EP1861586A2 - Procede et dispositif de production d'une puissance de regulation au moyen d'un systeme combine de turbine a gaz et de turbine a vapeur - Google Patents

Procede et dispositif de production d'une puissance de regulation au moyen d'un systeme combine de turbine a gaz et de turbine a vapeur

Info

Publication number
EP1861586A2
EP1861586A2 EP06725082A EP06725082A EP1861586A2 EP 1861586 A2 EP1861586 A2 EP 1861586A2 EP 06725082 A EP06725082 A EP 06725082A EP 06725082 A EP06725082 A EP 06725082A EP 1861586 A2 EP1861586 A2 EP 1861586A2
Authority
EP
European Patent Office
Prior art keywords
power
frequency
steam turbine
setpoint
control
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP06725082A
Other languages
German (de)
English (en)
Inventor
Reinhold Ackenheil
Oldrich Zaviska
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Siemens AG
Original Assignee
Siemens AG
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Siemens AG filed Critical Siemens AG
Publication of EP1861586A2 publication Critical patent/EP1861586A2/fr
Withdrawn legal-status Critical Current

Links

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K13/00—General layout or general methods of operation of complete plants
    • F01K13/02—Controlling, e.g. stopping or starting
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K23/00—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
    • F01K23/02—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
    • F01K23/06—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
    • F01K23/10—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
    • F01K23/101—Regulating means specially adapted therefor
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K23/00—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
    • F01K23/02—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
    • F01K23/06—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
    • F01K23/10—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
    • F01K23/106—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle with water evaporated or preheated at different pressures in exhaust boiler
    • F01K23/108—Regulating means specially adapted therefor
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E20/00—Combustion technologies with mitigation potential
    • Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]

Definitions

  • the present invention relates to a method for providing a control power by a combined cycle power plant with at least one gas turbine and at least one steam turbine.
  • the gas and steam turbine plant generates electrical power and feeds it into a network, which is operated at a predetermined grid frequency.
  • the waste heat of the gas turbine plant is fed to a waste heat boiler in which the working steam is generated for operating the steam turbine.
  • the steam turbine is connected upstream of at least one steam turbine steep valve whose passage cross-section is adjustable by a control.
  • the setpoint formation for adjusting the control valve passage cross-section is performed using a performance-relevant control parameter, i. a control parameter, which allows the regulation of the power of the steam turbine.
  • the power-relevant control parameter may in particular also be the power of the steam turbine itself. It should be noted at this point that the steam turbine often has several pressure levels.
  • a steam turbine may have a high-pressure, a medium-pressure and a low-pressure turbine, which differ in the pressure of the steam that prevails in the respective turbine sections. If the steam turbine has a plurality of such sub-turbines, then each of the sub-turbines may comprise at least one steam turbine control valve whose control valve passage cross-section is adjustable by a control.
  • Power grids are operated at a certain grid frequency, which is 50 Hz in Europe. The close constancy of the frequency is to be guaranteed by the network operator. However, grid frequency is related to the balance between power generation and load (consumer demand for linked). An increase of the load or a reduction of the power generation leads to a reduction of the mains frequency and vice versa. A load or power generation change must therefore be responded to by the grid operator on the power generation or load side as soon as the grid frequency leaves the permissible range of change.
  • a certain power quality is guaranteed.
  • the compensation must be made within a few seconds, so that no disturbances in the network occur.
  • the measure of the currently prevailing imbalance between the network load and the power fed into the grid is the frequency deviation.
  • the load power compensation takes place by the constant power adjustment of the power generation to the network load.
  • the adjustment is made by means of provided positive or negative control power, ie power that can be dynamically fed into the grid or taken off the grid.
  • the provision of control power is typically provided by dedicated power plants.
  • the maintenance of the control task in the entire range of occurring frequency changes and the occurring frequency change periods requires the presence of certain dynamic characteristics in the power plants involved in the control. In gas and steam turbine plants, there are mainly two difficulties to overcome in terms of providing the control power:
  • a request for positive or negative provision of a control power in the range of seconds ie a power available within a few seconds
  • the dynamic behavior of the steam turbine corresponds to the behavior of the waste heat process, whose dynamics are in the minute range (minute dynamics).
  • the reason for this is that the steam turbine part only acts as a recycler of the gas turbine waste heat.
