Digital substation. How digital substation equipment is made Digital equipment of a digital substation

DIGITAL

SUBSTATION

DIGITAL

SUBSTATION

INTERACTIVE CONTROL OF SUBSTATION SERVICE SYSTEMS THROUGH THE TOUCH PANEL OF THE INDUSTRIAL CONTROLLER

MICROPROCESSOR TERMINALS FOR PROTECTION AND AUTOMATION, ELECTRICITY METERS SUPPORTING IEC 61850 PROTOCOLS

CONVENTIONAL CURRENT TRANSFORMERS AND VOLTAGE TRANSFORMERS TOGETHER WITH BUS INTERFACE

MEASUREMENTS, CONTROL AND SIGNALING ARE IMPLEMENTED IN A SCADA SYSTEM CONTROLLED VIA INDUSTRIAL COMPUTER WITH HMI TOUCH PANEL

What is a digital substation?

This is a substation equipped with a complex of digital devices that ensure the functioning of relay protection and automation systems, electricity metering, automatic process control systems, and emergency event registration according to the IEC 61850 protocol.

The implementation of IEC 61850 makes it possible to connect all the technological equipment of the substation with a single information network, through which not only data from measuring devices to the RPA terminals, but also control signals are transmitted.

An exclusive solution has become available

IEC 61850 standard is very well known in substations with supply voltage class 110kV and above, we offer application solution this standard in classes 35kV, 10kV and 6kV.

Why is a digital substation necessary?

Reduce design time by 25%

Typification of circuit and functional solutions. Reducing the number of functional circuits, terminal rows in the relay compartments of cells.

Reducing the volume of installation and adjustment work by 50%

A high prefabrication solution is used. The plant performs the installation of switchgear equipment for the main and auxiliary circuits. Intercabinet communications of operating current systems are laid, automated process control systems, ASKUE are mounted. Parameterization, configuration and testing of RPA systems is carried out.

Reduce maintenance costs by 15%

Transition from scheduled maintenance by time to maintenance according to the state of the equipment due to On-line diagnostics of the state of the equipment. This reduces the number of trips of workers for routine maintenance.

100% operational switching is performed remotely with video monitoring of operations

Simple integration of all systems into a single digital space allows you to manage the substation safely and efficiently, as well as integrate other levels of process control systems into the system.

How it works?

DIGITAL SUBSTATION IEC 61850

The customer is supplied with 100% factory-ready digital packaged transformer substations, including all major substation systems: APCS, ASKUE and SN.

KRU "Classic" have a modern architecture and in terms of their design and operational parameters meet all modern requirements to the highest degree. Thanks to a wide grid of main circuit diagrams, a high degree of flexibility is achieved in the design and application of switchgear.

All 10 kV switchgear cells installed in the substation are equipped with an electric drive of the grounding switch and a withdrawable cassette element with a switch.

The SKP module is a special electrical container with insulation, equipped with lighting, heating and ventilation systems and electrical equipment built into it.

These modules have a high factory readiness with short installation and commissioning time, which, along with high corrosion resistance and the ability to operate in harsh climatic conditions, makes them indispensable in the construction of complete transformer substations.

■ The modular building does not require maintenance during its entire service life.

■ manufacturer gives a guarantee for anti-corrosion protection and painting for the entire service life.

■ The modular building has a heat loss capacity of no more than 4 kW in normal operation (outside temperature-40°C, inside temperature +18°C) and 3 kW in energy saving mode (outside temperature -40°C, inside temperature +5°C).

SKP modules are made of metal with an aluminum-zinc coating (Al-55%-Zn-45%), which provides guaranteed protection against corrosion for the entire service life of the modules.

How it works?

How it works?

DIGITAL SUBSTATION IEC 61850

Switchgear cabinets are equipped with microprocessor terminals for protection and automation, as well as analog-to-digital converters. The conversion of analog signals into digital ones does not go beyond one switchgear cabinet.

For the operation of the protections UROV, ZMN, AVR, LZSH, arc protection, DZT, OBR, an inter-terminal connection is required. Using the IEC 61850 protocol, all signals between terminals are transmitted over one optical cable or one Ethernet cable. Thus, the exchange between cabinets is carried out only on a digital channel, which eliminates the need for traditional circuits connecting cabinets.

The use of optical cable or Ethernet cable instead of conventional signal cables reduces the duration and cost of substation downtime during the reconstruction of secondary equipment and creates an opportunity for easy and quick reconfiguration of the protection and automation system.

Most of the discrete signals transmitted between relay protection and automation devices directly affect the rate of elimination of the emergency mode, so the signal is transmitted using the IEC 61850-8.2 puncture. (GOOSE), which is characterized by high performance.

Transmission time of one GOOSE data packet

messages does not exceed 0.001 seconds.

Was Became

The transmission of measurements and discrete signals from RPA devices to the APCS system is carried out using the MMS protocol (using buffered and unbuffered report services). During the operation of telesignaling and telemetry systems, a large amount of data is transmitted. To reduce the load on the information network, the MMS protocol is used, which is characterized by the compactness of the transmitted information.

How it works?

