Old Lippendorf power station
| Old Lippendorf power station | |||
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| location | |||
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| Coordinates | 51 ° 10 '36 " N , 12 ° 22' 29" E | ||
| country | Germany | ||
| Data | |||
| Type | Steam power plant | ||
| Primary energy | Fossil energy | ||
| fuel | Lignite , heavy fuel oil , natural gas | ||
| power | 600 megawatts electrical 550 megawatts thermal |
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| operator | VEB Elbe Vockerode / VEB Kombinat lignite power plants (until 1990) Vereinigte Kraftwerke - Aktiengesellschaft (VK-AG Peitz) (1990) |
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| Project start | 1963 | ||
| Start of operations | 1968 | ||
| Shutdown | 2000 | ||
| turbine | 4 condensation turbines 2 extraction counter pressure turbines 2 extraction condensation turbines |
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| Chimney height | 300 m | ||
The old Lippendorf power plant was a lignite -fired steam power plant on the north-western edge of the town of Lippendorf in the Neukieritzsch municipality in the Leipzig district . It was replaced in 2000 by the new Lippendorf power plant .
History of the power plant location
The large open cast mine in Böhlen was opened up in 1921. The overburden from the outcrop was dumped above the Lippendorf location, creating the high heap. From 1923 to 1926, the joint stock company Sächsische Werke (ASW) acquired the land in the Medewitzsch district . Construction of the Böhlen industrial power station began in 1926 , and the Aschespülkippe dam broke on June 24, 1927 . Lippendorf was partially destroyed and had to be evacuated. In the war years of 1944 and 1945, the surrounding areas were affected during the bombing of the Böhlener Werke.
From 1964 Spahnsdorf and parts of Lippendorf had to give way to the old power station. The old Lippendorf power plant was operated from 1968 to 2000, and from 1997 the old power plant was gradually dismantled. Two years earlier, in 1995, the construction phase began with the laying of the foundation stone for the new Lippendorf power plant . The new power plant has been in permanent operation since 2000, and in 2006 there was a festive event with the theme "80 years of the Böhlen / Lippendorf power plant".
planning phase
On November 12, 1963, the lay of National Economy and the State Planning Commission of the GDR laid out instead of the location for the power plant Rohrbach in the area south of the Kombinat Böhlen a combined condensation and industrial power plant with an installation capacity of 600 MW to build.
The old power station consisted of a condensation power station with 4 × 100 MW electrical output (hereinafter referred to as Kond ) and an industrial power station with 4 × 50 MW electrical and 550 MW thermal output (hereinafter referred to as IKW ).
On July 27, 1964, it was decided to carry out the project with the aim of putting the first unit into operation by March 1, 1968. The general project planner for the building project was Energieprojektierung Berlin . VVB Brown Coal developed the technical project for the condensation power plant , while VVB Mineralöle planned the industrial power plant.
At the end of 1967 it was decided to build only two extraction counter pressure turbines and an additional 2 extraction condensation turbines in the IKW instead of the four originally planned. All 4 turbines should have a nominal output of 50 MW.
Construction work
In 1964 the production facilities of the Böhlen Combine were relocated and parts of the Lippendorf and Spahnsdorf towns were demolished. On September 1, the construction site was set up by VE BMK Süd Leipzig . In November, the topsoil began to be removed. In 1965 the site was cleared as well as the relocation of production facilities in the area of the locations for the later coal bunker with belt systems, the boiler house with flue gas systems and the main pump house. Since the chimney was to be erected on the site of a sewage pond, four holes had to be drilled in the foundation area up to 120 meters deep to ensure stability. These boreholes were sunk from pontoons in the clarification pond and the empty cavities were filled with concrete. The 110 kV cable route for the electric melting furnaces of the VEB ferro-alloy plant was also relocated. At the beginning of 1965, 600 apartments were built in Neukieritzsch and west of Lippendorf to accommodate the construction and assembly workers. In October 1967 the kitchen and the administration building went into operation.
In March 1966 the gravel bed for the hall construction was put in and foundation work for the 6-storey administration building was carried out. The earthworks on cooling tower 1 began. In the former sewage pond, the earth was excavated and the sub-concrete for the chimney foundation and the excavation for the power plant blocks were excavated.
On April 18, 1966, the foundation stone was laid in the foundation of cooling tower 1. In September, the shell for the future administration building with the changing rooms and the kitchen wing was completed. The foundation work for the chimney was completed in December. In January 1967 the sub-concrete for the power plant blocks was put in, in September the assembly started for the steam generator 1. On December 15, 1967 the cooling tower 1 was shell-finished. In January 1968, the shell construction of the chemical water treatment finally followed and in May the start of assembly on turbine set 1.
Installation
On December 8, 1968, the Technical Acceptance Commission gave the approval for the trial operation of Unit 1. After the steam generator 1 was ignited for the first time on December 15 and the operating parameters were approached, irregularities in the measuring equipment and faults in the generator occurred, whereupon the release declaration was withdrawn. On December 30th, the clearance was renewed, so that on January 1st, 1969 generator 1 ran dry for the first time. On January 4, 1969, Unit 1 went online and the first trial operation took place, which went into continuous operation on July 1. On April 29 of the same year, Unit 2 went into trial operation before it was switched to continuous operation on September 19. The trial operation of Unit 3 took place on July 30th. This also ended on November 1, 1969 with the transition to continuous operation.
The trial operation of Unit 4 began on January 17, 1970. This was followed by continuous operation on April 3, 1970. On June 23, 1970, steam generator 5 was tested before turbo set 5 was also tested for the first time three days later. Both went into continuous operation on October 14, 1970. Turboset 6 was put into operation for the first time on September 25, 1970 and steam generator 6 on November 4, both went into continuous operation on December 10.
On July 30, 1971, steam generator 7 went into operation and on December 21 of the same year it was put into continuous operation together with turbo set 7, which began its trial period on September 17, 1972. The trial run of turbo set 8 began on February 17, 1972 finally connected to continuous operation on April 22, 1972.
Productive phase
Operations
Extensive stabilization measures were required as early as the commissioning phase, the trial operation of the systems and faults that occurred in the first phase of continuous operation.
A major fire in the coaling plant on December 9, 1969 caused a delay of five days due to its effect on the trial and continuous operation phase at the 100 MW units.
Irregularities in the temperature mode of the chimney resulted in the demolition of the smoke pipe in the upper area. The fire pipe made of fireclay brickwork , which was routed in a ring shape in the static reinforced concrete column in sliding shoes every 50 m, had obviously jammed due to excessive temperature differences during the start-up and shutdown processes, which ultimately led to its demolition.
To remedy this damage, a power plant shutdown was ordered and carried out between June 16 and July 13, 1973. During shutdown and subsequent restart, the temperature gradients on the flue pipe of the chimney were monitored specifically in order to avoid further damage.