  • the gas turbine alone must provide and provide the required block control performance. For the gas turbine this leads to a stationary gas turbine operation, which is reduced by the amount of power to be held for the regulation (partial load operation).
  • the partial load mode of the gas turbine not only has the steam turbine power, which is lower by the reduced amount of waste heat, but also further disadvantages associated with partial load operation. These disadvantages range from a reduction in plant efficiency to an increase in specific emission levels to a reduction in the annual use of installed capacity.
  • Gas turbines are operated over a wide power range with constant exhaust gas temperature.
  • the load changeability ie the response to a change in the requested power is essentially determined by the dynamic properties exhaust gas temperature control system.
  • the gas turbines can provide the required control power relatively easily.
  • gas turbines can no longer adequately meet the requirements. Therefore, gas and steam turbine plants are only partially capable of primary control in the case of the aforementioned smaller, rapid frequency changes.
  • Gas and steam turbine plants are usually operated with a passive steam part. This means that the steam turbine is operated with fully open control valves (so-called Gleitdruckfahrweise) and depends on the dynamic characteristics of the waste heat boiler. Gas and steam turbine plants can therefore usually participate in the frequency control in the interconnected network only with the gas turbine part, which in addition leads to the above-mentioned disadvantages of the reduced dynamics to be accepted.
  • Steam turbine power setpoint is returned to its original state after a period of time. Since an increase in the block power would be registered in the block power management with such an increase of the steam turbine power, whereupon, in a concrete embodiment (Siemens), the block power control would counteract the increasing block power, the block power is stopped by means of a stop circuit until the steam turbines Power setpoint has reached its original value again.
  • Such a controlled steam turbine may provide control power to compensate for mains frequency fluctuations whose period is determined by the disappearance signal.
  • the magnitude of the frequency deviation that can be responded to is determined by the steam turbine in this period of time using the additional power retrievable from the memory. The higher the retrievable additional power, the greater the frequency fluctuations can be compensated.
  • Control power by a combined gas and steam turbine plant with at least one gas turbine and at least one steam turbine wherein the electric power generated by the gas and steam turbine plant is fed into a network with a Netzfre- frequency that has to correspond to a predetermined target frequency, the steam turbine involved in a frequency control for maintaining the target frequency.
  • a control reserve for generating the control power with the steam turbine is provided.
  • a positive or negative control power is fed into the network, which is made available at least partially by charging or discharging the control reserve.
  • a charging of the control reserve at an overfrequency and a discharge of the control reserve at an underfrequency In the method according to the invention, the control reserve is charged or discharged with a coordinated distribution of the control power to the gas turbine and the steam turbine associated. In other words, the balancing power is provided by the
  • control module according to EP 1 174 591 A1 leads to a substantial improvement in the dynamic properties of the gas and steam turbine plant in the second range, it is suitable only for providing a positive control power at individual larger, relatively rare frequency drops, e.g. about ⁇ f> -5OmHz.
  • a control of the steam turbine down valve is used, which ensures a reduction of the passage cross-section of the valve (so-called fast valving).
  • fast valving With the almost valving, however, only a few relatively rare events can be achieved with frequency increases, e.g. compensate for ⁇ f> + 50mHz.
  • the method according to the invention allows a continuous frequency control with the gas and steam turbine plant in the entire range of permissible frequency deviations starting at approximately +10 mHz.
  • the inventive method allows the continuous frequency control by means of the structure of a control reserve, such as in the form of a heat storage in Abhitzekes- by a steam turbine throttling, together with the coordinated distribution of the required positive and negative control power to the gas turbine and the steam turbine.
  • the coordinated distribution also takes into account the charging and discharging of the heat accumulator used by the steam turbine of the heat boiler, ie the control reserve
  • the frequency control takes place predominantly with the steam turbine, ie the control power is provided mainly by the steam turbine. Due to its dynamic properties, the steam turbine is predestined for frequency control in the aforementioned ranges. The reason for this is that it is possible to load or unload the control reserve within seconds. For larger frequency deviations or longer periods there is a common frequency control.
  • the control power of the gas turbine and the steam turbine is shared.
  • the establishment of the control reserve can be done by forming a corresponding additional power value for the gas turbine based on the deviation of the mains frequency from the desired frequency and a predetermined block setpoint. As long as the deviation of the mains frequency from the nominal frequency .DELTA.f is approximately zero, the additional power value serves merely to maintain the control reserve. In the case of a significant deviation of the mains frequency from the nominal frequency, the control reserve is returned to a predetermined value after charging or discharging by means of the additional power value.
