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Modern technologies of dispatching control of electrical networks. On the way to digitalization: operational and technological management of electric networks. Digital and information technologies

Their age is estimated at five to ten years, and these complexes are already outdated. About what is coming to replace them, we talked with director of the Moscow branch of JSC "Monitor Electric" Sergey Silkov.

- Sergey Valeryevich, now Monitor Electric is a significant enterprise for the development and creation of software technical systems for dispatch control centers in the electric power industry. Where did it all begin?

– Perhaps we should start from 2003, when we released the operational information complex SK-2003: it was a real software product, and it is still in operation in some centers. It was followed by a more advanced model - SK-2007. It was quite successful, and there are customers who still buy it today.

The creation at the same time of the electronic operational journal "eZh-2" was a truly revolutionary event, which made it possible to replace the seemingly eternal "paper" dispatching documents. Its use allows you to quickly enter and organize operational information about various events, ensuring their division into categories and maintaining dependencies. Very popular and, dare I say it, practically the best of its kind, it has become the de facto industry standard on-the-fly magazine.

We have also created a mode dynamic dispatcher simulator (RTD) "Finist", which makes it possible to simulate almost any event in power systems, allowing you to train operational dispatch personnel.

These three products have become the basis for the industrial production of software systems in the company.
Finally, we are now actively promoting our next generation system, the SK-11, which took eight years to develop.

– The SK-11 system is your main product. In short, what is its advantage?

– SK-11 is based on a high-performance information technology platform. This is a system for maintaining the information model of the control object, writing / reading data, storing the information model, organizing access for user applications. Thanks to the innovative architecture of the SK-11 platform, it achieves super-fast telemetry data processing characteristics (up to 5 million parameter changes per second), work with large-scale power grid models, a large number of users, and more.

Various applications are connected to the platform at the request and capabilities of customers. Today there are more than fifty of them. These are SCADA / EMS / DMS / OMS / DTS applications for various services of energy companies that are involved in operational management, repair planning and network development, and training of dispatching personnel. Due to the modularity of the architecture in the system, as it is mastered, financial opportunities change, already during operation, user components are quite simply added or changed.

The second important advantage of our system is that, unlike information systems of previous generations based on remote control signals, the SK-11 information model includes absolutely all the equipment of the power system. This approach allows increasing the composition of previously unsolvable problems. As an example, our system models consumers, and since consumers are also part of the information model, we can implement the task of effectively managing outages. Simulation of non-telemechanized equipment and consumers reduces the time it takes to search for a failed element, automatically generates a program of actions for operational personnel and speeds up the process of restoring power supply.

I also note that we are modeling a network of any voltage, up to a network of 0.4 kilovolts.

– To what extent do domestic grid companies trust Russian developers of such systems?

- There is, in my opinion, a very competent, balanced policy for the development of this direction. Firstly, Rosseti has a document that defines the import substitution policy. It complies with the requirements of the Russian government: no foreign software For driving electrical networks should not be used.

In addition, Rosseti has its own standardized certification procedures, and everything that is done by developers is checked for compliance with Rosseti standards.

Only after this is the conclusion of the attestation commission issued on the possibility of using this product for network management, and only if there is a positive conclusion from the attestation commission of PJSC Rosseti, one or another software product can be used.

To date, only Monitor Electric has such a conclusion.

– Do Russian grid companies really have a need for such systems, or is it a matter of decrees and regulations of regulatory bodies?

– The management of grid companies is constantly developing the system of operational, technological and situational management (OTiSU). They have investment programs within which they work.

Naturally, we are always in constant contact with them. We are invited to discuss tasks, to consider the necessary set of functions of automatic systems and, most importantly, to implement. Periodic conferences, scientific and technical councils are held. For example, in July we participated in the Scientific and Technical Council of IDGC of Siberia. In September we will take part in the conference of IDGC of the South. So, in summary, the management of PJSC Rosseti and subsidiaries of grid companies is very actively planning investment activities to modernize OH&S systems.

The Ministry of Energy of the Russian Federation and Rosseti carry out intensive research work, research and development in this direction. For example, our company Monitor Electric is involved in several pilot projects under the EnergyNET National Technology Initiative. Firstly, this is the Digital Distribution Zone project, where we work with Yantarenergo. Together with our colleagues from Kaliningrad, we are developing digital distribution technologies, including the issues of integrating a software complex for operational and technological management with a number of related systems. For example, now we have solved the problem of integrating GIS and APCS, the next step is the integration of APCS and accounting systems. These are extremely complex tasks that have not yet been solved in the Russian energy sector.

The second project is the development of a set of tools for long-term planning of network development. It has been created, tested in practice, and by the end of the year we will have to report to the NTI management on the implementation of the project.

– I got acquainted with the geography of implementation of your systems. It turns out that you can meet your systems all over Russia!

- And not only. If we talk about recent projects, then we have implemented SK-11, and almost in a fully functional mode, in IDGC of Urals, in their SDCs - the Yekaterinburg Electric Grid Company. This is probably one of our most respected customers. There is a very high level of training of personnel and management, they quickly went through all the stages, and now the complex is actively used there. We have implemented SK-11 in Yantarenergo, it includes an interesting subsystem that calculates technical indicators urban electric network on a development model with a horizon of four years ahead. In total, over the past three years, there have been about ten implementations of our systems. Yes, they are presented throughout Russia in different companies and in completely different configurations.

- But you said that not only in her ...

- Exactly. For example, three companies that train air traffic controllers in the United States have bought our Finist software simulator, and with its help more than 1,000 air traffic controllers have been trained.