The uncontrollable disposal of the electrostatic precipitator ash led in 1973 to a fundamental conversion of the hydropneumatic ash removal system (imported from Hungary) in the area of the Kond power plant and thus to the closure of the HP station north.
The now common hydraulic flushing of the furnace and electrostatic precipitator ashes did not work properly either. Leakages in the ash lines could be suppressed by mechanical grinding, but there were incrustations in the lines, caused by the high lime content of the ash. These incrustations restricted the transport considerably, so that the operation could only be maintained through constant cleaning work using high pressure technology or pigging .
The IKW's electrostatic precipitator pockets were flushed separately via the HP station south until the renovation work was carried out in the 1990s. Due to the good cementing properties of these ashes, they were used over a long period of time to move old charred routes in mining and, due to the high proportion of lime, in the area of recultivation. A loading station has been set up in the HP station south for loading onto trucks.
The raw lignite of the most varied of quality used resulted in enormous slagging phenomena in connection with air infiltration at the steam generators. Slag falls during operation and the associated slag accumulations in the funnel slopes required an enormous amount of work. In some cases slag accumulated up to +10 m in the furnace, which made the use of blasting technology necessary (although the use of blasting technology is still common today in modern power plants).
The slag deposits on the pipe system were removed by spraying them off with water. Initially this had to be done manually, but later controllable automatic lances took over the cleaning process. The associated water entry, partly behind the evaporator heating surfaces, led to signs of corrosion on the seals and joints of the sections, which in turn caused damage to the pressure hulls. About 40% of all malfunctions in the steam generators originated here.
The degrees of separation of the electrostatic precipitators were not satisfactory in the first years of operation. The induced drafts often ran as pure "ash pumps". The wear and tear on the induced draft rotor was correspondingly high. By constantly optimizing the electrostatic precipitator, however, the degree of separation has been improved over the years.
Another problem turned out to be the cold end of turbo sets 1 to 4 in the Kond power plant from the start. The contamination of the condensers on the cooling water side due to the entry of deposits from the pipe system was very high and prevented the ABEKA systems from functioning properly.
All of this meant that a great deal of manual effort had to be made to clean the condensers and the spray systems on the cooling tower. Manual cleaning of the capacitors by shooting through rubber stoppers ("capacitor shooting") was associated with a high level of physical and health stress on the cleaning staff.
It was only with the introduction of thermal cleaning of the capacitors that there was a significant improvement in capacitor grading and thus in efficiency.
In the mid-1970s, an initiative for the heat-efficient operation of the main systems (steam generator and turbine), the so-called "calorie hunter movement", made a name for itself. The content of this initiative was the operation of the main systems with the most favorable parameters in terms of energy efficiency. The way the systems were operated was accounted for via process computers and did indeed lead to an improvement in the specific fuel heat consumption.
In the planning and project planning phase of the power plant, process computing technology was provided as an integral part of the BMSR technology in accordance with international standards .
- Block 1 to 4 each have a PR 2100 process computer
- Steam generator 5 to 7 each have a PR 2100 process computer.
- Ancillary systems a process computer of the type PR 2100.
The technology used by the general contractor did not initially achieve the projected reliability values. Therefore, between 1970 and 1972, the central unit was replaced with improved technology. In addition, the entire computing technology was centralized in the machine house. This process computer application ran successfully until the mid-1980s and had the following tasks:
- Thermal accounting for blocks 1 to 4 and steam generators 5 to 7 as well as the ancillary systems according to the standard method
- Billing of electrical energy generation daily and cumulatively with plan-actual comparison
- Planning, emissions calculation, test evaluations
The process computer system PR 4000-V 4010 replaced the outdated technology in the mid-1980s. In addition, a computer-controlled black and white data display system with real-time data for the components was set up:
- Complete overview of the power plant
- Coaling (conveyor belts / trench scoops)
- Ancillary systems (water / steam systems)
- Parameters of blocks 1 to 4
- Sales measurements
- Boiler feed water balance
From 1984 onwards the conception, project planning and implementation of a color data system that was directly suitable for process management was started. The prerequisite was the use of fiber optic cables for the required high transmission speed and interference immunity. The control centers of units 1 to 4, the steam generators 5 to 7 and the shift supervisor were equipped with the appropriate technology. In addition, a computer-aided gradient measuring device was set up (recording of the time-dependent temperature change of a thick-walled component → the drum , display in K / min → a measure of its thermal stress). The entire process computer technology has been upgraded over the years and ran successfully until it was decommissioned.
In order to replace heating oil (heavy oil), systems for the use of coal dust as ignition and support lights were installed on steam generators 2, 3, 4 and 5 in the mid-1980s. The supply of coal dust was carried out via the existing mill systems in specially constructed coal dust bunkers. However, the systems did not prove themselves in practical use, the systems continuously clogged due to the moisture still present in the coal dust.
The use of imported natural gas (IEG) as the main combustion on steam generators 6 and 7 was positive in the years 1973 to 1978. The possibility of combustion with raw lignite was never given up. The gradual changeover of a mode of operation from natural gas to raw lignite and vice versa, as well as the mixed mode of operation, was possible at any time without any reduction in performance.
The construction of a plant for the production of screened coal in the area of the crusher tower of the coaling plant in the mid-1980s had not proven itself. The use of this system was possible to a relatively limited extent due to the coaling method and was more of a "stone holding" than a production facility for screened coal.
In October 1970, with the continuous operation of the steam generator 5 and the turbo set 5, the process steam supply of the former combine "Otto Grotewohl" Böhlen began . After commissioning of all systems of the IKW and the evaporator system, process steam was in the pressure stages
- 38 bar via a pipe DN 300 and DN 400
- 4.8 bar via four DN 800 pipes
delivered to the steam distributor in the petrolchemical combine Böhlen (hereinafter referred to as PCK). The 38 bar process steam via the DN 400 pipeline was delivered directly to the “Olefine” in PCK Böhlen. This was primarily used to cool the ethylene plants in the PCK.
The 38 bar process steam supply, the internal consumption of the turbo feed pumps and HDV 2 in the IKW were covered by withdrawals from the back pressure turbines (200 t / h each). In addition, the 150 t / h station secured the network requirements with 38 bar steam in the event of a fault.
The 4.8 bar process steam supply, internal consumption such as cushion steam for all feed water tanks and heating steam for the evaporator system were covered by counter pressure from the extraction counterpressure machines, exhaust steam from the turbo feed pumps, vapor from the evaporator system or via taps from the extraction condensation turbines, depending on the heat demand of the steam network .