  • the inventive method can be realized with two different control concepts.
  • control of the distribution of control power to the gas turbine and the steam turbine is accomplished by forming a corresponding gas turbine power set point and a corresponding steam turbine power setpoint based on the frequency deviation and the predetermined block setpoint.
  • the first control concept is based on a power-controlled steam turbine operation in which the steam turbine is controlled on the basis of a power setpoint.
  • the gas and steam turbine can be operated with a predetermined block power setpoint if the grid frequency corresponds to the setpoint frequency, with a split of the block power setpoint to the gas turbine power setpoint and the steam turbine power setpoint based on a predetermined ratio.
  • the ratio can be predetermined in the form of a function, for example. But it is also fundamentally possible to use the ratio in the form of a look-up table. pretend to belle. In the case of a deviation of the network frequency from the nominal frequency, the first control concept involves a change in the block power by the necessary control power.
  • the control power is first provided by changing the steam turbine power setpoint while charging or discharging the control reserve, leaving the predetermined ratio of the block power setpoint split to the gas turbine power setpoint and the steam turbine power setpoint.
  • the control power is thus provided mainly by the control reserve. Delayed to the steam turbine power setpoint, the gas turbine power setpoint is then changed, simultaneously restoring the predetermined ratio of the block power setpoint split to the gas turbine power setpoint and the steam turbine power setpoint.
  • the ratio may in particular also depend on the size of the block power setpoint value, ie it may be different after the change in the block power setpoint value than before the change, as long as the new ratio corresponds to the predefined function or lookup table. Parallel to this, a dynamic, ie temporary change of the live steam pressure setpoint value can take place, so that after restoring the predetermined distribution, the control reserve is again properly filled.
  • the distribution of the control power to the gas turbine and the steam turbine is regulated on the basis of a gas turbine power setpoint and an opening setpoint value for the valve opening of at least one control valve of the steam turbine.
  • the steam turbine in the second control concept has an opening control.
  • the actuator here is a steam turbine control valve, and the corresponding relevant for the performance of the steam turbine control parameters is the opening setpoint for the control valve.
  • the method according to the invention is suitable both for use in power-controlled steam turbines and for use in pressure-controlled steam turbines.
  • the structure of the control reserve can be achieved by throttling at least one steam turbine control valve and charging or discharging the control reserve by setting a suitable throttling.
  • the control device comprises a gas turbine module for determining a gas turbine power setpoint, which is connected to the block power setpoint input and the frequency signal input and is designed to switch the gas turbine power setpoint when the network frequency deviates from the setpoint frequency, taking into account a gas turbine engine based on the frequency deviation signal. To determine control power.
  • control device comprises a main steam module, which is connected to the block power setpoint input and the frequency signal input and is designed to output a live steam pressure setpoint on the basis of the frequency deviation signal and the block power setpoint.
  • the live steam module is also designed to output an additional power value to the gas turbine module, which represents an additional power of the gas turbine required for maintaining the control reserve in the event of a deviation of the power frequency from the desired frequency.
  • the gas turbine module is configured based on the additional power value to change the gas turbine power setpoint so that in the
  • Gas and steam turbine plant reserve the reserve is maintained.
  • the live steam module is further configured to change the live steam pressure setpoint on the basis of the frequency deviation signal in the event of a deviation of the mains frequency from the solar frequency in such a way that charging or discharging of the control reserve is brought about.
  • the control device comprises a splitting module, which is in communication with the frequency signal input and the block power setpoint input and configured to adjust the gas turbine power setpoint and the steam turbine power setpoint upon charging or discharging the control reserve based on the frequency deviation signal. set the block power setpoint and the additional power value so that a division of the control power to the gas turbine and the steam turbine takes place.
  • the device according to the invention makes it possible to carry out the method according to the invention in accordance with the first control concept.
  • the device according to the invention is designed for a power control of the steam turbine.
  • the control device may include a conversion module connected to the block power setpoint input for receiving the block power setpoint, to the frequency signal input for receiving the frequency deviation signal, and to the live steam module for outputting a pressure setpoint.
  • the conversion module is designed to convert the block power setpoint into a pressure setpoint, taking the frequency deviation signal into account.
