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Article

Design of Hardware Setup Based on IEC 61850 Communication Protocol for Detection & Blocking of Harmonics in Power Transformer

by
Abdul Azeem
1,
Majid Jamil
1,
Shamimul Qamar
2,*,
Hasmat Malik
3 and
Rayees Ahmad Thokar
4
1
Department of Electrical Engineering, Jamia Millia Islamia, Delhi 110025, India
2
Computer Science and Engineering, Faculty of Sciences & Managements, King Khalid University, Dhahran Al Janub, Abha 64351, Saudi Arabia
3
BEARS, NUS Campus, University Town, Singapore 138602, Singapore
4
Department of Electrical Engineering, Malaviya National Institute of Technology (MNIT), Jaipur 302017, India
*
Author to whom correspondence should be addressed.
Energies 2021, 14(24), 8284; https://doi.org/10.3390/en14248284
Submission received: 22 November 2021 / Revised: 30 November 2021 / Accepted: 3 December 2021 / Published: 9 December 2021
Browse Figures
Versions Notes

Abstract

:
In this paper, the authors have developed a hardware model for blocking even and odd harmonics of a power transformer. In the proposed hardware model, intelligent differential & over-current relays are used for the blocking of harmonics of a power transformer. The harmonic restraint function on the differential relay (7UT61) prevents the relay from tripping during transformer magnetizing inrush current. However, the over-current relays which are used for back up protection does not have a harmonic restraint element, and over-current relay trips due to magnetizing inrush current, causes unwanted interruptions and power failures. The establishment of harmonic blocking scheme for over-current protection in power transformers is an important finding of this research study. IEC61850 standard-Based GOOSE (Generic Object Oriented Substation Event) applications used in power transformer protection for fast detecting and clearing of faults is an interested study presented in the proposed work.

1. Introduction

A transformer is an integral part of the power system. Electricity is generated in different ways, but without a transformer, we can neither transmit nor distribute electricity. With the help of a power transformer, we can increase and decrease the current and voltage, delivered in alternating current form over the transmission wires. When an electrical device operates regularly, it also malfunctions or generates faults. Similarly, the transformer works day and night, in such a situation some faults occur in it. Insulation failure is the most prevalent cause of transformer failure; heat, oxidation, acidity, and water deteriorate—overheads such as switching rises, spikes in voltage, line defects, and distribution defects.
Transformer, the most expensive equipment in an electric power system, is anticipated to last 35 years under the CERC standards throughout its life. Transformer life is different in different countries, such as 40 years in the United States, 45 in Germany, and 36 in Australia. The major responsible module of transformer failure is on-load tap changer (OLTC)—31.16%, winding—19.40%, and bushing—13.99%. It is worrying that around 50% of the reported broken transformers were in operation for less than ten years [1,2].
When the transformer is commissioned, it is in good condition, but from time to time, it has a lot of impact on its life cycle and health due to various influences on it. The condition of the transformer is monitored to reduce the rate of failure. This is called condition monitoring. If the transformer fails, it affects the acoustic. Condition monitoring is done to ensure that the transformer does not fail quickly. All transformer tests are done in condition monitoring [3]. Condition monitoring of transformers is two ways, the first one is online and the other is offline. Both online and offline condition monitoring diagnosis tests are shown in Figure 1.
The installation of the monitoring devices on the transformer is for two primary reasons:
  • By monitoring essential operations of the transformer, errors may be identified and removed before their catastrophic failure occurs.
  • By changing maintenance, i.e., on request, from the regular to the condition-based service.
Another important aspect is analysis of harmonics in power transformers. There can be many reasons for harmonics generation, and due to this, there is a lot of impact on the life of the transformer and the utility’s economy. In a power transformer, voltage and current harmonics are generated from a non-linear load. It has the potential to harm electrical energy delivery equipment; unwanted load also produces voltage and current harmonics, which increases the heating problem in the transformer. As per the IEEE standard C57.91-1995, the normal life of a transformer is twenty to twenty-one years. But due to poor power quality problems, different types of losses, it’s not possible.
Here are three types of recommendations for harmonics control and protection of power transformers.
  • Series line reactors, tuned harmonic filters, and larger pulse number converter circuits like 12-pulse, 18-pulse, and 24-pulse rectifiers can all help to reduce the load’s harmonic current.
  • Condition monitoring of transformer should be done from time to time so that if any problem keeps on creating in the transformer, it can be solved in time like harmonics.
  • Install digital substation, these digital substations use IEC-61850 protocol to block harmonics through GOOSE messages. Due to this, if the inrush current is increased in the power transformer, then it has the capability that it can block the harmonics.
A block diagram showing different types of harmonics and their effects on power transformers is presented in Figure 2. The problem of harmonics in transformer and other power system equipment is many years old. Because of this, the heating problem in the transformer increases. Transformer oil gets hit too much due to heating problems. Due to excessive heating, the chances of the transformer getting damaged are high if this problem is not resolved soon. Due to the failures of a transformer, the chances of damage increase to the instruments engaged in T & D and Industries. In order to increase the protection and life of the transformer, the use of multi-protection relay/IED (Intelligent Electronic Device) has increased in digital substations. This multi-protection relay is microprocessor-based; this relay reads faults quickly, and trips CBs. At present, the world is moving towards a digital substation in an electricity substation. The term of digital substation is described as “Electrical substations in the operation of distributed IEDs connected to communication networks amongst dispersed intelligent electronic devices”.
In recent years, researchers have made extensive research on power transformer harmonics using different types of models and techniques such as physical laboratory model, On-Site transformer work and artificial intelligence which is summarised in the Table A1 in Appendix A. The authors’ in [4] presented an OPNET Modeler simulation library that employs the IEC 61850 standard for communication and control while analyzing the network traffic in electric power substations. The authors’ in [5] proposed a successful real-time modelling and testing of an over-current protection system based on IEC 61850-9-2. For testing real-time performance, the True Time software and Matlab Simulink had been incorporated into the real-time environment simulator. To accomplish a quick and secure trip decision during the fault and harmonics conditions, an improved phaselet-based distance protection scheme is proposed in [6]. To ensure enhanced performance authors tested the proposed method using hardware-in-the-loop simulations using an RTDS simulator and digital substation communication protocols (IEC 61850 SV and GOOSE). In Ref. [7], authors developed a laboratory model for transmission line interface with IEC-61850 communication protocol for improving control and protection. In this study, the TransView packet of Omicron Test Universe was used to measure the harmonic content of the components. A relay model based on a manufactured differential transformer relay, SEL-787, developed in a real-time digital simulator is presented in [8]. The developed model outperforms when compared with the actual relay and a built-in model.
From the literature survey, it is found that the authors in [9] have developed hardware model for harmonic blocking scheme for transformer which uses element (87HB) of the transformer differential relay to send an IEC61850 GOOSE signal to the backup over-current relay to inhibit from tripping. In this study, the model is presented to block only second harmonics. In the existing literature, to the best of authors’ knowledge, there is no research found that shows development of hardware model for blocking the fifth harmonics in transformers which serves as a motivation and research gap for the present study. Further, in [9] the model is developed to block the harmonics only during the transformer magnetizing inrush current conditions at 16.60%. Therefore, to develop a hardware model which can detect and block both even as well as odd harmonics in power transformers while considering different conditions of transformer magnetizing inrush current is imperative. In this paper, we have presented a study based on IEC-61850 for blocking of harmonics (2nd and 5th) of the power transformer. During this research, transformer current differential protection, 7UT61, backup over-current protection, 7SJ64 Intelligent Electronic Device (IED) support IEC 61850, are used and their data are shared for tripping/blocking signals which are sent to the other IEDs. In comparison with a typical hardwired signal with a considerable time delay, this increases speed and reliability of backup over-current protection by using IEC 61850, Generic Object-Oriented Substation Event (GOOSE) communication. A hardware model has been developed for the protection of power transformers against harmonics in the proposed study.
The followings are the contributions of the proposed study.
  • A hardware model is developed to enhance the speed and reliability of backup protection in power transformers.
  • In this model, IEC 61850 Protocol is employed to communicate between IEDs to block even and odd harmonics (2nd & 5th) in power transformers. The scheme uses GOOSE messaging to send a harmonic blocking signal from the 7UT61 differential IED to the 7SJ64 over-current IED.
  • To demonstrate the efficacy of the developed model the harmonic blocking procedure is performed over a range of transformer magnetizing inrush current conditions.
  • The interfacing of various equipments of the hardware model for experimental procedure is done by implementing the powerful and efficient operating programs, which include DIGSI4 and Omicron Test Universe 2.11.
This paper is divided into four parts. Section 1 explains the introduction of a power transformer and explains the condition monitoring of the power transformer. Section 2 explains the overview of IEC-61850 and shows the IEC-61850 architecture diagram & GOOSE message traveling between the IEDs. Section 3 describes the experimental demonstration of harmonic identification and shows Laboratory Hardware Model Picture. Section 3 presents the experimental results in graphical form & tabular form for 2nd and 5th harmonic diagnosis. The last part of this paper, Section 4 explains the conclusions and the future work.

