The International Electrotechnical Commission (IEC) is the primary international standardization organization for electrical, electronic and all related technologies, including the development and production of temperature sensors. The IEC was founded in London in 1906. The first president of the IEC was the famous British scientist Lord Kelvin. It includes representatives of 82 countries (60 countries are full members, 22 countries are associate members). Russia, Ukraine and Belarus are full members of the IEC. Representatives of the Tax Code of the Russian Federation are members of many technical committees and working groups of the IEC. Standards for temperature sensors are developed mainly within the framework of TK 65B/RG5 (SC 65B - Measurement and control devices , WG5 - Temperature sensors and instruments). On the basis of the Tax Code of the Russian Federation, the IEC has created the Russian Group of Experts on Temperature (RGE), whose task is Active participation in the development of IEC temperature standards. Details are in the RGE section. All information on current and newly developed IEC standards is obtained from the IEC portal: www.iec.ch

Current standards:

On the participation of Russian specialists in the development of IEC standards - in the section

The main set of chapters of the IEC 61850 standard, first edition, was published in 2002 - 2003. Later in 2003 - 2005 The remaining chapters of the first edition were published. In total, the first edition consisted of 14 documents. Later, some of the chapters were revised and supplemented, and some documents were added to the standard. The current edition of the standard already consists of 19 documents, a list of which is given below.

• IEC/TR 61850-1 ed1.0
• IEC/TS 61850-2 ed1.0
• IEC 61850-3 ed1.0
• IEC 61850-4 ed2.0
• IEC 61850-5 ed1.0
• IEC 61850-6 ed2.0
• IEC 61850-7-1 ed2.0
• IEC 61850-7-2 ed2.0
• IEC 61850-7-3 ed2.0
• IEC 61850-7-4 ed2.0
• IEC 61850-7-410 ed1.0
• IEC 61850-7-420 ed1.0
• IEC/TR 61850-7-510 ed1.0
• IEC 61850-8-1 ed2.0
• IEC 61850-9-2 ed2.0
• IEC 61850-10 ed1.0
• IEC/TS 61850-80-1 ed1.0
• IEC/TR 61850-90-1 ed1.0
• IEC/TR 61850-90-5 ed1.0

Let's take a closer look at the structure of the standard and its constituent documents. But first of all, let's define the terminology according to which documents are designated.

Types of IEC documents

The International Electrotechnical Commission distinguishes between the following types documents:

• International Standard (IS) – International Standard
• Technical Specification (TS) - Technical requirements
• Technical Report (TR) – Technical report

International Standard (IS)

An international standard is a standard formally adopted by the International Organization for Standardization and officially published. The definition given in all IEC documents is “A normative document, developed in accordance with approval procedures, which has been adopted by the members of the IEC National Committees of the responsible technical committee in accordance with Chapter 1 of the ISO/IEC Directives.

There are two conditions for the adoption of an international standard:

1. Two-thirds of the current members of a technical committee or subcommittee vote to adopt the standard
2. No more than one quarter of the total number of votes was cast against the adoption of the standard.

Technical Requirements (TS)

Specifications are often published when a standard is under development or when the necessary agreement has not been achieved for formal adoption of an international standard.

The specifications approach the International Standard in detail and completeness, but have not yet gone through all stages of approval because agreement has not been reached or because standardization is considered premature.

The technical requirements are similar to the International Standard and are a normative document developed in accordance with approval procedures. Technical requirements are approved by a two-thirds vote of the current members of the IEC Technical Committee or Subcommittee.

Technical Report (TR)

A technical report contains information different from that usually published in international standards, for example, data obtained from studies carried out among national committees, the results of the work of others international organizations or advanced technology data obtained from national committees and relevant to the subject of the standard.

Technical reports are purely informational in nature and do not act as regulatory documents.

Approval of the technical report is carried out by a simple majority vote of the current members of the IEC technical committee or subcommittee.

Published chapters of IEC 61850

Let us consider the contents of the chapters of the standard in order, as well as the documents being developed.

