A full-scale experiment confirmed the possibility of restoring power supply to a part of the central power region of yakutia at the expense of the oes of the east. Parallel possibilities of the power system of the East Main problems and imbalances in the functioning of the UES of Russia

The creation of a controlled connection of power systems to increase the reliability and efficiency of their operation is advisable, first of all, in those places where there are difficulties in ensuring reliable parallel operation. These are interstate power transmission lines, where, as a rule, there is a need to separate power systems by frequency, as well as "weak" intersystem power transmissions that significantly limit the possibilities of power exchanges between power systems operating in parallel, for example, 220 kV power transmission lines for connecting the power systems of Siberia and the Far East, passing through along the Baikal-Amur (northern transit) and Trans-Siberian (southern transit) railway lines up to 2000 km long each. However, without special measures, parallel operation of power systems along the northern and southern transits is impossible. Therefore, a merger is being considered, which is a variant of parallel asynchronous operation of power systems along the southern double-circuit transit (at the subsequent stages of the merger, asynchronous closure of the northern transit is also possible). The urgency of the problem is that it is necessary to find technical solutions to ensure the operation of the 220 kV power transmission Chita-Skovorodino, which feeds the traction substations of the Trans-Baikal Railway and at the same time is the only electrical connection between the UPS of Siberia and the East. Today, this long-distance communication does not have the required bandwidth, and also does not meet the requirements for maintaining within the ranges of acceptable values. It operates in an open mode and has a division point on the VL-220 Holbon-Erofei Pavlovich section. All this determines the insufficient reliability of the 220 kV network, which is the reason for repeated violations of the power supply of traction substations and malfunctions of signaling devices, interlocks and the train schedule. One of the possible options for asynchronous combination is the use of the so-called asynchronized electromechanical frequency converter (AS EMPCH), which is an aggregate of two AC machines of the same power with rigidly connected shafts, one of which is designed as an asynchronous synchronous machine (ASM), and the other as ASM (AS EMPCH type ASM + ASM) or as a synchronous machine (AS EMPCH type ASM + SM). The latter option is structurally simpler, but the synchronous machine is connected to a power system with more stringent requirements for. The first machine in the direction of power transmission through the AC EMPH operates in the engine mode, the second - in the generator mode. The excitation system of each AFM contains a direct-coupled frequency converter supplying a three-phase excitation winding on a laminated rotor.
Earlier in VNIIElektromash and Electrotyazhmash (Kharkov) for the AS EMPCH, draft and technical designs of ASM of vertical (hydrogenerating) and horizontal (turbine generating) versions with a capacity of 100 to 500 MW were carried out. In addition, the Research Institute and the Electrotyazhmash plant have developed and created a series of three experimental industrial samples of AS EMPCH-1 from two AFMs with a capacity of 1 MW (that is, for a throughput capacity of 1 MW), comprehensively tested at the LVVISU test site (St. Petersburg). The converter of two AFM has four degrees of freedom, that is, four parameters of the unit mode can be simultaneously and independently regulated. However, as theoretical and experimental studies have shown, all modes that are possible on the AS EMPH of the ASM + ASM type are realizable on the AS EMPH of the ASM + SM type, including the modes of consumption of reactive power from the side of both machines. The permissible frequency difference of the combined power systems, as well as the controllability of the AC EMPCH, are determined by the "ceiling" value of the excitation of the machines. The choice of the installation site for the AS EMPCH on the route under consideration is due to the following factors. 1. According to the data of JSC Institute Energosetproekt, in the winter maximum in 2005, the power flow through Mogoch will be approximately 200 MW in the direction from the Kholbon substation to the east towards the Skovorodino substation. It is the magnitude of this overflow that determines the installed capacity of the AS EMPCH-200 unit (or units).
2. The complex with AS EMPCH-200 is designed for turnkey delivery with fully automatic control. But from the control room of the Mogocha substation and from the ODU of Amurenergo, the settings for the magnitude and direction of active power flows can change.
3. The installation site (Mogocha substation) is located approximately in the middle between the Holbon substation and the powerful Skovorodino substation, especially since the Kharanorskaya GRES can provide the required voltage levels at the Holbon substation by the specified time (that is, by 2005). At the same time, the inclusion of AS EMPCH-200 in the cut of the power transmission line at the Mogocha substation will practically divide the connection into two independent sections with approximately half the resistances and independent EMF of the machines of the unit on each side, which will allow approximately one and a half to two times to increase the throughput of the entire double-circuit Power transmission line-220 kV. In the future, if it is necessary to increase the exchange power, it is possible to consider the installation of the second AS EMPCH-200 unit in parallel with the first.

This will make it possible to significantly postpone the construction of -500 kV and the timing of the possible expansion of the Kharanorskaya GRES. According to preliminary estimates, with the parallel operation of the power systems of Siberia and the Far East only along the southern transit, the static stability limiting exchange power flows in the Mogocha-Ayachi section are without an EMPCH: in the east direction - up to 160 MW, in the west direction - up to 230 MW.

After the installation of the AC EMPCH, the problem of static stability is automatically removed and the flows, respectively, can be 200-250 MW and 300-400 MW when controlling the limiting flows by thermal limitation of individual, for example, head sections of power lines. The issue of increasing exchange flows becomes especially relevant with the commissioning of Bureyskaya.

It is assumed, as indicated, the installation of the AS EMPCH-200 in the cut of the 220 kV overhead line at the Mogoch substation of the main double-circuit intersystem communication with numerous intermediate power take-offs.

On such an intersystem connection, accidents are possible with the loss of electrical communication with a powerful power system and the formation of an energy district with power supply through the AC EMPCH-200, that is, with the operation of the AC EMPCH-200 on a console load. In such modes, the AC EMPCH-200 cannot and should not support, in the general case, the pre-emergency value of the transmitted power set by the master.

At the same time, he must retain the ability to regulate on his own tires and the speed of the unit shaft. The adaptive control system developed for the AS EMPCH requires teleinformation about turning off and on the switches of the adjacent sections of the power transmission line. Based on this teleinformation, it transfers the AFM of the unit from the side of the non-emergency section of the route to control according to the shaft rotation frequency, and from the side of the console, the AFM takes over the load of the energy region.

If this load is greater than the installed power of the AFM, then the AC EMPCH is shunted with the transfer of the machines to the compensatory mode. It is also important that the transmission of tele-information about the vector behind the open switch allows, without catching synchronism, to immediately turn on the AC EMPCH-200 into normal operation without shock after turning on the disconnected switch.