2. Overview of IEC 61850

Ethernet was discovered in the mid-1970s. The speed of Ethernet cable is much faster than before, from 10 Mbps in the 1980s to 1 Gbps now is commonly used. Most of the communication network is 100 Mbps, and some large network systems may have 1 Gbps for trunk links for the substation. F. Engler et al. [10] have proved the real-time performance of SAS can meet the standard requirements [11] by doing the feasibility studies of IEC 61850. LAN congestion scenarios for the Ethernet-Based substation have been examined by Tengdin et al. [12]. However, any process bus is not included in the examined substation. The voltage transformers (VT) are still hard wirings that use primary injection to the protection relays. The background traffic load has not been matched to IEC 61850. Therefore, further investigation is required for the performance of the substation automation system Based on the IEC 61850 standard, which is largely unknown. Many different types of process bus architecture have been proposed using the ring, star, point to point or meshed topology in the literature [13,14,15,16,17,18,19]. J Mo [19] is of the opinion that the process bus and station bus should be separate from each other to avoid the overflow of the station bus network. Because the high data rate traffic which is required by the protection and control equipment is contained by the process bus. Researchers [10,20,21,22,23] have proposed the architectures which merges the process bus and station bus. Reducing the number of switches used could be the one possible reason for this. Merging of the process bus and station bus by using HSR and PRP redundancy is provided by the researchers additionally in [23]. Factors such as the actual application requirements and IED limitations play an important role in the decision to use either separated or merged process bus and station bus design.
Many researchers have studied the reliability of the IEC 61850-Based substation. IEC 61850 standards have left the redundancy design of the communication system to substation design engineering. The hierarchical structure of the substation automation system provided by IEC 61850 includes three levels—Process Level, Bay Level, and Station Level. Between the Station and Bay Level lies Station Bus. Process Level comprises primary equipment in the switchyard, such as CT/VT and circuit breakers, and provides instantaneous status, signals from instrument transformers, and control data exchanges between Bay Level and Process Level.
Bay Level consists of protection and control IEDs for each bay and provides protection data and control data exchange between the bays, Process Level, and Station Level. Station Level lays out functions related to the overall operation of the equipment in the substation. The functions use data from different bays, so the data exchange between Station Level and Bay Level. Station Bus acts as a communication channel between Station Level and Bay Level, which provides the data exchange for different bays and between local controls. Process Bus is the communication channel between Process Level and Bay Level such that data from CT/VT can transmit to P & C IEDs and to GOOSE messages gradually to control the circuit breaker. A block diagram showing the communication between Intelligent Electronics Devices (IEDs) through GOOSE signal is presented in Figure 3.