IEC/TR 61850-1 ed. 1.0 Introduction and general provisions

The first chapter of the standard is issued as a technical report and serves as an introduction to the IEC 61850 series of standards. The chapter describes basic principles, forming the basis of an automation system operating in accordance with IEC 61850. The first chapter of the standard defines a three-level automation system architecture, including the process level, bay level and station level. Initially, the standard defined only an automation system within one object and connections between several substations were not included in the model. Later the model was expanded in Fig. Figure 1 shows the architecture of the communication system described by the second edition of the standard, which also provides for communications between substations (see Fig. 1). Within each of the levels, as well as between levels, the structure of information exchange is described.

Rice. 1. Communication system architecture.

The list of interfaces and their purposes are also given in the first chapter of the standard and described in Table 1.

Table 1 – Interface Definitions

№	Interface
1	Exchange of protection function signals between bay and station levels
2	Exchange of protection function signals between the connection level of one object and the connection level of an adjacent object
3	Data exchange within the connection level
4	Transmission of instantaneous current and voltage values ​​from measuring transducers (process level) to bay level devices
5	Signal exchange between process and bay level equipment control functions
6	Exchange of control function signals between bay level and station level
7	Data exchange between the station level and the engineer’s remote workstation
8	Direct data exchange between bays, in particular for the implementation of high-speed functions such as online blocking
9	Data exchange within the station level
10	Exchange of control function signals between the station level and the remote control center
11	Exchange of control function signals between connection levels of two different objects, for example, discrete signals for implementing operational blocking or other automation

In addition, the first chapter of IEC 61850 describes for the first time:

• data modeling concept;
• concept of data naming with representation of logical nodes, objects and attributes of data;
• a set of abstract communication services;
• System Configuration Description Language.

The description of the above is presented in a fairly condensed form and in the first chapter is intended for informational purposes only.

IEC/TS 61850-2 ed. 1.0 Terms and definitions

The second chapter of the standard contains a glossary of terms, abbreviations and abbreviations used in the context of substation automation in the IEC 61850 series of standards. The chapter is approved in the format of Technical Requirements.

IEC 61850-3 ed. 1.0 General requirements

The third chapter of the standard is the only chapter in the series that specifies physical hardware requirements. Among these requirements, first of all, the requirements for electromagnetic compatibility of devices, permissible operating conditions, reliability, etc. are described.

The bulk of the requirements are given in the form of references to IEC 60870-2, -4 and IEC 61000-4.

It should be noted that one of the requirements of the standard, for example, is a declaration by the manufacturer of the mathematical expectation of time to failure (MTTF), as well as a description of the methodology according to which it is calculated. Knowledge of this important parameter will allow calculating the time between failures of the system as a whole.

IEC 61850-4 ed. 2.0 Systems engineering and project management

This chapter of the standard describes all entities involved in the implementation of the substation automation system and the distribution of responsibilities between them. Thus, the document describes the following participants: the customer in the form of an electric power company, a design organization or designer, an installation and commissioning organization and a manufacturer of equipment and software tools.

The document also describes the basic principles of project execution, commissioning and testing. In addition, the concept of distributing various functions between software and hardware tools is given. More detailed information on this part is given in the sixth chapter.

IEC 61850-5 ed. 1.0 Requirements for functions and devices regarding data transmission X

The fifth chapter of the standard details the conceptual principles of dividing the automation system into levels described in the first chapter, and also describes the concept of using logical nodes and proposes their classification in accordance with the functional purpose. In addition, the chapter provides examples of interaction diagrams of various logical nodes when implementing a number of functions RZA.

The terms “interoperability” and “interchangeability” are also mentioned here. At the same time, emphasis is placed on the fact that the standard does not imply interchangeability of devices; its purpose is to ensure functional compatibility of devices. These two concepts are often confused when discussing the IEC 61850 standard.

An important part of this chapter is also a description of the system performance requirements in terms of acceptable time delays.

The standard normalizes the total signal transmission time, which consists of three components:

• encoding time received from internal function signal by communication interface,
• signal transmission time over the communication network,
• the time of decoding data received from the communication network and transmitting it to the function of another device.

The total signal transmission time will be related to the total transmission time of similar signals using analog interfaces (for example, discrete relay inputs/outputs or analog current and voltage circuit inputs). The fifth chapter of the standard normalizes the permissible time delays for various types signals, including discrete signals, digitized instantaneous values ​​of currents and voltages, time synchronization signals, etc.

It should also be noted that in the second edition of the fifth chapter, the official publication of which is scheduled for autumn 2012, new system performance classes. However, in fact, the requirements for acceptable delays in the transmission of certain types of signals have not changed.