Long-term theoretical and experimental studies carried out for a complex of controlled connection of power systems of the North Caucasus and Transcaucasia on a 220 kV Sochi-Bzybi Krasnodarenergo power transmission based on the AS EMPCH-200 project have confirmed the expected and known capabilities of the EMPCH AS to regulate the active and machine voltages and the rotor speed. unit.

In fact, within the limits of the constructive capabilities of the AC EMPH, it is an absolutely controllable element for combining power systems, which also has damping capabilities due to the kinetic energy of the flywheel masses of the rotors of the machine's machines, which static converters are deprived of. The control system together with ARV of machines with self-excitation and start-up systems after giving the Start command provides automatic testing of the state of the elements of the entire complex with subsequent automatic connection to the network in the required sequence without the participation of personnel or the unit shutdown after giving the Stop command. There is also a manual connection to the network and manual adjustment of settings, emergency shutdown and automatic reclosure. When starting the AC EMPCH-200 into operation, it is sufficient for a quiet turn-on to provide a slip in the specified range and settings that provide a mode along the power line before the shunt switches open. In general, the control of the AC EMPCH-200 on intersystem communication must be approached from the position that the regulation structure must carry out the required control of the operation of the unit in steady and unsteady modes and ensure the performance of the following main functions in electrical systems.

1. Maintaining the values ​​of voltages (reactive powers) in accordance with the settings in normal modes. So, for example, each of the AC EMPCH machines is capable, within the limits limited by the rated currents, to generate the required reactive power value or to provide its consumption without loss of stability. 2. Control in normal and emergency modes of the magnitude and direction of the active power flow in accordance with the setting for synchronous and asynchronous operation of parts of power systems, which, in turn, contributes to an increase in the throughput of intersystem links. 2.1. Flow control with the help of AS EMPCH-200 according to a schedule agreed in advance between the power systems to be connected, taking into account daily and seasonal changes in loads. 2.2. On-line regulation of intersystem flow up to reverse with simultaneous damping of irregular oscillations. If it is required to quickly change the direction of active power transmission through the unit, then by coordinating the active power settings on the first and second machines, it is possible to change the active power flow at a practically constant speed of rotation, overcoming only the electromagnetic inertia of the machine winding circuits. With appropriate excitation “ceilings”, the power reversal will take place quite quickly. So, for an AS EMPC consisting of two ASM-200, the time of full reversal, from +200 MW to -200 MW, as calculations show, is 0.24 s (in principle, it is limited only by the value of T "(f). 2.3 .Using the AC EMPCH-200 as an operational source for maintaining the frequency, as well as for suppressing electromechanical vibrations after large disturbances in one of the power systems or in the console power district. 3. Work for the dedicated (console) power district of consumers with the required level of frequency and voltage. 4 . Damping of vibrations in emergency modes of operation of electrical systems, a significant reduction in disturbances transmitted from one part of electrical systems to another. In transient modes, thanks to the ability of the AC EMPH to change the rotation frequency within the specified limits, that is, the kinetic energy of the unit, intensive damping is possible
fluctuations and during a certain time the disturbance that has arisen in one part of the power system will not be transmitted to another. So, at short-circuit. or automatic reclosing in one of the power systems, the unit will accelerate or decelerate, but the value of the active power of the AFM connected to another power system will remain unchanged with appropriate control. 5. Transfer, if necessary, of both machines of the unit into the operation mode of the synchronous compensator. The cost of constructing a converter substation with an EMPCH-200 AS is determined by the composition of the equipment and, in fact, is no different from the usually constructed substations with synchronous compensators. The site for the construction of the device should ensure the convenience of equipment delivery, compact installation and communication with the existing power equipment at the Mogocha substation. To simplify the entire substation system, an option is needed without separating the AC EMPCH-200 into a separate substation. To connect to the power systems of the unit, the machines of which are designed for full capacity = 200 / 0.95 = 210.5 MVA (according to JSC Electrosila, St. Petersburg and), two transformers for 220 / 15.75 kV are required. A technical and economic comparison of the AC EMPH with static converters was carried out for a transmitted power of 200 MW. The compared parameters are shown in the table. A DC link (DC link) is a classic option. The table shows the power transmitted through the HVDC 355 MW, which corresponds to one block of the Vyborg substation. The unit cost of HVAC is indicated (taking into account substation equipment), which is given in the table. The efficiency of the HVAC substation (taking into account synchronous compensators, power transformers and filters) is at the level of 0.96.
HVAC on lockable (two-operation) keys with PWM and parallel connected reverse diodes. It is known that the internal losses of lockable keys are 1.5-2 times higher than that of conventional thyristors, therefore, the efficiency of such a HCC with special power transformers, taking into account high-frequency switching filters, is 0.95. The cost issue is not clearly defined. However, the specific cost of HVAC is indicated on the basis of STATCOM 165 USD / kW and above.
For HVDCs of the Directlink type with two-level formation of the output curve, the unit cost is higher and amounts to $ 190 / kW. The table shows the data for both STATCOM and Directlink-based variants.

According to JSC "Electrosila", the unit cost of the installed capacity of the AS EMPCH-200 of two ASM = 98.3% (98.42% each) is $ 40 / kW. Then the cost of the converter unit itself will be $ 16 million.In accordance with the base cost of a 220 kV alternating current substation with two transformers is $ 4 million, and the specific cost of the converter with the substation will be = (16 + 4) 10 6/400 10 3 = 50 dollars / kW. Taking into account the transformers, the overall efficiency will be = 0.983 2 0.997 2 = 0.96.
Along with the above options, it is necessary to consider the option of the converter using the synchronous compensators of the KSVBM type operated in power systems with hydrogen cooling of the outdoor installation. It should be noted that in the AC EMPCH of the ASM + SM type, the KSVBM 160-15U1 synchronous compensator can be used as a synchronous machine without any alterations in all modes, subject to the conditions for the stator current. For example, at = 1 power P = ± 160 MW; at = 0.95 (as in the project of JSC Electrosila) P = 152 MW, Q = ± 50 MV A, and EMF E = 2.5<Еном =3 отн.ед.

