Introduction
The need for smarter and more advanced power systems and electrical infrastructure has increased due to recent technological advancements. Substation automations allows security measures and increased precision in managing power distribution, which increases the effectiveness of electrical infrastructure. One of the most pivotal innovations driving this progress is the IEC 61850 standard. This innovation alters the integration and coordination processes of intelligent electronic devices (IEDs) within a substation and therefore streamlines the operation of IEDs and real-time data sharing.
Renewable energy sources are a distributed energy resource that can often complicate energy networks due to their intermittent nature. There is an increasing need to address this problem. Incorporation of IEC 61850 solves this issue by eliminating the traditional silos of one-way communication, and instead enables high-speed, standardized communication between multiple devices. Increases in cost efficiency, installation, and wiring as well as future-proofing also result from the integration of multiple devices on one network. The continued evolution of automation substations make IEC 61850 vital for creation of interoperable energy infrastructures.
Understanding IEC 61850 Substation Architecture
Integrated and smart designs of substations help to ensure real-time control, reliability, and overall stability for any modern energization system. With the architecture of IEC 61850 substations, modifying outdated Substation Automation Systems (SAS) can be done with ease, making it possible to use uniform, scalable frameworks for the substation’s automation design, operation, and communication. The use of the IEC 61850 standard ensures that there is smooth integration of all the subsystem components within the substations, improving the overall interoperability and control within and between the substations.
The functional structure of an IEC 61850 substation is divided into three layers: process, bay and station levels.
-
Process Level (Primary Equipment)
Control devices that include switchgear, transformers, and circuit breakers with corresponding sensors are located at this level. These components are a critical part of the electrical power physical layer as they perform the functions of passing and changing electrical power. Within this level, there are data acquisition devices that capture the current status of operations and send the information for higher level assessment and control analysis.
-
Bay Level (Secondary Systems)
At this level, automation, protection, and monitoring activities are accomplished through IEDs, protection relays and intelligent electronic units. These devices can communicate with each other and are equipped with advanced functionalities such as GOOSE messaging and SMV, according to the IEC 61850 standard. These protocols are essential for transmission of data for protection and control operations due to their speed and ability to use event-driven mechanisms.
-
Station Level (Communication Network)
This is the control center of the substation where SCADA systems, HMIs (Human-Machine Interfaces), and network control systems are located. For high-level information exchange and system supervision, the MMS (Manufacturing Message Specification) Protocol, part of the IEC 61850 suite, is used. Also, the station level uses Ethernet-based communications to coordinate devices and integrate them with the central control rooms, resulting in better traffic and device management.
A notable advantageous feature of the IEC 61850 substation architecture is its neutral-vendor approach, which allows for the use of different manufacturers’ equipment within a single system and ensures the interoperability of the components. This makes it easier to perform upgrades and improves the lifecycle management of the substation.
The evolution of Substation Automation Systems with the integration of intelligent and dynamic protocols to inter-substation communication, wiring, and response capabilities within the framework of the IEC 61850 standard, is nothing short of transformative. Because of its emphasis on real-time operation and a sustained architectural provision for future technological integrations, the standard serves as a foundational pillar in the design of substations with advanced embedded technologies and enhanced flexibility and reliability.
Communication Protocols of IEC 61850
Real-time data exchange, interoperability, and efficiency are vital components for streamlined data transfer within Substation Automation Systems (SAS). These components are demonstrated astonishingly and can be directly linked to one of the most notable advantages of the IEC 61850 standard which is its robust communication protocols. The advanced substations that fall under the scope of IEC 61850 are equipped with protocols that serve as the backbone to the substations as all elements including, Intelligent Electronic Devices (IEDs), Human-Machine Interfaces (HMI) and data acquisition devices are integrated and work seamlessly over an Ethernet based network.
IEC 61850 identifies many communication protocols, each serving a distinct purpose for a substation.
1. MMS (Manufacturing Message Specification)
As the IEC 61850 architecture’s substation level protocol, MMS aids high-level communications between the network control system, SWSCADA, and the intelligent electronic devices (IEDs). It is capable of performing comprehensive data models and controls, thus aiding supervision tasks. Control centers manage IEDs within the network, changing their state and retrieving status information seamlessly using MMS.
2. GOOSE (Generic Object-Oriented Substation Events)
GOOSE is an event-driven, high-speed protocol applicable basely on protection and control functions. It has the capability of transmitting crucial information such as the state of circuit breakers and fault indications instantaneously among all IEDs and data acquisition equipment. Because GOOSE message transmission speed must be low-latency, the reliability and speed of GOOSE messaging is crucial for automation responsiveness. This underpins effective Substation Automation.
3. SMV (Sampled Measured Values)
SMV serves the purpose of streaming real-time measurements of voltage and current signals from mechanized sensors and instrument transformers to IEDs and other monitoring subsystems. Its role is crucial to digital substations where precise and time-synchronized measurements are significantly critical for the analysis and control of the systems. SMV further fosters the advancement of SAS by reducing the need for traditional analog wiring alongside measurement errors.
With these protocols, the IEC 61850 substation can be operated as an intelligent responsive integrated system. The use of Ethernet-based networks enables reduced systemic intricacies, enhanced adaptability, and multifarious interoperability supporting devices from multiple vendors reinforcing the IEC 61850 backbone as the cornerstone for Substation Automation.