The return of condensate from steam consumers was only 60% and led to acute boiler feedwater bottlenecks, especially in the winter months. Peak values of process steam deliveries:
- Pressure level 38 bar: 150 t / h
- Pressure rating 4.8 bar: 350 t / h
- Heat supply: 380 MW th
The 100% supply of the 38 bar process steam network over all periods was essential and resulted in extensive stabilization measures. Another 150 t / h station and a cold reserve 4 were installed. By using the tap 1 of the extraction condensation turbines, the live steam busbar in the cond / IKW, the availability was increased even further.
In addition, the Neukieritzsch community (complete new building area, kindergarten and community administration), the Kieritzsch nursery and the Lippendorf residential camp were supplied with 4.8 bar process steam, with a converter station (U3) in the Lippendorf ferro-alloy plant. In the converter station U3, heating water was heated up to 130 ° C by means of 4.8 bar process steam (summer pipe DN 150 / winter pipe DN 400). The district heating supply for the cities of Groitzsch and Pegau was also in the planning stage . Due to a lack of investment funds, this project never got beyond the planning phase.
With the breakdown of the carbochemistry in the former combine "Otto Grotewohl" Böhlen and the start of self-supply through the "olefin complex", there was a drastic reduction in process steam consumption. The existing free heat capacities were the basis for the planning of a district heating line to the city of Leipzig carried out by the former VEAG . After completing complicated negotiations with Stadtwerke Leipzig, the joint declaration by the board members of VEAG and Stadtwerke on November 12, 1993 on the district heating supply of the city of Leipzig formed the basis for the planning, approval and construction of the district heating supply system until winter 1996/97. To supply the city of Leipzig with base load, a heat output of 207 MW was extracted from the IKW via heating steam, converted into hot water, transported in a district heating line to the Leipzig-Süd heating power station and fed into the network.
The maintenance tasks included not only the maintenance / repair of the main and ancillary systems, but also building repairs, spare and wear parts production to the production of rationalization equipment and consumer goods production , i.e. everything that was necessary in such a large company: painters, glaziers , Carpentry work, etc. All measures had to be carried out with your own resources. In times of chronic shortages, this required a high level of improvisation skills. In the context of the consumer goods production were for the "working population" of the GDR
- Garden swings
- Terrazzo tiles
- Exhaust systems for the Moskvich car
- Rechauds (kitchen utensils for keeping food warm)
- Cloakroom walls
manufactured.
Stabilization measures on the main groups of steam generators
- 1973 Conversion to imported natural gas (IEG) as the main combustion by means of multi-lance burners of steam generators 6 and 7.
- 1975 Detection of hole reveal cracks on the drums of the 420 t / h steam generators in the IKW.
- 1976 Constructive change to the steam discharge pipes on the steam generator 6.
- 1978 Dismantling of the IEG main combustion on steam generators 6 and 7.
- 1980 Extension of the findings of embedment cracks on the drums of the 420 t / h steam generators.
- 1981 Determination of enlargement of the hole reveal cracks on the drums of the 420 t / h steam generators.
- 1982 Start of retrofitting and commissioning of gas and support lights based on imported natural gas (IEG) on steam generators 1, 3, 5, 6 and 7.
- 1984 Drum downpipe tubing drilled out on steam generator 3 and hole edges rounded.
- 1985 Start of reconstruction of steam generator 4 with replacement of the lower part of the evaporator heating surface up to a height of +24 m.
- 1986 On steam generator 2, the lower part of the evaporator heating surface was changed to a height of +24 m, the Luvo and Eco and drum downpipe tubing were drilled out and the hole edges rounded.
- 1987 On steam generator 1, the entire piping including Luvo and Eco was changed and the drum was renovated by drilling, welding and mechanical processing of the downpipe holes.
- 1988 Drum renovation carried out by drilling, welding and mechanical processing of the downpipe holes on steam generators 5 and 6.
- 1989 On the steam generator 3, the complete tubing including the Luvo and Eco was changed and the drum downpipe tubing on the steam generator 7 was drilled and the hole edges rounded. Furthermore, a complete change from Luvo and Eco was carried out on steam generators 5, 6 and 7 (reconstruction measures were completed by 1989).
- 1990 Replacement of the upper part of the evaporator heating surface and the rest of the pressure part piping, as well as replacement of all mills on the steam generator 4.
- 1991 Replacement of the upper part of the evaporator heating surface and the rest of the pressure part piping, as well as replacement of all mills on the steam generator 2. Upgrading the electrostatic precipitator (retrofitting / renovation of the spray and collecting electrodes and housing) on the steam generators 1 and 2.
- 1992 Upgrading the electrostatic precipitator system (retrofitting / refurbishing spray and collecting electrodes and housing) and changing the pressure part piping and all coal mills on the steam generator 5.
- 1993 Retrofitting of steam generators 1, 3, 5, 6 and 7 with flame monitoring of the pilot gas burner. Change of the pressure part piping, as well as all coal mills on the steam generator 6, as well as upgrading of the electrostatic precipitator systems with associated replacement of the spray electrodes and knocking and renovation of the housing on the steam generators 3 and 4.At steam generator 6, the old electrostatic filter system was completely demolished and a new type of system was built 2xH 130.01 / 1x4.0 + 2x4.5 / 12.5 / 400 G from the company “Rothemühle” with a new design of the ash removal via trough belt conveyor, bucket elevator and Möller pumps.
- 1995 Change of all coal mills on steam generator 3 (installation of the mills of the now decommissioned steam generator 2) and the parallel connection of the electrostatic precipitator systems of steam generators 2 and 3 to improve the degree of separation.
- 1996 Parallel connection of the electrostatic precipitator systems of steam generators 4 and 5 to improve the degree of separation.
Technical developments and additions
- 1978–79 Procurement of a 125 MVA and a 63 MVA machine transformer as a central fault reserve for the then VVB power plants. Construction of a lightweight hall with a storage area of 1,620 m² and impact wheel preparation in the hall construction.
- 1979–80 Installation and commissioning of a fourth trench scooping device on the coal bunker to stabilize the coal supply, especially in the event of weather-related bottlenecks.
- 1979–82 Construction of a second ash water return line NW600 from the ash dump to the power plant.
- 1973–82 On instructions from the former energy minister of the GDR and the general director of VVB Kraftwerke, the use of imported natural gas (IEG) was prepared and implemented. This included the construction of a gas control station with integration into the long-distance gas pipeline passing by the site and the laying of a gas line from the gas control station to the steam generator 6 and 7, as well as their conversion to gas firing. In addition, a natural gas filling station was built and one of the company's vehicles was converted to run on gas. The filling station was also used by the former motor traffic of the city of Zwenkau .