IEC 61850-6 ed. 2.0 Configuration description language for data exchange

The sixth chapter of the standard describes the file format for describing the configurations of devices involved in data exchange according to IEC 61850. The main task of the general format is to provide the ability to configure the device with external software.

This description file format is known as Substation Configuration Language (SCL) and is based on the XML markup language generally accepted in the IT environment.

In order to define clear rules for the generation of SCL format files, as well as ease of verification of the correctness of their composition, an XSD scheme was developed, which is also described in Chapter 6 and is an integral part of the IEC 61850 standard.

The original version of the diagram was published with the first edition of Chapter 6 in 2007. Later, the scheme underwent a number of changes, related, in particular, to error corrections and a number of additions to SCL files, and in 2009 its new edition was published.

Thus, there are now two editions of the scheme: 2007 and 2009, usually referred to as the “first” and “second” editions. Despite the differences between them, it is expected that devices that are compatible with the “second edition” should be backward compatible with the “first edition” devices. In practice, this does not always happen, unfortunately. However, this does not prevent communication between devices by assigning each device a configuration using the manufacturer’s software.

IEC 61850-7 Basic communication structure

The IEC 61850 standard defines not only data transfer protocols, but also the semantics with which this data is described. The seventh section of the standard describes approaches to modeling systems and data in the form of classes. All parts included in the seventh section are interconnected with each other, as well as with chapters 5, 6, 8 and 9.

IEC 61850-7-1 ed. 2.0 Basic Communication Structure – Principles and Models

Section 7-1 of the standard introduces basic methods for modeling systems and data, presents principles for organizing data transmission and information models used in other parts of IEC 61850-7.

This chapter describes the principle of representing a physical device with all the functions it contains as a set of logical devices, which, in turn, consist of a set of logical nodes. The technology for grouping data into data sets and then assigning this data to communication services is also described.

This chapter also describes the principles of data transfer carried out using the client-server or publisher-subscriber technology. However, it should be noted that this chapter, like the entire section 7, describes only the principles and does not describe the assignment of signals to specific communication protocols.

IEC 61850-7-2 ed. 2.0 Basic communications structure – Abstract Communications Interface (ACSI)

Chapter 7-2 describes the so-called “abstract communication interface” for power plant automation systems.

The chapter describes the class diagram and data transfer services. A conceptual diagram of class connections is shown in Fig. 2. A more detailed description of this scheme will be given in one of the future publications under the heading.

Rice. 2. Class connection diagram.

The chapter gives detailed description properties of each class, and the data transfer services section presents the connection of these classes with possible services, such as reports, event logs, reading/writing data or files, multicasting and instantaneous value transfer.

Thus, the chapter in abstract form describes in detail the entire structure of communications, starting from the description of the data itself, as a class, and ending with the services for transmitting it. However, as mentioned above, all this description is given only in abstract form.

IEC 61850-7-3 ed. 2.0 Basic Communication Structure – General Data Classes

As can be seen from Fig. 2, each data class (DATA) includes one or more data attributes (DataAttribute). Each data attribute is, in turn, described by a specific data attribute class. Chapter 7-3 describes all possible data classes and data attribute classes.

Data classes include several groups:

• Classes for describing state information
• Classes for describing measured values
• Classes for control signals
• Classes for discrete parameters
• Classes for continuous parameters
• Classes for Descriptive Data

The described classes allow you to model all kinds of data within the framework of the PS automation system for the purpose of further exchange of this data between devices and systems.

Compared to the first chapter, the second took into account adjustments in accordance with Tissues, in addition, new classes of data and attributes were added that were required in new information models built in accordance with the requirements of the standard and used outside of substation automation systems.

IEC 61850-7-4 ed. 2.0 Basic Communication Structure – Logical Node and Data Object Classes

This chapter of the standard describes the information model of devices and functions related to substations. In particular, it defines the names of logical nodes and data for data transfer between devices, and also determines the relationship of logical nodes and data.

The logical node and data names defined in Chapter 7-4 are part of the class model proposed in Chapter 7-1 and defined in Chapter 7-2. The names defined in this document are used to construct hierarchical references to objects for the purpose of further reference to data in communications. This chapter also applies the naming rules defined in Chapter 7-2.

All logical node classes have names consisting of four letters, and the first letter in the name of a logical node class indicates the group to which it belongs (see Table 3).