According to the developer Uralelektrotyazhmash OJSC, the KSVBM 160-15U1 synchronous compensator costs $ 3.64 10 6. , 46 10 6 dollars and then the total cost of the converter of the ASM + SM type (that is, from the serial and re-equipped synchronous compensators) will be 9 10 6 dollars (see table). It should be noted here that
GOST 13109-97 on the quality of electrical energy (Resolution of the State Committee for Standardization and Certification of the Russian Federation, 1998) allows the following frequency deviations: normal ± 0.2 Hz for 95% of the time, maximum ± 0.4 Hz for 5% of the day ... Taking into account that the AFR will be triggered further, it can be argued that the ceiling value of the excitation voltage for sliding with a frequency of ± 2 Hz set in the AFM will ensure reliable operation of the AC EMPH also in case of other large system disturbances. At the rated stator current, the losses in the SC are 1800 kW, and then the efficiency is = 0.988. Taking the efficiency of the re-equipped ASM from the SC is the same as in the project of JSC Electrosila, taking into account the transformers, we get: = 0.988 0.983 0.997 2 = 0.966.
The table shows data for two ACM + CM units in parallel, which allows to cover the expected increase in transit capacity when the converter is installed at the Mogocha substation. At the same time, the unit cost is less, and the efficiency is higher than that of all other options. An obvious advantage should also be emphasized - KSVBM expansion joints are designed for outdoor installation at ambient temperatures from -45 to +45 o С (that is, the entire technology has already been worked out), therefore there is no need to build a turbine room for AS EMPCH units, but only a housing is needed for auxiliary devices with an area, as required by building codes, two six-meter spans in width by six six-meter spans in length, that is, 432 m 2. Thermal calculations for expansion joints
are made for both hydrogen cooling and air cooling. Therefore, the aforementioned two-unit AC EMPH can operate for a long time on air cooling at a load of 70% of the nominal, providing the required flow of 200 MW.
In addition, the Energosetproekt institute has developed an original standard design of an SC unit with a capacity of 160 MVA with a reversible brushless excitation, which can significantly reduce the volume of construction work, accelerate the installation and commissioning of SCs, and significantly reduce the cost of their installation.

CONCLUSIONS
1. Asynchronous parallel interconnection of the UPS of Siberia and the Far East along the southern double-circuit transit of 220 kV using an asynchronized electromechanical frequency converter (AC EMPCH) is preferable in terms of technical and economic indicators in comparison with the well-known VAC based on STATKOM and DIRECTLINK.
2. Long-term theoretical and experimental studies and completed projects have shown the capabilities of the AS EMPCH to regulate the active and reactive powers, machine voltages and the rotor speed of the unit. By installing a converter at the Mogocha substation, the Holbon-Skovorodino transit is practically divided in half, so the throughput of this transit will increase by 1.5-2 times, which will allow to postpone the construction time of the 500 kV transmission line and the expansion time of the Kharanorskaya GRES.
3. A preliminary technical and economic comparison of the converters showed that the construction of a substation with HVDC on lockable keys with PWM for a transmitted power of 200 MW on the basis of the Directlink project costs $ 76 million, and on the basis of the STATKOM project - $ 66 million. At the same time, the AC EMPCH-200 of the ASM + ASM type, according to the data of Electrosila OJSC and the Electrotyazhmash Research Institute (Kharkov), costs $ 20 million.
4. For AS EMPCH type ASM + SM based on serially produced by JSC Uralelectrotyazhmash and operated in power systems synchronous compensators with hydrogen and air cooling for outdoor installation KSVBM 160 MV A, the specific cost of the installed capacity of AS EMPCH with complete substation equipment is $ 40 / kW and at the same time the efficiency is not lower than other types of converters. Considering the small volume of construction and installation work, low unit cost and high efficiency, it is precisely such a substation with an EMPH AC completely on domestic equipment that can be recommended for the asynchronous integration of the UPS of Siberia and the Far East.

IES East - 50

United East

The decision to create the United Energy System of the East on the basis of the power systems of the Amur Region, Primorsky and Khabarovsk Territories and the Jewish Autonomous Region (over time, the power system of the southern part of Yakutia joined the IES East) was made by the USSR Ministry of Energy. The same order, number 55A, created the Operational Dispatch Office (ODU) of the East, which is now a branch of System Operator UES JSC. The path from the decision to the creation of the IES took two years - on May 15, 1970, the Amur and Khabarovsk energy systems were merged. And although isolated energy systems have survived to this day in the Far Eastern Federal District (in the north of Yakutia, in the Magadan and Sakhalin regions, in Kamchatka and Chukotka, as well as in the Nikolaev energy district of the Khabarovsk Territory), since then the IES of the East has become the most important part of the region's energy sector. It includes power plants with a total installed capacity of 9.5 GW (as of January 1, 2018). The IES of the East was connected to the IES of Siberia by three 220 kV transmission lines, and in 2015 they were for the first time included in parallel synchronous operation.

Rise above local interests

According to Sergei Drugov, one of the former heads of the OEC East, the development of the IES East did not always go smoothly - in particular, local interests interfered. “For example, the leadership of the Amur Region at one time was not interested in the construction of a power transmission line in the Khabarovsk Territory, since a powerful source appeared on its territory - the Zeyskaya HPP. The leadership of the Khabarovsk Territory had a negative attitude towards the construction of the Bureyskaya HPP, considering it necessary to build power facilities only on the territory of the Territory and only those that close to their own consumer, ”recalls Sergei Drugov.

However, power supply crises (Amur Region - 1971-1973; Khabarovsk Territory - 1981-1986; Primorsky Territory - 1998-2001) pushed the regions and their leaders to join efforts. We needed powerful transmission lines between generating capacities and the main centers of consumption. The former are concentrated in the west of the region (Zeyskaya and Bureyskaya HPPs, Neryungrinskaya GRES), the latter in the southeast (in Primorye and Khabarovsk).

Further more

In recent years, the consumption of electricity by the IES of the East and the power systems of the constituent entities of the Federation has been growing noticeably, from time to time updating historical highs. IES East has a reserve in terms of capacity, allowing, for example, the export of electricity to neighboring China, but in order to avoid problems in the very near future, new generating facilities and further development of networks are needed.

Much is being done in this direction. The second stage of the Blagoveshchenskaya CHPP is already in operation (additional installed electric capacity - 120 MW, heat capacity - 188 Gcal / h). The launch of the Vostochnaya CHPP in Vladivostok is scheduled for the third quarter of 2018 (installed electric capacity will be 139.5 MW, heat capacity - 421 Gcal / h; the station will provide heat and hot water to more than 300 thousand city consumers). Next year, a new CHPP in the town of Sovetskaya Gavan should provide current (installed electric capacity will be 120 MW, heat capacity - 200 Gcal / h).

A new version of the centralized emergency control system (CSPA) of the United Energy System of the East with the Bureyskaya HPP emergency control system connected to it was put into commercial operation at the branch of SO UES OJSC “United Dispatching Management of Energy Systems of the East” (ODU Vostoka).