The IEC 61850 communication protocol enables real-time self-diagnosis of the equipment and all systems installed in the substation. In case of detection of deviations from the normal mode of operation, the system automatically activates the backup circuit, and the corresponding message is issued to the operating personnel.

The system analyzes the received data and generates recommendations for maintenance equipment, which allows you to change the principle of work from regular scheduled preventive work to work in the event of a malfunction. This principle of operation makes it possible to reduce the cost of personnel for the maintenance of equipment.

Thanks to the IEC 61850 protocol with a standardized interface, when designing a substation, it is possible to use equipment from any manufacturer that supports this protocol. The DSP has the ability to be easily integrated into the upper-level process control system.

How it works?

DIGITAL SUBSTATION IEC 61850

In the digital substation ETZ Vector, full remote control of all switching devices of connections is implemented: a circuit breaker, withdrawable element, grounding switch. Thus, the complete control of the substation is carried out remotely, which significantly increases the safety of personnel.

Collection of information from the entire substation and real-time control of switching devices is carried out using the Scada-system, which is included in the basic package of all ETZ Vector digital substations.

An automated workspace is provided for operational personnel at the substation and/or control room. Scada-system allows you to visualize the signals and events occurring at the substation, and provides detailed information about an alarm or event in a graphical display.

Additionally, one of the functions of the Scada-system is the broadcast of video images from cameras installed in the compartments of cells, which allows you to monitor the status of switching devices.

Scada - the system is easily integrated with any software systems the top level, so it will not be difficult to include the substation in a single digital space of the power district.

V.M. Zinin (JSC NIPOM)
A.M. Podlesny (InSAT LLC)
V.G. Karantaev (JSC InfoTeKS)

Used technological solutions of the Unified Energy Grid (UES), created more than 60 years ago, in many respects approach the frontier of operational possibilities. According to the development concept of the UES, developed in 2011, the next step could be an intelligent system with an active-adaptive grid (AAC), in foreign terminology - Smart Grid. The process of increasing the level of automation of UES facilities is already underway, introducing new technologies, the use of which generates not only all kinds of difficulties in purely technological implementation, but also risks information security.

One of the most important constituent parts concept of Smart Grid is a digital substation (DSP). DSP is understood as a substation with a high level of control automation, in which almost all processes of information exchange both between DSP elements and with external systems, as well as the control of the DSP operation are carried out digitally based on IEC protocols, in particular, according to the open object-oriented standard IEC 61850. In accordance with this standard, devices must support (Fig. 1): the ability to receive samples of instantaneous values ​​(Simpled Values), analog current/voltage signals, the possibility of publishing/subscribing to GOOSE messages, the possibility of information exchange using the “client-server” technology using the MMS protocol. MMS works on top of the TCP stack, which affects the data transfer rate, so MMS is often used to solve problems of transferring non-delay-critical data, for example, transferring telecontrol commands, collecting telemetry and telesignaling data and transferring them to the upper level - SCADA systems. Unlike the MMS protocol, GOOSE, on the contrary, can be used to transmit "fast signals", such as commands to turn off the circuit breaker, due to the fact that the data in this protocol is assigned directly to the Ethernet frame, bypassing the TCP stack.

Newly created software and hardware systems, such as a digital substation, must comply with the current regulatory legal acts of the Russian Federation, as well as take into account the best world practices in building cyber defense systems.

A DSP that satisfies the formulated requirements must have high-tech means of protection against cyber attacks, since it is primarily an object of critical information infrastructure (CII), as evidenced by the project federal law No. 47571-7 “On the safety of CII Russian Federation”, recommended by the State Duma Energy Committee and adopted in the first reading on January 27, 2017. This bill defines the main principles of state regulation in the field of protecting the country's CII in order to ensure its sustainable functioning in the event of computer attacks. It was developed to implement the “Information Security Doctrine
of the Russian Federation”, approved by the President of Russia on December 5, 2016, which defines the protection of CII as one of the strategic goals. According to the bill, “critical infrastructure includes information systems and telecommunications networks of government agencies, automated process control systems operating in the defense industry, healthcare, transport, communications, credit and finance, energy, fuel, nuclear, rocket and space, mining, metallurgical and chemical industry."

Detailing these requirements, the created DSP must have the following characteristics that ensure the cyber protection of the object:

• be created on a Russian trusted hardware and software platform with the main components (operating system, microprocessor, peripheral interface controller, basic input / output system) developed in the Russian Federation by Russian specialists and having
• complete design documentation;
• take into account the provisions of the standards developed by the IEC TC57 group: IEC 61850, IEC60870, IEC 62351, regarding the security of communication protocols, as well as the requirements of the INL Cyber ​​Security Procurement Language 2008 standard, a series of ISO/IEC 27000 standards, regarding general principles
• ensuring the security of digital control systems and GOST-R IEC 62443-3-2013;
• use Russian hosted cryptographic algorithms that are built into each element or each subsystem of a digital substation.

Another distinguishing feature of the construction technological systems management in the electric power industry is that the use of cryptographic information protection tools (CIPF) in them should not reduce performance, since the duration of transient (emergency) processes is tens of microseconds. In many microcontrollers used today, the embedding of cybersecurity elements is either not initially provided by the developer, or it is impossible, since their embedding will not provide the required performance.