The United Dispatch Department of the Republic of Belarus also works on our complex SK-2007. By the way, now we are also negotiating with them on the transition to the SK-11.

Our complex works in the urban networks of Tbilisi. We were called to the project after some difficulties with a well-known vendor, and we successfully implemented our products in their control center. There is a successful experience in Kazakhstan, in the energy supply management system of Alma-Ata (AZhK company). We received positive feedback from our Kazakh colleagues, and now we are negotiating with a number of energy companies in the Republic of Kazakhstan, where we have been chosen as IT solution providers.

– You highlighted the project with Yantarenergo, where you are jointly building smart grids. Tell us more about it.

- At the beginning of the year, we completed all the technical procedures to complete the first stage of implementation in the scope of the SCADA system (automatic control and information collection system) and the complex of electronic journals. Now we are jointly conducting very intensive work to fine-tune what has been done, and we are preparing documents for the deployment of the second stage. At this stage, the calculation and analytical functions will be implemented, allowing you to perform a whole set of technological operations for truly intelligent network management.

- In connection with the talk about the need to switch to smart grids everywhere in Russia, how difficult will it be to replicate this experience in other networks?

- Of course, everywhere has its own specifics. In almost every implementation, we are faced with the need to adapt our complex to the existing information environment, represented by the means of various, including foreign, developers. Everything is different for everyone, and this, of course, is not very good for us as a manufacturer and carrier of a fairly modern technical ideology. But we still believe very much in the regulatory role of Rosseti, which is now paying a lot of attention to the standardization of systems.

On the other hand, this diversity turns into our competitive advantage. Including before foreign companies, which are reluctant to remake their systems, for example, the user interface. As for us, this is the first thing we start with.

After all, everyone has their own opinion and their own standards regarding how and where information should be displayed to users: dispatchers, operational services specialists, managers. It is a very difficult task to display a huge array of information on a video wall, because the main task of the dispatcher is to see the whole picture as a whole. Finally, there is still a very difficult moment of ergonomics, and each dispatcher also has his own idea of ​​\u200b\u200bit. So the process of so-called circuit balancing is very complicated and can take 4-6 months.

As for us, we successfully solve these problems using our own graphics subsystem. This is what we do in the Voronezh branch, there is a very strong team that has vast experience and owns the most modern means and methods of displaying information, thanks to which all tasks are solved quickly and efficiently. It may sound a little daring, but so many of our users say that our circuits are the most beautiful in the world.

So, this is only one point, but there are other purely technical differences. But that is the advantage of our system. Thanks to many years of experience and the modularity of the complexes we create, the technical development of information systems of control centers never stops. We start with a simple configuration for any networks and, as we master it, we improve and develop without interrupting operation to the world level.

– Do you have a dream?

- Well, of course, in a few years we will have a robot dispatcher, and then, like a driver of an unmanned vehicle ... Experienced specialists will move from shifts and engage in in-depth planning and analytical work, improving network architecture, and developing new "smart" components.

The TSF software outside the core consists of trusted applications that are used to implement security features. Note that shared libraries, including PAM modules in some cases, are used by trusted applications. However, there is no instance where the shared library itself is treated as a trusted object. Trusted commands can be grouped as follows.

  • System initialization
  • Identification and authentication
  • Network Applications
  • batch processing
  • System management
  • User level audit
  • Cryptographic support
  • Virtual machine support

The execution components of the kernel can be divided into three parts: the main kernel, kernel threads, and kernel modules, depending on how they will be executed.

  • The core core includes code that is executed to provide a service, such as servicing a user system call or servicing an exception event or interrupt. Most compiled kernel code falls into this category.
  • Kernel threads. To perform certain routine tasks, such as flushing disk caches or freeing up memory by swapping out unused page frames, the kernel creates internal processes or threads. Threads are scheduled just like regular processes, but they don't have a context in non-privileged mode. Kernel threads perform certain functions of the kernel C language. Kernel threads reside in kernel space, and only run in privileged mode.
  • The kernel module and device driver kernel module are pieces of code that can be loaded and unloaded into and out of the kernel as needed. They extend the functionality of the kernel without the need to reboot the system. Once loaded, the kernel module object code can access other kernel code and data in the same way as statically linked kernel object code.
A device driver is a special type of kernel module that allows the kernel to access hardware connected to the system. These devices can be hard drives, monitors, or network interfaces. The driver interacts with the rest of the kernel through a specific interface that allows the kernel to deal with all devices in a generic way, regardless of their underlying implementations.

The kernel consists of logical subsystems that provide various functionality. Even though the kernel is the only executable program, the various services it provides can be separated and combined into different logical components. These components interact to provide specific functionality. The kernel consists of the following logical subsystems:

