Substation automation

Smart grid implementations rely on the real-time monitoring and controlling of the electric power grid. To achieve real time there is need for a messaging system with minimum delays. After mentioning latest implementations and their delays we analyze the role of the different communication protocols needed within smart grids and we describe key factors to a message's delay. Taking into consideration a packet's speed constraints we then calculate a radius, within which, the ETSI communication requirements for smart grids are satisfied.

IEC61850 is the mainstream of the development for substation automation. This paper presents a practical consideration and analysis for implementing a secure sampled measured value (SeSV) message in substation automation system. Due to the lack of security features in the standard, IEC Working Group 15 of Technical Committee 57 published IEC62351 on security for IEC61850 profiles. However, the use of authentication methods for SV based on IEC62351 standards are still not integrated, and computational capabilities and performance are not validated and tested with commercial grade equipment. Hence, this paper shows the performance of security feature enabled SeSV packets transmitted between protection and control devices by appending a message authentication code (MAC) to the extended IEC61850 packets. A prototype implementation on a low cost commodity embedded system has proved that the MAC-enabled SV message can fully secure the process bus communication in the digital substation with negligible time delay.

The increase of cyber-attacks on industrial and power systems in the recent years make the cybersecurity of supervisory control and data acquisition and substation automation systemsa high important engineering issue. This paper proposes a defense in depth cybersecurity solution for smart substations in different layers of the substation automation system. In fact, it presents possible vulnerabilities in the substation automation system and propose a multiple layer solution based on best practice in cyber security such as the hardening ofdevices, whitelisting, network configuration, network segmentation, role-based account management and cyber security management and deployement. 1. INTRODUCTION The power grid is a national critical infrastructure that plays an important pillar for the development of a nation, when electricity stops everything stop. The growth of power grid and the use of communication technologies make it vulnerable to cyber-attacks, terrorist attacks, vandalism and other threats. According to National Institute of Standards and Technology NIST the threats of cyber-attacks on Supervisory control and data acquisition SCADA has increased four times in the last years. The first attack on a power grid was the attack on a Ukrainian utility (Ivano-Frankivsk) SCADA in December 2015. First, the hacker got access to the SCADA and started disabling the power backup system. Then, he blocked the customer call centres. Finally, he started opening circuit breakers and deleting user's accounts which prevent the operators from closing the circuit breakers to restore normal state. the damages of these attack were a disconnection of 30 substations which impacted 225 000 customers for 3 hours [1]. The impact of this attack shows the necessity of taking actions to secure the power grid against cyber-attacks. Substations are the hearth of the power grid, and the security of the power grid needs to be done first at the substations level. As new modern substations or smart substations are based on IEC61850 standards and Ethernet communication; also, they are connected to SCADA and corporate network, which make them more vulnerable to cyber-attacks [2]. Recently, the cyber security in substations has received more and more attention [3]-[4]. There have been many researches and actions on the cybersecurity of substations. In fact, the Technical Committee Number 57 TC57 of the International Electrotechnical Commission IEC has already developed several standards to solve security problems in the automation system IEC 62351 standards for Power systems management and associated information exchange-data and communications security [5]-[6]. The IEC 62443 standard defines security for industrial control systems of the power systems. These standards give a guideline on how to apply cybersecurity in operation and maintenance [7].

Electric power system substations are being modernized to better serve user requirements for more efficient communication and more comprehensive protection and to facilitate future expansion by installing and applying higher-performance IEDs. There is a demand for a substation automation system (SAS) that is simple to integrate and provides high performance and flexibility. IEC 61850 capacities provide interoperability and advanced communications capabilities in substation protection, coordination, control, monitoring, metering, and testing. IEC 61850 is the result of the efforts of IEC Technical Committee 57 (TC57) to produce an open standard for substation modeling and communications. Substation configuration description language (SCL) is used in IEC61850-based substations to create substation configuration description files that contain full information about the substation. The main purpose of this format is to ensure that IED capability and substation descriptions are exchanged in a compatible way between the IEDs.

A substation is a part of an electrical generation, transmission and distribution system. The assembly of apparatus used to change some characteristics (e.g. voltage, frequency, p.f., A.C. to D.C. etc.) of an electrical supply is called a substation. Some of the main operations of substations are:  To receive energy transmitted at high voltage from the generating stations.