Table 3 – List of logical node groups

Group indicator	Group name
A	Automatic control
B	Reserved
C	Dispatch control
D	Distributed Energy Sources
E	Reserved
F	Function blocks
G	General Features
H	Hydropower
I	Interfaces and archiving
J	Reserved
K	Mechanical and non-electrical equipment
L	System logical nodes
M	Accounting and measurements
N	Reserved
O	Reserved
P	Protection functions
Q	Electrical energy quality control
R	Protection functions
S*	Supervisory control and monitoring
T*	Instrument transformers and sensors
U	Reserved
V	Reserved
W	Wind power
X*	Switching devices
Y*	Power transformers and related functions
Z*	Other electrical equipment
* Logical nodes of these groups exist in dedicated IEDs, provided that the process bus is used. If the process bus is not used, then the specified logical nodes correspond to I/O modules and are located in the IED, connected by copper links to the equipment and located at a higher level (for example, at the bay level) and represent the external device by its inputs and outputs (process projection).

IEC 61850-7-410, -420 and -510

The IEC 61850-7-410 and -420 standards are extensions of Chapter 7-2 and contain descriptions of logical node classes and data for hydroelectric power plants and small-scale generation.

Technical Report IEC/TR 61850-7-510 explains the use of logical nodes defined in Chapter 7-410, as well as other documents in the IEC 61850 series, to model complex control functions in electrical power plants, including variable speed pumped storage plants.

IEC 61850-8-1 ed. 2.0 Assignment to a specific communication service – Assignment to MMS and IEC 8802-3

As noted above, section 7 of the standard describes only the fundamental mechanisms for data transfer. Chapter 8-1, in turn, describes methods for exchanging information over local networks by assigning abstract communication services (ACSI) to the MMS protocol and ISO/IEC 8802-3 frames.

Chapter 8-1 describes protocols for both latency-critical and non-latency-critical data exchanges.

Services and the MMS protocol operate on the full OSI model on top of the TCP stack, due to which data transmission over this protocol is carried out with relatively large time delays, so the use of the MMS protocol allows you to solve data transfer tasks for which the delay is not critical. For example, this protocol can be used to transmit telecontrol commands, collect telemetering and telesignaling data, and send reports and logs from remote devices.

In addition to the MMS protocol, Chapter 8-1 describes the purpose of data that requires fast data transfer. The semantics of this protocol are defined in IEC 61850-7-2. Chapter 8-1 describes the protocol syntax, defines the purpose of ISO/IEC 8802-3 data frames, and defines procedures related to the use of ISO/IEC 8802-3. This protocol is known to specialists as the GOOSE protocol. Due to the fact that data in this protocol is assigned directly to the Ethernet frame, bypassing the OSI model and bypassing the TCP stack, data transmission in it is carried out with noticeably lower delays compared to MMS. Thanks to this, GOOSE can be used to transmit circuit breaker tripping commands and similar fast signals.

IEC 61850-9-1 ed. 1.0 Assignment to a specific communication service – Transmission of instantaneous values ​​via the serial interface

This chapter described methods for transmitting instantaneous values ​​by assigning data to a serial interface according to IEC 60044-8. However, in 2012, this chapter was removed from the IEC 61850 series of standards and is no longer supported.

IEC 61850-9-2 ed. 2.0 Assignment to a specific communication service – Transmission of instantaneous values ​​via the IEC 8802-3 interface

Chapter 9-2 of the IEC 61850 standard describes methods for transmitting instantaneous values ​​from CTs and VTs via the IEC 8802-3 interface, that is, they will determine the assignment of the class of service for transmitting instantaneous values ​​from measuring CTs and VTs IEC 61850-7-2 to the ISO/IEC 8802- protocol 3.

This chapter of the standard applies to current and voltage measuring transformers with a digital interface, process bus interface devices and IEDs with the ability to receive data from CTs and VTs in digital form.

In fact, this chapter describes the format of an Ethernet frame depending on what data is assigned to it, that is, it will determine its relationship with the data class according to IEC 61850-7-2 and description according to IEC 61850-6.

The first edition of Chapter 9-2 did not provide for such important points, as provision of redundancy. In the second edition, these shortcomings were taken into account, and therefore the 9-2 frame format was supplemented with fields for PRP or HSR reservation protocol labels.