Based on many years of experience and knowledge in their subject areas, specialists from the companies NIPOM OJSC, InSAT LLC, InfoTeKS OJSC and PJSC INEUM im. I.S. Bruk have developed a digital substation that meets all these requirements. The “lower” level of the DSP is based on innovative relay protection terminals (RPA) of the NIPOM OJSC company. The developed relay protection and automation terminal (Fig. 2) is made in the form of a cassette of a block design with rear connection of external wires and is equipped with a test control system that serves
to check the performance of the main components and blocks.

The RPA terminal housing contains discrete input/output boards, an analog input board for supplying measured currents and voltages, a cross-board for matching the cable part of universal boards (AI, DO/DI), a power supply unit and an industrial computer with an Elbrus microprocessor , since the functioning of the CSIS of the OS Elbrus provides the required level of protection of information from unauthorized access (UAS) and does not affect the performance of the system. Each DO/DI board contains 11 DI channels and 10 DO channels. So

Thus, from 33 to 66 DI channels and from 30 to 60 DO channels can be made in one housing, which allows using the developed RPA terminals both at objects with a small number of signals and at complex ones with a large number of connections. To implement the signaling functions of the differential current longitudinal protection of the line (DLL) using the SV protocol (IEC 61850), the number of Ethernet ports can be increased by adding a standard Ethernet card to an industrial computer without changing its design. The complete separation of the terminal logic and its hardware design has made it possible to provide ample opportunities for freely configurable protection circuit logic. The special features of the terminal that increase its cybersecurity include strong two-factor authentication mechanisms implemented by JSC NIPOM together with JSC InfoTeKS.

The “upper” level of the developed system, as mentioned earlier, is a server based on the domestic Elbrus processor with the same name. operating system, which can be reserved if necessary. In addition, depending on the requirements of a particular object, the AstraLinux OS can also be used in the solution. The Russian SCADA-system MasterSCADA 4D manufactured by InSAT LLC is used as a data collection and processing environment. MasterSCADA 4D is a cross-platform, vertically integrated software platform with object-oriented programming methods, including languages ​​of the IEC 61131-3 standard, and the only SCADA system currently running on the Elbrus OS. MasterSCADA 4D collects information from the RPA terminal through the built-in IEC 61850 (MMS) protocol driver and provides data in the form of mnemonic diagrams, reports and trends to the automated workplace substation operator. The starting (main) mnemonic diagram of the operator (Fig. 3) displays a single-line diagram of the substation, connection and the state of the primary equipment.

In addition, the operator always has information about the health of the network topology of the DPS in the form of status signaling (including workstations, SCADA servers and secondary communication equipment) with latching complete list alarms in the event log. The built-in protection mechanisms of MasterSCADA 4D provide authentication and identification of users in the system, as well as the differentiation of their access rights according to a role model predefined by the developer, registration of all user actions from the moment of identification to logging out of the system.

In order to protect the electronic perimeter of the substation and implement the principle of multi-level protection, security gateways developed by InfoTeKS OJSC, ViPNetCoordinator HW 1000, were used. The local area network of the substation was divided/segmented into several security domains, i.e. substation zones with different requirements for providing information security.

Thus, using the industrial security gateway ViPNetCoordinator IG, access rights were delimited between
station level and bay and process bus levels, which is shown by the functional diagram in fig. five.

The implementation of the principle of multi-level protection using firewalls is not only possible, but also a necessary measure for protecting information at substations that are in operation and undergoing partial modernization in accordance with the requirements of the Order of the FSTEC of Russia dated March 14, 2014 No. 31.

It would be wrong to recognize the use of imposed SI tools both at newly created substations and at substations undergoing deep modernization as sufficient, since there remain high risks of computer attacks on unprotected telecommunication protocols: MMS, GOOSE, SV.

Given the need to meet a set of requirements for functional reliability, security, speed of telecommunication protocols, as well as cost-effectiveness, the implementation of the concept of embedding cryptographic information protection tools in each element or each subsystem of a digital substation looks most promising.

OJSC NIPOM, LLC InSAT, OJSC InfoTeKS and PJSC INEUM im. I.S. Bruk” do not stop there and continue to improve the developed DSP using domestic solutions that allow the implementation of cyber-secure DSP execution to improve the reliability of high-voltage facilities electrical networks.

Bibliography

1. Main provisions of the concept of an intelligent power system with an active adaptive network.
   
2. International Electrotechnical Commission. Communication Networks and Systems for Power Utility Automation – Part 8-1: Specific Communication Service Mapping (SCSM)-Mappings to MMS (ISO 9506-1 and ISO 9506-2) and to ISO/IEC 8802-3; IEC 61850-8-1-2011; International Electrotechnical Commission (IEC): Geneva, Switzerland, 2011.
3. Order FSTEC of Russia dated March 14 2014 No. 31.

Zinin Vladimir Mikhailovich - Director of the department of advanced developments of JSC "NIPOM",
Podlesny Andrey Mikhailovich - Head of Sales Department software LLC "InSAT",
Karantaev Vladimir Gennadievich - Head of business development at OJSC InfoTeKS.