2.1. Method of IEC 61850

IEC 61850 has used three methods:
  • Functional decomposition—to understand the logical relationship between components of a distributed function. They are presented in terms of logical nodes to describe the functions, sub-functions, and functional interfaces.
  • Data Flow—helps to understand the communication interfaces supporting the information exchange between distributed functional components and functional performance requirements.
  • Information Modelling—defines the abstract syntax and semantics of the information exchanged presented in terms of data object classes, attributes, etc.
The object-oriented method has been used by IEC 61850 to define the hierarchical data model for the communication network and physical object of the substation that includes the primary equipment, secondary equipment, control, measure, and protection functions.
IEC 61850 application functions have perished into small entities (called logical nodes). Logical Nodes (LN) are a named group of data and associated services that virtually represent the power system functions. An LN comprises data objects and attributes containing the status, information, settings, etc., related to the real applications. LD models, which provide the properties and allocation of functions in a physical device model, can be build up using several logic nodes. The physical device is the hardware and operating system that connects to the network through its network address. IEC 61850 defines the abstract services to access and exchange data for power control, protection, and monitoring within the substation automation system. The Abstract Communication Service Interface (ACSI) has been defined in the IEC 61850 standard Part 7-2. ACSI operates above the OSI 7 Layer model, provides the abstract interfaces for communication services, and defines the common utility services for substation and feeder applications. A typical IEC 61850 architecture is shown in Figure 4.

2.2. IEC-61850 Communication Protocol Challenges and Limitations

For the implementation of IEC-61850 Communication Protocol there are some important types of Challenges and limitations in Digital substations.
Challenges:
  • Very high Costly Equipment
  • Issues of time Synchronization between relays and substation
Limitation:
  • Lack of availability of trained human personal
  • Concern of Existing Infrastructure of substation

2.3. Experimental Demonstration of Even & Odd Harmonic Blocking

A hardware model is developed in Smart Energy Systems Automation Laboratory, Department of Electrical Engineering, Jamia Millia Islamia, New Delhi, India for blocking even and odd harmonics in power transformers as shown in Figure 5. The following substation equipment and software are included in the entire hardware model.
  • Siemens, Differential Relay, 7UT61
  • Siemens, Over-current relay, 7SJ64
  • Omicron CMC 256-6 testing kit
  • ABB- AFS677, RUGGEDCOM, Ethernet
  • DIGSI4, Omicron Test Universe 2.11, IED set-up software
  • For testing and monitoring purposes, a personal computer is used
The hardware model is developed according to the IEC-61850 protocol. To install the hardware, we have interfaced both the relays (differential and over-current) to Ethernet via LAN cable. And another LAN cable is connected to the PC via Ethernet. Through this LAN cable, commands signal to relay and Omicron kit. Omicron kit and both relays are connected to single-phase supply, and Ethernet is connected at 25 V DC supply. GOOSE messages have an important role in harmonic blocking. Both differential and over current relays communicate through GOOSE message. Further, the complete operation of the developed hardware model for blocking both the even and odd harmonics in power transformers is presented in the flowchart as shown in Figure 6.

3. Experimental Results Demonstration

In this section, we have discussed the even-odd harmonics blocking in power transformer. The harmonic blocking scheme is implemented to prevent the operation of the 7SJ64 overcurrent element during the transformer magnetizing inrush current conditions. Omicron CMC 256-6 test set is used to inject the inrush currents into the differential relay, 7UT61. The RUGGEDCOM Ethernet switch links the two protective IEDs with the personal computer and the CMC 356 test via a virtual local area network (VLAN). To block the even/odd harmonics in power transformer a harmonic blocking signal is transmitted as a GOOSE message through the Ethernet kit, ABB AFS677. A sample representation of the even-harmonic blocking signal in L1, L2 and L3 as a GOOSE message is shown in Figure 7. The hardware model developed shows that the harmonics or any undesirable effects produced in power transformers can be identified quite fast through GOOSE message of IEC-61850, which communicates to other relay and blocks the harmonics in power transformer.