- 1980–84 step-by-step installation of new process computing technology
- 1982–84 Installation of a second 38 bar reducing station to improve the safeguarding of the heat supply to PCK Böhlen in the event of a malfunction
- 1982–84 Implementation of measures to substitute heating oil with coal dust
- 1988 Establishment of a fourth cold reserve to meet the increased demand for feed water
The power plant after the political change in the GDR in 1989
As early as autumn 1989, groups of employees were found in several areas of the power plant who were dealing with the future of other interest groups. There were meetings in the company as well as at the Monday demonstrations in Leipzig. Since the beginning of 1990 it has become increasingly clear that there was no future for workers' interests to be represented by the works union management (BGL). For a long time there were no candidates for a new election to the BGL. The election nevertheless took place on May 16, 1990. Due to the political and economic development, however, the BGL was hardly effective.
The constituent meeting for the creation of works councils took place on April 4, 1990. For the first time there was a cross-departmental group whose main objective was the preparation of works council elections and the separation of the Lippendorf power plant from the former VEB Elbe Vockerode power plant network . In preparation for the transfer of the former VEB Kombinat lignite power plants to the planned United Power Plants - Aktiengesellschaft (VK-AG Peitz) based in Peitz, the working group trade union / works councils was founded as a forerunner of the general works council . On 16./17. In July 1990 the first works council elections took place at the Lippendorf power plant.
The independence of the Lippendorf power plant in 1990 was short-lived. At the end of the year, the decision was made to merge the two power plant locations in Lippendorf and Thierbach into one branch. This measure was jokingly called "MW's instead of wall newspaper" by the Lippendorf power plants. After the reunification of Germany , the restructuring of the energy industry in the GDR, which began in mid-1990, was also completed in December 1990 with the establishment of VEAG (Vereinigte Energiewerke Aktiengesellschaft).
VEAG became the legal successor of the former lignite power stations, the meanwhile founded VK-AG Peitz, the network operations and the state main load distribution of the GDR. A corporate concept was drawn up for the continuation of energy generation and distribution, which was geared towards three main goals:
- Improving the reliability and quality of the electricity supply in East Germany
- Improvement of environmental protection by drastically reducing pollutant emissions
- Increasing the profitability of electricity generation and distribution
For the Lippendorf power plant, continued operation was planned within the framework of the large-capacity combustion ordinance. In the public law contract between VEAG and the Free State of Saxony of July 23, 1993, a remaining use of 30,000 full load hours was agreed (beginning July 1, 1992). In accordance with the Federal Emissions Protection Act, extensive measures were taken to ensure compliance with the emission limit values . The values according to the approval notice were valid as of July 1, 1996:
- for dust with 80 mg / Nm³
- for NO x with 650 mg / Nm³
- for CO with 250 mg / Nm³
- for SO 2 with 10,500 mg / Nm³
The financial outlay for the stabilization measures was:
- Upgrading all electrostatic precipitators DM 6,150,000
- Installation of the TALAS system for automatic emission value recording and evaluation 192,000 DM
- Reconstruction of the electrostatic precipitators on steam generators 3, 5 and 6 (new construction or enlargement) DM 13,060,000
Despite extensive stabilization measures, the federal German laws now in force and the results of a feasibility study on the continued operation of the power plant sealed the future fate of the old Lippendorf power plant. A flue gas desulfurization system for the 100 MW systems and the 50 MW systems, as well as other measures to improve the efficiency of the main and ancillary units, were not economically viable.
The difficult struggle to maintain the site began:
- January 15, 1991 Conference on future site development at the Thierbach power plant.
- June 10, 1991 Works council conference in Hoyerswerda with Kurt Biedenkopf, then Prime Minister of the Free State of Saxony .
- July 2, 1991 Regional conference in Markkleeberg on the future development of the “southern Leipzig area”.
- March 4, 1992 “Footnote resolution” of the VEAG Supervisory Board on the location issue.
- June 4, 1992 The works councils of the Lippendorf / Thierbach power plants sent an open letter to the board members of the future shareholders of VEAG, demanding clear decisions in favor of a new power plant at the Lippendorf site.
- June 5, 1992 Demonstration of the miners and energy workers for the preservation of their jobs in Leipzig .
- June 27, 1992 Another demonstration followed by a panel discussion between miners and energy workers and members of the supervisory board took place in Borna .
- October 15, 1992 Talks with the CEO of RWE .
- November 4, 1992 joint press conference of VEAG and Bayernwerke in Lippendorf brought the announcement of the declaration of intent to build a new power plant at the site with an electrical output of 2x800 MW planned at the time.
- March 11, 1993 joint press release by the Presidium of the VEAG Supervisory Board on the construction of a new power plant at the Lippendorf site together with Badenwerk AG, Bayernwerk AG and Energie -versorgung Schwaben AG (hereinafter referred to as southern partner).
- April 1, 1993 Consolidation talks with the Lord Mayor of Leipzig and representatives of the municipal utilities on the planned district heating supply for the new Lippendorf power plant.
- November 2, 1993 Contract between VEAG and Stadtwerke Leipzig for the district heating supply from Lippendorf. This ensured that the old power plant could continue to operate until December 31, 1999.
- November 29, 1995 Laying of the foundation stone for the new Lippendorf power plant in the presence of the then Prime Minister of the Free State of Saxony Kurt Biedenkopf .
Accidents and incidents
- December 9, 1969 - In the evening hours, a major fire broke out in the coaling system in the heavy bunker area, which resulted in extensive damage to the systems and the structure. The cause of the fire was welding and cutting work on the not yet completely finished coaling systems.
- October 8, 1970 - An automatic oil pump for the oil supply to the support bearings on turbo set 1, which was not carried out according to the project, led to an interruption in the oil supply to the bearings. The turbine generator was taken out of service without a sufficient supply of bearing oil. There was a high level of property damage to all support bearings.
- February 25, 1972 - At around 1:50 a.m., the measurement and control voltage of the turbine safety device on turbine set 5 failed. As a result, the turbine generator was shut down and the generator was disconnected from the grid. After the power supply for the turbine safety device was restored, the turbine generator was started up again. It was noticed that the speed kept increasing (the speed display on the turbine showed 3,500 rpm in the end deflection). The attempt to counter-regulate using the speed adjuster failed. The activation of the manual override and the closing of the control valve triggering of the main steam override valves also did not lead to success. The speed was only reduced when the main steam valve was closed. The calculations carried out later by the manufacturer resulted in an overspeed of> 4,500 rpm. The cause of the behavior of the turbine control was a defective tachometer.
- June 28, 1976 - As a result of the inability to discharge water and the resulting standstill corrosion of the steam discharge pipes in the upper dead space of the steam generator 6, these pipes were destroyed. The sudden escape of steam in the area of the front dead space of the steam generator destroyed the feed water lines and impulse lines for the control valves of the high pressure safety valves, which also ran there.