  • File subsystem and I/O subsystem: This subsystem implements functions related to file system objects. Implemented functions include those that allow a process to create, maintain, interact with, and delete file system objects. These objects include regular files, directories, symbolic links, hard links, files specific to certain types devices, named pipes, and sockets.
  • Process Subsystem: This subsystem implements functions related to process control and thread control. The implemented functions allow creating, scheduling, executing, and deleting processes and thread subjects.
  • Memory Subsystem: This subsystem implements functions related to managing system memory resources. The implemented functions include those that create and manage virtual memory, including the management of pagination algorithms and page tables.
  • Network subsystem: This subsystem implements UNIX and Internet domain sockets, as well as the algorithms used to schedule network packets.
  • IPC Subsystem: This subsystem implements functions related to IPC mechanisms. Implemented features include those that facilitate the controlled exchange of information between processes by allowing them to share data and synchronize their execution when interacting with a shared resource.
  • Kernel Module Subsystem: This subsystem implements the infrastructure to support loadable modules. Implemented functions include loading, initializing, and unloading kernel modules.
  • Linux security extensions: Linux security extensions implement various aspects of security that are provided throughout the kernel, including the framework of the Linux Security Module (LSM). The LSM framework serves as the basis for modules that allow you to implement various security policies, including SELinux. SELinux is an important logical subsystem. This subsystem implements the mandatory access control functions to achieve access between all subjects and objects.
  • Device driver subsystem: This subsystem implements support for various hardware and software devices through a common, device-independent interface.
  • Audit Subsystem: This subsystem implements functions related to recording security-critical events in the system. Implemented functions include those that capture each system call to record security-critical events and those that implement the collection and recording of control data.
  • KVM Subsystem: This subsystem implements maintenance life cycle virtual machine. It performs statement completion, which is used for statements requiring only minor checks. For any other instruction completion, KVM invokes the user-space component of QEMU.
  • Crypto API: This subsystem provides a kernel-internal cryptographic library for all kernel components. It provides cryptographic primitives for callers.

The kernel is the main part of the operating system. It interacts directly with the hardware, implements resource sharing, provides shared services for applications, and prevents applications from directly accessing hardware-dependent functions. The services provided by the kernel include:

1. Management of the execution of processes, including the operations of their creation, termination or suspension, and interprocess data exchange. They include:

  • Equivalent scheduling of processes to run on the CPU.
  • Separation of processes in the CPU using time-sharing mode.
  • Process execution in the CPU.
  • Suspend the kernel after its time quantum has elapsed.
  • Allocation of kernel time to execute another process.
  • Rescheduling kernel time to execute a suspended process.
  • Manage process security related metadata such as UIDs, GIDs, SELinux labels, feature IDs.
2. Allocation of RAM for the executable process. This operation includes:
  • Permission granted by the kernel to processes to share a portion of their address space under certain conditions; however, in doing so, the kernel protects the process's own address space from outside interference.
  • If the system is running low on free memory, the kernel frees memory by writing the process temporarily to second-level memory or the swap partition.
  • Consistent interaction with the machine's hardware to establish a mapping of virtual addresses to physical addresses, which establishes a mapping between compiler-generated addresses and physical addresses.
3. Maintenance of the life cycle of virtual machines, which includes:
  • Set limits on resources configured by the emulation application for this virtual machine.
  • Running the program code of the virtual machine for execution.
  • Handling the shutdown of virtual machines either by terminating the instruction or delaying the completion of the instruction to emulate user space.
4. Maintenance of the file system. It includes:
  • Allocation of secondary memory for efficient storage and retrieval of user data.
  • Allocation of external memory for user files.
  • Utilize unused storage space.
  • Organization of the file system structure (using clear structuring principles).
  • Protection of user files from unauthorized access.
  • Organization of controlled access of processes to peripheral devices, such as terminals, tape drives, disk drives, and network devices.
  • Organization of mutual access to data for subjects and objects, providing controlled access based on the DAC policy and any other policy implemented by the loaded LSM.
The Linux kernel is a type of OS kernel that implements preemptive scheduling. In kernels that do not have this capability, execution of the kernel code continues until completion, i.e. the scheduler is not capable of rescheduling a task while it is in the kernel. In addition, kernel code is scheduled to execute cooperatively, without preemptive scheduling, and execution of this code continues until it terminates and returns to user space, or until it explicitly blocks. In preemptive kernels, it is possible to unload a task at any point, as long as the kernel is in a state in which it is safe to reschedule.

Dispatching technological control should be organized according to a hierarchical structure, providing for the distribution of technological control functions between levels, as well as strict subordination of lower levels of control to higher ones.
All supervisory technological control bodies, regardless of the form of ownership of the relevant market entity that is part of the energy system (IPS, UES), must obey the commands (instructions) of the superior technological dispatcher.
There are two categories of operational subordination:
operational management and operational management.
The operational control of the relevant dispatcher should include power equipment and controls, operations with which require coordination of the actions of subordinate dispatch personnel and coordinated performance of operations at several objects of different operational subordination.
The operational control of the dispatcher should be the power
equipment and controls, the condition and mode of which
affect the mode of operation of the corresponding power system (IPS, UES). Operations with such equipment and controls
must be carried out with the permission of the relevant dispatcher.
The current rules and regulations provide that
that all elements of the EPS (equipment, apparatus, automation devices and controls) are under the operational control and management of dispatchers and senior duty personnel at different levels of management.
The term operational control denotes the type of operational subordination, when operations with one or another EPS equipment are carried out only by order of the appropriate dispatcher (senior duty personnel) who manages this equipment. The operational control of the dispatcher is equipment, operations with which require coordination of the actions of subordinate operational personnel.
The term operational management refers to the type of operational
subordination, if operations with one or another EPS equipment
are carried out with the knowledge (by permission) of the relevant dispatcher in whose jurisdiction this equipment is located.
Operational maintenance of two levels is envisaged. Operational control of the 1st level is equipment, operations with which are carried out by agreement or with notification of a higher-level dispatcher or a dispatcher of the same level.
Operational control of the II level is equipment, the condition of which or operations with which affect
mode of operation of a certain part of the electrical network. Operations with
this equipment are carried out in agreement with the higher
by the controller and notifying the concerned controllers.
Each element of the EPS can be under the operational control of the dispatcher not only of one stage, but also under the authority of several
dispatchers of one or different levels of control. The division of equipment, automation and control between the levels of the territorial hierarchy by types of management characterizes not only the distribution of management functions between the levels of the territorial hierarchy at the temporary level of operational management, but to a large extent determines the distribution of functions at other temporary levels.
Along with this, in operational management, and in some cases in the planning of regimes, it is envisaged that one of the subdivisions, on a certain range of issues, is subordinate to another, located at the same level of management. Yes, dispatcher
one of the power systems can be entrusted with the operational management of the power transmission line connecting this power system with the neighboring one. Thus, the unloading of the ODU dispatcher is organized by transferring to the energy system dispatchers some of the functions that can be performed at this level.
All EPS equipment that ensures the production and distribution of electricity is under the operational control of the duty dispatcher of the power system or the operational personnel directly subordinate to him (shift supervisors of power plants; dispatchers of electrical and thermal networks, substation duty personnel (PS), etc.). Lists of equipment in operation
management and maintenance, are approved by the chief dispatchers of the CDU
UES of Russia, ODU of UES and CDS of energy systems, respectively.


