In such a paradigm, all that users would need to access the system is to log in remotely using their corporate credentials. In addition to various encryption methods, a Virtual Private Network (VPN) can also be used to secure a communication link and to hide it from unauthorized users that may use the same shared connection. The main drawback of a remote access system is that security may be compromised, especially when shared links such as cellular modems or internet connection are used to establish communication. Its main purpose is to limit access and grant it only to authorized people, to secure connections and to log every access to an element in the system – while documenting any changes.
Instead of individually setting up the devices in the substation in the SCADA system, only one gateway with one communication link and one set of points is required to be integrated in the SCADA system. A data concentrator can also offer more storage to maintain log and event files as compared to internal storage of https://consultprofound.com/top-10-technology-trends-to-watch-2025.html?noamp=mobile the IEDs. Although the data concentration function is not as important as it previously was, it still adds a lot of flexibility to the system. With more processing power and internal storage, IEDs can now produce more information regarding their internal activities.
- Hitachi Energy offers a comprehensive portfolio of automation, protection and control solutions for utilities, renewables, data centers and other electro‑intensive industries.
- Concentrating information would improve the communication (and reduce the cost) as sending data points in one burst would reduce the communication time – as compared to sending small data packets from different devices over a longer period of time.
- Native Vendor Tools (NTV) provided by IED manufacturers often have limited log capability (if any) – and that doesn’t meet the requirements for an enterprise-level system.
- Logging user interaction with a device can provide system administrators or other users with valuable information – especially in case of a failure.
- With the evolution of digital relays, most system parameters became digitally available directly from relays and meter-over-ethernet links and via new protocols – and the demand for high-capacity RTUs was reduced.
The malware protection system on a gateway uses a whitelisting approach to constantly monitor the codes run on the gateway. A gateway firewall will block all communication ports, except those necessary for normal operation. Logging user interaction with a device can provide system administrators or other users with valuable information – especially in case of a failure. The password manager system then provides the access management system with the device password without exposing it to the user.
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These may help a protection engineer to better investigate the cause of a fault and take necessary measures to https://theprimalx.com/articles/lakes-nevada-lakeside-living/ readjust the system to prevent future similar faults. A user should also be able to compare two configuration files to better investigate the changes and to spot unauthorized modifications, if any. On the other hand, keeping track of all devices in a utility with many (often remote) substations is quite a big challenge.
Like other protocols, substation automation communication protocols have evolved along with communication infrastructure improvement. Most of the early protocols in the electrical automation industry were proprietary protocols developed by device manufacturers. Substation information is collected via communication protocols, physical communication and other substation technologies. Rapid evolution of communication and process technologies now offers system administrators the luxury of polling more and more operational and non-operational data points from their substations.
This type of system can also leverage a central authentication system such as MS Active Directory to authenticate and authorize users before they can access a device. IED firmware changes over time – as new features or bug fixes become available, so utilities may need to update the firmware version of their IEDs. Unlike early digital control systems, control centers are no longer only interested in operational data. Only a small set of information was sent to the control center due to the communication limits and this information was only used in real-time control systems. Another function of a HMI system is to show some form of a summary on the general health of a substation. This approach eliminates the use of a substation computer – resulting in less hardware and software maintenance considering that a computer running on Windows OS needs regular patch management.
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A substation automation system also automates some repetitive, tedious and error-prone activities to increase the overall efficiency and productivity of the system. Substation automation is aimed for automated operation of the power system with minimal human intervention. SCADA (Supervisory Control and Data Acquisition) system is a software program used for remote monitoring and control of substation operations. Substation Automation is a fundamental concept that represents a transition from traditional electric grid to an intelligent and more efficient electric grid. Speak with specialists who understand your challenges, provide clarity, and guide you toward the right fit for your operations.
Managing passwords on hundreds of devices cannot be done manually, so an automated system is required to keep track of password changes. To eliminate travel time to a substation, utilities will use a remote access system that works in conjunction with user access management tools. A user management system should also log and timestamp every access to the system and make sure access privileges are revoked once a user leaves the company. A major requirement in a secure system is to make sure users can only access or modify the assets they are given permission to by a system administrator. A good security infrastructure should make sure the right information will be accessible only to the right people at any time using proper authentication, authorization and access control. Most of the communication was done using dedicated methods such as telephone lines and modems that where not visible to outsiders.
A substation automation system consists of several smart components for real-time monitoring and automated control of power system operations. Wired communication solutions designed for reliable, high-capacity mission-critical networks with uncompromised performance under all conditions. Our protection, control, and automation solutions for substations and the power grid ensure the highest level of reliability, safety, and operational efficiency for grid operators and owners. SEL Blueframe is a modern software platform designed to meet the needs of OT environments.Secure and scalable, Blueframe allows a seamless exchange of data between applications on the platform, minimizes the frequency of patches and upgrades, and offers features to prevent unauthorized access and potential attacks.It can be embedded in the SEL-3350, SEL-3355, and SEL-3360 computing platforms or deployed in virtual environments. IEC based substation automation architectures ensure reliable, interoperable digitalization for new substations, retrofits, and digital upgrade projects.
Digital substation technology is applicable for new and retrofit installations of air and gas-insulated switchgear substations. The Hitachi Energy Intelligent Electronic Devices (IEDs) for protection and control are an integral part of the substation automation system. Introducing MicroSCADA X, your reliable automation and control solution for power utilities, industries, transportation, and renewables.
Substation HMI
Information such as the number of successful and failed communications, gateway CPU and memory usage and the software version can be shown in a graphical form, so an operator can evaluate the overall condition of the system at a glance. Although sensor signals are still mainly in hardwired form, modern IEC based substations can communicate digital information between sensors and relays using sample values or GOOSE protocols. With the evolution of digital relays, most system parameters became digitally available directly from relays and meter-over-ethernet links and via new protocols – and the demand for high-capacity RTUs was reduced. These devices generally had high I/O capacities as most of the system parameters were not yet available in digital format and they communicated over serial links.
It can also help utilities to lower maintenance costs by planning maintenance in advance and combining multiple maintenance sessions into one based on the information they get from a condition-based maintenance system. By analyzing information coming from devices in the field, an application can be used to predict when and why a particular device or equipment may need maintenance. This type of system can also send notifications to the stakeholders with the files attached to the message or a link to the folder where they can find a copy of the files. A better approach would be to have an automated system monitor the protection devices and download the new files when they become available. Even if the device is remotely accessible, a user should take time to go through the files to find the new ones and then download and share them in case more than one person requires access to these files.
