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Technical Overview and Benefits of the IEC 61850 Standard for Substation Automation

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Technical Overview and Benefits of the IEC 61850 Standard for Substation Automation 1 Technical Overview and Benefits of the IEC 61850 Standard for Substation Automation Ralph Mackiewicz SISCO, Inc. Sterling Heights, MI USA Abstract-- Legacy substation automation protocols and much higher rates. With this migration in technology, the architectures typically provided basic functionality for power “cost” component of a data acquisition system has now system automation and were designed to accommodate the become the configuration and documentation component. technical limitations of the networking technology available for Consequently, a key component of a communication system is implementation. There has recently been a vast improvement in networking technology that has changed dramatically what is the ability to describe themselves from both a data and now feasible for power system automation in the substation. services (communication functions that an IED performs) Technologies such as switched Ethernet, TCP/IP, high-speed perspective. Other “key” requirements include: wide area networks, and high-performance low-cost computers are providing capabilities that could barely be imagined when · High-speed IED to IED communication most legacy substation automation protocols were designed. · Networkable throughout the utility enterprise IEC61850 is an important new international standard for substation automation that will have a very significant impact on · High-availability how electric power systems are designed and built for many · Guaranteed delivery times years to come. IEC61850 is a part of the International · Standards based Electrotechnical Commission’s (IEC) Technical Committee 57 · Multi-vendor interoperability (TC57) architecture for electric power systems. The model- · Support for Voltage and Current samples data driven approach of the TC57 standards, including IEC61850, is · Support for File Transfer an innovative approach that requires a new way of thinking about substation automation that will result in very significant · Auto-configurable / configuration support improvements in both costs and performance of electric power · Support for security systems. Given these requirements, work on a “next generation” I. COMMUNICATION SYSTEM NEEDS communication architecture began with the development of ommunication has always played a critical role in the the Utility Communication Architecture (UCA) in 1988. The C real-time operation of the power system. In the result of this work was a profile of “recommended” protocols beginning, the telephone was used to communicate line for the various layers of the International Standards loadings back to the control center as well as to dispatch Organization (ISO) Open System Interconnect (OSI) operators to perform switching operations at substations. communication system model. This architecture resulted in Telephone-switching based remote control units were the definition of a “profile” of protocols, data models, and available as early as the 1930’s and were able to provide abstract service definitions that became known as UCA. The status and control for a few points. As digital concepts and fundamental work done in UCA became the communications became a viable option in the 1960’s, data foundation for the work done in the IEC Technical Committee acquisition systems (DAS) were installed to automatically Number 57 (TC57) Working Group 10 (WG10) which collect measurement data from the substations. Since resulted in the International Standard – IEC 61850 – bandwidth was limited, DAS communication protocols were Communication Networks and Systems in Substations. optimized to operate over low-bandwidth communication channels. The “cost” of this optimization was the time it took to configure, map, and document the location of the various data bits received by the protocol. II. SCOPE AND OUTLINE OF IEC 61850 The stated scope of IEC 61850 was communications within As we move into the digital age, literally thousands of the substation. The document defines the various aspects of analog and digital data points are available in a single the substation communication network in 10 major sections as Intelligent Electronic Device (IED) and communication shown in Table 1 below. bandwidth is no longer a limiting factor. Substation to master communication data paths operating at 64,000 bits per second are now commonplace with an obvious migration path to 2 TABLE I object and services onto the Manufacturing Messaging STRUCTURE OF THE IEC 61850 STANDARD Specification – MMS and sections 9.1 and 9.2 define the Part # Title mapping of the Sample Measured Values (unidirectional 1 Introduction and Overview point-to-point and bi-directional multipoint accordingly) onto 2 Glossary of terms an Ethernet data frame. The 9.2 document defines what has 3 General Requirements become known as the Process Bus. 4 System and Project Management 5 Communication Requirements for Functions and From a system perspective, there is a significant amount of Device Models configuration that is required in order to put all the pieces 6 Configuration Description Language for together and have them work. In order to facilitate this Communication in Electrical Substations Related to process and to eliminate much of the human error component, IEDs an XML based Substation Configuration Language (SCL) was 7 Basic Communication Structure for Substation and defined in part 6. It allows the formal description of the Feeder Equipment relations between the substation automation system and the 7.1 - Principles and Models substation (switchyard). At the application level, the 7.2 - Abstract Communication Service Interface switchyard topology itself and the relation of the switchyard (ACSI) structure to the SAS functions (logical nodes) configured on 7.3 - Common Data Classes (CDC) the IEDs can be described. Each device must provide an SCL 7.4 - Compatible logical node classes and data classes file that describes the configuration of itself. 8 Specific Communication Service Mapping (SCSM) 8.1 - Mappings to MMS(ISO/IEC 9506 – Part 1 and Although the scope of 61850 was originally focused Part 2) and to ISO/IEC 8802-3 “inside” the substation, discussions are underway to look at 9 Specific Communication Service Mapping (SCSM) defining 61850 for the Substation to Master communication 9.1 - Sampled Values over Serial Unidirectional protocol (already in service in several installations). In Multidrop Point-to-Point Link addition, applications are in service that uses various 9.2 - Sampled Values over ISO/IEC 8802-3 components of 61850 for wide area substation-to-substation 10 Conformance Testing communication. Parts 3, 4, and 5 of the standard start by identifying the Finally, part 10 of the document defines a testing general and specific functional requirements for methodology in order to determine “conformance” with the communications in a substation (key requirements stated numerous protocol definitions and constraints defined in the above). These requirements are then used as forcing functions document. to aid in the identification of the services and data models The rest of this paper goes into some focused details of the needed, application protocol required, and the underlying various parts of the IEC 61850 standard. transport, network, data link, and physical layers that will meet the overall requirements. III. MODELING APPROACH Legacy protocols have typically defined how bytes are The major architectural construct that 61850 adopts is that transmitted on the wire. However, they did not specify how of “abstracting” the definition of the data items and the data should be organized in devices in terms of the services, that is, creating data items/objects and services that application. This approach requires power system engineers to are independent of any underlying protocols. The abstract manually configure objects and map them to power system definitions then allow “mapping” of the data objects and variables and low-level register numbers, index numbers, I/O services to any other protocol that can meet the data and modules, etc. IEC 61850 is unique. In addition to the service requirements. The definition of the abstract services is specification of the protocol elements (how bytes are found in part 7.2 of the standard and the abstraction of the transmitted on the wire), IEC 61850 provides a data objects (referred to as Logical Nodes) is found in part comprehensive model for how power system devices should 7.4. In as much as many of the data objects are made up of organize data in a manner that is consistent across all types common pieces (such as Status, Control, Measurement, and brands of devices. This eliminates much of the tedious Substitution), the concept of “Common Data Classes” or non-power system configuration effort because the devices “CDC” was developed which defined common building can configure themselves. For instance, if you put a CT/VT blocks for creating the larger data objects. The CDC elements input into an IEC 61850 relay, the relay can detect this module are defined in part 7.3. and automatically assign it to a measurement unit without user interaction. Some devices use an SCL file to configure the Given the data and services abstract definitions, the final objects and the engineer need only import the SCL file into step was one of “mapping” the abstract services into an actual the device to configure it. Then, the IEC 61850 client protocol. Section 8.1 defines the mapping of the abstract data application can extract the object definitions from the device 3 over the network. The result is a very large
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