Digital Substation - important element of intellectual power system OJSC "STC Electric Power Industry" OJSC "Institute "ENERGOSETPROEKT" CJSC "ETC "Continuum PLUS" JSC "STC of electric power industry"

Digital Substation 3 There is currently a wide variety of views and approaches in the industry on what is meant by the term “digital substation”. For the successful development of automation of the processes of transmission, conversion and distribution of electricity on the scale of the UNEG, a general concept of the software and hardware complex of the digital substation is being developed. Since the beginning of developments in the domestic electric power industry of projects of automated process control systems for substation, there has been significant development hardware and software tools control systems for use in electrical substations. High-voltage digital current and voltage transformers appeared; primary and secondary power grid equipment with built-in communication ports is being developed; microprocessor controllers are produced, equipped with development tools, on the basis of which it is possible to create a reliable software and hardware complex of PS; the international standard IEC 61850 was adopted, which regulates the presentation of data on the substation as an automation object, as well as the protocols for digital data exchange between microprocessor intelligent electronic devices (IEDs) of the substation, including monitoring and control devices, relay protection and automation (RPA), emergency control automation (PA) , telemechanics, electricity meters, etc. All this creates the prerequisites for building a new generation substation - a digital substation (DSS), in which the organization of all information flows when solving monitoring, analysis and control tasks is carried out in digital form.

Digital substation 4 The transition to digital signal transmission at all levels of substation control will allow obtaining whole line advantages, including: Significantly reduce the cost of cable secondary circuits and their laying channels, bringing sources of digital signals closer to the primary equipment; To increase the electromagnetic compatibility of modern secondary equipment - microprocessor devices and secondary circuits due to the transition to optical communications; Simplify and, ultimately, reduce the cost of the design of microprocessor-based intelligent electronic devices by eliminating analog signal input paths; Unify the interfaces of IEDs, significantly simplify the interchangeability of these devices (including the replacement of devices from one manufacturer with devices from another manufacturer), etc.

OBJECTIVES OF CREATION, BASIC PRINCIPLES OF OBJECTIVES OF CREATION REDUCTION OF CAPEX - reduction of costs for cable products and cable structures - reduction of the cost of terminals (unification of hardware, replacement of input modules with digital interfaces) - reduction of area land plots required for the arrangement of the substation (the use of optical digital CTs and VTs, modern microprocessor secondary equipment will make it possible to reduce); - increase in the service life of power electrical equipment (advanced diagnostics); - reducing the cost of design, installation and commissioning (reducing the number of cables, reducing the number of equipment, expanding the possibilities for typing design solutions in terms of cabinet equipment and digital communications).

OBJECTIVES OF CREATION, MAIN PRINCIPLES OF OBJECTIVES OF CREATION REDUCTION OF OPERATING COSTS (for maintenance) - simplification of operation and maintenance (permanent extended diagnostics in real time, including metrological characteristics; collection and display of comprehensive information about the state and functioning of the substation); - increase in the accuracy of measurements (especially at currents less than 10-15% In) and due to this increase in the accuracy of electricity metering and the accuracy of OMA; - reduction of the possibility of the appearance of defects such as "ground in the DC network" (reduction of the dimension of the SOTS due to the use of digital optical communications); - reduction in the number of sudden failures of the main electrical equipment and related fines for undersupply of electricity and violations of the production cycle (extended diagnostics of the entire complex of technical means of the CPS);

OBJECTIVES OF CREATION, BASIC PRINCIPLES OF OBJECTIVES OF CREATION REDUCTION OF OPERATING COSTS (for maintenance) - reduction of the number of failures, malfunctions, failures of relay protection and automation devices (the use of optical cables instead of copper ones will increase the electromagnetic compatibility of modern secondary equipment - microprocessor-based relay protection devices and automation); - increasing the algorithmic reliability of the RPA operation (the absence of saturation and the possibility of measuring the aperiodic component of optical digital CTs will simplify and improve the RPA algorithms); - reduction of consumption in alternating current and voltage circuits (as a result of the use of optical CTs and VTs)

OBJECTIVES OF CREATION, BASIC PRINCIPLES MAIN PRINCIPLES OF CREATION Transition to digital (mainly optical) technologies of information retrieval and transmission of control commands - the possibility of "replacement on the go" of the signal source and thereby - increasing the reliability of the relay protection; - increase in speed (protection "against bounce" is not required, reduction in the response time of the executive part - due to optical IGBT modules, reduction in the time for detecting an emergency mode *). - improvement of conditions in terms of safe work performance and electromagnetic compatibility (thanks to optical communications there is no potential carryover from the outdoor switchgear) Increase in the intellectual component in the DSP equipment - development of tools and methods for continuous diagnostics (control of degradation of characteristics, control of readiness to perform operations, control of metrological characteristics), - expansion of the number of functions implemented in each terminal; - transfer of part of the calculation and diagnostic tasks to interface modules (Smart-IED).