The modernization of the centralized control system and the connection of the Bureyskaya HPP to the local automatic stability control system (LAPNU) as its downstream device will make it possible to minimize the amount of control actions in the power system to disconnect consumers in the event of emergencies at electric power facilities.

TsSPA IES East was put into commercial operation in 2014. Initially, the LAPNU of the Zeyskaya HPP and the LAPNU of the Primorskaya GRES were used as grassroots devices for it. After the upgrade of the hardware and software base of LAPNU carried out by the branch of PJSC RusHydro - Bureyskaya HPP, its connection to the centralized control center also became possible.

“The successful commissioning of the LAPNU of the Bureyskaya HPP as part of the Centralized Control System of the IES of the East made it possible to bring the automatic emergency control in the power grid to a qualitatively new level. The number of start-up bodies increased from 16 to 81, the CSPA covered two-thirds of the controlled sections in the IES of the East, the volume of control actions for disconnecting consumers in the event of an emergency in the power system was significantly minimized, ”noted Natalya Kuznetsova, Director for Mode Management - Chief Dispatcher of the ODS East.

To connect the Bureyskaya HPP emergency control system, specialists from the ODE Vostok in 2017–2018 carried out a set of measures, which included the preparation and configuration of the TsSPA test site, setting up its network interaction with the LAPNU of the Bureyskaya HPP. According to the developed ODE of the East and the program coordinated with the Branch of PJSC RusHydro - Bureyskaya HPP, tests were carried out for the operation of the LAPNU as a downstream device of the Centralized Control System, as well as monitoring and analysis of computational models, monitoring the communication channels and information exchange between the Centralized Control System and the LAPNU, setting up network interaction and software.

TsSPA IES East belongs to the family of third generation centralized emergency control systems. Compared to previous generations, they have extended functionality, including a more advanced algorithm for calculating the static stability of the power system and an algorithm for choosing control actions according to the conditions for ensuring not only static, but also dynamic stability - the stability of the power system in the process of emergency disturbances. Also, the new CSPA operate on the basis of a new algorithm for assessing the state of the electric power mode of the power system. Each CSPA has a two-tier structure: upper-level software and hardware complexes are installed in the dispatch centers of the ODU, and the lower-level devices are installed at dispatching facilities.

In addition to the IES of the East, the IES of the third generation successfully operate in the IES of the North-West and the IES of the South. Systems in the IES of the Middle Volga, the Urals and the Tyumen power system are in trial operation.

2.1. Characteristics of the structure of the Unified Energy System of Russia

What is the UES of Russia?

The Unified Energy System of Russia is a highly automated complex of power plants, electric grids and power grid facilities, which is developing throughout the country, united by a single technological regime and centralized operational dispatch control.

UES of Russia is the world's largest synchronously operating electric power association, covering about 7 thousand km from west to east and more than 3 thousand km from north to south.

The UES of Russia provides reliable, economical and high-quality power supply to the sectors of the economy and the population of the Russian Federation, as well as the supply of electricity to the power systems of foreign countries.

Development of the UES of Russia and its modern structure

The development of the UES of Russia took place through a phased unification and organization of parallel operation of regional energy systems, the formation of interregional unified energy systems (UES) and their subsequent unification as part of the Unified Energy System.

The transition to this form of organization of the electric power industry was due to the need for a more rational use of energy resources, increasing the efficiency and reliability of the country's power supply.

At the end of 2005, six interconnected energy systems were operating in parallel within the UES of Russia (see Fig. 2.1) - the North-West, Center, Middle Volga, Urals, South, Siberia. IES of the East, which includes 4 regional power systems of the Far East, operates separately from the IES of Siberia. The dividing points between these interconnected power systems are located on the 220 kV transit high-voltage line (OHL) Chitaenergo - Amurenergo and are installed promptly depending on the balance of both power interconnections.

The experience of more than 40 years of work of the UES of Russia has shown that the creation of an integral unified system, despite the relative weakness of network connections between the European part of Russia - Siberia and Siberia - the Far East, provides tangible savings in electricity generation costs due to efficient management of electrical energy flows and contributes to reliable power supply of the country.

UES of the North-West

Power facilities located in the territories of St. Petersburg, Murmansk, Kaliningrad, Leningrad, Novgorod, Pskov, Arkhangelsk regions, the republics of Karelia and Komi operate as part of the UES of the North-West. The UPS provides synchronous parallel operation of the UES of Russia with the power systems of the Baltic States and Belarus, as well as asynchronous parallel operation (via a converter) with the power system of Finland and the export of electricity to the countries that are part of the Nordic power grid NORDEL (Denmark, Finland, Norway, Sweden).

Distinctive features of IES North-West are:

  • extended (up to 1000 km) single-circuit transit overhead lines 220 kV (Vologda - Arkhangelsk - Vorkuta) and 330 kV (St. Petersburg - Karelia - Murmansk);
  • a large share of power plants operating in the basic mode (large nuclear power plants and thermal power plants), providing about 90% of the total electricity generation in the UPS. In this connection, the regulation of the unevenness of the daily and seasonal total power consumption schedules of the UPS is mainly due to intersystem power flows. This leads to reversible loading of intra- and intersystem transit lines 220-750 kV practically to the maximum permissible values.

ECO Center

The IES of the Center is the largest (in terms of production potential concentrated in it) unified energy system in the UES of Russia. Power facilities located in the territories of Moscow, Yaroslavl, Tver, Smolensk, Moscow, Ivanovsk, Vladimir, Vologda, Kostroma, Nizhny Novgorod, Ryazan, Tambov, Bryansk, Kaluga, Tula, Orel, Kursk, Belgorod, Voronezh and Lipetsk region, and the generating capacity of the power plants of the association is about 25% of the total generating capacity of the UES of Russia.

Distinctive features of the ECO Center are:

  • its location at the junction of several IES (Northwest, Middle Volga, Urals and South), as well as the energy systems of Ukraine and Belarus;
  • the highest share of nuclear power plants in the structure of generating capacity in the UES;
  • a large number of large power consumption nodes associated with ferrous metallurgy enterprises, as well as large industrial urban centers (Vologda-Cherepovets, Belgorod, Lipetsk, Nizhny Novgorod);
  • the presence of the Moscow energy system, the largest in Russia, which makes increased demands on ensuring the reliability of power supply modes and is currently distinguished by high rates and a large increase in power consumption;
  • the need for widespread involvement of power units of thermal power plants in the process of regulating the frequency and power flows in order to increase the flexibility of controlling the modes and reliability of the UPS.