IEC 61850 based high speed peer-to-peer communication called GOOSE (Generic Object Oriented Substation Event) has an impact on the development and testing of IEC 61850 relays and the associated protection schemes in modern power system. GOOSE not only provides an opportunity to optimize the system performance at reduced hardware cost but also eliminates various constraints in traditional protection schemes. Performance testing for GOOSE is an important item for the correctness and the real time performance of substation applications. The primary objective of this paper is to analyze the factors affecting the performance of GOOSE based protection schemes. The paper then discusses the methodology and advanced hardware and software tools available for performance measurement of IEC 61850 GOOSE.

Substation has a critical role in power stability.
The equipments in conventional substation have been
work for several years and problem in one of them make
disruptive in power network. Optimization of
conventional substation increase reliability but usually
these substations are online and working in critical point
of the power network and changing device in offline
mode is not accessible.
This paper proposes to replace online substation
automation system for optimizing conventional system in
parallel mode with previous system with Hard Fiber
because it is the best way for connecting old device to
IEC61850 network.

Energy cyber physical systems such as power systems are increasingly controlled by embedded microcontrollers that are connected to communication networks. Thus, modern power systems are increasingly under increased threat of cyber-attacks and tools are required to research the impact of these threats to the physical system. Cyber-attacks can be carried out in an electrical power system for the purpose of controlling switching devices or circuit breakers.  Such attacks could weaken the power system or result in a power outage. A cyber physical security test bed is a necessary tool for conducting research in cyber physical security.  It provides a platform by which attacks are simulated and evaluated on cyber physical systems. Methods to mitigate these threats can be validated in the same platform. This paper presents a hardware-in-the-loop based cyber-physical security test bed for substations. It consists of commercial equipment, and has capabilities to simulate the potential cyber threats and attacks, detect cyber intrusions, and could be used to validate cyber attack mitigation methods. A power system is modeled containing a detailed substation and simulated using Real Time Digital Simulator (RTDS), which is connected to Intelligent Electronic Devices (IEDs) and substation gateway to mimic power system protections and operations. Various types of cyber threats and intrusions are tested using this test bed to check the consequences and impacts of cyber attacks to power grids.

The IEC 61850 standard is being largely used in the Smart Grid (SG) context mainly due to its ability to address communication, interoperability and migration issues. IEC 61850 currently aims at internal substation communication. Nevertheless, there is a demand to generalize its use for distributed SG systems like Home Energy Management Systems (HEMS) and Advanced Monitoring Infrastructure (AMI) Communication which potentially involves distributed substations or distributed SG components. IEC 61850-based systems require constrained timing requirements for communication and the common approach is to allocate static link bandwidth resources leading in some cases to over di-mensioning. This paper presents the Substation Cognitive Communication Resource Management (IC 2 RM), that aims the management of bandwidth allocation for IEC messages using a cognitive approach for its provisioning and the SDN/OpenFlow for its deployment. By dynamically deploying bandwidth for IEC messages, IC 2 RM optimizes links between SG substations and systems and potentially reduces the operational costs (OPEX).

The continuous increase in power transmission over long distances along with economical and environmental constraints associated with building new lines such as rights of way; necessitate the increasing of the power transmission capability of the existing system to balance the increasing power demand. This paper assesses the use of two different types of Flexible Alternating Current Transmission System (FACTS) techniques to increase the power transfer capability of long distance interconnection links. High Voltage Direct Current (HVDC) system is one of these techniques while Thyristor-Controlled Series Compensation (TCSC) is the other. The paper provides a basis feasibility study to decide which technique is the optimum to be used for a particular case. This decision is based upon compromising between the advantages and disadvantages of each technique based on system requirements, such as amount of power to be transmitted, interconnection link distance, geographical circumstances, switchgear & protection system complexity, power quality aspects, cost and other requirements. Also, a case study of the ongoing project for interconnecting the electrical networks of Kingdom of Saudi Arabia (KSA) and Arab Republic of Egypt (ARE) is discussed to verify the study. Finally, a sequential flow chart is constructed as a guideline to determine the optimum technique for a given system requirements.