3.1. Experimental Results Demonstration for 2nd Harmonic Diagnosis

In this work, we have taken a 160 MVA power transformer for harmonic blocking, with a primary voltage of 220 kV on one side and 132 kV on side two. Rated frequency of this transformer is 50 Hz and phase sequence L1L2L3. The pickup value of differential current is set to 0.20 I/InO, pickup value of high set trip is taken as 7.5 I/InO and CT ratio is set to 500:1 at the primary side and secondary side respectively.
The results presented in this section demonstrate second harmonic blocking method to ensure safety during energization of both the IEDs (7UT61 and 7SJ64) for transformers. As per the demonstration of the results, Figure 8, Figure 9, Figure 10, Figure 11, Figure 12, Figure 13, Figure 14, Figure 15, Figure 16, Figure 17, Figure 18, Figure 19, Figure 20, Figure 21 and Figure 22 shows second harmonic tripping. In these figures, x-axis shows harmonic frequency and y-axis shows the current value (i). Every figure shows different parameters which are visible on the top of upper left side of each figure, these include,
  • time (ms)
  • measuring signal
  • RMS value (A)
  • DC component (%)
  • even/odd-harmonics (%)
Here time in ms means relay tripping time, when the inrush current is increased in power transformer as per the set values then the relay trips due to second harmonic. Measuring signals are of four types which include iL1-M2, iL2-M2, iL3M2, and 3i0-M2 and these represent three phases and neutral respectively. Corresponding to these signals the RMS value and DC component are also shown in the figures. Since, in this section we are only dealing with the second harmonic blocking therefore only second harmonic (in %) are shown in these figures while as other harmonics (3rd and 5th) are zero. Further, the values of all these parameters for second harmonic blocking at different values of rated current (1000 mA to 5000 mA) are also presented in Table 1. Corresponding to the particular rated current the inrush current condition is varied in the range from 15% to 20% to perform the 2nd harmonic blocking in the power transformer.
In the present study, nine cases (I–IX) have been analyzed for 2nd harmonic blocking with each case being subjected to five values of inrush current condition. The results obtained for all the cases are tabulated in Table 1. From the table it can be observed that the RMS value (A), DC component (%) and 2nd harmonics (%) depends upon the type of measuring signal (phase) and inrush current value. However, the graphical retresentation is shown only for few cases (I, III, V, VII and IX) so as to avoid the unnecessary increase in length of the paper. In these cases the 2nd harmonic blocking is performed at inrush current values in the range from 15–20% of the rated current values which include 1000 mA, 2000 mA, 3000 mA, 4000 mA, and 5000 mA.
Figure 8, Figure 9 and Figure 10 shows second harmonic blocking at inrush current values of 15%, 18% and 20% and rated current which is 1000 mA for case I. The upper half of the figures represents high voltage (HV) side denoted by M1 while as lower half represents medium voltage (MV) side which is denoted by M2. From the figures, it can be observed that the inrush current is composed of 14.1%, 14.2% and 14.2% of 2nd harmonic content and 0.2%, 0.2% and 0.1% of DC component in L1, L2 and L3 respectively. Due to these components the RMS value increases, as is also evident from the table, which will ultimately result into increased losses in core as well as windings of the power transformer. Further, the DC component elimination is a very challenging task. However, the DC component of the inrush current is very low on the M2 side as compared to the M1 side. Therefore, the proposed methodology performs harmonic blocking on the M2 side of the device while employing differential relay-7UT61’s harmonic restraint function to deliver a blocking signal to the over-current relay-7SJ64 in order to prevent its tripping during inrush current condition.
Consequently, Figure 11, Figure 12, Figure 13, Figure 14, Figure 15, Figure 16, Figure 17, Figure 18, Figure 19, Figure 20, Figure 21 and Figure 22 show second harmonic blocking at rated current values of 2000 mA, 3000 mA, 4000 mA, and 5000 mA for cases III, V, VII and IX respectively. In each case, three graphical representations are presented at inrush current condition of 15%, 18% and 20%. The figures show that the harmonic content in transformer inrush current increases with the increase in rated current. However, the DC component doesn’t show much variation. It varies in the range of 0.0–0.2% mostly and goes up to 0.5% rarely. The RMS value also shows enhancement with the increase in inrush current components. It can be concluded, that the results of the IEC 61850 GOOSE message-based simulation prove.
That the harmonic blocking scheme can be employed to prevent the tripping or blocking of the 7SJ64 relay due to the transformer magnetization inrush current condition.

3.2. Experimental Results Demonstration for 5th Harmonic Diagnosis

In this section, we have discussed the fifth harmonics blocking in power transformer. To demonstrate the experimental results the hardware set up discussed in above section is used. The results presented in this section demonstrate fifth harmonic blocking method to ensure security of power transformers during over-excitation condition. In this part, only one case has been analysed to perform the fifth harmonic blocking process in power transformers at different values of the inrush current. The results obtained are shown in Table 2. The table shows rated current (mA), inrush current (mA), RMS value (A), DC component (%) and fifth harmonic (%). For a particular rated current the inrush current is varied in the range from 35–40% to perform the fifth harmonic blocking in the power transformer as shown in Table 2.
The graphical representations of the obtained results at different values of inrush current are shown in Figure 23, Figure 24, Figure 25, Figure 26, Figure 27 and Figure 28. In each figure the upper half represents high voltage (HV) side denoted by M1 where as lower half represents medium voltage (MV) side which is denoted by M2. As we know that the DC component of the inrush current is very low on the M2 side as compared to the M1 side. Therefore, the proposed fifth harmonic blocking analysis is performed on the M2 side. Figure 23 shows fifth harmonic blocking at an inrush current value that is 35% and rated current which is 1000 mA. That means the inrush curent condition is applied at 250 Hz frequency. From the figure, it can be observed that the inrush current is composed of 21.7%, 21.8% and 21.8% of fifth harmonic content and 0.0%, 0.0% and 0.1% of DC component in L1, L2 and L3 respectively. Due to the presence of these components the RMS value increases, as is also evident from the Table 2, which will further losses in core as well as windings of the power transformer.
Similarly, Figure 24, Figure 25, Figure 26, Figure 27 and Figure 28 show fifth harmonic blocking at inrush current values of 35–40% and the rated current of 1000 mA respectively. The figures show that the harmonic content increases with the percentage increase in inrush current. However, the DC component doesn’t show any significant variation. It varies in the range of 0.0–0.2%. However, the DC component may go beyond 0.2% if rated current is increased as has been observed in section A. The RMS value also shows enhancement with the increase in inrush current components. From graphical results it is evident the setup shows proper blocking of fifth harmonics at different values of inrush current.

4. Conclusions and Future Scope

In this article, a hardware model comprising of IEDs, Omicron kit, Siemens’ differential relay-7UT61, over-current relay-7SJ64, ABB-AF677 Ethernet according to the IEC 61850 protocol is developed to block the even-odd harmonics in power transformers. With the help of the proposed model, we have blocked even (2nd) and odd (5th) harmonics produced in differential protection and the over-current protection relay. Second harmonics are blocked when the inrush current exceeds up to 15%, similarly, when the inrush current exceeds up to 35%, then the 5th harmonics are blocked. During the transformer magnetizing inrush current condition, the scheme uses IEC 61850 GOOSE messaging to send a harmonic blocking scheme from the 7UT61 differential IED to the 7SJ64 over-current IED.
Presently, mostly electric substation power transformer does not interface to IEC-61850 communication. The use of IEC 61850 to protect electric instruments of electric substations is quite fast, accurate, economical, efficient and reliable as compared to conventional protection. The power transformer is one of the most important & costly equipment in an electric substation. By using IEC-61850 protocols Based proposed model, harmonics problems in the transformer are prevented and transformer are protected from failures. In the future, using IEC 61850, more than two relays can communicate and sense any faults and trip the relay.

Author Contributions

Conceptualization, A.A., M.J. and H.M.; methodology, A.A. and M.J.; software, A.A.; validation, A.A. and M.J.; formal analysis, A.A.; investigation, A.A.; resources, A.A.; data curation, A.A.; writing—original draft preparation, A.A.; writing—review and editing, A.A. and R.A.T.; visualization, A.A.; supervision, M.J.; project administration, M.J.; funding acquisition, S.Q. All authors have read and agreed to the published version of the manuscript.