UES of the Middle Volga

Power facilities located in the Penza, Samara, Saratov, Ulyanovsk regions, Mordovia, Tatar, Chuvash and Mari republics operate as part of the UES of the Middle Volga.

The IES is located in the Central part of the UES of Russia and borders on the IES of the Center and the Urals, as well as the energy system of Kazakhstan. The IES provides transit power transmission - up to 4300 MW from east to west and up to 3800 MW from west to east, which allows the most efficient use of the generating capacities of both the association itself and the IES of Center, Urals and Siberia during the day.

A distinctive feature of the UES of the Middle Volga is a significant share of hydro-generating capacities (HPPs of the Volga-Kama cascade), which makes it possible to quickly change generation in a wide range up to 4880 MW, providing both frequency regulation in the UES of Russia and maintaining the value of transit flows from the UES of Center, Urals and Siberia within the given limits.

URES of the Urals

The URES of the Urals is formed from power facilities located in the territories of the Sverdlovsk, Chelyabinsk, Perm, Orenburg, Tyumen, Kirov, Kurgan regions, the Udmurt and Bashkir republics. They are united by more than 106 thousand kilometers of power transmission lines (a quarter of the total length of the overhead lines of the UES of Russia) with a voltage of 500-110 kilovolts, located on an area of ​​almost 2.4 million square kilometers. There are 106 power plants operating in the UES of the Urals, the total installed capacity of which is over 42 thousand MW or 21.4% of the total installed capacity of power plants of the UES of Russia. The IES is located in the center of the country, at the junction of the IES of Siberia, the Center of the Middle Volga and Kazakhstan.

Distinctive features of the UES of the Urals are:

  • a complex multi-ring network of 500 kV, in which two to eight 500 kV overhead lines are disconnected daily for scheduled or emergency repairs, as well as a voltage reserve;
  • significant daily fluctuations in the value of electricity consumption with an evening decline (speed up to 1200 MWh) and morning growth (speed up to 1400 MWh), caused by a high share of industry in the consumption of the Urals;
  • a large share of highly maneuverable block equipment of TPPs (58% of the installed capacity), which makes it possible to daily change the total load of power plants of the UES of the Urals in the range from 5000 to 7000 MW and switch off two to ten power units with a total capacity of 500 to 2000 MW. This makes it possible to regulate intersystem flows from the IES of the Center, the Middle Volga, Siberia and Kazakhstan and to ensure reliable power supply to consumers in the Urals.

IES South

Power facilities located on the territory of Krasnodar, Stavropol Territories, Volgograd, Astrakhan, Rostov Regions, Chechen, Ingush, Dagestan, Kabardino-Balkarian, Kalmyk, North Ossetian and Karachay-Cherkess Republics operate within the IES of the South. The UES ensures the parallel operation of the UES of Russia with the energy systems of Ukraine, Azerbaijan and Georgia.

Distinctive features of IES South are:

    a historically established scheme of an electrical network based on 330-500 kV overhead lines, stretching from the north-west to the south-east along the Caucasian ridge in areas with intense ice formation, especially in the foothills;

    uneven runoff of the rivers of the North Caucasus (Don, Kuban, Terek, Sulak), which has a significant impact on the balance of electricity, leading to a shortage of electricity in winter, with a corresponding load of the electrical network in the west-east direction, and a surplus in summer, with the load in the opposite direction;

    the largest (in comparison with other ECOs) share of the household load in the structure of electricity consumption, which leads to sharp jumps in electricity consumption with temperature changes.

UES of Siberia

UES of Siberia is the most territorially extended association in the UES of Russia, covering the territory from the Omsk region in Western Siberia to the Chita region in Eastern Siberia. Power facilities located in the Altai, Krasnoyarsk Territories, Omsk, Tomsk, Novosibirsk, Kemerovo, Irkutsk, Chita Regions, the Republics of Khakassia, Buryatia and Tyva operate within the UPS. Taimyrenergo works in isolation. The IES combines about 87 thousand kilometers of overhead lines with a voltage of 1150-110 kilovolts and more than 46 GW of generating capacities of power plants, more than 50% of which are the capacities of hydroelectric power plants.

UES of Siberia was formed from scratch in a short historical period. Simultaneously with the construction of powerful and efficient cascades of hydroelectric power plants and the construction of large hydroelectric power plants on the basis of cheap open-pit brown coal, large territorial industrial complexes were created (Bratsk, Ust-Ilimsk, Sayan, Kansk-Achinsk fuel and energy complex - KATEK). The next step was the construction of high-voltage power lines, the creation of regional energy systems through the interconnection of powerful power plants by electric grids, and then the formation of the IES of Siberia.

Distinctive features of the UPS of Siberia are:

    a unique structure of generating capacity, more than 50% of which are hydroelectric power plants with reservoirs of long-term regulation and reserves of about 30 billion kWh for a period of prolonged low water. At the same time, hydroelectric power plants in Siberia produce almost 10% of the total electricity generation by all power plants of the UES of Russia;

    significant natural fluctuations in the annual flow of the rivers of the Angara-Yenisei basin, the energy potential of which ranges from 70 to 120 billion kWh, with poor predictability of the water content of the rivers, even in the short term;

    the use of the peak capacity of the hydroelectric power station in Siberia in regulating the load of the European part of the UPS and the regulation of the annual irregularity of the energy output of the hydroelectric power station along the watercourse by the reserves of the TPPs of the Urals and the Center. For this purpose, the construction of 500 kV and 1150 kV overhead lines was carried out for the transit of Siberia - Kazakhstan - Ural - Srednaya VolgaCenter with the planned power reverse up to 3–6 million kW.

IES of the Far East

In the Far East and the Far North, there are power facilities located in the Primorsky, Khabarovsk Territories, the Amur, Kamchatka, Magadan, Sakhalin Regions and the Republic of Sakha (Yakutia). Of these, power facilities located on

The territories of the Amur Region, the Khabarovsk and Primorsky Territories and the South Yakutsk Power District of the Republic of Sakha (Yakutia) are united by 500 and 220 kV intersystem power lines, have a single mode of operation and form the IES of the East.

The IES of the East operates in isolation from the UES of Russia, and its distinctive features are:

    prevalence in the structure of generating capacities of thermal power plants (more than 70% of the installed capacity) with a limited range of regulation;

    limited possibilities of using the regulation ranges of the Zeya and Bureyskaya HPPs due to the need to ensure navigation on the Zeya and Amur rivers;

    placement of the main generating sources in the north-western part, and the main consumption areas - in the south-east of the UPS;

    one of the highest in the UES of Russia (almost 21%) the share of utilities load in electricity consumption;

    extended power lines.