A grounding grid of a substation is essential for reducing the ground potential rises inside and outside the substations during a short-circuit event. The performance of a grounding grid is affected by a number of factors, such as the soil conductivity and grounding rod corrosion. Industry always has a strong desire for a reliable and cost-effective method to monitor the condition of a grounding grid. In view of the increased adoption of telecom and sensor technologies in power industry through the smart grid initiative, this paper proposes an online condition monitoring scheme for ground grids. The scheme monitors touch and step voltages in a substation through a sensor network. The voltages are created by a continuously-injected, controllable test current. The results are transmitted to a database through wireless telecommunication. The database evaluates the grid performance continuously by comparing the newly measured results with the historical data. Many of the limitations of the offline measurement techniques are overcome. Computer simulation studies have shown that the proposed scheme is highly feasible and technically attractive.

Smart grid is an innovating solution for the electrical systems that consists in an integrated architecture for all system components, including generation, transmission, distribution, and users. This architecture is strongly based on telecommunications networks with potential and inherent advantages such as greater overall eficiency and system-wide reliability, providing communication among intelligent devices. This short-course explains the main smart grid concepts and challenges and explores the IEC 61850 standard which, in turn, standardizes the communications among devices. The IEC 61850 and other relevant protocols are the basic building blocks of a communication network in a smart grid style. The challenges discussed include a new generation of telecommunications network for the smart grid together with security, management, control, quality of service, and migration issues.

The paper discusses substation IED data integration and its importance for implementation of automated analysis solutions. Recorded data collected from various substation IEDs is stored into a substation data mart that utilizes standardized file formats and a database interface. The data mart provides a foundation for multiple uses of substation data. Utilities are faced with a challenge of how to bring together internal needs and requirements, available standards, and recommendations developed by professional organizations, as well as the requirements imposed externally (i.e. NERC standards). Sometimes, there is a challenge of understanding what to expect from solutions that implement all those requirements.

A substation is a part of an electrical generation, transmission, and distribution system. Early electrical substations required manual switching or adjustment of equipment, and manual collection of data for load, energy consumption, and abnormal events. As the complexity of distribution networks grew, it became economically necessary to automate supervision and control of substations from a centrally attended point, to allow overall coordination in case of emergencies and to reduce operating costs. Early efforts to remote control substations used dedicated communication wires, often run alongside power circuits. Power-line carrier, microwave radio, fibre optic cables as well as dedicated wired remote-control circuits have all been applied to Supervisory Control and Data Acquisition (SCADA) for substations. The development of the microprocessor made for an exponential increase in the number of points that could be economically controlled and monitored. Today, standardized communication protocols such as DNP3, IEC 61850 and Modbus, to list a few, are used to allow multiple intelligent electronic devices to communicate with each other and supervisory control centres. In this paper the various parameter for fault identification and remote operation are performed with the help of the IOT (Internet Of Things). A module of sensors and transducers monitors the parameters and also check for the healthiness of the system. The implementation of this type of schemes will increase the working efficiency of the system by continuously monitoring the healthiness of parameters of the system and also to identify the faulty part as well as the reason of the fault in the system directly within a short period of time.

This paper proposes new concepts for detecting and mitigating cyber attacks on substation automation systems by domain-based cyber-physical security solutions. The proposed methods form the basis of a distributed security domain layer that enables protection devices to collaboratively defend against cyber attacks at substations. The methods utilize protection coordination principles to cross check protection setting changes and can run real-time power system analysis to evaluate the impact of the control commands. The transient fault signature (TFS)-based cross-correlation coefficient algorithm has been proposed to detect the false sampled values data injection attack. The proposed functions were verified in a hardware-in-the-loop (HIL) simulation using commercial relays and a real-time digital simulator (RTDS). Various types of cyber intrusions are tested using this test bed to evaluate the consequences and impacts of cyber attacks to power grid as well as to validate the performance of the proposed research-grade cyber attack mitigation functions. Index Terms-Collaborative cyber defense models, cyber-physical security test bed, digital substation, domain-based mitigation, smart grid cybersecurity, substa-tion cybersecurity.

The increase of cyber-attacks on industrial and power systems in the recent years make the cybersecurity of supervisory control and data acquisition and substation automation systemsa high important engineering issue. This paper proposes a defense in depth cybersecurity solution for smart substations in different layers of the substation automation system. In fact, it presents possible vulnerabilities in the substation automation system and propose a multiple layer solution based on best practice in cyber security such as the hardening ofdevices, whitelisting, network configuration, network segmentation, role-based account management and cyber security management and deployement.