Funding

Deanship of Scientific Research, King Khalid University, Abha, Saudi Arabia financial and technical support under Grant Number G.R.P 338/1442.

Acknowledgments

The authors would like to submit their gratefulness to Deanship of Scientific Research, King Khalid University, Abha, Saudi Arabia for providing administrative, financial and technical support under Grant Number G.R.P 338/1442.

Conflicts of Interest

The authors declare no conflict of interest.

Appendix A

Table
Table A1. Literature summary on harmonics detection & blocking.
Table A1. Literature summary on harmonics detection & blocking.
Ref. & YearType of ApplicationTopologies/Analyzed MethodsMain Contribution and Characteristics
[4], (2014)Electric Power Substation (EPS)Simulation, Modelling, performance of the network, OPNET Modeler, SCADADevice Communication between inside and outside the substation, IEC 61850-IEEE 802.3, GOOSE message
[5], (2015)Process bus of IEC-61850Kalman filter, True Time software, Matlab SimulinkCommunication Sampled Measured Values, delay or loss sampled value, harmonic produced in microprocessor-Based protection technology, noise covariance satisfies the TVE criteria in IEEE C37.118,
[6], (2018)Distance relay, transmission linefield programmable
gate arrays (FPGAs), Full-cycle discrete Fourier transform (FCDFT), half-cycle DFT (HCDFT)		phase let-Based distance relaying method, phase & magnitude angle, FPGA provide fast computation speed, Ethernet-Based GOOSE message as per the IEC-61850, HCDFT loss the ability to reject even harmonics,
[7], (2017)Power transmission, Laboratory study IEC-61850, measurement systemIEC 61850 used in power transmission and improving control and protection, BRICK and transmission system Based on fiber-optic connections through Ethernet, Omicron & CMC 256 used for harmonics, harmonic distribution by using a harmonic module
[8], (2018)Transformer differential relayDifferential protection, IEC 61850Physical differential relay under analysis, cover all possible protection problems, developed inside real-time digital simulator, cross & over excitation second and fourth harmonic, blocking, restrained harmonic differential (BHRD)-87HR, harmonic blocking differential (HBD)-87HB, 24HBL—second and fourth harmonic blocking
[9], (2019)Power transformerIEC-61850, laboratory Test, differential protectionHarmonic block due to transformer magnetizing inrush current, second & fifth harmonic block, installation, and maintenance cost reduced due to IEC-61850, analyzed GOOSE message,
[4,24], (2021)Smart grid,
Microgrid, prediction of fault		Fault prediction, different network types, ANN, RNN, Wavelet filter Investigated fault location in Distribution Network (DN), fast fault recovery, and Wavelet transform have been used for third harmonics fault detection.
[25], (2020)Distributed generators, micro gridDistributed generator (DG), Micro grid Conventional and not conventional in a micro grid, IEEE Standard C37.2-2008 for conventional protection scheme, PV array and converter not synchronism & produced harmonics
[26], (2019)Process Bus SystemOver sampling (OS), sampling synchronization (SS), GPS time synchronizationThe SV’s (sampled value) high-speed publication pace, protection, automation, and control (PAC) applications like security and harmonic monitoring require certain frequency ranges
[27], (2020)Micro GridBlackout, On-grid black-start, Off-grid black-startGeneral guidelines for the established micro grid, Small faults are created in the different micro grid due to harmonics.
[28], (2015)system of multi-fold distributionAdvanced Metering Infrastructure (AMI), Distribution Automation (DA)Two-way communication through AMI, block harmonic through GOOSE message, Load segment (LS) show THD
[29], (2011)transmission and distribution networks (T & D)Global Positioning System (GPS), Phasor Measurement Unit, PTP (Precision Time Protocol)Intelligent Electronics Device (IEDs) play an important role in T & D system, synchronization between
IEDs for control & protection of systems, breaker operation within milliseconds & fault detection, combined network of communication network & GPS excellent accuracy,
[30], (2020)Power Transformer protectionHardware-in-the-loop test, dynamic state estimationDynamic state estimation (DSE) Rated approach regular check health status of a transformer, transformer energization due to harmonics, second and fourth harmonic higher when transformer energization, second harmonic block level 20%,
[31], (2017)Smart power gridSCADA system, MATLAB/Simulink, OMNET++ simulator, Denial of Service (DoS)IEC-61850 communication protocol implemented, smart grid secure and self-healing and recovery, analyzed and testing of Smart grid (SG) core, network, and components, analyzed harmonics issue in Smart power grid, Electrical Transient Analyzer Program (ETAP) software for analyzed harmonics
[32], (2017)Digital substation process busfield-programmable gate array (FPGA)Sampled value of transmission line error electronics transformer, Ethernet communication channel, time offset and time delay in the communication network, different time delay created by the harmonic component
[33], (2007)Overhead lines
Protection, transmission line		IEC-61850, arc Modelling, laboratory
test		a numerical algorithm for transmission lines protection, fault location in the transmission line, a fast communication channel between two IEDs installed at line terminal, suddenly fault in the transmission line could result in an arc and arc was thought to be a cause of high harmonics.
[34], (2015)Digital Substation Ethernet, IEC-61850 communication ProtocolEthernet-Based communication used in the substation of different venders, Real-time data, harmonic block or transformer through differential function, Ethernet integrate between two IEDs, cost-saving to use the IEC-61850