The operational control of the power system dispatcher is the main equipment, the operation of which requires
coordination of actions of the duty personnel of power enterprises (power facilities) or coordinated changes in relay protection and automation
multiple objects.
The operational management of energy facilities that play a particularly important role in the association or in the UES, as an exception, may be entrusted not to the power system dispatcher, but to the dispatcher of the ODU or CDU of the UES.
Under the operational jurisdiction of the on-duty dispatcher of the ODU are
total operating power and power reserve of power systems, power plants and high-power units, inter-system communications and objects of main networks that affect the IPS mode. In operational
control of the ODU dispatcher is transferred to the equipment, operations with
which require coordination of the actions of dispatchers on duty
power systems.
The duty dispatcher of the CDU UES, the top operational head of the UES, is in charge of the total operating capacity and power reserve of the UES, electrical connections between the associations, as well as the most important connections within the UES and objects, the mode of which decisively affects the mode of the UES.
In the operational management of the dispatcher of the CDU UES are the main links between the IPS and some objects of system-wide importance.
The principle of operational subordination extends not only to the main equipment and apparatus, but also to the relay protection of the relevant facilities, linear and emergency automation, means and systems for automatic control of the normal mode, as well as dispatch and technological control tools used by operational personnel.
Duty dispatchers of AO-energos, ODUs and CDUs of the UES are the top operational managers of the energy system, the association and the UES as a whole, respectively. Equipment that is under the operational control or control of the dispatcher of the corresponding link cannot be taken out of operation or in reserve, and also put into operation without the permission or instructions of the dispatcher. Orders of the administrative management of power facilities and power systems on issues within the competence of dispatchers can be carried out by operational personnel only with the permission of the operational
senior officer on duty.
The top level (CDU UES) provides round-the-clock operational management of the parallel operation of the UES and continuous regulation of the UES mode. The middle link (MDL) leads the combination mode and manages the parallel operation of power systems. The dispatching service of the power system manages the mode of the power system, ensuring the coordinated operation of all its energy facilities.
During the operation of the EPS as part of the IPS, the responsibility of the energy systems for the use of the power of power plants, ensuring the maximum available power and expanding the range of regulation is fully preserved. At the same time, the available power and adjusting capabilities are determined by the conditions for covering the loads of the IPS, taking into account the throughput of intersystem communications.
The main responsibility for maintaining the normal frequency rests with the top operating manager of the UES - dispatcher of the UES remote control. Dispatchers of the ODS and power systems ensure the maintenance of schedules of power flows between the UES and power systems set respectively by the CDU of the UES and the ODS, the implementation of instructions for changing the flows in order to maintain
normal frequency when changing the power balance. The responsibility for maintaining the frequency is also shared by the dispatchers of the ODE and power systems in terms of providing a given rotating power reserve, and in the case of automatic frequency and active power control, in terms of using automatic systems and devices involved in automatic regulation and to maintain the required control range at power plants.
The control of the mode of the main electric networks by voltage is carried out by the coordinated actions of the personnel of the corresponding stages of dispatching control. Dispatchers
CDU UES and ODU maintain voltage levels at the corresponding points of the main electrical network, determined by the instructions.
In the event of a temporary shortage of power or electricity in the UES, the duration of load or power consumption restrictions
established by the CDU UES and agreed with the management of RAO "UES of Russia"; orders to impose restrictions CDU dispatcher
Gives ODEs to controllers, and the latter to power system controllers.
The highest level of operational management (CDU UES) develops and approves the basic instructions for maintaining the regime and operational management, which are mandatory for the operational personnel of the ODU and facilities directly subordinate to the CDU. Territorial ODUs for their associations develop instructions that are in accordance with general provisions instructions
CDU and employees, in turn, serve as the basis for the development of CDS local instructions that take into account the peculiarities of the structure and mode of power systems.