International Conference on Automation and Engineering (AUEN 2022) is an international forum for sharing knowledge and results in theory, methodology and new advances and research results in the fields of Automation and Engineering. The conference will bring together researchers and practitioners from both academia as well as industry to meet and share cuttingedge development in the field. The Conference welcomes significant contributions in all major fields of the Automation in theoretical and practical aspects. Authors are solicited to contribute to the conference by submitting articles that illustrate research results, projects, surveying works and industrial experiences that describe significant advances in the following areas, but are not limited to.

The aim of this paper is to introduce two important issues when selecting new Intelligent Electronic Devices (IEDs) as a part of the substation automation system implementation, namely the evaluation means and new applications. For the evaluation purposes, several digital simulator applications are discussed together with the benefits obtained by utilizing the simulators. The evaluation of the IEDs prior to the purchase as well as in the field is described. Regarding implementation of new functions, the importance of the concept of data integration and information exchange is elaborated. It is pointed out that most of the new applications require unconventional use of data and information to yield specific benefits, which will justify the use of substation automation systems. The scope of the paper is restricted to discussion of various methodologies and generic tools and it is not aimed at discussing specific commercial products or services. In conclusion, the paper points out that the use of advanced IEDs and substation automation systems requires significantly different approach in evaluating and implementing the new solutions.

A software architecture is presented that supports faithful, modular and efficient implementation of a set of concurrent switching sequences in distribution substations specified through Petri Nets. The keys to provide speed, modularity and correct Petri Nets (PN) mapping are a multitasking kernel, a token-player algorithm plus a predicate data base, and source code compactness achieved by coloring the PN. The complete software system was implemented on a laboratory prototype similar to a RTU and tested on a distribution substation simulator, exhibiting real-time efficiency and user-friendly man-machine interface.

The paper discusses issues related to integration of substation IED data. The approach to discussion is based on the purpose of integrating substation data and how the integrated data can be used. Main reasons for substation data integration can be categorized into following groups: 1) data archival and exchange purposes, 2) easy access and viewing, and 3) data analysis. The paper identifies issues important for proper substation data integration: 1) handling system configuration information, 2) automated and straightforward communication, and 3) data file formats. Modern substations may be equipped with different types of intelligent electronic devices (IEDs) such as digital protective relays (DPRs), digital fault recorders (DFRs), phasor measurement units (PMUs), power quality monitors (PQMs), digital revenue meters (DRMs), etc. It is an engineering challenge to design and implement automated data integration and analysis systems today since most of the above mentioned issues are addressed through use of vendor-specific solutions, which are quite different from one vendor to another. The paper gives an overview of the options how existing vendor solutions may be combined with standards and recommendations to enable feasible means for easy and proper use of substation data. The discussion is followed by an example of an existing substation data integration system.

The adoption of business processes to design business activities is becoming a reality to a significant number of companies. In addition, the Service-Oriented Architecture (SOA) is being used in diverse situations for the execution of business processes using computational resources. In this context, the need of business process automation appears with high relevance. In this work, we present a solution named BPA-SOA, which aims to automate SOA-based business processes, specified in BPMN, into WS-BPEL executable processes. In BPA-SOA, business and service information can be specified at the business level, translated into executable artifacts, deployed in execution-level resources and enforced at runtime. An illustrative scenario is presented to better illustrate and showcase the proposed solution.

This modern era is about pursuing your passion, people not only focus on work but take up several hobbies to follow, either it be learning a new instrument, hiking, or vlogging your life. Everything must be done within 24 hours of a day. This creates a never-ending demand for technology that could encourage full utilization of time by eliminating the basic and mundane tasks of individuals. Inspired by this stream of thoughts we are developing a system that provides a cost-effective solution to the problem by creating a voice-operated home automation system. This is achieved by using the principles of the Internet of Things integrated with Neural Libraries. We can create an environment in which several appliances can be operated on voice commands, either it be turning on a fan or closing a door all are just one command away. The system utilizes BOLT IoT with a voice flow application to make an economical, scalable, and user-friendly home automation model.