[35], (2016)Electricity substationField Programmable Gate Array (FPGA), Supervisory Control and Data Acquisition (SCADA), VHSIC Hardware Description Language (VHDL)GOOSE communication network in the substation for monitoring control & protection, IEC 61850 standards cost-effective alternative to parallel copper wiring, reduced overall cost, GOOSE message on FPGA platform, SVs used for transmitting VI (voltage/current) transformer, protection Based on over Ethernet, power system disturbance due to distorted voltage & current signals, transformer heating due to harmonics, generate 2nd & 3rd harmonic, published VI signals during the harmonic disturbance,
[36], (2019)MicrogridReal-Time Digital Simulator (RTDS), hardware-in-the-loop (HIL), IEC-61850Integrate renewable energy source into disturbance network, decentralized adaptive security approach MVAC micro grid, high-speed fault clearing through Hybrid Permissive Overreaching Transfer Trip (HPOTT) and Fast Bus Tripping (FBT), low pass filter removes harmonics
[37], (2008)Power substationsElectrical Power Communication
Synchronization Simulator (EPOCHS), Supervisory Control and Data Acquisition (SCADA)		International Electrotechnical Commission (IEC) 61850 and Utility Communication Architecture 2.0 laid the foundation & used in substation, EPOCHS used for run simulation, benefits of utility communication, 48 different simulations configure, power quality of system depends upon the harmonics,
[38], (2012)Electric Substation, transformerMatlab, IEC-61850, Four Steps Phase Overcurrent Protection (OC4PTOC)Process bus communication interface with light-weight MU testing environment, Sampled value service from the communication interface, generate 2nd harmonic due to over excitation of the transformer, 2nd harmonic restrain function, 2nd harmonic content of the inrush current, 2nd harmonic introduced with a fault during 20–25 s to test the 2nd harmonic constraint in the OC4PTOC function, OC4PTOC not trip during 20–25 s, trip after 25 s,
[39], (2018)Electrical distribution networks (EDN)
with distributed generation (DG)		SCADA, Customer Information System (CIS), Geographic Information System(GIS), Advanced Metering Infrastructure (AMI), Enterprise Asset Management (EAM),Power quality is an important key to any electrical system. Power quality depends on availability, wave quality, and commercial quality, IEC-61850 GOOSE service used to facilitate adaptive 67/67N protection arrangement, Combining technologies BPLC and IEC 61850 GOOSE service improve recovery times, power quality divided such as sag, wells, transients, harmonics, negative effect on the electrical system,
[40], (2015)Digital Substation Automation System (SAS) IED Scout, Vamp set configuration tool, Fault analyzer software, ABB PCM 600 IED configuration tool, CMC GOOSE, OPNET, reliability, and probability of failure estimation algorithm
(RaFSA)		Issue of IEC-61850 implementation in SAS, different venders & different equipment issues, real-time information available & access through IEC-61850, RaFSA is suitable for analysis & reliability of damaged any device, AC power systems are always in a steady-state and can have flaws like harmonic distortion, sags, and swells, among other things, IEC-61850 standard is used to increase the power quality so that harmonics can generate less
[41], (2019)Smart gridVirtual Merging Units, IEC 61850, Test Evaluation toolPower quality, recoding, and protection function is available in IEC-61850, IEC 61850-9-3 allows for time synchronization precision of less than one microsecond, harmonics available or generate in any system to affect the power quality
[42], (2015)FACTS Controllers in IEC 61850, Static
VAR Compensator, SVC		SCADAFACTS devices using in IEC-61850, more logical nodes is required in IEC-61850 for other extensions, the extension of IEC 61850 with Modelling of FACTS, HVDC and Power conversions, Harmonic filters usually passive, those are used to increase voltage stability, filter harmonics, and reduce resonance issues in the system, Shunt connected FACTS devices typically include one or more harmonic filters and control shunt coupled reactor or capacitor branches, ZHAF = Harmonic Filter
[43], (2011)SubstationSCADA, IEC-61850, AutoCad®, CoDeSys, Siemens Step7®, Factory Link® and
ISaGRAF®, EnerVistaTM		Software and hardware manufacturers supporting the electric utility sector gathered at Clamart, France, to test their products’ capacity to share data and correctly interpret data Based on the IEC 61850 set of standards. Interoperability in the following areas was the focus of these tests, exchanging configuration information through SCL language, communication services specified by IEC-61850-7-2, 8-1, 9-2LE. Exchange on harmonic information, inrush current increased & energized transformer block 2nd & 5th harmonic.
[44], (2015)Substation
Protection and Control		Optical Current and Voltage Sensors, Rogowski Coils as Current Sensor, Intelligent Merging Unit, iSAS, SCADACentralized protection and control (CPC), availability of standardized communication technology, advancements in sensor, merging unit, and remote I/O technologies enable the simple gathering of power system data at any place inside a substation, regardless of the location of protection and control equipment. Sending GOOSE message one IEDs to another over the optical fiber Ethernet link. Problems in power quality due to voltage sag, interruption, harmonic, transient. Power quality (PQ) monitoring and investigation conform to international standards IEC 61000-4-30 and IEC 61000-4-7.