- February 12, 1979 - At 12:53 p.m., flashovers occurred on the insulators of the 110 kV overhead line portal. The reason for these flashovers was heavy icing due to extreme weather conditions. The first earth faults of the inductively earthed 110 kV network expanded through further flashovers to double earth faults and led to the short circuit of the so-called full coupling in the 110 kV switchgear. The special switching status that existed at the time (isolated operation to supply the olefin complex) was no longer given and led, among other things, to the triggering of the 110 kV circuit breakers of the four internal transformers. As a result, the power plant's own 6 kV supply collapsed, and all steam generators and turbo sets currently in operation, including all ancillary systems (coaling, ash removal, chemical and thermal water treatment), failed. The careful action of the shift staff on duty and the perfectly functioning emergency power supply (diesel and battery systems) prevented damage to the systems. After the self-supply was restored, the first turbo sets could be connected to the grid again in the late evening hours of the same day. This so-called Schwarzwerdefall was one of the bitterest days in the long history of the power plant.
- October 3, 1990 - The pipe wall section 8 of the left side wall of the steam generator 5 was torn from its mounts due to material fatigue and, when severely deformed, fell into the combustion chamber. This caused further damage to the combustion chamber tubing, the upper dead space, the radiation superheater, the boiler frame and the outer skin.
- June 24, 1992 - In the afternoon hours, a switching electrician routinely checked the voltage of the four power transformers (ET 105 to ET 108 / transformation ratio of the transformers 110 kV / 6 kV). He noticed a lower voltage (normal operation of the internal supply network was 6.2 kV) on the internal supply transformer ET 106. The voltage should be adjusted by activating the multiple switchgear from the control room. After activation, the step switch mechanism of the ET 106 automatically moved to step 19 (last step in the step switch mechanism). Normally only one step could be carried out and the next step could only be approached after the feedback from the step controller. The voltage of the internal supply network supplied by the ET 106 rose to 10 kV. Since entering the transformer box in order to downgrade the tap changer with a hand crank was too dangerous under these circumstances, the switch manager on duty decided to couple the two power supply networks and then to take the ET 106 out of operation using the 110 kV infeed circuit breaker. In order to achieve approximately the same voltage in both power supply networks (fulfillment of the synchronization conditions), the voltage was also increased on the ET 105. In the meantime the first failures occurred in the internal supply network of the ET 106. With a voltage of approx. 8 kV in the internal supply network of the ET 105 and 10 kV in the internal supply network of the ET 106, both networks were interconnected using a coupling switch . A deviation of approx. 12 ° from the synchronization point could be seen on the synchronization device (consisting of a double voltage meter, a double frequency meter and a synchronoscope ). The equalizing currents that occurred when the two networks were coupled caused the failure of other systems in the internal demand network. After the networks were connected, the ET 106 was immediately taken out of service and the voltage of the internal supply network was reduced to 6.2 kV again. The causes of the automatic steps of the ET 106 were firstly a defective limit switch in the step switch control on the transformer and secondly a defective voltage increase protection relay that switches off the stepping after a set time.
- August 18, 1993 - At around 7:00 am, improper crane work tore off the brackets for the cooling water return line of turbine set 7. The line with a diameter of DN 1200 fell to the ground over a length of 60 m.
Decommissioning and dismantling
In accordance with the strategic concept of the then VEAG, the inevitable shutdown took place. Understandably, this concept did not meet with the undivided approval of the many employees, as many of them had looked after and maintained the systems since they were first commissioned. Until the two new blocks were fully commissioned in the summer of 2000, the plants were gradually shut down.
- December 15, 1993 Decommissioning of the steam generator 7
- March 23, 1996 Block 4 closed
- June 29, 1996 Block 1 closed
- December 6, 1997 Blasting of cooling tower 1
In the course of the construction of the coal belt system for the fuel supply of the new power plant, the cooling tower 1 was taken out of operation, gutted and kink points were knocked into the concrete shell by means of a crane in order to achieve the desired direction of fall when blasting. At the time of the blast, all systems remained in operation. Only the 110 kV switchgear in the immediate vicinity was switched off for an hour for the first time in the history of the power plant.
- February 4, 2000 Block 3 closed
- March 10, 2000 Shutdown of steam generator 5
- March 31, 2000 Shutdown of steam generator 6
- 2005 Dismantling using demolition tongs cooling tower 2
- August 27, 2005 Blowing up the chimney
- September 5, 2005 Blasting of the boiler house
- September 10, 2011 Bunker blasting
Technical data (compared to the new Lippendorf power plant )
general overview
| Cond | IKW | New building | |
|---|---|---|---|
| Nominal output per plant in MW | 400 | 200 | 1867.2 |
| Steam generator | 4th | 3 (SS-KW 1 ) | 2 |
| Turbo sets | 4th | 4th | 2 |
| Nominal output per block / TS in MW | 100 | 50 | 933.6 |
| Short-term output per TS in MW | 110 | 55 | 970 |
| Type of combustion | Pulverized lignite combustion | Pulverized lignite combustion | Pulverized lignite combustion |
| Type of use | Base load | Timetable 2 | Designed for base load , but also medium load due to the EEG |
| Flue gas dedusting per DE | 2 E-filter lines with 4 individual filters each | 2 E-filter lines with 4 individual filters each | 2 E-filter lines with 16 individual filters each |
| Flue gas desulfurization system | unavailable | unavailable | available |
| Flue gas denitrification | unavailable | unavailable | not required, as limit values are undercut due to low NO x combustion |
| CO 2 reduction | unavailable | unavailable | through increased efficiency and partial substitution of primary fuel with CO 2 -neutral secondary fuel |
| Heat extraction in MW th | unavailable | 550 | 330 |
| Net efficiency in% | 26th | 24 | 42.5 |
| Fuel efficiency in% | 26th | 60 | 46 |
1 busbar power plant (3 steam generators feed a busbar which supplies 4 turbo sets )
2 ratio of electrical energy to heat energy generation depending on the load requirement
Steam generator
| Cond | IKW | New building | |
|---|---|---|---|
| Art | 4 × natural circulation | 3 × natural circulation | 2 × forced run |
| Height in m | 54 | 54 | 163 |
| Nominal output in t / h | 330 | 420 | 2420 |
| Combustion chamber height in m | 35 | 35 | 90 |
| FD pressure in bar | 135 | 120 | 267.5 |
| FD temp. In ° C | 535 | 535 | 554 |
| ZD pressure in bar | 30th | without reheating | 52 |
| ZD temp. In ° C | 530 | without reheating | 583 |
| Mills per DE | 4 × NV 50 1 | 4 × NV 50 | 8 × NV 110 |
1 wet fan mills with 50 or 110 t / h coal throughput each, one mill in reserve
The 420 t / h steam generator in the IKW old Lippendorf power station
General
Three 420 t / h steam generators (DE 5, DE 6 and DE 7) were installed in the industrial power plant (IKW). These were built by the former VEB Dampferzeugerbau Berlin. These steam generators fed on busbars (SS), from which the 4 turbo sets installed in the IKW obtained their steam.