Resumo-Smart gridé uma solução inovadora para as redes elétricas que proporciona uma arquitetura integrada para todos os componentes do sistema, incluindo geração, transmissão, distribuição e usuário. Essa arquiteturaé fortemente baseada em redes de telecomunicações com vantagens inerentes, tais como uma maior eficiência e confiabilidade para o sistema, permitindo a comunicação entre dispositivos inteligentes na rede. Nesse minicurso, são explicitados os principais conceitos e desafios acerca de smart grids e da norma IEC 61850, a qual estabelece um padrão para a interoperabilidade na comunicação. A norma IEC 61850, em conjunto com outros padrões e protocolos,é um dos elementos básicos para o desenvolvimento de um sistema de telecomunicações num estilo smart grid. Entre os desafios discutidos para o desenvolvimento de uma rede de nova geração para as smart grids, destacam-se a segurança, a gerência, o controle, a qualidade de serviço e a migração tecnológica.

This paper describes the evolution of a system for automated analysis of transmission line faults. The analysis is based on the substation data primarily collected from digital fault recorders. The paper provides a historical overview of the implementation steps and illustrates requirements changes throughout the process. In addition, the paper shares some interesting experiences related to the usage of the system that illustrate the value and benefits of having the automated fault analysis solution in place. The encounters include events developed during hurricanes Rita and Ike, as well as events during dry weather in 2011. The solution for automated fault analysis played important role in diagnostics and system restoration process.

Resumo-Smart gridé uma solução inovadora para as redes elétricas que proporciona uma arquitetura integrada para todos os componentes do sistema, incluindo geração, transmissão, distribuição e usuário. Essa arquiteturaé fortemente baseada em redes de telecomunicações com vantagens inerentes, tais como uma maior eficiência e confiabilidade para o sistema, permitindo a comunicação entre dispositivos inteligentes na rede. Nesse minicurso, são explicitados os principais conceitos e desafios acerca de smart grids e da norma IEC 61850, a qual estabelece um padrão para a interoperabilidade na comunicação. A norma IEC 61850, em conjunto com outros padrões e protocolos,é um dos elementos básicos para o desenvolvimento de um sistema de telecomunicações num estilo smart grid. Entre os desafios discutidos para o desenvolvimento de uma rede de nova geração para as smart grids, destacam-se a segurança, a gerência, o controle, a qualidade de serviço e a migração tecnológica.

This paper presents the results of the demonstration of a research project on collaborative defense system of transmission relays against cyber attacks in an electrical substation. The system is based on methods that monitor inconsistencies between the physical state of the substation, the power system around it, and the measurements as an indication of cyber intrusion. We assumed that the attacker has gained access to the substation communication network, either as an insider or a " virtual insider " , and initiates actions to gain control of intelligent electronic devices (IEDs). A hardware‐in‐the‐ loop cyber‐physical security test bed consisting of line protection and transformer protection relays, merging units, and a real time digital simulator (RTDS) was set up at BPA to simulate the cyber threats and to validate the effectiveness of the collaborative methods to block cyber attacks in real time. Cyber threats are continuously evolving and getting more sophisticated with time. The Ukraine cyber attack incident underlined the need for more distributed security in electrical infrastructures. This collaborative system of protective devices with distributed intelligence has demonstrated its capability, in a hardware in a loop simulation inside BPA lab, to block attempts to maliciously control circuit breakers remotely from the control center or locally from the substation network. The distributed intelligence also allows protection relays to collaboratively block attacks on settings that intentionally mis‐coordinate relay operation. The simulated cyber attacks were focused on a 500 kV substation within a study area consisting of four interconnected substations representing a region at BPA. Several 500 kV and 230 kV transmission lines, some with series capacitors, interconnects the various substations. Modeling the system in a real time simulated environment using RTDS allowed the generation of analog voltage and currents using amplifiers, fed to merging units which generated the sampled values, and then streamed to the protective relays. The hardware in the loop demonstration was used extensively to validate the timing performance of the security algorithms. A key requirement of the demonstration is that the security functions must not delay existing protection system's capability to detect and protect against faults in the system. It was confirmed in the lab set up that the distributed cyber security functions performed dependably in blocking simulated cyber attacks with timing performance that did not compromise the relays' protection times.