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Energies 14 08284 g001 550
Figure 1. Different types of condition monitoring of transformers.
Figure 1. Different types of condition monitoring of transformers.
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Figure 2. Types of harmonics and their effect on power transformer.
Figure 2. Types of harmonics and their effect on power transformer.
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Figure 3. GOOSE communications between lEDs.
Figure 3. GOOSE communications between lEDs.
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Figure 4. IEC 61850 typical architecture.
Figure 4. IEC 61850 typical architecture.
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Figure 5. Hardware set-ups with current differential function for power transformer Harmonic Blocking.
Figure 5. Hardware set-ups with current differential function for power transformer Harmonic Blocking.
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Figure 6. Flowchart depicting the Harmonic Blocking.
Figure 6. Flowchart depicting the Harmonic Blocking.
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Figure 7. Relay trip during harmonic blocking signal (GOOSE message) recorded by IEDs.
Figure 7. Relay trip during harmonic blocking signal (GOOSE message) recorded by IEDs.
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Figure 8. 2nd HB at 1000 mA Rated current & 15% of Inrush current condition.
Figure 8. 2nd HB at 1000 mA Rated current & 15% of Inrush current condition.
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Figure 9. 2nd HB at 1000 mA Rated current & 18% of Inrush current condition.
Figure 9. 2nd HB at 1000 mA Rated current & 18% of Inrush current condition.
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Figure 10. 2nd HB at 1000 mA Rated current & 20% of Inrush current condition.
Figure 10. 2nd HB at 1000 mA Rated current & 20% of Inrush current condition.
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Figure 11. 2nd HB at 2000 mA Rated current & 15% of Inrush current condition.
Figure 11. 2nd HB at 2000 mA Rated current & 15% of Inrush current condition.
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Figure 12. 2nd HB at 2000 mA Rated current & 18% of Inrush current condition.
Figure 12. 2nd HB at 2000 mA Rated current & 18% of Inrush current condition.
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Figure 13. 2nd HB at 2000 mA Rated current & 20% of Inrush current condition.
Figure 13. 2nd HB at 2000 mA Rated current & 20% of Inrush current condition.
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Figure 14. 2nd HB at 3000 mA Rated current & 15% of Inrush current condition.
Figure 14. 2nd HB at 3000 mA Rated current & 15% of Inrush current condition.
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Figure 15. 2nd HB at 3000 mA Rated current & 18% of Inrush current condition.
Figure 15. 2nd HB at 3000 mA Rated current & 18% of Inrush current condition.
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Figure 16. 2nd HB at 3000 mA Rated current & 20% of Inrush current condition.
Figure 16. 2nd HB at 3000 mA Rated current & 20% of Inrush current condition.
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Figure 17. 2nd HB at 4000 mA Rated current & 15% of Inrush current condition.
Figure 17. 2nd HB at 4000 mA Rated current & 15% of Inrush current condition.
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Figure 18. 2nd HB at 4000 mA Rated current & 18% of Inrush current condition.
Figure 18. 2nd HB at 4000 mA Rated current & 18% of Inrush current condition.
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Figure 19. 2nd HB at 4000 mA Rated current & 20% of Inrush current condition.
Figure 19. 2nd HB at 4000 mA Rated current & 20% of Inrush current condition.
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Figure 20. 2nd HB at 5000 mA Rated current & 15% of Inrush current condition.
Figure 20. 2nd HB at 5000 mA Rated current & 15% of Inrush current condition.
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Figure 21. 2nd HB at 5000 mA Rated current & 18% of Inrush current condition.
Figure 21. 2nd HB at 5000 mA Rated current & 18% of Inrush current condition.
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Figure 22. 2nd HB at 5000 mA Rated current & 20% of Inrush current condition.
Figure 22. 2nd HB at 5000 mA Rated current & 20% of Inrush current condition.
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Figure 23. 5th HB at 1000 mA Rated current & 35% of Inrush current condition.
Figure 23. 5th HB at 1000 mA Rated current & 35% of Inrush current condition.
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Figure 24. 5th HB at 1000 mA Rated current & 36% of Inrush current condition.
Figure 24. 5th HB at 1000 mA Rated current & 36% of Inrush current condition.
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Figure 25. 5th HB at 1000 mA Rated current & 37% of Inrush current condition.
Figure 25. 5th HB at 1000 mA Rated current & 37% of Inrush current condition.
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Figure 26. 5th HB at 1000 mA Rated current & 38% of Inrush current condition.
Figure 26. 5th HB at 1000 mA Rated current & 38% of Inrush current condition.
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Figure 27. 5th HB at 1000 mA Rated current & 39% of Inrush current condition.
Figure 27. 5th HB at 1000 mA Rated current & 39% of Inrush current condition.
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Figure 28. 5th HB at 1000 mA Rated current & 40% of Inrush current condition.