OBJECTIVES OF CREATION, MAIN PRINCIPLES MAIN PRINCIPLES OF CREATION Two-stage implementation of the DSP: Stage 1: - use of the existing main equipment, to which is added an interface digital intelligent module (usually placed indoors) based on IEC and IEC It is possible to adjust the composition and type of sensors used. Gaining operating experience. - development of the entire range of relay protection and automation devices, PA, measurements with IEC and IEC interfaces Stage 2: - significant modernization of the main electrical equipment with the integration of specialized digital unattended sensors, field controllers, solid-state executive modules into it. Expansion of the scope of tasks performed by the interface module. Refinement of all components of the DSP, taking into account operating experience.

DIGITAL SUBSTATION COMPONENTS Digital instrument transformers Measurement of harmonic components Extended dynamic and frequency range Synchronism of measurements Reduced metrological losses Eliminated the influence of electromagnetic effects (interference, residual magnetization, etc.) currents), improving the accuracy of the WMD. Self-diagnosis Easier installation (less weight) Lower cost (for voltage class kV)

COMPONENTS OF A DIGITAL SUBSTATION (Substation Coordinating Center - SCC) SCC is the software and hardware core of the DSC, coordinating the main information flows in the central processing station and automating the processes of making and implementing decisions on managing the equipment of the substation. To this end, the PCC should ensure: maintenance of an updated model technological processes substations as the basis for building algorithms for monitoring, analysis, information verification and management of the substation operation; the work of subsystems for the analysis of technological situations, incl. support for decision-making processes for management in complex / emergency situations based on the current model; organization and maintenance of a database of the state of the CPS equipment; tracking its pre-emergency conditions and issuing warning or emergency signals and messages; interaction with control centers as a "representative" of the CPS in the highest levels of the control hierarchy in the EPS; remote control of the DSP equipment with control over its capability, admissibility and safety (taking into account the actual state of the substation equipment), as well as the success of the execution of control commands

Metrological support New quality of measurements Losses in secondary circuits (different for all devices); Multiple AD conversions (in each device); Not synchronous measurements; Great influence of EM effects; etc. No loss in information transmission; Unlimited replication of information; AD conversion performed once (primary measurement), etc. Traditional substationDigital substation

INFORMATION SUPPORT (tools, ESKK) SOFTWARE TOOLS - support for the full life cycle of the HSS DSP (during design, commissioning, during operation) - support for a single information space (single classification and coding system, following international IEC standards when working with data) - support for "self-documentation" of the HSS CPS (automated generation of documentation in electronic form, agreed forms of access to documents from the NCC, MES, PMES); - support for configuring and maintaining Smart IED (technological software, up-to-date configuration files, operational documentation); - continuous monitoring and diagnostics of data transmission networks. UNIFIED CLASSIFICATION AND CODING SYSTEM - unified designation system for all types of power grid facilities; - a single designation of objects of classification and labeling in the design, implementation (construction), operation and modernization (reconstruction) of power facilities; - decentralization of the equipment identification process; - uniqueness of the identification code; - stability of the identification code to the scope; - uniqueness and correctness of query execution for obtaining various data and documents during machine processing (at the design stage and during operation); - the possibility of harmonization with other classification systems (in particular - CIM); - ensuring the possibility of saving the existing local designations of equipment

INFORMATION SUPPORT (common information model - CIM) CIM-representation is a single language for describing data and, accordingly, an interface in a common integrated environment. CIM is a common language for applications when working in a single automated control system of JSC FGC UES. The initial data for building an information model are: - circuit diagram normal mode PS; - classification tables and methodology for constructing unique identifiers of objects, equipment, measurements, signals and documents; -model profile, which defines: 1) classes, attributes and relationships between them in the information model schema; 2) standards in the field of information technology (up to versions), following which is mandatory in the process of designing, implementing and operating a control system.
RELIABILITY PROVISION (diagnostics and testing) Hardware self-diagnostics: - Smart IED modules of the main electrical equipment - microprocessor terminals - digital networks External automatic diagnostics by specialized software and hardware: electrically connected VT, control of the sum of currents/powers in the node). - with short-term shutdown (emulation of test signals for terminals and comparison of the received terminal response with the test one)

Digital Substation 20 JSC "NTC Electric Power Industry" As part of the pilot project of JSC FGC UES, "Digital Substation" coordinates the following areas: Research and Development Center for Electric Power Industry" 110/10 kV into the "Digital Substation" consisting of: Optical current and voltage transformers; Station bus, process bus; Multifunctional electronic measuring and accounting devices; Substation Information Display and Control System (SCADA); -December 2010 In 2011 microprocessor protection of the substation. 3. Establishment of an experimental site "Digital substation" in JSC "STC of electric power industry"

New production technologies modern systems controls have moved from the stage of scientific research and experimentation to the stage of practical use. Modern communication standards for information exchange have been developed and are being implemented. Digital protection and automation devices are widely used. There has been a significant development of hardware and software control systems. The emergence of new international standards and the development of modern information technologies open up the possibility of innovative approaches to solving the problems of automation and control of power facilities, making it possible to create a new type of substation - a digital substation (DSS). Distinctive characteristics of the DPS are: the presence of intelligent microprocessor devices built into the primary equipment, the use of local area networks for communications, a digital method for accessing information, its transmission and processing, automation of the substation and its management processes. In the future, the digital substation will be key component intellectual network (Smart Grid).