Specification IEC 61850-9-2LE

The first edition of the IEC 61850-9-2 standard was published in 2004, however, the lack of clearly defined requirements for sampling rates of instantaneous values ​​and the composition of the transmitted packet could lead to potential incompatibility of solutions different manufacturers. In order to facilitate the development of compatible solutions based on the IEC 61850-9-2 protocol, the UCA user group, in addition to the standard, also developed a specification (referred to as “9-2LE”), which specified the composition of the transmitted data packet and defined two standard frequencies: 80 and 256 samples per power frequency period, that is, it actually established standard requirements for the IEC 61850-9-2 interface for all devices.

The appearance of this specification along with the document significantly influenced the intensity of penetration of the protocol into equipment. However, it should be understood that this document is not a standard in itself, but only specifies the requirements of the standard, that is, it represents a specification of the standard.

IEC 61850-10 ed. 1.0 Compliance check

The tenth chapter of the standard defines the procedures for testing the conformity of devices and software requirements of the standard and specifications.

In particular, the chapter defines a methodology for checking the compliance of actual delays during the formation and processing of message packets with the stated parameters and requirements of the standard.

IEC/TS 61850-80-1 ed. 1.0 Guidance on transferring information from a common data class model using IEC 60870-5-101 or IEC 60870-5-104

The document describes the assignment of the general IEC 61850 data classes to the IEC 60870-5-101 and -104 protocols.

IEC/TR 61850-90-1 ed. 1.0 Use of IEC 61850 for communication between substations

Initially, the IEC 61850 standard was designed to ensure data transmission between devices only within a substation. Subsequently, the proposed concept found application in other systems in the electric power industry. In this way, the IEC 61850 standard can become the basis for global standardization of data networks.

Existing and developing protection and automation functions require the ability to transfer data not only within, but also between substations; therefore, it is necessary to expand the scope of the standard for data exchange between substations.

The IEC 61850 standard provides the basic tools, but a number of changes are required to standardize communication protocols between objects. Technical Report 90-1 provides an overview of the various aspects that must be taken into account when using IEC 61850 for data exchange between substations. Areas that require expansion of existing standard documents will later be included in the current versions of the standard chapters.

One example of a needed extension would be the transmission of GOOSE messages between objects. Currently, GOOSE messages can only be broadcast to all devices on the local network, but they cannot pass through network gateways. Chapter 90-1 describes the principles of establishing tunnels for transmitting GOOSE messages between different local networks objects.

IEC/TR 61850-90-5 ed. 1.0 Use of IEC 61850 for transmission of data from synchronized vector measurement devices in accordance with IEEE C37.118

The main purpose of Technical Report 90-5 was to propose a method for transferring synchronized phasor measurements between a PMU and a control system. Data described by the IEEE C37.118-2005 standard is transmitted in accordance with the technologies provided by IEC 61850.

However, in addition to the initial tasks, this report also presents profiles for routing GOOSE (IEC 61850-8-1) and SV (IEC 61850-9-2) packets.

IEC 61850 documents under development

In addition to the documents reviewed, 21 more documents are currently being developed by working group 10, as well as related working groups, which will be part of the IEC 61850 series of standards.

Most of specified documents will be published in the form of technical reports:

• IEC/TR 61850-7-5. Using information models of substation automation systems.
• IEC/TR 61850-7-500. Using logical nodes to model the functions of substation automation systems.
• IEC/TR 61850-7-520. Using logical nodes of small generation objects.
• IEC/TR 61850-8-2. Assignment to web services.
• IEC/TR 61850-10-2. Tests for functional compatibility of hydroelectric power plant equipment.
• IEC/TR 61850-90-2. Use of the IEC 61850 standard to organize communication between substations and control centers.
• IEC/TR 61850-90-3. Use of IEC 61850 in equipment condition monitoring systems.
• IEC/TR 61850-90-4. Guidelines for the engineering of communication systems in substations.
• IEC/TR 61850-90-6. Use of IEC 61850 for automation of distribution networks.
• IEC/TR 61850-90-7. Object models for power plants based on photocells, batteries and other objects using inverters.
• IEC/TR 61850-90-8. Object models for electric vehicles.
• IEC/TR 61850-90-9. Object models for batteries.
• IEC/TR 61850-90-10. Object models for systems for planning operating modes of small-scale generation facilities.
• IEC/TR 61850-90-11 Modeling of freely programmable logic.
• IEC/TR 61850-90-12. Guidelines for distributed communications network engineering.
• IEC/TR 61850-90-13. Expanding the composition of logical nodes and data objects for modeling equipment of gas turbine and steam turbine plants.
• IEC/TR 61850-90-14. Using the IEC 61850 standard to model FACTS equipment.
• IEC/TR 61850-90-15. Hierarchical model of small generation objects.
• IEC/TR 61850-100-1. Functional testing of systems operating under the terms of the IEC 61850 standard.