Automated monitoring of power systems has become an imperative due to two major developments that characterize the 21 st century electricity grid: a) large scale deployment of intelligent electronic devices (IEDs) has created huge amount of data recorder either continuously or at the time when IED recording is triggered by an event such as disturbance or fault, and b) the power system loading has increased to the point where it operates close to the limits, which requires much better monitoring capability than what is available today to make sure such operation does not create undesirable consequences such as cascading failures. Fully aware of the challenges the North American Electric Reliability Corporation (NERC) has developed standards for event monitoring and reporting, which will assure the bulk electricity system is reliable, adequate and secure. To fulfil NERC and/or internal requirements for improved monitoring utilities have started deploying advance solutions that enable automated collection of field data, extraction of information and distribution of monitoring reports so that the utility staff can respond to the events expeditiously. The deployment exaples illustrated in this paper are aimed at demonstrating various deployment strategies that are possible with such solutions: substation, distributed and centralized-based processing. The substation processing requires installation of a PC that serves as the integration hub which collects recorded files from all substation IEDs, converts data to information and creates event reports that are sent to the groups that need them. The distributed solution retrieves IED records and passes them to a location such as protection office, operator control room or maintenance canter where further processing is done. The centralized solution collects all the data to a centralized database, extracts information and sends it to the users per request. To illustrate the above concepts several hardware and software solutions are developed and deployed in the field: circuit breaker recorder, automated analysis of circuit breaker recorder (CBR) data, automated analysis of digital protective relay (DPR) data, automated analysis of digital fault recorded (DFR) data, automated integration of substation IED data, automated handling of user interfaces. All the solutions are implemented using advanced hardware and software concepts that allow the recorded data to be synchronized and time stamped utilizing receivers for Global Position System (GPS) of satellites. Time stamped data are communicated through variety of modern communication media such as wireless, optical fibre and high speed coaxial cable links. Handling of software applications is through advanced JAVA programming, and user interfaces deploy latest advancements in the web browsers and graphical user interfaces. Practical issues such as cyber security, implementation steps and personnel acceptance are addressed as well.

This paper addresses some new approaches to data integration and information exchange that are made possible due to the use of advanced Information Technology (IT). As a result, some traditional applications such as fault analysis can be significantly enhanced and automated. Paper first describes how the functional enhancement and automation of fault analysis may result in faster system restoration, better quality of power delivery, and more comprehensive preventive maintenance actions. The paper illustrates how in the competitive utility environment this leads to improved service and ultimately better customer satisfaction while maintaining and even reducing operational cost. Several examples related to automated fault analysis are described as follows: disturbance analysis, analysis of Circuit Breaker (CB) operation, and fault location analysis using sparse field data. INTRODUCTION Deregulation, liberalization, restructuring and privatization in the utility industry are simultaneously happening around the globe. They represent different approaches to making the utility industry more cost effective and responsive to customer needs. As a result, two important trends are recognized: the introduction of more automated functions and the use of more advanced information technology. The final aim is to provide better service to the customers and to reduce the operating cost. This paper illustrates how the existing fault analysis approach can significantly be enhanced through the use of advanced information technology [1]. In this context, the information technology relates to the technology for communications, processing, intelligent systems, computer networks, databases, user interfaces, etc. First, the application functions can be improved to include broader view of the analysis including data from multiple intelligent electronic devices (IEDs). This leads to a comprehensive data integration resulting in efficient data processing. Once the relevant information is extracted, it can be distributed to multiple users responsible for maintaining the quality and reliability of the energy supply service. All of this can easily be automated using information technology services embedded in the applications.

Automation of fault analysis is a desirable future application due to “explosion” of on-line substation data collected during disturbances. Analyzing this data manually is just not feasible; automation of the analysis is necessary. This paper focuses on three options for implementation of automated fault analysis based on: a) uses of individual Intelligent Electronic Devices such as Digital Fault Recorders (DFRs), Digital Protective Relays (DPRs), Sequence of Events Recorders(SERs), etc, b) integrated substation automation systems with all Intelligent Electronic Devices (IEDs) interconnected, and c) integrated
enterprise monitoring and control system including Supervisory Control and Data Acquisition (SCADA) Remote terminal units (RTUs) combined with other substation IEDs. For each of the approaches, implementation requirements are discussed and possible benefits are outlined.

The paper describes the use of automated analysis reports and field recorded signals in troubleshooting protection system operation. Utilizing automated analysis of field-recorded data dramatically expedites the process of setting up test equipment and choosing and creating test. Automated analysis reports provide both the analysis results and recorded waveforms. Analysis results can be utilized to select test locations in the power system of interest and choose the right simulation conditions. The recorded waveforms can generally be used in two ways: for fault playback simulation and as a reference to calibrate simulation model. Several tools and methods on how to utilize recorded signals for the fault playback and simulation calibration are presented. The tools and methodologies are discussed from through examples on field data recorded in a real power system.