Figure 28. 5th HB at 1000 mA Rated current & 40% of Inrush current condition.
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Table
Table 1. Harmonics blocking in lines (L1, L2, & L3).
Table 1. Harmonics blocking in lines (L1, L2, & L3).
Case(s)Rated Current, Rc (mA)Injected Inrush Current Condition (%)Measurement Signal R.M.S. (A)DC Component (%)2nd Harmonic (%)
I100015iL1-M21.00990.214.1
iL2-M21.01040.214.2
iL3-M21.00970.114.2
16iL1-M21.01190.215.2
iL2-M21.01250.215.1
iL3-M21.01120.115.1
17iL1-M21.01350.416.0
iL2-M21.01330.316.1
iL3-M21.01240.016.1
18iL1-M21.01450.517.0
iL2-M21.01500.317.0
iL3-M21.01450.117.0
19iL1-M21.01600.217.9
iL2-M21.01670.117.9
iL3-M21.01590.018.1
20iL1-M21.01760.218.9
iL2-M21.01830.118.9
iL3-M21.01800.018.8
II150015iL1-M21.51450.214.2
iL2-M21.51600.114.2
iL3-M21.51440.014.2
16iL1-M21.51630.115.1
iL2-M21.51820.115.1
iL3-M21.51640.115.1
17iL1-M21.51820.216.1
iL2-M21.52020.116.1
iL3-M21.51860.016.1
18iL1-M21.52200.217.0
iL2-M21.52240.117.0
iL3-M21.52070.017.0
19iL1-M21.52380.117.9
iL2-M21.52530.018.0
iL3-M21.52360.018.0
20iL1-M21.52670.218.9
iL2-M21.52760.118.9
iL3-M21.52560.018.9
III200015iL1-M22.02040.214.2
iL2-M22.02100.114.1
iL3-M22.01860.014.2
16iL1-M22.02240.115.1
iL2-M22.02350.115.2
iL3-M22.02150.115.1
17iL1-M22.02470.216.0
iL2-M22.02720.116.1
iL3-M22.02440.116.1
18iL1-M22.02810.117.0
iL2-M22.02930.117.0
iL3-M22.02770.017.0
19iL1-M22.03140.118.0
iL2-M22.03310.118.0
iL3-M22.03090.018.
20iL1-M22.03590.118.9
iL2-M22.03560.118.9
iL3-M22.03360.118.9
IV250015iL1-M22.52470.114.2
iL2-M22.52570.114.2
iL3-M22.52300.114.1
16iL1-M22.52780.215.1
iL2-M22.52930.115.1
iL3-M22.52620.115.1
17iL1-M22.53110.116.1
iL2-M22.53240.116.1
iL3-M22.53010.116.1
18iL1-M22.52600.217.0
iL2-M22.53670.117.0
iL3-M22.53360.117.0
19iL1-M22.54010.117.9
iL2-M22.54020.118.0
iL3-M22.53840.118.0
20iL1-M22.54380.218.9
iL2-M22.54490.118.9
iL3-M22.54240.118.9
V300015iL1-M23.02980.114.2
iL2-M23.03150.114.2
iL3-M23.02710.014.2
16iL1-M23.03350.115.1
iL2-M23.03440.115.1
iL3-M23.03160.115.1
17iL1-M23.03810.216.1
iL2-M23.03850.216.1
iL3-M23.03580.116.0
18iL1-M23.04250.217.0
iL2-M23.04320.117.0
iL3-M23.03990.117.0
19iL1-M23.04690.217.9
iL2-M23.04840.118.0
iL3-M23.04540.118.0
20iL1-M23.05230.218.9
iL2-M23.05450.118.9
iL3-M23.05030.118.9
VI350015iL1-M23.53520.114.2
iL2-M23.53560.114.2
iL3-M23.53120.114.2
16iL1-M23.53900.215.1
iL2-M23.54080.115.1
iL3-M23.53640.115.1
17iL1-M23.54330.116.1
iL2-M23.54590.116.1
iL3-M23.54050.116.1
18iL1-M23.54960.217.0
iL2-M23.55110.117.0
iL3-M23.54700.117.0
19iL1-M23.55510.217.9
iL2-M23.55630.117.9
iL3-M23.55300.118.0
20iL1-M23.56140.218.9
iL2-M23.56250.118.9
iL3-M23.55840.118.9
VII400015iL1-M24.03870.214.2
iL2-M24.04100.114.2
iL3-M24.03650.114.2
16iL1-M24.04510.215.1
iL2-M24.04590.115.1
iL3-M24.04170.115.1
17iL1-M24.05010.216.1
iL2-M24.05170.116.1
iL3-M24.04800.116.1
18iL1-M24.05690.217.0
iL2-M24.05780.117.0
iL3-M24.05400.117.0
19iL1-M24.06260.217.9
iL2-M24.06380.118.0
iL3-M24.06050.118.0
20iL1-M24.06990.218.9
iL2-M24.07090.118.9
iL3-M24.06740.118.9
VIII450015iL1-M24.54330.214.2
iL2-M24.54590.114.2
iL3-M24.54180.114.2
16iL1-M24.54960.215.1
iL2-M24.55210.115.1
iL3-M24.54730.115.1
17iL1-M24.55660.216.1
iL2-M24.55840.116.1
iL3-M24.55380.116.1
18iL1-M24.56300.217.0
iL2-M24.56530.117.0
iL3-M24.56060.117.0
19iL1-M24.57080.217.9
iL2-M24.57190.118.0
iL3-M24.56760.117.9
20iL1-M24.57860.218.9
iL2-M24.58040.118.9
iL3-M24.57540.118.9
IX500015iL1-M25.04840.214.2
iL2-M25.05080.114.2
iL3-M25.04570.114.2
16iL1-M25.05550.215.1
iL2-M25.05800.115.2
iL3-M25.05240.115.1
17iL1-M25.06260.216.1
iL2-M25.06480.116.1
iL3-M25.06010.116.1
18iL1-M25.07060.217.0
iL2-M25.07280.117.0
iL3-M25.06780.117.0
19iL1-M25.07880.218.0
iL2-M25.08010.118.0
iL3-M25.07600.117.9
20iL1-M25.08710.218.9
iL2-M25.08890.118.9
iL3-M25.08480.118.9
Table
Table 2. Fifth harmonics blocking in lines (L1, L2, & L3).
Table 2. Fifth harmonics blocking in lines (L1, L2, & L3).
Rated Current Rc (mA)Injected Inrush Current Condition (%)Measurement Signal R.M.S. (A)DC Component (%)5th Harmonic (%)
100035iL1-M21.02230.021.7
iL2-M21.02420.021.8
iL3-M21.02370.121.8
36iL1-M21.02370.222.3
iL2-M21.02650.122.5
iL3-M21.02490.022.5
37iL1-M21.02600.123.0
iL2-M21.02740.123.1
iL3-M21.02540.023.1
38iL1-M21.02760.123.5
iL2-M21.02870.023.7
iL3-M21.02730.023.7
39iL1-M21.02860.224.2
iL2-M21.03010.124.4
iL3-M21.02900.124.3
40iL1-M21.03010.224.8
iL2-M21.03210.025.0
iL3-M21.03030.025.0
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Azeem, A.; Jamil, M.; Qamar, S.; Malik, H.; Thokar, R.A. Design of Hardware Setup Based on IEC 61850 Communication Protocol for Detection & Blocking of Harmonics in Power Transformer. Energies 2021, 14, 8284. https://doi.org/10.3390/en14248284

AMA Style

Azeem A, Jamil M, Qamar S, Malik H, Thokar RA. Design of Hardware Setup Based on IEC 61850 Communication Protocol for Detection & Blocking of Harmonics in Power Transformer. Energies. 2021; 14(24):8284. https://doi.org/10.3390/en14248284

Chicago/Turabian Style

Azeem, Abdul, Majid Jamil, Shamimul Qamar, Hasmat Malik, and Rayees Ahmad Thokar. 2021. "Design of Hardware Setup Based on IEC 61850 Communication Protocol for Detection & Blocking of Harmonics in Power Transformer" Energies 14, no. 24: 8284. https://doi.org/10.3390/en14248284

APA Style

Azeem, A., Jamil, M., Qamar, S., Malik, H., & Thokar, R. A. (2021). Design of Hardware Setup Based on IEC 61850 Communication Protocol for Detection & Blocking of Harmonics in Power Transformer. Energies, 14(24), 8284. https://doi.org/10.3390/en14248284

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