Importance of IEC 61850
The Substation Automation Systems (SAS) had been designed and implemented around the physical connecting cables until inter-substation Ethernet communications became an integral part of the Substation Automation System. The shift dramatically synergizes operational efficacy alongside flexibilities within modern substations as power utilities are able to centrally control and manage their power infrastructure.
1. Interoperability
A notable advantage of IEC 61850 is facilitating effective integration of devices such as remote terminal units and data collection equipment from different vendors. This level of integration makes it possible for utilities to use devices from multiple vendors within one IEC 61850 substation, thereby eliminating compatibility concerns and averting vendor lock-in. This significantly reduces operational cost and complexity during system upgrades and expansions.
2. Faster Data Exchange
With the implementation of GOOSE and SMV protocols, MMS industry standards, real-time data transfer emerges as a critical capability. Quicker responsiveness to commands helps primary equipment, including circuit breakers, protective relays, and SCADA systems, to execute critical functions in monitoring and controlling the grid rapidly. Enhanced communication accelerates essential functions such as fault identification, isolation, and overall system recovery which helps maintain the grid’s equilibrium.
3. Simplified Engineering
The IEC 61850 standard facilitates systems engineering by offering pre-defined templates alongside dynamic configuration tools, resulting in faster streamlined system setups. This not only reduces the range of possible configuration errors but also greatly aids in ongoing system maintenance. New Substation Automation projects can be activated far more rapidly as utility companies face fewer interruptions during these operations and reduced operational costs.
4. Future-Proof Design
This one allows the integration of new technologies for energy management systems like smart grids and modern automation. Substations will be able to adapt to changing technologies and communication standards, which will enable them to keep incorporating newer functionalities, ultimately ensuring their sustainability. Power systems are environmentally sustainable due to the substations being adaptable to advancing automation and energy management systems.
5. High Reliability
The implementation of standardized communication protocols defined in IEC 61850 enhances functionality essential to substations to guarantee their high performance and reliability. This helps improve the overarching safety and reliability of the network control system and the entire substation environment, safeguarding the system from disruptions and damage while preserving critical infrastructure.
Necessity of Redundancy Systems in Substations
Reduces risks associated with failures and faults in modern Substation Automation Systems (SAS). In an IEC 61850 Substation where everything is controlled and communicated through Ethernet networks, there is a need for high reliability owing to network dependencies and control decisions. Redundancy secures uninterrupted performance in critical functions even if there are equipment or network failures or faults.
1. Network Redundancy (PRP & HSR Protocols)
Communication protocols such as Parallel Redundancy Protocol (PRP) and High-availability Seamless Redundancy (HSR) are employed to relay messages from IEDs to data acquisition devices and network control systems. They ensure there is communication even in the existence of multiple failures of a single link.
2. Device Redundancy
To ensure substations perform their requisite tasks after a hardware failure, intelligent electronic units such as backup IEDs and protection relays must be incorporated. This device-based redundancy enhances fault tolerance and seamless operation of the system.
3. Power Supply Redundancy
Some critical components (e.g. SCADA systems, HMIs, or communication devices) might shut down during a power outage, but redundant or dual power supplies eliminate this risk. Redundancy dual ensures controllability even during supply faults and shields the substation from power outages.
By adding redundancy at the network, device, and power levels, substations that are based on the IEC 61850 standard can attain high availability, mitigated risks, and improved operational safety.
Conclusion
The benefits brought by IEC 61850 extends beyond optimization of substation operations to include safety and resilience, thus necessitating its adoption as a contemporary standard for energy infrastructure. It provides a balanced communication framework and intelligent infrastructure mark the beginning of the self-sufficient Substation Automation Systems of the future.
At Zealinx, we enable advanced SCADA system integration under the IEC 61850 standard. Our automated turnkey solutions include smart interfaces for IED configuration and data acquisition on Ethernet networks, as well as deployment of scaling-ready harnessed security redundancy void systems, ensuring your substation infrastructure is fortified. For professional guidance and complete integration service under the IEC 61850 standard, reach out to Zealinx today.
FAQ
1. What are the challenges of implementing IEC 61850?
Challenges faced because of implementing the IEC 61850 standard stem from legacy systems, networked device complexity at the substation level, employee protocol familiarity, and cross-device cooperation within the configured sub networks.
2. How do redundancy systems prevent substation failures?
Maintaining equipment or network failure avoids downtime risks through communication alternate pathways offered by PRP and HSR redundancy systems. Backup intelligent electronic devices (IEDs) and dual power supplies economically ensure constant operation.
3. Can you provide case studies on IEC 61850 in substations?
Certainly, we saw many electric utilities adopting the use of IEC 61850 for the purposes of automation, reduction in wiring and increase in system reliability. For real-life case studies of integrating IEC 61850 into substations, please reach out to Zealinx
4. How does IEC 61850 support future-ready substation automation systems?
With IEC 61850, smart grid integration, sophisticated data processing, and even remote surveillance are possible due to the flexible and scalable SAS architecture with high speed standardized interfaces.
5. What is the role of GOOSE and SMV protocols in IEC 61850 substations?
The GOOSE and SMV protocols are indispensable for substations equipped with IEC 61850. These protocols are essential for high-speed transmission of protective and measurement data and system real-time operation and response to faults.