Links between the UES of Russia and the energy systems of foreign countries

At the end of 2005, the power systems of Belarus, Estonia, Latvia, Lithuania, Georgia, Azerbaijan, Kazakhstan, Ukraine, Moldova and Mongolia were operating in parallel with the UES of Russia. The energy systems of Central Asia - Uzbekistan, Kyrgyzstan and Tajikistan - operated through the energy system of Kazakhstan in parallel with the UES of Russia.

The structure of internal and external relations of the UES of Russia is shown in Fig. 2.2.

Parallel operation of the UES of Russia with the power systems of neighboring countries provides real advantages associated with the combination of schedules of electrical load and capacity reserves, and allows for mutual exchange (export / import) of electricity between these power systems (see Section 3.4).

In addition, the energy system of Finland, which is part of the union of the energy systems of Scandinavia, operated together with the UES of Russia through the devices of the Vyborg conversion complex. Electricity networks of Russia were also used to supply power to the designated regions of Norway and China.

2.2. Operational dispatch management in the UES of Russia

JSC SO-CDU UES is the supreme body of the operational dispatching

The management of such a large synchronously operating association, such as the UES of Russia, is an extremely complex engineering task that has no analogues in the world.

To solve it, Russia has created a multilevel hierarchical system of operational dispatch control (see Section 1.1), including: System operator - Central Dispatch Office (hereinafter also SO-CDU UES); seven territorial integrated dispatching offices (ODE or SO-ODE) - in each of the seven OES; regional dispatch offices (RDU or SO-RDU); control points of power plants and electric grid enterprises; operational field brigades.

Tasks and functions of JSC SO-CDU UES

JSC SO-CDU UES carries out centralized operational and technological management of the Unified Energy System of Russia.

The main tasks of JSC SO-CDU UES are:

  • ensuring system reliability in the context of developing competitive relations in the electric power industry;
  • ensuring compliance with the established technological parameters for the functioning of the electric power industry and standard indicators of the quality of electrical energy;
  • creation of conditions for the efficient functioning of the electricity (capacity) market and ensuring the fulfillment of obligations by the subjects of the electric power industry under contracts concluded in the wholesale electricity market and retail markets. JSC SO-CDU UES performs the following functions within the UES of Russia:
  • forecasting and balancing the production and consumption of electricity;
  • planning and taking measures to ensure the required power reserve for loading and unloading power plants;
  • operational control of current modes, carried out by dispatching personnel;
  • use of automatic control of normal and emergency modes;
  • implementation of safe operation, prevention of development and elimination of emergencies in power systems and the UES of Russia as a whole.

Strategic objectives for optimizing the operating modes of the UES of Russia

In addition, the dispatch management bodies with the participation of other infrastructure organizations of the electric power industry are solving strategic tasks to optimize the operating modes of the UES of Russia in the medium and long term, including:

    forecasting power and electricity consumption and developing power and electricity balances;

    determination of the capacity of the sections of the electrical network of the UES;

    optimization of the use of energy resources and overhaul of generating equipment;

    ensuring the implementation of calculations of electrical modes, static and dynamic stability;

    centralized control of technological modes of operation of relay protection devices and systems, automation and emergency control automation of intersystem and main backbone power transmission lines, buses, transformers and autotransformers of communication of the main voltage classes (performing calculations of short-circuit currents, choosing parameters for setting up relay protection and automation devices (RPA) and emergency automation (PA));

    distribution of functions of operational dispatch control of equipment and power lines, preparation of operational and technical documentation;

    development of schemes and modes for characteristic periods of the year (autumn-winter maximum, flood period, etc.), as well as in connection with the commissioning of new facilities and the expansion of the composition of parallel operating power systems;

    coordination of repair schedules for the main equipment of power plants, power lines, substation equipment, relay protection and safety devices;

    solving the whole range of issues of ensuring the reliability of power supply and quality of electricity, introducing and improving the means of dispatch control and automatic control systems.

Automated dispatch control system

To solve the problems of planning, operational and automatic control, a developed computer automated dispatch control system (ASDU) is used, which is a hierarchical network of dispatch centers for data processing SO-CDU, SO-ODU and SO-RDU, interconnected with each other and with power facilities (power plants, substations) telemechanics and communication channels. Each dispatch center is equipped with a powerful computer system that provides real-time automatic collection, processing and display of operational information about the parameters of the UES of Russia operation mode, the state of the electrical network and the main power equipment, which allows dispatch personnel of the appropriate management level to carry out operational control and management of the UES of Russia operation, and also solving problems of planning and analysis of modes, monitoring the participation of power plants in the primary and secondary regulation of the frequency of electric current.

The emergency automation system is the most important means of maintaining the reliability and survivability of the UES of Russia

The most important means of maintaining the reliability and survivability of the UES of Russia is a multi-level system of emergency control automation, which has no analogues in foreign electrical interconnections. This system prevents and localizes the development of system accidents by:

  • automatic prevention of stability violations;
  • automatic elimination of asynchronous mode;
  • automatic limitation of frequency reduction and increase;
  • automatic limitation of voltage decrease and increase;
  • automatic unloading equipment.

Devices for emergency and regime automation are located at power facilities (local complexes) and at dispatch centers of JSC SO-CDU UES (centralized emergency control systems that ensure coordination of the work of local complexes).


Steps to further optimize the system of operational dispatch control in the UES of Russia in the context of the reform of the electric power industry in Russia

In the context of the reform and reorganization of AOenergo, the most important task of SO-CDU UES is to maintain the functions of operational dispatch control, which requires the establishment of new technological relationships with newly formed companies in the industry.

For this purpose, in 2005, an Agreement was concluded between the System Operator and JSC FGC UES (Federal Grid Company, see section 1) on the temporary preservation of the existing scheme of operational dispatch control of the Unified National Electric Grid (UNEG) facilities and the procedure for organizing safe performance of work when separating from the regional power grid companies and transferring UNEG facilities for repair and maintenance services by FGC.

Also in 2005, in the course of the ongoing work on the redistribution of the dispatching functions of the networks of the UES of Russia, together with JSC FGC UES, the main criteria for assigning 110 kV overhead lines and higher to dispatch facilities were developed and agreed upon.