According to the Federal Law "On the Electric Power Industry", JSC FGC UES is responsible for the technological management of the Unified National Electric Grid (UNEG). At the same time, questions arose about a clear delineation of functionality between JSC SO UES, which carries out a unified dispatch control of electric power facilities, and grid companies. This led to the need to create an effective structure for the operational and technological management of the facilities of JSC FGC UES, the tasks of which include, among other things:
ensuring the reliable functioning of UNEG facilities and the fulfillment of the technological modes of operation of power transmission lines, equipment and devices of UNEG facilities specified by JSC SO UES;
ensuring the proper quality and safety of work during the operation of UNEG facilities;
creation of a unified system for training operational personnel to perform the functions of OTU;
ensuring technological equipment and readiness of operational personnel to carry out dispatcher commands (orders) of COs and commands (confirmations) of operational personnel of the Central Control Center of FGC UES;
ensuring a reduction in the number of technological violations associated with erroneous actions of operational personnel;
in cooperation and in agreement with SO UES JSC, participation in the development and implementation of UNEG development programs in order to increase the reliability of electric power transmission, network observability and controllability, and ensure the quality of electric power;
planning activities for the repair, commissioning, modernization / reconstruction and maintenance of power transmission lines, power grid equipment and devices for the coming period;
development in accordance with the requirements of JSC "SO UES", coordination and approval in the prescribed manner of schedules for emergency limitation of the mode of consumption of electric energy and the implementation of actual actions to introduce emergency restrictions on the dispatching team (order) of JSC "SO UPS";
fulfillment of the tasks of SO UES JSC on connecting the FGC electric grid facilities and power receiving installations of electric energy consumers under the action of emergency automatics.

To fulfill the tasks set, JSC FGC UES developed and approved the concept of operational and technological management of UNEG facilities. In accordance with this concept, a four-level organizational structure is being created (with a three-level control system): the executive office, the head MES NCC, the PMES NCC and the substation operational personnel.

The following functions are distributed between the respective levels of the organizational structure:
IA FSK - information and analytical;
head NCC MES - information-analytical and non-operational;
NCC PMES - non-operational and operational;
substation personnel - operating rooms.

At the same time, non-operational functions include tasks such as monitoring and monitoring the state of the network. The adoption by the network control centers of operational functions related to the issuance of commands for the production of switching requires highly qualified operational personnel, as well as appropriate technical equipment of the NCC.

In order to increase the efficiency and reliability of the transmission and distribution of electricity and power by automating the processes of operational and technological management based on modern information technologies, grid control centers of JSC FGC UES are equipped with software and hardware complexes (STCs) that allow automating such processes as monitoring modes equipment, production of switching in strict accordance with the approved program and others. Thus, due to the automation of the OTU, the reliability of the operation of electrical networks is significantly increased, the accident rate is reduced due to the elimination of errors of operational personnel, and the number of necessary operational personnel is minimized.

It should be noted that the technical policy of JSC FGC UES for new construction and reconstruction provides for:
ensuring energy security and sustainable development of Russia;
ensuring the required indicators of the reliability of the services provided for the transmission of electricity;
ensuring the free functioning of the electricity market;
improving the efficiency of the functioning and development of the UNEG;
ensuring the safety of production personnel;
reducing the impact of the UNEG on the environment;
along with the use of new types of equipment and control systems, ensuring the preparation of the PS for operation without permanent maintenance personnel.

At present, schemes of primary electrical connections operating substations are focused on equipment that requires frequent maintenance, therefore, they provide for redundant ratios of the number of switching devices and connections according to modern criteria. This is the reason for a significant number of serious technological violations due to the fault of operational personnel.

Now automation technological processes completed at 79 PS UNEG, another 42 PS are under implementation. Therefore, the main scheme of organization of operation is focused primarily on the round-the-clock presence of maintenance (operational) personnel on them, controlling the state of the facility and performing operational switching.

Operational maintenance of the UNEG Substation includes:
monitoring of the UNEG condition - control of the equipment condition, analysis of the operational situation at the UNEG facilities;
organization of operational actions to localize technological violations and restore UNEG regimes;
organization of operational maintenance of substations, production of operational switching, regime and circuit support for the safe production of repair and maintenance work in electrical networks related to the UNEG;
performance by operational personnel of operational functions for the production of switching in the UNEG.

Planning and organization:
to carry out repair planning in accordance with the schedules of scheduled preventive repairs with the determination of the scope of work based on the assessment of the technical condition, using modern methods and diagnostic tools, incl. without decommissioning equipment;
conducting a comprehensive survey and technical examination of equipment that has reached its standard service life in order to extend its service life;
development of proposals for modernization, replacement of equipment, improvement of design solutions;
optimization of financing for operations, maintenance and repairs by determining the volume repair work based on the actual state;
reduction of costs and losses;
improvement of organizational structures of management and service;
organization of professional training, retraining and advanced training in accordance with the SOPP-1-2005 standard;
analysis of the parameters and indicators of the technical condition of equipment, buildings and structures before and after repair based on the results of diagnostics;
optimization of the emergency reserve of equipment and elements of overhead lines;
the solution of technical problems during operation and construction is issued in the form of information letters, operational instructions, circulars, technical solutions with the status of mandatory execution, orders, instructions, decisions of meetings and other management decisions.

Monitoring and management of UNEG reliability:
organization of control and analysis of equipment accidents;
assessment and control of power supply reliability;
creation of an appropriate information base.


CREATION OF FULLY AUTOMATED SUBSTATIONS
WITHOUT SERVICE PERSONNEL.
DIGITAL SUBSTATIONS

In order to exclude the dependence of the trouble-free operation of a grid company on the qualifications, training and concentration of attention of operational and relay personnel, it is advisable to spread the automation of technological processes that has been taking place for a long time - relay protection, technological automation (AR, AVR, OLTC, AOT, etc.), emergency automation - on production of operational switches. For this, first of all, it is necessary to significantly increase the observability of technical parameters, to ensure control, position verification, effective operational blocking of switching devices, and automation of control actions. The power equipment used must be adapted to the latest control, protection and monitoring systems.

When introducing microprocessor devices, preference should be given to devices designed to work as part of automated systems. Stand-alone devices should be used only if there are no system analogues. In this regard, the facilities of JSC FGC UES should centrally exclude the possibility of using microprocessor devices with closed exchange protocols, devices that do not support operation in the common time standard.