The term "Digital substation" is still interpreted differently by different specialists in the field of automation and control systems. In order to understand what technologies and standards apply to a digital substation, let's trace the history of the development of APCS and RPA systems. The introduction of automation systems began with the advent of telemechanics systems. Remote control devices made it possible to collect analog and discrete signals using USO modules and measuring transducers. On the basis of telemechanics systems, the first process control systems for electrical substations and power plants were developed. APCS made it possible not only to collect information, but also to process it, as well as present information in a user-friendly interface. With the advent of the first microprocessor relay protections, information from these devices also began to be integrated into automated process control systems. Gradually, the number of devices with digital interfaces increased (emergency automation, monitoring systems for power equipment, systems for monitoring the DC shield and auxiliary needs, etc.). All this information from devices lower level integrated into the automated process control system via digital interfaces. Despite the widespread use of digital technologies for building automation systems, such substations are not fully digital, since all initial information, including the status of auxiliary contacts, voltages and currents, is transmitted in the form of analog signals from the switchgear to the operational control point, where digitized separately by each lower level device. For example, the same voltage is supplied in parallel to all lower-level devices, which convert it to digital form and transfer it to the process control system. In traditional substations, different subsystems use different communication standards (protocols) and information models. For the functions of protection, measurement, accounting, quality control, individual systems of measurements and information exchange, which significantly increases both the complexity of implementing an automation system at a substation and its cost.

The transition to qualitatively new automation and control systems is possible using the standards and technologies of the digital substation, which include:

1. IEC 61850 standard:
device data model;
unified description of the substation;
vertical (MMS) and horizontal (GOOSE) exchange protocols;
protocols for the transmission of instantaneous values ​​of currents and voltages (SV);

2. digital (optical and electronic) current and voltage transformers;
3. analog multiplexers (Merging Units);
4. remote USO modules (Micro RTU);
5. intelligent electronic devices (IED).

The main feature and difference of the IEC 61850 standard from other standards is that it regulates not only the issues of information transfer between individual devices, but also the issues of formalizing the description of circuits - substation, protection, automation and measurements, device configuration. The standard provides for the possibility of using new digital measuring devices instead of traditional analog meters (current and voltage transformers). Information Technology allow you to move on to the automated design of digital substations controlled by digital integrated systems. All information communications at such substations are carried out digitally, forming a single process bus. This opens up the possibility of a fast direct exchange of information between devices, which ultimately makes it possible to reduce the number of copper cable connections and the number of devices, as well as their more compact arrangement.
STRUCTURE OF A DIGITAL SUBSTATION

Let us consider in more detail the structure of a digital substation, made in accordance with the IEC 61850 standard (Fig.). The automation system of a power facility built using the Digital Substation technology is divided into three levels:
field level (process level);
connection level;
station level.

The field level consists of:
primary sensors for collecting discrete information and transmitting control commands to switching devices (micro RTU);
primary sensors for collecting analog information (digital current and voltage transformers).

The connection level consists of intelligent electronic devices:
control and monitoring devices (connection controllers, multifunctional measuring devices, ASKUE meters, monitoring systems for transformer equipment, etc.);
relay protection terminals and local emergency automatics.

The station level consists of:
top-level servers (database server, SCADA server, remote control server, process information collection and transmission server, etc., data concentrator);
Substation personnel workstation.

From the main features of the system construction, first of all, it is necessary to single out a new “field” level, which includes innovative devices for primary information collection: remote USOs, digital instrument transformers, built-in microprocessor diagnostic systems for power equipment, etc.

Digital instrument transformers transmit instantaneous voltages and currents according to the IEC 61850-9-2 protocol to bay level devices. There are two types of digital instrument transformers: optical and electronic. Optical instrument transformers are the most preferred when creating control and automation systems for a digital substation, as they use an innovative measurement principle that excludes the influence of electromagnetic interference. Electronic instrument transformers are based on traditional transformers and use specialized analog-to-digital converters.

Data from digital instrument transformers, both optical and electronic, is converted into broadcast Ethernet packets using multiplexers (Merging Units) provided by the IEC 61850-9 standard. The packets generated by the multiplexers are transmitted via the Ethernet network (process bus) to the connection level devices (controllers for APCS, RPA, PA, etc.) The sampling rate of the transmitted data is not worse than 80 points per period for RPA and PA devices and 256 points per period for APCS , AIIS KUE, etc.

Data on the position of the switching devices and other discrete information (the position of the control mode keys, the state of the heating circuits of the drives, etc.) are collected using remote USO modules installed in close proximity to the switching devices. Remote USO modules have relay outputs for controlling switching devices and are synchronized with an accuracy of at least 1 ms. Data transmission from remote USO modules is carried out via fiber optic communication, which is part of the IEC 61850-8-1 (GOOSE) process bus. The transfer of control commands to switching devices is also carried out through remote USO modules using the IEC 61850-8-1 (GOOSE) protocol.

