SLG faults, the fault resistance value was set to 1, 10, 20 and 100 Ω. The transient faults were represented by the RTDS arc model, as shown above. When RTDS simulator is used it is necessary to establish a method for generating similar transient cases, instead of simply applying the disturbance at a given instant of time as would occur in an offline simulator as ATP or PSCAD. In RTDS the disturbances should be applied observing the instant of the monitored signal cycle, either voltage or current. In the present study the fault was applied 4.5 ms after positive voltage cycle zero crossing in the fault location. The fault point was modified along the line and the fault was applied in the following points: 5, 25, 50, 75 and 98% from the sending terminal, consisting in a sliding fault. This procedure was carried out with the controls of Fig. 6. Fig. 6Open in figure viewerPowerPoint Procedure to obtain the switching instant on RTDS The results are presented in graphs of phase A voltage at the sending terminal of the protected line, fault current in phase A, and THD of faulted voltage. The graphs plotted for both tests refer to the 15 Arms test and to the point of fault application in 50% of the protected line. Resistance was 10 Ω in case of permanent faults. Other results are presented in Table 5. Table 5. Tests performed using proposed scheme Type of fault Fault resistance, Ω Fault application location, % Identification time, ms 15 Arms 15 Arms compensated 60 Arms permanent fault 1 5 37.50 100.03 91.69 25 37.50 54.17 58.33 50 45.84 66.69 66.69 75 41.68 66.69 66.69 98 41.68 70.84 75.04 10 5 37.50 83.36 79.20 25 41.66 58.33 54.17 50 41.66 66.69 62.53 75 45.84 66.69 66.69 98 41.68 70.86 70.84 20 5 41.66 66.69 70.84 25 41.66 54.17 54.17 50 41.66 62.53 62.53 75 41.66 66.69 66.69 98 41.66 70.86 70.84 100 5 50.02 54.19 45.86 25 50.02 50.02 45.86 50 50.02 58.37 54.19 75 50.02 62.53 58.37 98 41.70 62.53 62.53 transient fault RTDS arc model 1 Ω 5 39.34 65.60 41.16 25 43.60 66.27 41.07 50 38.79 46.21 33.05 75 39.28 62.25 41.34 98 39.22 49.30 41.07 RTDS arc model 10 Ω 5 40.27 62.20 41.08 25 41.32 65.2 40.5 50 40.20 55.6 41.1 75 42.40 57.6 35.7 98 39.52 62.5 39.4 RTDS arc model 20 Ω 5 45.56 63.24 42.56 25 47.65 61.54 47.86 50 48.56 67.75 40.56 75 45.38 68.87 52.87 98 44.95 70.54 44.55 RTDS arc model 100 Ω 5 51.58 55.52 48.23 25 53.54 60.54 72.53 50 56.53 63.54 70.65 75 50.52 72.53 73.55 98 55.53 67.53 68.75 The relay protection pulses, specifically reclosing or blocking signals, are also presented in the graphics. The disturbance bits are as follows: 52AA1 – phase A circuit breaker status. 52AB1 – phase B circuit breaker status. 52AC1 – phase C circuit breaker status. OUT101 – phase A trip. OUT102 – phase B trip. OUT103 – phase C trip. OUT104 – reclosing. IN104 – reclosing command from filter. IN105 – blocking command from filter. The analysed system was considered without any disturbance or imbalance, which could cause harmonic distortion, as well as it was not evaluated the terminal network strength. These conditions are under analysis and will be presented in future work. 7.1 Permanent fault Figs. 7 and 8 show the results from the test with the proposed method for permanent fault using harmonic filter. The relay recognises the fault and generates single-phase opening. As the fault is permanent, the voltage waveform at the faulted phase sending terminal (Fig. 7) is purely sinusoidal after initial transition period. As a result, the voltage harmonic distortion is almost zero, as shown in Fig. 7 (THD level). Therefore, a blocking pulse is generated (IN105, Fig. 8). Single-phase reclosing is blocked and three-pole opening is thus carried out due to a permanent fault. Recognition (IN105) takes place around 42 ms after fault application. Fig. 7Open in figure viewerPowerPoint Fault current at phase A, faulty phase voltage and THD at sending terminal under permanent fault Fig. 8Open in figure viewerPowerPoint Relay oscillography for single-phase permanent fault using proposed filter 7.2 Transient fault Figs. 9 and 10 show the results from the test with the proposed method for transient fault. The relay recognises the fault and generates single-phase opening. As the fault is transient, voltage waveform at the initial terminal of the faulted phase (Fig. 9) is quite distorted. Consequently, the harmonic distortion rate remains high until fault extinction, as shown in Fig. 9 (THD level). The detection of fault extinction is quickly made, generating the reclosing pulse (IN104, Fig. 10). Single-phase reclosing is thus applied and the system goes back to normal operation. The fault extinction recognition happens approximately 40 ms after extinction. Fig. 9Open in figure viewerPowerPoint Fault current at phase A, faulty phase voltage and THD at sending terminal under long transient fault Fig. 10Open in figure viewerPowerPoint Relay oscillography for single-phase transient fault using proposed filter Table 4 summarises the tests carried out to verify the proposed scheme behaviour. We made a scanning at the fault site for 5, 25, 50, 75, and 98% of the transmission line. Next, we changed the SAC value. For permanent fault and arc fault, we used the resistance of: 1, 10, 20, and 100 Ω. The proposed scheme had excellent performance for all simulated cases. For permanent faults, the time for protection actions varied from 37 to 100 ms after the faulty phase breaker opened. These were the best and worst cases, respectively, whereas transient faults took from 39 to 67 ms after SAC extinction. Whereas for the short line the filter response for permanent fault was faster, no matter the fault location, a larger influence of fault location was observed for the long line. No significant influence could be observed in time response when fault resistance was varied for permanent fault. Analysing transient fault, the time response varied more with SAC than with line length. The transient fault had no important impact on time response. 8 Conclusion In this study, we introduced a fast AdSPAR scheme based on harmonics measurements of the open phase voltage. RTDS simulations were carried out and the opening and reclosing manoeuvre was conducted by distance relay SEL 421. The adaptive method was implemented using a fast harmonic filter modelled in the RTDS. Two base cases were simulated: the first was application of permanent fault and the second of transient fault. Using the proposed method, the cases were successful for permanent fault, in which protection blocked automatic reclosing and three-pole opening was implemented, and for transient fault, in which protection detected the arc extinction moment and started single-phase reclosing always successfully. Performance was not compromised with fault location or with the SAC amplitude. For permanent faults, the time for protection actions varied from 38 to 100 ms after the faulty phase breaker opened, whereas transient faults took from 39 to 67 ms after SAC extinction. Overall, we can state that the proposed algorithm based on 3rd, 5th and 7th open phase voltage harmonic content can enhance SPAR, turning the manoeuvre more reliable and, consequently, improving system safety levels. It should be emphasised that the operation time of the proposed scheme was very fast, improving even more the response already presented in [25]. 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