A program of organizational and technical measures has been prepared and is being implemented for admission to dispatch control or dispatch management of the dispatcher of the RDU VL 220 kV, equipment, PA devices, relay protection and automation systems and dispatch and technological control systems (SDTU) of networks related to the UNEG. In 2005, the System Operator took over 70 220 kV overhead lines for dispatch control.

As part of the optimization of the operational dispatch management system, the Target organizational and functional model of the operational dispatch management of the UES of Russia was developed and put into effect. In accordance with this model, a pilot project for the enlargement of the operating zone of the branch of JSC SO-CDU UES - Smolensk Regional Dispatching Office

technical and technical measures to transfer the functions of operational dispatch control of dispatch facilities in the territory of the Bryansk and Kaluga regions to the Smolensk Regional Dispatch Office, a branch of OAO SO - CDU UES.

In 2005, work was carried out to optimize the scheme for transmitting dispatch commands to power facilities during the production of operational switching. Intermediate links are excluded from the dispatching command scheme, which is a factor in increasing the reliability of control over the UPS modes. As of December 31, 2005, out of 1,514 overhead lines of 220 kV and higher located in the dispatch control of the dispatch centers of OJSC SO-CDU UES, a direct command transmission scheme “dispatcher - power facility” was implemented to control 756 lines (49.9% of their total number).

2.3. Main performance indicators of the UES of Russia in 2005

Maximum load of power plants and maximum power consumption in the UES of Russia and the Russian Federation

The annual maximum load of power plants of the UES of Russia was recorded at 18-00 on 27.12.2005 and amounted to 137.4 thousand MW at an electric current frequency of 50.002 Hz. The annual maximum load of power plants in the Russian Federation reached 143.5 thousand MW.


The participation of generating capacities of various types in covering the load schedule during the period of maximum loads is shown in Fig. 2.3 for December days 2004 and 2005

The maximum power consumption in the Russian Federation in 2005 amounted to 141.6 million kW (an increase of 1.4% against 2004), in the UES of Russia - 134.7 million kW (+ 1.7%), in the UPS of the Center - 36.2 million kW (+ 0.7%), for the IES of the Middle Volga - 12.9 million kW (+ 0.7%), for the IES of the Urals - 33.4 million kW (+ 3.1% ), for the IES of the North-West - 13.3 million kW (+ 1.2%), for the IES of the South - 11.9 million kW (-0.6%), for the IES of Siberia - 29.5 million kW (+ 0.7%), in the IES East - 4.8 million kW (-0.3%).

Indicators of the actual frequency of electric current in the UES of Russia

The Unified Energy System of Russia in 2005 operated 100% of the calendar time at the standard frequency of the electric current determined by GOST (see Fig. 2.4). In addition, in 2005, 100% of the time, the frequency of electric current in the power grid of the UES of Russia, the CIS and the Baltic states was maintained within the limits established by the order of RAO UES of Russia, dated September 18, 2002, No. 524 “On improving the quality of regulation of the frequency of electric current in the UES Russia ”and the Standard of RAO“ UES of Russia ”OJSC“ Rules for the Prevention of Development and Elimination of Violations of the Normal Operation of the Electrical Part of Power Systems ”.

Tightening of the conditions for regulating the variable part of daily load schedules in the European part of the UES of Russia - a trend in recent years

During 2005, the trend of recent years continued

Deconsolidation of daily load schedules for consumers in the European part of Russia. This is especially typical for the daily power consumption schedules of the UPS of the Center, the Middle Volga and the North-West. The conditions for covering the daily load schedules of the listed IES and the European part of the UES of Russia largely depend on the structure of generating capacities. At the same time, the overall load regulation range of UES power plants is decreasing due to the continuing decline in the share of IES with cross-links in recent years due to aging and dismantling of this type of equipment, an increase in the installed capacity of nuclear power plants, as well as a relatively small share of hydroelectric power plants and the presence of only one pumped storage power plant. in the structure of generating capacities of the UPS of the European part of the UES of Russia. In almost all ECOs, this has led to an increase in the conditions for regulating the variable part of the daily load schedules, especially on weekends and holidays. Regulation of daily schedules is ensured due to deeper night unloading of TPP power units, as well as stopping them in reserve on weekends and holidays. On some days in 2005, due to the insufficient regulation range, it became necessary to partially unload the NPP power units up to their withdrawal to the reserve.

The great potential of the hydroelectric power station of the UES of Siberia in regulating the variable part of the load schedule of the UES of Russia still cannot be used due to the considerable distances and weak electrical connections with adjacent UES.

The stability of the UES of Russia and the main major technological violations

In 2005, the Unified Energy System worked steadily.

The system reliability of the UES of Russia was ensured, despite the presence of technological disruptions in the operation of enterprises in the industry and power systems.

Among the most significant violations are the following:

1) 05/25/2005, as a result of the combination of a number of factors, an accident occurred, the development of which led to the disconnection of a large number of consumers in Moscow, Moscow, Tula, Kaluga regions and disconnection of a number of consumers in Ryazan, Smolensk and Oryol regions with a total load of 3500 MW;

2) July 27, 2005, under the conditions of a repair scheme as a result of shutdown of two 110 kV overhead lines and subsequent shutdown due to a power surge and disturbance of stability by the ALAR action of two 220 kV overhead lines, the Permsko-Zakamsky power center was allocated for isolated operation with a power deficit, a short-term decrease in frequency to 46.5 Hz and power outage of consumers by AChR with a total load of 400 MW;

3) 08/07/2005, under the conditions of the repair scheme in the 220 kV network of the Kuban energy system, the 220 kV and 110 kV overhead lines were disconnected. The double-circuit overhead line 220 kV was disconnected by the action of PA and the remaining 110 kV transit lines along the Black Sea coast by overload protection. At the same time, the Sochi power district with a load of 280 MW was de-energized;

4) In the period from September 16 to September 17, 2005 in the western regions of the Chita region due to unfavorable weather conditions with a sharp drop in the outside air temperature, an increase in wind up to 30 m / s, heavy precipitation in the form of rain and sleet with sticking and Ice formation on the wires and structures of the overhead line supports caused numerous wire breaks with damage to the supports. As a result, four 220 kV overhead lines were disconnected, which led to the allocation of the Chita power system for asynchronous operation and the repayment of three 220 kV substations with blackout of settlements, traction transit substations and a failure in the movement of trains of the Trans-Baikal Railway;

5) From 18 to 20 November 2005, under unfavorable weather conditions (strong wind, wet snow), JSC Lenenergo experienced massive shutdowns of 6-220 kV overhead lines. As a result, the power supply to 218 settlements was disrupted, including the regional centers Mga (with a population of 9 thousand people), Vsevolozhsk (with a population of 43 thousand people), Kirovsk (with a population of 50 thousand people), Nikolskoye ( with a population of 17 thousand people), Shlisselburg (with a population of 10 thousand people) with a load of 140 MW.