Conclusion

The IEC 61850 standard, originally developed for use within substation automation systems, is gradually beginning to extend to automation systems for other power system assets, as evidenced by a number of recently published and even more upcoming documents. New equipment and new technologies developing “under the flag” of intellectualization of the power system are accompanied by their description in the context of the IEC 61850 standard, while the development/modernization of other standards similar in purpose is not carried out. This allows us to make a bold assumption that every year the standard will become more widespread in practice.

Bibliography

1. http://www.iec.ch/members_experts/refdocs/governing.htm
2. http://tissue.iec61850.com
3. Implementation Guideline for Digital Interface to Instrument Transformers Using IEC 61850-9-2. UCA Internation Users Group. Modification Index R2-1. http://iec61850.ucaiug.org/implementation%20guidelines/digif_spec_9-2le_r2-1_040707-cb.pdf

With the development of digital technologies, manufacturers of electrical equipment have not been left behind. Despite the presence international classification ISO, in Russia the European standard IEC 61850 was used, which is responsible for substation systems and networks.

A little history

Development computer technology electrical grid management systems were not spared. The IEC 61850 standard, which is generally accepted today, was originally presented in 2003, although attempts to implement systems on this basis were carried out back in the 60s of the last century.

Its essence comes down to the use of special protocols for managing electrical networks. Based on them, the functioning of all networks of this type is now monitored.

If previously the main attention was paid exclusively to the modernization of computer systems that control the electric power industry, then with the introduction of rules, standards, and protocols in the form of IEC 61850, the situation has changed. The main objective of this GOST was to ensure monitoring in order to timely identify problems in the operation of the relevant equipment.

IEC 61850 protocol and its analogues

The protocol itself began to be used most actively in the mid-80s. Then, the first versions tested were modifications of IEC 61850-1, IEC 60870-5 versions 101, 103 and 104, DNP3 and Modbus, which turned out to be completely untenable.

And it was this initial development that formed the basis of the modern UCA2 protocol, which was successfully applied in Western Europe in the mid-90s.

How it works

Dwelling on the issue of functioning, it is worth explaining what the IEC 61850 protocol is for “dummies” (people who are just learning the basics of working and understanding the principles of communicating with computer equipment).

The bottom line is that a microprocessor chip is installed at a substation or power station, which allows data on the state of the entire system to be transmitted directly to the central terminal, which carries out the main control.

But, as practice shows, these systems also turn out to be quite vulnerable. Have you watched American films when in one of the episodes the power supply of an entire block is cut off? Here it is! Control of electrical networks based on the IEC 61850 protocol can be coordinated from any external source (it will be clear why later). For now, let's look at the basic system requirements.

Standard R IEC 61850: requirements for communication systems

If previously it was understood that the signal had to be transmitted using a telephone line, today communications media have stepped far forward. The built-in chips are capable of providing transmission at the 64 Mbit level, being completely independent of providers providing standard connection services.

If we consider the IEC 61850 standard for dummies, the explanation looks quite simple: the power unit chip uses its own data transfer protocol, and not the generally accepted TCP/IP standard. But that's not all.

The standard itself is the IEC 61850 protocol for data transmission with a secure connection. In other words, connecting to the same Internet, wireless network, etc. is carried out in a very specific way. The settings, as a rule, use the parameters of proxy servers, since they are the most secure (even virtual ones).

General Applications

It is clear that according to the requirements set by GOST IEC 61850, it will not be possible to install equipment of this type in a regular transformer booth (there is simply no place for a computer chip there).

Such a device will also not work even if desired. It needs at a minimum an initial input/output system akin to a BIOS, as well as an appropriate communication model for data transfer (wireless network, wired secure connection, etc.).