The adoption of business processes to design business activities is becoming a reality to a significant number of companies. In addition, the Service-Oriented Architecture (SOA) is being used in diverse situations for the execution of business processes using computational resources. In this context, the need of business process automation appears with high relevance. In this work, we present a solution named BPA-SOA, which aims to automate SOA-based business processes, specified in BPMN, into WS-BPEL executable processes. In BPA-SOA, business and service information can be specified at the business level, translated into executable artifacts, deployed in execution-level resources and enforced at runtime. An illustrative scenario is presented to better illustrate and showcase the proposed solution.

Resumo-Smart gridé uma solução inovadora para as redes elétricas que proporciona uma arquitetura integrada para todos os componentes do sistema, incluindo geração, transmissão, distribuição e usuário. Essa arquiteturaé fortemente baseada em redes de telecomunicações com vantagens inerentes, tais como uma maior eficiência e confiabilidade para o sistema, permitindo a comunicação entre dispositivos inteligentes na rede. Nesse minicurso, são explicitados os principais conceitos e desafios acerca de smart grids e da norma IEC 61850, a qual estabelece um padrão para a interoperabilidade na comunicação. A norma IEC 61850, em conjunto com outros padrões e protocolos,é um dos elementos básicos para o desenvolvimento de um sistema de telecomunicações num estilo smart grid. Entre os desafios discutidos para o desenvolvimento de uma rede de nova geração para as smart grids, destacam-se a segurança, a gerência, o controle, a qualidade de serviço e a migração tecnológica.

The paper focuses on deployment challenges for automated substation data analysis solutions. Through examples from recent deployment projects, the paper discusses the fact that both the utilities and suppliers are dealing with a set of requirements defined as a compromise between the needs of variety of in-house stakeholders. These requirements are prone to changes and that itself is one of the biggest challenges. In addition, the deployment is almost always faced with unexpected challenges from the production environment itself.

This paper gives an overview of future requirements for fault and disturbance analysis. Special attention is given to the issues of the extent of analysis, data integration, information exchange, speed of processing, database needs, dissemination of analysis results and related user interface, and support through existing and new standards. Selecting implementation options and moving towards more integrated solutions are discussed and supported with a summary of the existing relevant standards as well as the need for defining new ones. Examples of the most advanced solutions deployed by the utility companies are given as well.

The paper discusses substation IED data integration and its importance for implementation of automated analysis solutions. Recorded data collected from various substation IEDs is stored into a substation data mart that utilizes standardized file formats and a database interface. The data mart provides a foundation for multiple uses of substation data. Utilities are faced with a challenge of how to bring together internal needs and requirements, available standards, and recommendations developed by professional organizations, as well as the requirements imposed externally (i.e. NERC standards). Sometimes, there is a challenge of understanding what to expect from solutions that implement all those requirements.
In this paper a data mart implementation concept for automated integration and analysis of substation is given first. The solution and implementation requirements are discussed through realistic examples and evaluation of the solution with a variety of test data. Evaluation examples are based on both simulated fault data as well as the actual fault disturbances captured in field by substation IEDs. The presented test examples illustrate what can be expected from substation data mart based solution for automated analysis and how such a solution can be further expanded.

The paper focuses on deployment challenges for automated substation data analysis solutions. Through examples from recent deployment projects, the paper discusses the fact that both the utilities and suppliers are dealing with a set of requirements defined as a compromise between the needs of variety of in-house stakeholders. These requirements are prone to changes and that itself is one of the biggest challenges. In addition, the deployment is almost always faced with unexpected challenges from the production environment itself. The paper illustrates a gradual step-by-step approach from a solution demonstration to the production deployment. The first part focuses on the solution that analyzes digital fault recorder and digital protective relay data. In-house testing with both simulated data and with the data obtained from the field is discussed. The second part of the paper discusses implementation and deployment of a new circuit breaker recorder aimed at on-line monitoring circuit breaker operations.

This paper presents some difficulties encountered when evaluating information obtained from infrared thermal inspections conducted in uncovered power substations. Technical, physical, and environmental factors are the main influences that have been identified. Based on field data and laboratory tests, mathematical models were derived to understand the load current variation influence on the thermal behavior of electrical components, which are suitable either to extract its influence or forecast the system behavior under specified conditions of interest.