2.4. Main problems and imbalances in the functioning of the UES of Russia

The main problems of the UES of Russia

The presence in the European part of the UES of a large share of TPPs and NPPs with low maneuverability, the concentration of mobile TPPs and hydroelectric power plants in the UES of the Urals, the Middle Volga and Siberia causes a significant range of changes in power flows on the links Center - Middle Volga - Ural when covering consumption schedules. Increasing the transit capacity of the Center - Middle Volga - Ural transit through the construction of a number of lines of the 500 kV backbone network will reduce the restrictions on power transmission along the main controlled sections, increase the reliability of the parallel operation of the European and Ural parts of the UES of Russia.

The task of increasing the reliability of the Saratov-Balakovsky power center and strengthening the power distribution scheme of the Balakovo NPP by increasing the transit of the IES of the Middle Volga - IES of the South is urgent.

The construction of new transit lines Ural - Middle Volga will improve the reliability of power supply to the South Urals and the power output of the Balakovo NPP. It is also necessary to strengthen transit in the North-West region of the UES of Russia and its connection with the IES Center at a voltage of 750 kV. Network solutions will increase the throughput of the North-West - Center section and eliminate the locked capacity in the Kola power system.

The main problems of the regions

Territory of Moscow and Moscow region

The growth of power consumption in the region, the maximum loads in the 110 kV distribution network, the limitation of the transmission of power from the 500 kV network to the lower voltage network due to the lack of autotransformer connections necessitate the strengthening of the 220-110 kV network, the construction of new and reconstruction of existing substations with their increase. transformer capacity, as well as the commissioning of additional maneuverable capacities.

Territory of the Nizhny Novgorod region

Strengthening the 220 kV network of the Nizhny Novgorod power system, construction of flexible capacities will increase the reliability of power supply to consumers in case of emergency outages in the 500 kV network.

Territory of Kaluga and Bryansk regions

Kaluga and Bryansk power systems are in short supply. The commissioning of a new generating capacity linked to a 220 kV network will ensure reliable power supply to consumers.

Territory of the Saratov region

Limited power output of power unit No. 1 of Balakovo NPP in repair schemes. Strengthening the 500-220 kV network of the Balakovsko-Saratov junction will increase the throughput of links between the Saratov energy system and the UES of the Middle Volga by 500-600 MW.

Territory of St. Petersburg and the Leningrad region

Improving the reliability of power supply to the north of the Leningrad Region, St. Petersburg and the supply of electricity to Finland in connection with the high load of 220-330 kV in-system networks is urgent. There are also restrictions on the power output of the Leningrad NPP in the repair schemes. Reconstruction of existing and construction of new power grid facilities is required.

IES South

To ensure reliable power delivery of the second power unit of the Volgodonsk NPP, it is necessary to increase the transmission capacity of the Rostov and Stavropol power systems through the construction of new lines of the backbone network. The active growth of consumption in the Kuban power system, the transfer of power to the deficit Astrakhan power system cause the emergence of restrictions in the intrasystem networks, which can be eliminated by the commissioning of generating capacities in the power systems.

It is required to improve the reliability of the operation of the interstate transit of the IES of the South - the Azerbaijan energy system, power supply to consumers of the Dagestan energy system and the Chechen Republic.

URES of the Urals

It is necessary to increase the capacity of links with the UES of Russia of the Bereznikovsko-Solikamsk and Permsko-Zakamsky energy regions of the Perm energy system, the Western and Northern energy regions of the Orenburg energy system, the Northern, Noyabrsky, Kogalymsky, Neftyugansk, Nizhnevartovsk energy regions of the Tyumen energy system, Kropachevo

Zlatoust region of the Chelyabinsk power system, Serovo - Bogoslovsky region of the Sverdlovsk power system, Kirov power system.

High growth rates of consumption (development of metallurgical and aluminum production, development of the Subpolar Urals) necessitate an increase in the network capacity and commissioning of new capacities.

To eliminate deficiencies in certain regions and to form a promising capacity reserve, it is necessary to commission generating capacity at a number of sites in the Tyumen, Sverdlovsk, Chelyabinsk energy systems. Electric grid construction, installation of reactive power compensation means is required.

UES of Siberia

The active development of consumption in the presence of network restrictions characterizes the operating mode of the Tomsk power system and the southern region of the Kuzbass power system. In these areas, it is necessary to commission generating capacities and power grid construction.

ECO East

The power output of the Zeyskaya HPP has been limited and the reliability of power supply to consumers of the Trans-Siberian Railway in the Amur power system has been reduced. Insufficient reliability of power supply to consumers in Vladivostok and Nakhodka in Dalenergo. The presence of restrictions on the transmission of power on the connections of the Khabarovsk power system and Dalenergo, the power delivery of the Khabarovsk CHPP-3 leads to a decrease in the reliability of power supply in the city of Khabarovsk. There is a problem of ensuring reliable power supply to consumers of the Sovgavan energy center. It is necessary to carry out the construction of a number of lines of the backbone network, to carry out the reconstruction of existing and construction of new substations.

1 Under normal conditions, the dividing point is at Amurenergo, and if there is a power shortage at Chitaenergo, the dividing point is transferred to Chitaenergo.

2 26% of the total installed capacity in the UES of the Middle Volga and about 15% of the total installed capacity of hydroelectric power plants of the UES of Russia.

3 Northern Synchronous Zone (NORDEL) - energy interconnection of the Nordic countries (Sweden, Norway, Denmark, Finland and Iceland). The western (continental) part of the Danish power system operates in parallel with the Western synchronous zone UCTE, and the eastern part with NORDEL, while the Icelandic power system operates autonomously.

4 By Order of RAO UES of Russia dated 30.01.2006 No. 68 “On approval of the target organizational and functional model of the operational dispatch management of the UES of Russia”.

5 Measures to optimize the functions of operational dispatch control in the operational area of ​​the Center's ODU are carried out on the basis of the Order of JSC SO-CDU UES dated 26.12.2005 No. 258/1.

6 Indicated for power systems operating in parallel in the interconnected power system.

7 Power plants in which all boilers operate on a common live steam collector, from which all steam turbines are fed.

8 ALAR - automation of asynchronous mode elimination.

9 AChR - frequency unloading automation.

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