Power equipment is equipped with a set of digital sensors. There are specialized systems for monitoring transformer and gas-insulated equipment that have a digital interface for integration into process control systems without the use of discrete inputs and 4-20 mA sensors. Modern GIS are equipped with built-in digital current and voltage transformers, and control cabinets in GIS allow you to install remote USO to collect discrete signals. Installation of digital sensors in switchgear is carried out at the factory, which simplifies the design process, as well as installation and commissioning work at the facility.

Another difference is the integration of the middle (data concentrators) and upper (server and workstation) levels into one station level. This is due to the unity of data transfer protocols (IEC 61850-8-1 standard), in which the middle layer, which previously performed the work of converting information from various formats into a single format for an integrated process control system, is gradually losing its purpose. The connection level includes intelligent electronic devices that receive information from field level devices, perform logical processing of information, transmit control actions through field level devices to primary equipment, and also transmit information to the station level. These devices include connection controllers, MPRZA terminals and other multifunctional microprocessor devices.

The next difference in structure is its flexibility. Devices for a digital substation can be made according to a modular principle and allow you to combine the functions of many devices. The flexibility of building digital substations allows us to offer various solutions, taking into account the characteristics of the power facility. In the case of upgrading an existing substation without replacing power equipment, remote USO cabinets can be installed to collect and digitize primary information. At the same time, remote USOs, in addition to discrete I/O boards, will contain direct analog input boards (1/5 A), which allow collecting, digitizing and outputting data from traditional current and voltage transformers in the IEC 61850-9-2 protocol. In the future, full or partial replacement of primary equipment, including the replacement of electromagnetic transformers with optical ones, will not lead to a change in the levels of connection and substation. In the case of using GIS, it is possible to combine the functions of remote USO, Merging Unit and connection controller. Such a device is installed in the switchgear control cabinet and makes it possible to digitize all initial information (analogue or discrete), as well as perform the functions of a connection controller and backup local control functions.

With the advent of the IEC 61850 standard, a number of manufacturers have released digital substation products. At present, quite a lot of projects related to the use of the IEC 61850 standard have already been completed all over the world, showing the advantages of this technology. Unfortunately, even now, when analyzing modern solutions for a digital substation, one can notice a fairly loose interpretation of the requirements of the standard, which may lead to inconsistencies and problems in integration in the future. modern solutions in the field of automation.

Today, Russia is actively working on the development of the Digital Substation technology. A number of pilot projects have been launched, leading Russian firms have started developing domestic products and solutions for the digital substation. In our opinion, when creating new technologies focused on a digital substation, it is necessary to strictly follow the IEC 61850 standard, not only in terms of data transfer protocols, but also in the ideology of building a system. Compliance with the requirements of the standard will make it easier to upgrade and maintain facilities based on new technologies in the future.

In 2011, leading Russian companies (NPP EKRA LLC, EnergopromAvtomatization LLC, Profotek CJSC and NIIPT OJSC) signed a general agreement on the organization of strategic cooperation in order to combine scientific, technical, engineering and commercial efforts to create a digital substations in the Russian Federation.

In accordance with IEC 61850, the developed system consists of three levels. The process bus is represented by optical transformers (ZAO Profotek) and a remote USO (microRTU) NPT Expert (LLC EnergopromAvtomatization). Connection level - microprocessor protection of NPP EKRA LLC and connection controller NPT BAY-9-2 of EnergopromAvtomatization LLC. Both devices accept analogue information according to IEC 61850-9-2 and discrete information according to IEC 61850-8-1(GOOSE). The station level is based on SCADA NPT Expert with IEC 61850-8-1(MMS) support.

The joint project also developed a system computer-aided design DSP - SCADA Studio, worked out the structure of the Ethernet network for various options construction, a model of a digital substation was assembled and joint tests were carried out, including on a test bench at OAO NIIPT.

The operating prototype of the digital substation was presented at the Electric Networks of Russia-2011 exhibition. Implementation of a pilot project and full-scale production of digital substation equipment is scheduled for 2012. The Russian equipment for the Digital Substation has passed full-scale testing, and its compatibility according to the IEC 61850 standard with the equipment of various foreign (Omicron, SEL, GE, Siemens, etc.) and domestic (LLC Prosoft-Systems, NPP Dinamika and others) companies.

The development of our own Russian solution for a digital substation will allow not only to develop domestic production and science, but also to improve the energy security of our country. The conducted studies of technical and economic indicators allow us to conclude that the cost of a new solution in the transition to serial production will not exceed the cost of traditional solutions for building automation systems and will provide a number of technical advantages, such as:
a significant reduction in cable connections;
improving the accuracy of measurements;
ease of design, operation and maintenance;
unified data exchange platform (IEC 61850);
high noise immunity;
high fire and explosion safety and environmental friendliness;
reduction in the number of I/O modules for APCS and RPA devices, which reduces the cost of devices.

A number of other issues require additional checks and solutions. This applies to the reliability of digital systems, to the issues of configuring devices at the level of substation and power interconnection, to the creation of publicly available design tools targeted at different manufacturers of microprocessor and main equipment. To ensure the required level of reliability in the framework of pilot projects, the following tasks should be solved.