But in the control center of a general or local power grid, you can get access to almost all functions of power plants. An example, although not the best, is the film “The Core”, when a hacker prevents the death of our planet by destabilizing the energy source that powers the “backup” version of promotion

But this is pure fantasy, rather even a virtual confirmation of the requirements of IEC 61850 (although this is not directly stated). However, even the most primitive emulation of IEC 61850 looks exactly like this. But how many disasters could have been avoided?

The same 4th power unit Chernobyl nuclear power plant, if diagnostic tools that complied with at least IEC 61850-1 were installed on it, perhaps it would not have exploded. And since 1986, all that remains is to reap the fruits of what happened.

Radiation is such that it acts secretly. In the first days, months or years, they may not appear, not to mention the half-lives of uranium and plutonium, which few people pay attention to today. But integrating the same into the power plant could significantly reduce the risk of staying in this zone. By the way, the protocol itself makes it possible to transmit such data at the hardware and software level of the involved complex.

Simulation technique and conversion to real protocols

For the simplest understanding of how, for example, the IEC 61850-9-2 standard works, it is worth saying that not a single iron wire can determine the direction of the transmitted data. That is, we need an appropriate relay capable of transmitting data about the state of the system, and in encrypted form.

Receiving a signal, as it turns out, is quite simple. But in order for it to be read and decrypted by the receiving device, you will have to work hard. In fact, in order to decipher an incoming signal, for example, based on IEC 61850-2, at the initial level you need to use visualization systems like SCADA and P3A.

But based on the fact that this system uses wired communications, the main protocols are GOOSE and MMS (not to be confused with mobile messages). The IEC 61850-8 standard performs this conversion by sequentially using first MMS and then GOOSE, which ultimately makes it possible to display information using P3A technologies.

Basic types of substation configuration

Any substation using this protocol must have at least a minimum set of tools for data transmission. First, it concerns the physical device itself connected to the network. Secondly, each such unit must have one or more logical modules.

In this case, the device itself is capable of performing the function of a hub, gateway, or even a kind of intermediary for transmitting information. The logical nodes themselves have a narrow focus and are divided into the following classes:

• "A" - automated systems management;
• “M” - measurement systems;
• “C” - telemetric control;
• "G" - modules general functions and settings;
• “I” - communication means and data archiving methods used;
• “L” - logical modules and system nodes;
• "P" - protection;
• "R" - related protective components;
• “S” - sensors;
• “T” - transformers-meters;
• “X” - block-contact switching equipment;
• “Y” - power type transformers;
• "Z" - everything else that is not included in the above categories.

It is believed that the IEC 61850-8-1 protocol, for example, can provide less use of wires or cables, which, of course, only has a positive effect on the ease of equipment configuration. But the main problem, as it turns out, is that not all administrators are able to process the received data, even if they have the appropriate software packages. I would like to hope that this is a temporary problem.

Application software

However, even in a situation of misunderstanding physical principles the actions of programs of this type, emulation of IEC 61850 can be carried out in any operating system(even on mobile).

It is believed that management personnel or integrators spend much less time processing data coming from substations. The architecture of such applications is intuitive, the interface is simple, and all processing consists only of entering localized data with subsequent automatic output of the result.

The only disadvantages of such systems include the inflated cost of P3A equipment (microprocessor systems). Hence the impossibility of its mass use.

Practical use

Until now, everything stated in relation to the IEC 61850 protocol concerned only theoretical information. How does this work in practice?

Let's say we have power point(substation) with three-phase power supply and two measuring inputs. When defining a standard logical node, the name MMXU is used. For the IEC 61850 standard there can be two of them: MMXU1 and MMXU2. Each such node may also contain an additional prefix to simplify identification.

An example is a modeled node based on XCBR. It is identified by using some basic operators:

• Loc - determination of local or remote location;
• OpCnt - method of counting completed (in progress) operations;
• Pos is an operator responsible for location and similar to the Loc parameters;
• BlkOpn - command to disable the switch lock;
• BlkCls - enable blocking;
• CBOpCap - select the switch operation mode.

This classification for describing CDC data classes is mainly used in modification 7-3 systems. However, even in this case, configuration is based on the use of several characteristics (FC - functional restrictions, SPS - state of a single control point, SV and ST - properties of substitution systems, DC and EX - description and extended definition of parameters).