The architecture and functionality of the automated process control system of a substation (APCS of the substation) as an integrator of all functional systems of the substation is determined by the level of development of technology designed to collect and process information on the substation to issue control decisions and actions. Since the beginning of the development of projects in the domestic power industry for automatic process control systems for substations, there has been a significant development of hardware and software for control systems for use in electrical substations. High-voltage digital current and voltage measuring transformers appeared; primary and secondary power grid equipment with built-in communication ports is being developed; international standard IEC 61850, which regulates the presentation of data on the substation as an automation object, as well as protocols for digital data exchange between microprocessor intelligent electronic devices of the substation, including monitoring and control devices, relay protection and automation (RPA), emergency automation (PA), telemechanics, electricity meters, power equipment, measuring current and voltage transformers, switching equipment, etc.

All this creates the prerequisites for building a new generation substation - a digital substation (DSS).

This term refers to a substation using integrated digital measurement systems, relay protection, control of high-voltage equipment, optical current and voltage transformers and digital control circuits built into switching equipment, operating on a single standard information exchange protocol - IEC 61850.

The introduction of DSP technologies provides advantages over traditional PS at all stages of the implementation and operation of the facility.

Stage "Design":
simplification of the design of cable connections and systems;
data transmission without distortion over virtually unlimited distances;
reduction in the number of pieces of equipment;
unlimited number of data recipients. Distribution of information is carried out by means of Ethernet networks, which allows you to transfer data from one source to any device at the substation or outside it;
reduction of time for interconnection of individual subsystems due to a high degree of standardization;
reduction of labor intensity of metrological sections of projects;

unity of measurements. The measurements are performed with a single high-precision measuring instrument. Dimension recipients receive the same data from the same source. All measuring devices are included in a single clock synchronization system;
the ability to create standard solutions for objects of different topological configurations and lengths;
the possibility of preliminary modeling of the system as a whole to determine the "bottlenecks" and inconsistencies in various modes of operation;
reducing the complexity of redesigning in case of changes and additions to the project.

Stage "Construction and installation work":
reduction of the most labor-intensive and non-technological types of installation and commissioning works related to laying and testing of secondary circuits;
more thorough and comprehensive testing of the system due to the wide possibilities for creating various behavioral scenarios and their modeling in digital form;
reducing the cost of unproductive movement of personnel due to the possibility of centralized configuration and control of work parameters;
reducing the cost of the cable system. Digital secondary circuits allow multiplexing of signals, which involves the two-way transmission through one cable of a large number of signals from different devices. It is enough to lay one optical backbone cable to switchgears instead of tens or even hundreds of analog copper circuits.

Stage "Operation":
a comprehensive diagnostic system, covering not only intelligent devices, but also passive measuring transducers and their secondary circuits, allows you to quickly determine the location and cause of failures, as well as identify pre-failure conditions;
line integrity control. The digital line is constantly monitored, even if no significant information is being transmitted over it;
protection against electromagnetic interference. The use of fiber optic cables provides complete protection against electromagnetic interference in data transmission channels;
ease of maintenance and operation. Switching digital circuits is much easier than switching analog circuits;
reduction of repair time due to the wide offer on the market of devices from different manufacturers that are compatible with each other (the principle of interoperability);
transition to the event-based method of equipment maintenance due to the absolute observability of technological processes allows to reduce operating costs;
support of design (calculated) parameters and characteristics during operation requires lower costs;
the development and refinement of the automation system requires lower costs (unlimited in the number of information receivers) than with traditional approaches.

JSC FGC UES adopted the Kuzbass and Prioksky NCCs as pilot facilities for the creation of a central control center with operational functions.

The Kuzbass NCC has become the first grid control center implemented as part of the JSC FGC UES program to create a NCC with operational functions. As part of the creation of an innovative NCC to ensure continuous operational and technological control and dispatching, the center is equipped with modern software and hardware systems, a video wall is installed to display the network diagram, software is installed that allows you to fully display the state of the energy facility selected by the dispatcher on-line, receive information about outages produced repair and preventive measures up to the names of fitters working at the facility. In addition, the equipment allows NCC dispatchers to intercept control of remote objects in case of an emergency and, in case of emergency, shortest time make a decision to reduce the recovery time of the normal operation of the equipment.

Prioksky TsUS was also created using the latest technologies. Among the equipment used here is a video wall for displaying information, consisting of fifty-inch projection modules and a redundant high-performance video controller, an operational information complex for monitoring the modes of the electrical network and the state of switching devices of substations, which allows the operational personnel of the NCC to monitor the operation of the equipment and control it in real time, the latest system satellite communications, uninterruptible power supply and automatic fire extinguishing systems.

Vladimir Pelymsky, Deputy Chief Engineer - Head of the Situational Analytical Center of JSC FGC UES, Vladimir Voronin, Head, Dmitry Kravets, Head of Department, Magomed Gadzhiev, Leading Expert of the Electric Regime Service of JSC FGC UES

Yuri MORZHIN, Deputy CEO- director of the branch of OJSC "STC of electric power industry" - VNIIE;

Yuri SHAKARYAN, Deputy General Director - Scientific Supervisor of OAO Scientific and Technical Center for Electric Power Industry, Scientific Supervisor of VNIIE;

Valery VOROTNITSKY, Deputy Director of the branch of JSC "STC of Electric Power Industry" - VNIIE for scientific work;

Nikolai NOVIKOV, Deputy Scientific Director of JSC "STC of Electric Power Industry"

Speaking about the reliability, quality and environmental friendliness of power supply, we must first of all keep in mind the development and development of fundamentally new - innovative technologies for calculating, analyzing, predicting, standardizing and reducing power losses in electrical networks, operational dispatch control of their modes. We offer the material provided by the Scientific Research Institute of Electric Power Industry (VNIIE), a branch of JSC "Scientific and Technical Center of the Electric Power Industry", which tells about the most important developments of the institute in this area to date.