1. Determination of the optimal structure of the digital substation as a whole and its individual systems.
2. Harmonization of international standards and development of domestic normative documentation.
3. Metrological certification of automation systems, including AISKUE systems, with the support of IEC 61850-9-2.
4. Accumulation of statistics on the reliability of digital substation equipment.
5. Accumulation of implementation and operation experience, personnel training, creation of competence centers.

At present, the mass introduction of digital substation class solutions based on IEC 61850 series standards has begun in the world, Smart Grid control technologies are being implemented, applications are being put into operation automated systems technological management. The use of the "Digital Substation" technology should allow in the future to significantly reduce the cost of designing, commissioning, operation and maintenance of energy facilities.

Alexey Danilin, Director for Automated Control Systems of SO UES OJSC, Tatyana Gorelik, Head of the APCS Department, Ph.D., Oleg Kiriyenko, Engineer, NIIPT OJSC Nikolai Doni, Head of Advanced Development Department, EKRA Research and Production Enterprise

The digital substation has been called the core component of the creation of a smart grid - and this topic in Lately is gaining more and more popularity. This is a breakthrough, recognized on international level task-solving automation method effective management energy facilities, completely converting it into a digital format. By integrating this technology into substation automation systems, manufacturing companies have combined more than a decade of experience in the production of "non-traditional" current and voltage instrument transformers with the latest technologies connections and made possible connection primary high-voltage equipment to relay protection and automation devices (RPA). This improves the reliability and availability of the system, as well as optimizing secondary circuits in the substation.

Leading companies in this industry continue to develop this technology, and, as experts say, the combination of efforts is of particular value, given the significance and scale of the tasks set. This strategically important project for the industry cannot be implemented by one company, experts note. In their opinion, the time when all these technologies were trade secrets has already passed and a real community has appeared for the implementation of digital substations, which promotes this technology in all directions.

Confirmation of these words is the agreement between Alstom and Cisco, which agreed to develop solutions for the safe automation of digital substations together. These solutions will use ruggedized Cisco Connected Grid substation routers and switches with advanced communication and security features, and the Alstom DS Agile control system for substation automation.

This will bring the performance of IP communications to a new level and ensure the integration of information security, distributed monitoring and control. On the basis of such a solution, information transmission and energy distribution centers have already been created within the framework of a modern power grid architecture.

Solutions allow you to manage user access to critical resources, detect and eliminate possible electronic attacks throughout the network infrastructure. The architecture of digital substations contains comprehensive functionality safety management, taking into account the recommendations of NIST (US National Institute of Standards and Technology) and IEC (International Electrotechnical Commission, IEC).

According to Cisco, the applied layered architectural approach will ensure optimal deployment of the substation automation system and will enable efficient design for implementation of solutions. It makes it easy to design a communications infrastructure and integrate it with mission-critical security and control functions, asset monitoring, and power management equipment. Intelligent functions help you carefully control the load capacity and operate the power grid equipment at maximum efficiency.

The layered architectural approach will also allow wired and wireless communications to be maintained on the same converged network, while allowing facilities to implement preventive maintenance programs that extend equipment life and reduce equipment maintenance costs. The substation network supports existing and new communication standards (eg IEC 61850) as well as the prioritization of control data transmission over other traffic.

The main advantages of digital substations lie in the field of economics: the cost of creation and the cost of operation are reduced. Savings are achieved by reducing the space required to accommodate the facility, reducing the amount of equipment (for example, by combining different devices) and, as a result, the cost of installation work.

As a result, the cost of substation control automation will be no more than 15 percent of the cost of its construction and equipping with primary equipment. In terms of reliability, the digital substation benefits from fewer elements and the use of monitoring and diagnostic tools.

How do experts assess the prospects for introducing this technology in Russia? There are enough companies claiming that they have the necessary equipment, mastered the technology and have the necessary competencies, but, as usual, there are fewer practical steps. Another issue is the choice between domestic and foreign proposals. According to FGC UES specialists, a compromise is needed, when "brand decisions can be made and, as a backup option, domestic developments offered to the market." Moreover, this process will not be successful without elements of administrative regulation by FGC.

And yet, in Russia, the process of introducing digital substations has unequivocally begun, as evidenced by the meeting between the management of Alstom and OJSC Russian Grids, dedicated to the discussion of current and future projects of digital substations. On behalf of Rosseti, the meeting was attended by CEO Oleg Budargin, which speaks of the importance this direction For the company.

As for Alstom, it is actively involved in the implementation of smart grid technologies with an active-adaptive grid. Currently, the company is involved in the implementation of the project of the first digital substation in Russia based on the 220 kV Nadezhda substation, a branch of JSC FGC UES of MES Ural. Alstom supplies equipment and installs IEC 61850‑9‑2 LE-compliant bay controllers, RPA and APCS systems, and performs their commissioning.

Currently, several projects of digital substations are being implemented in Russia, such as the Digital Substation experimental site based on the STC FGC UES, the Nadezhda 500 kV substation based on the Ural Power Grids, and the Elgaugol cluster.

However, as experts note, the most important component is still missing in this issue - the design methodology in full. It is necessary to solve the issue of automating this process until the staff is trained. Otherwise, this will significantly slow down the development of digital substations in Russia, which is highly undesirable.