Regarding the definition and description of the SPS class, the logical chain includes the properties stVal, quality - q, and current time parameters - t.

In this way, data is transformed using Ethernet connection technologies and TCP/IP protocols directly into the MMS object variable, which is then identified with an assigned name, which leads to obtaining the true value of any indicator currently involved.

In addition, the IEC 61850 protocol itself is just a generalized and even abstract model. But on its basis, a description of the structure of any element of the energy system is made, which allows microprocessor chips to accurately identify each device involved in this area, including those that use energy-saving technologies.

In theory, the protocol format can be converted to any data type based on the MMS and ISO 9506 standards. But why then was the control standard IEC 61850 chosen?

It is associated solely with the reliability of the received parameters and the easy process of working with assigning complex names or models of the service itself.

Such a process without using the MMS protocol turns out to be very labor-intensive, even when generating queries like “read-write-report”. No, of course, it is possible to perform this type of conversion even for the UCA architecture. But, as practice shows, it is the use of the IEC 61850 standard that allows you to do this without much effort and time.

Data verification issues

though this system is not limited to transmission and reception. In fact, embedded microprocessor systems allow data exchange not only at the level of substations and central control systems. If they have the appropriate equipment, they can process data among themselves.

The example is simple: an electronic chip transmits data about current or voltage in a critical area. Accordingly, any other subsystem can activate or disable the additional power system based on the voltage drop. All this is based on the standard laws of physics and electrical engineering, although it depends on the current. For example, our standard voltage is 220 V. In Europe it is 230 V.

If you look at the deviation criteria, in former USSR this is +/- 15%, while in developed European countries it is no more than 5%. It is not surprising that branded Western equipment simply breaks down due to voltage fluctuations in the electrical network.

And it probably doesn’t need to be said that many of us see a structure in the yard in the form of a transformer booth, built back in the days of the Soviet Union. Do you think it is possible to install a computer chip there or connect special cables to obtain information about the state of the transformer? That's just it, no!

New systems based on the IEC 61850 standard allow for complete control of all parameters, but the obvious impossibility of its widespread implementation discourages relevant services like Energosbyt from using protocols of this level.

There is nothing surprising about this. Companies that distribute electricity to consumers may simply lose profits or even market privileges.

Instead of a total

In general, the protocol, on the one hand, is simple, but on the other, very complex. The problem is not even that today there is no appropriate software, but that the entire system of control over the electric power industry, which we inherited from the USSR, is simply not prepared for this. And if we take into account the low qualifications of the service personnel, there can be no question of anyone being able to monitor or eliminate problems in a timely manner. How is it customary here? Problem? We cut off power to the neighborhood. That's all.

But the use of this standard allows us to avoid such situations, not to mention any rolling blackouts.

Thus, all that remains is to draw some conclusions. What benefits does using the IEC 61850 protocol bring to the end user? In the simplest sense, this is an uninterrupted power supply with no voltage drops in the network. Please note that if the computer terminal or laptop is not equipped with an uninterruptible power supply or voltage stabilizer, a surge or surge can cause an immediate shutdown of the system. Okay, if you need to restore at the software level. What if the planks burn out? random access memory or the hard drive fails, what should I do then?

This, of course, is a separate subject for research, but the standards themselves, currently used in power plants with the appropriate hardware and software diagnostic tools, are capable of monitoring absolutely all network parameters, preventing situations with the occurrence of critical failures that can lead not only to the breakdown of household appliances , but also to the failure of the entire home wiring (as is known, it is designed for no more than 2 kW at a standard network voltage of 220 V). Therefore, turning on the refrigerator at the same time, washing machine or a boiler for heating water, think a hundred times how justified this is.

If these protocol versions are enabled, the subsystem settings will be applied automatically. And in the most to a greater extent this concerns the tripping of the same 16-amp fuses that residents of 9-story buildings sometimes install on their own, bypassing the services responsible for this. But the price of the issue, as it turns out, is much higher, because it allows you to bypass some of the restrictions associated with the above-mentioned standard and its accompanying rules.

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Work on international cooperation in the field of electrical engineering began in 1881, when the first International Congress on Electricity was convened. In 1904, at a meeting of government delegates of the International Electricity Congress in St. Louis (USA), it was decided that it was necessary to create a special body dealing with the standardization of terminology and parameters of electrical machines.

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