Improving the means and systems for calculating the reductionelectricity losses

New approaches to the power industry management system, to the formation of tariffs for electricity transmission services, to the system of regulation and management of the level of electricity losses require a corresponding development of methods for their calculation. This development is being carried out today in several directions.

Accuracy calculations of technical losses (RTP) electricity is expected to be increased through a more complete use of operational information about the switching state of the electrical network (Fig. 1), the physical parameters of its elements, regime data on loads, voltage levels, etc.

It is necessary to move from deterministic calculations of the level of electricity losses to probabilistic estimates with a given accuracy and confidence intervals, followed by risk assessment when making decisions on investing money in reducing losses.

Another vector of development is the use of fundamentally new intelligent models for accounting for many uncertain factors that affect the magnitude of actual and technical losses of electricity, and for forecasting losses. One of these models is based on the use of artificial neural networks, which are, in fact, one of the actively developing areas of artificial intelligence technologies.

The development of automated information and measurement systems for commercial electricity metering (AIIS KUE), automated process control systems (APCS) for electric networks, graphic and geographic information systems (GIS) creates real opportunities for improving the software for calculating, analyzing and standardizing electricity losses (RP software) . In particular, at present, there is an urgent need to integrate software and hardware complexes (STC) and the databases contained in them of AIIS KUE, ASTU, GIS and RP software to improve the accuracy, transparency and validity of calculations of the modes of electrical networks, balances and losses of electricity. Some of this integration has already taken place. Its further development should be based on new approaches to the standardization of information exchanges between various hardware and software complexes on a single information platform, including using the so-called SIM models.

As practice shows, traditional methods and means of reducing electricity losses cannot ensure that the level of losses is maintained at a technically and economically justified level. Approaching this level is becoming more expensive and requires more effort. It is necessary to use fundamentally new equipment and technologies for the transmission and distribution of electricity. First of all it is:

  • Modern static adjustable longitudinal and transverse compensation devices reactive power.
  • Devices based on the use of high-temperature superconductivity (HTSC).
  • The use of "smart" technologies in electrical networks (SmartGrid technologies). This allows, by providing electrical networks with means of system control and load management at the pace of the process, not only to carry out operational monitoring of power consumption and electricity of consumers, but also to manage this power and electricity in order to most efficiently use the capacity of the electrical network at any given time. Due to such control, the optimal level of electricity losses in the networks is also ensured with acceptable values ​​of electricity quality indicators.

According to the American Council for an Energy Efficient Economy (ACEEE), by 2023 the use of Smart Grid technologies in combination with other measures to efficient use energy resources will save up to 30% of the planned energy costs. That is, every third kilowatt-hour can be obtained not by expanding generating capacities, but by distributing existing energy resources using new information technologies.

The amount of actual electricity losses in electric networks, for which electric grid organizations must currently pay, largely depends on the accuracy of measurements of electricity supplied to the electric network and shipped from the electric network.

The practice of introducing modern AIIS KUE shows that these rather expensive and space-distributed information-measuring systems can fail during operation, lose measurement accuracy, introduce random significant failures in measurement results, etc. All this requires the development and implementation of methods assessing the reliability of measurements, identifying and localizing imbalances in power and electricity, introducing fundamentally new measuring instruments, including optical instrument transformers current and voltage.

In the figure: screenshots of the RTP 3 program.

Interactive simulation of calculations of the work of power systems

Dynamic model of real-time EPS. It provides the possibility of modeling EES of large dimensions in accelerated, delayed and real time scales. The model is used for: building simulators-advisers of the dispatcher for mode control, analysis of steady and transient modes, analysis of accidents, modeling of primary and secondary control systems and emergency automatics (PA). The EPS model takes into account electromechanical and long-term transient processes, frequency and active power control systems (AFCM). The calculation of technical losses of electricity and power (including by voltage classes and regions) and other mode parameters is carried out. For the first time in Russia, a model of this class is used to build complex simulators-advisers together with a topological analysis of a complete switching circuit of a power interconnection.

The model uses fairly accurate algorithms for modeling transient processes in the "frequency - active power" mode (speed controllers, steam reheating, boiler automation, etc.). Voltage regulators are made according to two possible schemes: simplified (as a regulated source of reactive power that maintains the voltage value at a given level) and refined (as a control system for the EMF of a synchronous machine with the ability to control voltage, frequency and their derivatives).

The model provides tracking of the current mode of power facilities based on the information of the state estimation task (OS) and OIC data. The calculation scheme obtained from the OS problem is expanded (about 2 times) through the use of normative reference and a priori information, as well as reliable TI and TS in the OIC.

In the model, a topological analysis of the complete switching circuit is performed and its informational interaction with the regime (calculated) circuit of power facilities is performed. This provides control of the model mode by turning on / off switching devices, that is, in the usual way for operational personnel.

The model is controlled interactively by the user, control systems and PA, and scenarios for the development of accidents. An important function of the model is to check violations and the existence of the current regime according to the N-1 criterion. Sets of control options can be set according to the N-1 criterion, intended for different modes of controlled power interconnection. The program allows you to compare the design mode in the EPS model with the OIC data and identify erroneous and missing mode data.