  • This module can in particular also be integrated as a submodule in the live steam module. It is used to calculate the pressure setpoint on the basis of the block setpoint and to adapt it to a frequency deviation.
  • the live steam module can then determine the additional power value and the live steam pressure setpoint adjusted to the frequency deviation.
  • the gas turbine module, the steam turbine module and the distribution module can be combined in a setpoint formation module.
  • the control device can be adapted for pressure control of the steam turbine by the conversion module is designed to output a conversion factor for converting a vapor pressure into a power on the basis of a pressure characteristic, and an opening control module is integrated.
  • the opening control module communicates with the steam turbine module for receiving the steam turbine setpoint, with the live steam module for receiving the live steam pressure setpoint, and with the conversion module for receiving the conversion factor. It is designed to determine and output an opening target value for the opening of the at least one steam turbine control valve on the basis of the received values.
  • the opening module can be designed in particular for determining and outputting a linear opening setpoint value.
  • Fig. 1 shows a schematic block diagram of a gas and steam turbine plant.
  • FIG. 2 shows a schematic block diagram, which represents a control device according to the first control concept.
  • FIG. 3 shows a schematic block diagram which represents an opening regulation module according to the second control concept.
  • a combined cycle power plant 100 is shown. It comprises a gas turbine part 102 with two gas turbine systems 125, 126 and a steam turbine part 103 with two waste steam pistons 104, 105, which in the present exemplary embodiment are designed as so-called three-pressure steam boilers, and a steam turbine set 101.
  • a block guide 110 is present, which coordinates the coordinated one Control and regulation of the entire combined cycle power plant 100 takes over.
  • Each gas turbine plant 125 comprises a compressor 129 for sucking in and compressing ambient air, a combustion chamber section 150 downstream of the compressor 129 with at least one combustion chamber in which a mixture of supplied fuel and compressed air is ignited and burned, and a fluidic combustion chamber section 150 Downstream turbine section 130.
  • the combustion exhaust gases produced during combustion in the combustor section 150 are supplied to the turbine section 130 where they perform work under expansion and cooling which is transmitted to a gas turbine coupled generator 128 for generating electrical power.
  • the still hot exhaust gases emerging from the gas turbine plants 125, 126 are fed via exhaust ducts 127 to the waste heat boiler 104, 105 of the steam turbine plant 103.
  • each pressure stage of the waste heat boiler (each three-pressure waste heat boiler 104, 105 is equipped with three pressure stages, a high-pressure stage, a medium-pressure stage and a low-pressure stage) is generated via the supplied waste heat steam, which in the downstream turbine sections 111, 112, 113 of the steam turbine 101st work under relaxation and cooling. With the work, a generator 114 is driven to generate electric power.
  • a gas turbine control device 31 is present, which receives its power setpoint values 34 from the block guide 110.
  • the steam turbine plant comprises a steam turbine control device 115, which in the present embodiment for Execution of a pressure-based control concept is designed.
  • the steam turbine control device 115 for outputting actuating signals via signal lines 143, 144 is connected to a steam turbine partial valve 106 of the high-pressure turbine section or to a steam turbine control valve 107 of the medium-pressure turbine section 112.
  • the low-pressure turbine section 113 which in addition to the exhaust steam from the intermediate-pressure turbine stage is still supplied with steam from the low-pressure stage of the heat recovery steam generator, can be regulated via a low-pressure control flap 108.
  • the steam turbine control device 115 receives from the block guide 110 an opening command value 116 for regulating the high-pressure section turbine 111 and an opening command value 117 for regulating the medium-pressure section turbine 112. From the steam turbine system 103, the block guide 110 receives via corresponding signal lines 118, 119 the respective actual pressure (admission pressure) upstream of the steam turbine control valve 106 of the high-pressure turbine section 111 or the steam turbine control valve 107 of the medium-pressure turbine section 112. In addition, the block guide 110 receives the actual frequency of the network via a signal line 151 the current is fed from the generators 114, 128.
  • control device comprises at least one module in addition to the modules shown in FIG. 2, as shown in FIG.
  • FIG. 2 shows a control apparatus for performing power control of both the gas turbine plants 125, 126 and the steam turbine plant 103. It includes a power setpoint formation module 200 for generating the power setpoints for both the gas turbine and gas turbine engines Steam turbine, a setpoint forming module 202 for the pressure of the high-pressure stage and a conversion module 204 for converting the vapor pressure into a performance on the basis of a sliding pressure characteristic.