There were two busbars, with the SS NW 200 functioning as the starting and reserve busbar and the SS NW 300 as the operating busbar.
Technical characteristics of the 420 t / h steam generator
- Steam generator type: Radiant boiler
- Steam generator design: two-pass, semi-open air construction
- Type of water circulation: natural circulation
- Superheaters: 4 (including 2 radiant superheaters and 2 touch superheaters)
- Feed water preheater: steel pipes co
- Air preheater: Röhrenluvo
- Superheated steam cooling: injection of feed water
- Safety valves: pilot operated
- Cleaning facilities: combustion chamber water spray
- Type of firing: Lignite dust mill corner firing
- Ignition device: gas burner
- Ash removal type: scraper belt
- Type of dedusting: electrostatic precipitator
The 420 t / h steam generator is a radiant steam generator with natural circulation. Radiant steam generators are small water room steam generators, whereby the water to be evaporated flows through the pipes, which in turn are heated by the radiant flame in the furnace or by the flue gases. The downpipes from the drum, which are arranged outside the directly heated combustion chamber, activate the natural circulation of the water, as the colder water sinks in the downpipe and, due to its greater density, displaces the lighter water vapor mixture from the boiler pipe. The flow of steam through the superheater is due to the pressure difference between the drum and the downstream steam lines. The advantages of the small water room steam generator are its large steam generator output and the relatively short time in which it can be run to operating parameters from readiness for operation.
Construction of the 420 t / h steam generator in the IKW
Each steam generator had a height of 53 m, a depth of 22 m and a width of 13 m. The first pass of the steam generator was the octagonal furnace with the bulkhead above it. Both the furnace and bulkhead were lined on all sides with the 20 sections of the evaporator heating surfaces. The bulkhead space was derived from the design of the radiant superheater (hereinafter referred to as SÜ, the heat was transferred by radiant heat), which was housed in it. In total there were 12 bulkheads per steam generator. The three outer walls belonged to SÜ1, the six in the middle to SÜ2. The outlet header of SÜ1, the inlet header of SÜ2 and the two mixing tubes of the coarse injection (left / right) between the two superheater stages SÜ1 / 2 were located in the dead space. This room, which was formed by the special piping of the evaporator heating surfaces, was not directly exposed to the radiation from the fire.
The two stages of the contact superheater (hereinafter referred to as the BÜ, the heat transfer took place by contact heat transfer, convection) were located in the cross-section of the steam generator. The BÜ2, which represented the last stage of the 4 high pressure superheater stages, was installed in front of the flue gas grille. The flue gas grids are the sections of the evaporator heating surfaces that lead to the drum and were attached to the rear wall of the first pass. The first stage of the high-pressure superheater, the BÜ1, was installed after the flue gas grille.
The upper dead space was located above the transverse train or the bulkhead space. Like the lower dead space, it was not exposed to radiation from the fire. The separation from the combustion chamber was made by bulkheads made of refractory concrete. This upper dead space was again divided into two sections. The steam generator drum was located in the front part of the upper dead space. This served to separate the water from the saturated steam. An abundance of lines were integrated into the drum (feed water lines, steam discharge pipes from the sections of the evaporator heating surfaces or to the superheaters, impulse lines for the control valves of the high-pressure safety valves, drum quick discharge, drum desalination, various measuring lines, vents and the downpipes). These 32 downpipes were led outside the steam generator to the lower collectors of the evaporator heating surfaces.
The rear part of the upper dead space housed the outlet headers of BÜ1, the inlet and outlet headers of BÜ2, the inlet headers of SÜ1 and the outlet headers of SÜ2. In addition, the two mixing tubes for the basic injection (left / right) were located between BÜ1 and SÜ1 and the two mixing tubes for fine injection (each left / right) between SÜ2 and BÜ2 in the rear part. The feed water lines also led from the feed water preheater to the steam generator drum through this rear dead space. The main steam lines (left / right) of the steam generator were led out of the dead space from the outlet headers of the BÜ2. Outside there were two outlets to the main valves of the four auxiliary high pressure safety valves on the left and right of the main steam lines.
The two-stage feed water preheater was installed in the upper part of the second pass. Each tier was divided into eight packages (four packages belonged to the left side, four packages belonged to the right side). The feed water reached the first stage of the feed water preheater on the left and right via a pressure line which was split outside the boiler. After the first stage, the feed water pipes crossed from left to right or from right to left.
The air preheater was installed in the lower part of the second pass (at the end of the boiler). In terms of design, it was a tubular air preheater, divided into three stages in a horizontal version. Its job was to preheat the air required for combustion. This preheated air was fed to the pulverized coal burners via air ducts and corresponding burner hot air flaps. If necessary, the preheated air could be used to lower the temperature of the mills via mill hot air flaps. A hot air flap was assigned to each mill.
The necessary combustion air was provided by two fresh fans (radial fans). A caloriferous unit belonged to each fresh fan. These calorifiers are heat exchangers and were supplied from the 4.8 bar network of the IKW.
The calorifers should prevent the flue gas from falling below the dew point at the first stage of the air preheater. The preheated air required for combustion was fed to the pulverized coal burners, which were designed as flat burners.
The 4-mill corner firing was used as the type of firing. The coal required for firing was stored in four bunker pockets per steam generator (one bunker pocket per coal mill) with a capacity of approx. 150 t and fed to the plate distributors via transfer boxes. Via these plate distributors (one distributor per coal mill) the coal reached the coal inlet shaft, which led into the flue gas recirculation. The mill sucked in hot flue gases from the combustion chamber via the flue gas recirculation duct, which served as protective gas against deflagration (inert gas) as well as for pre-drying the coal.
In the coal mill, the coal was thermally and mechanically crushed, sifted in a gravity sifter (too large pieces of coal get back into the mill room by gravity) and fed to the pulverized coal burners via the dust channel and trouser piece. Each mill had a double burner with two associated hot air ducts and burner hot air flaps.
Four gas burners were available as an ignition device or as a supporting light.
The evacuation of the flue gases from the steam generator was done by two induced drafts. In front of the induced drafts there were three gravity separators below the air preheater . These should separate part of the fly ash contained in the flue gas (approx. 90% of the total ash in the case of pulverized lignite combustion). The electrostatic precipitator connected to the gravity separator. Most of the remaining fly ash was filtered out in it. Then the flue gases were fed to the chimney via the suction hoods.
A scraper belt was located under the furnace of the steam generator to remove larger ash and slag (approx. 10%).
In addition, the steam generator system also included equipment for cleaning the furnace, feed devices and an extensive range of fittings and measuring, control, safety and warning devices.