Initially, the model was used to build real-time regime simulators, and later its functions were extended to analyze accidents, test algorithms for identifying power systems as control objects, and other tasks. The model is used for regime study of applications for putting equipment into repair, modeling of ARCHM systems, information support for operational personnel of EPS and power associations, and as an adviser to the dispatcher on mode maintenance. On the model, studies were carried out on the propagation of a frequency and voltage wave in real circuits of large dimensions under large perturbations, as well as on circuits of a chain and ring structure. A technique has been developed for using WAMS data to verify the current regime by OS and OIC data.

The difference of this development from others is in the possibility of modeling the dynamics of large-scale power facilities in real time, cyclic monitoring of the mode according to the OIC data and the OS task, expanding the design scheme by 70-80% by taking into account buses of substations, power units, reactors, etc. .

To date, a dynamic real-time EPS model has been implemented in SO UES, FGC UES, ODU Center, JSC "Bashkirenergo".

Complex KASKAD-NT for displaying operational

information on individual and collective means

(dispatching boards and video walls)

The complex is a means of forming and displaying various screen forms (diagrams, maps, tables, graphs, instruments, etc.) on individual (displays) and collective means. Designed to display information of OIC and other software systems in real time both on individual (displays) and collective (mosaic control boards and video walls) facilities.

The system for displaying operational information on video walls is implemented in SO UES, ODU Center and OAO Bashkirenergo. In SO UES on a video wall 4 x 3 cubes, the display of generalized information in graphical and tabular forms is implemented, as well as the display of the UES scheme on a Finnish mosaic shield. In the ODU of the Center on the video wall by means of the KASKAD-NT complex, the information of the dispatching personnel support system is displayed in the form of an operational diagram, diagrams against the background of a map of the area and detailed diagrams of substations.

For JSC "Bashkirenergo" the complex is currently used in the gym when displaying on the video wall 3 x 2 cubes of structural and switching circuits and generalized information in tabular form. On the small block diagram there is the possibility of opening 5 main substations of JSC "Bashkirenergo". On the video wall of 8 x 4 cubes of the control room with a large structural diagram, it is possible to reveal 62 substations and process task data. On a large video wall, it is possible to perform topological analysis and display the complete switching diagram of the power interconnection.

The KASKAD-NT system is open for integration with other complexes and is built as a set of constructors used to build display systems by both developers and users. This feature provides the ability to support and develop the functionality of the display system directly by users and maintenance personnel without the involvement of developers.

power grid assets

In 2008, VNIIE specialists completed a major project - the Program for the Reconstruction and Development of the Automated Process Control System (APCS) of OAO MOESK. The need to implement this project was due to the moral and physical deterioration of the material base of the control system (for well-known reasons of a national nature), taking into account a significant change in the requirements for dispatch control when working in market conditions, as well as taking into account the structural reorganization of the company. The development is aimed at solving the task set in MOESK of building a high-quality vertical of operational dispatch control, using in its work the most modern methods of organization and technical support of the control process.

The program was developed jointly with OAO Enera and active participation MOESK specialists. The work includes sections on the analysis of the current state of APCS, on the development of basic technical requirements for a promising APCS, its elements and subsystems, as well as proposals for technical solutions. Including with options for the reconstruction and development of the system based on technical means of leading domestic and foreign manufacturers of control equipment.

When developing, the main provisions of the existing scientific and technical documentation in the field of automation of the grid complex, which provide for the development of centralized technological control of electrical networks, the creation of automated substations based on a single complex of modern technical means, with the integration of measurement systems, protection, automation and equipment control of objects, were taken into account and specified for the company's conditions electrical networks.

Due to the large number of PSs and the moral and physical wear and tear of the bulk of telemechanics, phased automation of PSs is envisaged, the first stage of which is the reconstruction of the TM, consistent with the reconstruction and development of the communication system, that is, the formation of the basis of modern SSPI, and the second stage - for part of the PS - creation of full-scale APCS.

The program provides for updating the hardware and software complex of dispatch centers based on the modern power grid management system adopted by MOESK (ENMAC GE), which automates control and dispatch control operations, as well as network operation management during equipment maintenance and interaction with electricity consumers.

The development of the communication system is focused on a complete transition to digital data transmission technologies by the wide use, along with the existing high-frequency communications, of fiber-optic technology and wireless communications.

An important place is given to the creation of an integration platform (IP) that supports a single IEC information model (SIM-model) and allows you to connect various applications to a common information bus using WEB-Service technology. Together with OAO "ETsN" and OOO "MODUS" the first version of the graphical instrumental system for creating IP was developed and introduced into trial operation in RGC "Kubanenergo", to which OIK KOTMI is connected.

We add that VNIIE developed the following expert systems for use in operational dispatch control: advisory systems for annual planning of network equipment repairs; systems-advisers for the regime study of operational repair requests; systems for the analysis of topology in the electrical network with the analysis of emergency situations; simulator systems for operational switching; instrumental expert system MIMIR for energy applications; ESORZ expert system for processing operational applications (application with SO-CDU, ODU of the Center, ODU of the Middle Volga); system for analyzing the topology of the power grid ANTOP (application in the ODU of the Urals); training system KORVIN for operational switching (application in regional power systems).

At present, a system for annual planning of repairs of electric grid equipment (for SO-CDU) is being developed.

The whole complex of works of JSC "STC of electric power industry" on new information technologies is complemented by topical technological tasks, some of which will be completed in the near future and which we hope to tell about on the pages of the magazine.