Technical specifications
- maximum continuous steam output - 420 t / h
- constant overload - 450 t / h
- Approval pressure - 137 bar
- Pressure after HP superheater - 117 bar
- Superheated steam temperature according to BÜ1 - 410 ° C
- Superheated steam temperature before SÜ1 - 410 ° C
- Superheated steam temperature according to SÜ1 - 450 ° C
- Superheated steam temperature before SÜ2 - 436 ° C
- Superheated steam temperature according to SÜ2 - 510 ° C
- Superheated steam temperature before BÜ2 - 510 ° C
- Superheated steam temperature according to BÜ2 - 535 ° C
- HP cooling with 1st injection before SÜ1 - basic injection
- HP cooling with 2nd injection before SÜ2 - coarse injection (approx. 10 t / h)
- HP cooling with 3rd injection before BÜ2 - fine injection (approx. 5 t / h)
- Feed water temperature before HDV - 150 ° C (temperature of cushion steam feed water tank)
- Feed water temperature according to HDV - 236 ° C
- Feed water temperature before Eco - 236 ° C
- Air temperature according to Luvo - 290 ° C
- Flue gas temperature in front of the grille - 780 ° C
- Flue gas temperature before Eco - 550 ° C
- Flue gas temperature in front of Luvo - 314 ° C
- Flue gas temperature at the end of the steam generator (2nd pass) - 170 ° C
- Heating surface design evaporator heating surface - 3750 m²
- Heating surface design superheater surface (radiant superheater) - 1420 m²
- Heating surface design superheater surface (contact superheater) - 3035 m²
- Heating surface design feed water preheater - 5520 m²
- Heating surface design air preheater - 19260 m²
- Capacity of the feed water preheater - 25 m³
- Filling volume of the evaporator part - 150 m³
- Capacity superheater - 40 m³
- Drum capacity - 28 m³
- Coal mill type - four NV 50 each (wet fan mills with 50 t / h throughput)
- Flue gas temperatures in front of the mill - max. 700 ° C
- Flue gas temperatures after mill with coal throughput - max. 180 ° C (classifier temperature)
- Burner type - flat burner
- Burner arrangement - register
- Number of burners - four double burners
- Pilot burner type - gas burner
- Number of gas burners - four pieces
chimney
| Old power plant | New building | |
|---|---|---|
| Height in m | 300 1 | not available 2 |
1 At the time of construction the tallest solid structure in the GDR (served as a test object for the Berlin television tower ) and at the time of dismantling it was the tallest blasted structure in Europe. The lower shaft of the chimney was made of reinforced concrete in climbing formwork . From a height of 44.7 m, the first time a 300 m chimney was built using sliding formwork . The internal cylindrical fire pipe made of fireclay was routed every 50 m in a ring in the chimney shaft. The height expansion was ensured by sliding guides. An ALPICA elevator led between the chimney shaft and the smoke pipe up to a height of 250 m. The remaining 50 m had to be climbed for controls on the outside of the chimney.
2 The cleaned exhaust gases are released into the environment by using the cooling tower convection via the two 174.5 m high cooling towers.
turbine
| Cond | IKW | New building | |
|---|---|---|---|
| number | 4th | 2 + 2 | 2 |
| Type | P 50-130 and PR-50-111 / 38/5 | ||
| design type | 3-casing condensation turbine | 1-housing extraction - condensation turbine 2-housing extraction - back pressure turbine |
5-casing condensation turbine |
| Pressure v. HD part in cash | 128 | 115 | 259.5 |
| Temp. HD part in ° C | 530 | 530 | 550 |
| Pressure v. MD part in cash | 30th | without reheating | 50 |
| Temp. MD part in ° C | 530 | without reheating | 582 |
| Nominal speed in min −1 | 3000 | 3000 | 3000 |
| FD quantity in t / h | 320 | 250 ( extraction condensation turbine ) 420 ( extraction back pressure turbine ) |
2420 |
Extraction condensing turbine
The type P 50-130 / 5 is an extraction - condensation turbine from the 50 MW industrial steam turbine series of the VEB Bergmann-Borsig / Görlitzer Maschinenbau. These turbines (turbo sets 7 and 8) have been specially developed for use in industrial power plants. Thermally elastic behavior, automated start-up and shutdown process with suitability for daily start-up and shutdown allowed optimal power plant operation even in transitional states for heat and power generation. The machines were designed with a single housing and provided with heat-elastic, radial seals.
All auxiliary systems were combined in assembly blocks. The capacitor was designed as a box construction. The hydraulic turbine unit control was operated with water as the control fluid for fire protection safety.
- Withdrawal pressure normal - 5 bar
- Application range - 4–7 bar
- Number of taps - 5
- Cooling water temperature - 28–40 ° C
- HD part - 7 stage execution
- ND part - 6 stage execution
- Turbine bearings - 8 support bearings / 1 block bearing
- Critical speed range - between 1050 and 2000 rpm; The rotational frequency is the same as the natural frequency of the rotor and dangerous vibrations arise due to resonance - this speed range must be passed through quickly when starting up
In the project planning phase for the IKW turbo sets 7 and 8, a decision was made in favor of a water-hydraulic standard control from VEB Bergmann Borsig / Görlitzer Maschinenbau. Decisive for the use of this regulation was, among other things, the delivery and commissioning of a 57/62 MW heating back pressure turbine for the Naistenlahti power plant in Tampere (Finland) by VEB BB / GMB.
The water-hydraulic unit control is a hydrodynamic control that works according to the inlet-outlet principle and had a largely friction-free and wear-free structure. Since water was used as the control fluid, there is no risk of fire. The system consisted of four basic modules and several additional modules for special control tasks. This regulation is supplemented by a uniform safety system.
What spoke in favor of using a water-hydraulic control versus an oil-hydraulic control?
advantages
- The regulation is absolutely fire-safe. (The turbines equipped with this regulation were the most fireproof in the world).
- No increased wear compared to hydraulic controls.
- No reduction in functionality.
- Improvement of assembly, testing, adjustment and maintenance work.
- Specially trained lubricating oil supply with the following main features:
- Minimized volume of lubricating oil.
- Combination of all units necessary for the bearing oil supply in one lubricating oil block.
- Removal of the lubricating oil block from the turbine and a separate installation according to structural conditions.
- No turbine shaft driven main oil pump.
- Instead of the main oil pump, there were electric pumps in the lubricating oil block.
- Emergency oil was supplied via a turbine shaft-driven emergency oil gyro.
- Shielding of all oil lines from hot parts.
disadvantage
- The oxygen dissolved in water makes water aggressive and corrodes steel.
- Water is thinner than oil.
- Water has almost no lubricity.
Constructive features
Control and oil systems were set up separately. Instead of the high-pressure oil, water (condensate) is used, which supplies a central water supply. Avoidance of sliding parts such as pistons, bushings and pin joints in the transmission system. Use of control elements whose control edges or control surfaces are arranged so as to be free of contact or relative movement through structural measures (nozzle-flapper system). Use of soft packings to seal cylinder chambers in power pistons and power piston spindles of servomotors. Use of rustproof materials. In consideration of these prerequisites, the experience with hydraulic controls was used. The basic concept with the standardized components (control block, universal measuring unit, calculator and servomotor) were retained.
1st building block - control block
Control and oil supply elements are combined in the control block. In this block, oil acts up to the separating devices. Its task is to generate the speed signal and signals for the turbine safety system. The control block consists of a cylindrical housing that houses a small emergency oil pump (impeller) that generates the speed signal, as well as the overspeed switch and the thrust bearing safety device. The regulator block was flanged to the turbine outer bearing and coupled to the turbine shaft.
2nd component - universal measuring mechanism
The universal measuring mechanism is a measuring and transmission element. It has the task of measuring pressures and converting them into a quantity corresponding to the downstream device. The measuring mechanism consists of two main parts (measuring device and adjusting device). Depending on the intended use of the module, the input pressure acting on the pleat lining is either the withdrawal pressure, the counter pressure or the speed signal coming from the control block.
3rd module - arithmetic unit
The arithmetic unit is a proportionally acting transmission element which enables both signal amplification and signal mixing, while maintaining the necessary decoupling, in the case of multiple controls. The arithmetic unit consists of a housing that contains a lever on which a fold lining and a compression spring act. Depending on the type of turbine, the lever controls one to three processes depending on the signal coming from the universal measuring mechanism and thereby generates corresponding output signals.
4. Module - servomotor
The servomotor is a pressure / displacement converter which is connected downstream of the calculator. It is used to operate the control valves, and each control valve has a servomotor. The servomotor consists of the control part and the power part. The desired relationship between the input signal coming from the calculator and the valve lift is achieved by means of various return springs and stops in the control section.
Extraction back pressure turbine
The type PR-50-111 / 38/5, a two-casing extraction - back pressure turbine , represented a special construction due to the high extraction steam volumes . These turbines (turbo set 5 and 6) for the IKW power plant were made by VEB Bergmann-Borsig (BB ) / Görlitzer Maschinenbau (GMB) designed and manufactured. The turbine was developed for use in industrial power plants and has proven itself over many years of operational use. The machines were designed to be highly thermally mobile and equipped with the proven system of the hydraulic BB / GMB unit control. Nominal withdrawal pressure - 38 bar control range - 36-40 bar Number of taps - 1 nominal back pressure - 5 bar control range - 4–7 bar HP part - 9-stage version (1st stage designed as a Curtis wheel) LP part - 8-stage version Turbine bearings - 10 Support bearing / 1 block bearing Critical speed range - between 1100 and 1750 / min (the speed range where the natural shaft oscillation overlaps with the speed (= frequency) and undesired resonances occur. This range must be passed quickly when starting up, otherwise it will increase Shaft vibration, which leads to mechanical destruction of the rotor or the bearings.)
The steam flow of an extraction counterpressure turbine is analogous to that of an extraction condensation turbine, only that the steam from the low-pressure part does not flow into a condenser, but is fed to another use.
The speed controller of an extraction counterpressure turbine is only used to start up the turbine generator and is switched off after the extraction and counterpressure controller has been started up. This means that the speed of the machine is determined by the electrical network with which it runs synchronously .
The primary thing is to regulate the steam pressure. The electrical power depends on them. In this type of turbine, the folding coverings of the pressure regulators adjust so-called baffle plates, which control the aperture. If several such turbines work on a steam network, the control pulses are not taken directly from the steam lines, but are only converted by pressure transducers. This is to prevent several pressure regulators working in a steam network at the same time. The impulses are passed on to the individual turbines from the pressure transducers. The back pressure regulator influences high and low pressure valves in the same direction, while the extraction pressure regulator only influences the high pressure valves. A change in the individual steam quantities is therefore always associated with a change in the electrical power. The safety devices for the turbine are the same as for the extraction condensation turbine, only that the condenser pressure safety device is omitted here. There is also an interlock for the generator protection, which acts on the back pressure regulator and relieves the machine in the event of an electrical overload of the generator.
generator
| Cond | IKW | New building | |
|---|---|---|---|
| number | 4th | 4th | 2 |
| Manufacturer | Bergmann-Borsig | Bergmann-Borsig | FIG |
| Type | H 125 x 10.5 | H 58.8 x 10.5 | 50WT25E-158 |
| Apparent power in MVA | 125 | 58.8 | 1167 |
| circuit | star | star | star |
| Voltage in kV | 10.5 | 10.5 | 27 |
| Current in kA | 3.235 | 24,954 | |
| cos phi | 0.85 | 0.8 | |
| Excitation voltage in V | 180 | 757 | |
| Excitation current in A | 6001 | ||
| H 2 excess pressure in bar | 0.29 | 5 | |
| Mass of stator in t | 105 | 430.3 | |
| Mass of rotor in t | 23 | 93.6 | |
| Frequency in Hz | 50 | 50 | 50 |
| Speed in min −1 | 3000 | 3000 | 3000 |
| cooling | H 2 / H 2 O | H 2 | H 2 > / H 2 O |
Machine transformer
| Cond | IKW | New building | |
|---|---|---|---|
| number | 4th | 4th | 4 1 |
| Type | KDRF 63001/110 | TWSM / KDOR | |
| Apparent power in MVA | 125 | 63 | 1100 |
| Art | LT / R | LT / R | |
| circuit | Yd5 | Yd5 | YNd5 |
| Max. Short circuit duration in s | 10 | 8th | |
| Mass in t | 87 | 550/555 | |
| Oil mass in t | 21st | 92.5 / 102 | |
| Rear derailleur in stages | 19th | 19th | 27 |
| Translation in kV | 10.5 / 220 | 10.5 / 110 | 27/410 |
1 parallel connection of two transformers per block
Cooling tower
| Old power plant | New building | |
|---|---|---|
| number | 2 1 | 2 2 |
| design type | Natural draft wet cooling tower | Natural draft wet cooling tower |
| Cooling water throughput in t / h | 36000 | 84600 |
| Height in m | 113.2 | 174.5 |
1 Erected with hydraulically operated sliding formwork while the advance is ongoing. At the time, it was an engineering masterpiece by the building contractor SBKM Kühlturmbau Leipzig, as it was used for the first time worldwide. The highest performance was achieved by driving 1.5 m in 24 hours.
2 The exhaust gases are also discharged through the two cooling towers
See also
literature
- VEAG: Lippendorf power plant 1969–2000. Lippendorf-Thierbach 2000.