  • a power setpoint formation module 200 for generating the power setpoints for both the gas turbine and gas turbine engines Steam turbine
  • a setpoint forming module 202 for the pressure of the high-pressure stage
  • a conversion module 204 for converting the vapor pressure into a performance on the basis of a sliding pressure characteristic.
  • Inputs to power setpoint module 200 are the rated deviation of the line frequency from the desired frequency and the block setpoint.
  • the weighted frequency deviation is input via a frequency signal input 206, the block power setpoint via a block power signal input 208 and an adjustable block power setpoint generator 208, respectively.
  • the power setpoint module 200 includes a set point control unit 210 and a characteristics module 212, in which the characteristic of dividing the setpoint value into a steam turbine Power setpoint and a gas turbine
  • Power setpoint is stored as a function.
  • the function describes the gas turbine portion of the block power setpoint.
  • the power setpoint formation module 200 includes two higher order lag elements 214 which serve to model the time delay of the electrical power provided by the gas turbine upon a change in the block power set point.
  • Output signals of the power setpoint formation module 200 are, on the one hand, the gas turbine power setpoint 216 and, on the other hand, the steam turbine power setpoint 218.
  • the power setpoint formation module 200 includes a steam turbine module for determining the steam turbine power setpoint and a gas turbine module for determining the gas turbine power setpoint.
  • Main components of both the gas turbine module and the steam turbine module are the set point control unit 210 and the function module 212.
  • both the steam turbine module and the gas turbine module include a division unit 220 in which the gas turbine portion of the block power setpoint is divided by the block power setpoint and a multiplier in which Result is multiplied by the change in power resulting from the frequency deviation.
  • the steam turbine module and the gas turbine module are also designed as independent modules could be. In this case, the aforementioned modules would be and
  • the steam turbine module additionally comprises the two higher-order delay elements 214 in addition to the gas turbine module.
  • the conversion module 204 comprises a function module 224 in which the natural sliding pressure characteristic is stored and a division unit 226 in which the input signal of the functional unit 224 is divided by the output signal of the functional unit 224 to obtain a conversion factor for converting pressure into power.
  • the conversion factor represents an output signal of the division unit 226.
  • the setpoint generation module 202 for the live steam pressure in front of the high-pressure turbine section 111 is designed to determine a setpoint value for the steam pressure upstream of the high-pressure turbine section 111 on the basis of the output signal of the function module 224 in the conversion module 204 and the frequency deviation.
  • the setpoint value for the live steam pressure upstream of the high-pressure turbine section represents the output signal of the setpoint generation module 202 for the live steam pressure.
  • a control concept can be realized, which is based on a power-controlled steam turbine operation.
  • the steam turbine control valves are throttled to build a memory in the form of a throttle reserve. If the mains frequency deviates from the reference frequency, the throttle reserve is first activated in time, with the accumulator charging or discharging. With the timing of the steam generation of steam storage is brought back to its original state after completion of the measure. Thereafter, the turbine control valves are also back in their load-dependent throttle position.
  • the scheduled, specified by the load distributor setpoint changes are made with an adjustable gradient 1.
  • the power setpoint (block power setpoint) is divided into a gas turbine fraction and a steam turbine fraction. Since the steam turbine works in the follow-up mode, its performance also changes with the generation of steam, which depends on the load-dependent heat output from the gas turbine exhaust gas. This characteristic is stored in a characteristic curve 2.
  • the allocation of the block power setpoint to the power control of the gas turbine and the steam turbine is carried out with the aid of this function.
  • the set point for the steam turbine is delayed by the timing of the steam generation from the gas turbine power adjustment in order to coordinate the power change of the steam turbine so that it takes place only when the steam generation changes.
  • the steam storage is not claimed and is available in this way even during a change in performance of the primary control.
  • the setpoint for the live steam pressure is derived from the block power setpoint 4.
  • the Gleitdrucksollwert proportional to the steam turbo additional power is limited to a lower 5 and an upper 6 fixed pressure value.
  • the sliding pressure setpoint 7 is to be set so that the control valves are fully opened in steam turbine operation.
  • To obtain the power reserve necessary to provide the primary control place the turbine valves in the throttle position to build up a reservoir. This is achieved by transition to the modified Gleittik compassion, ie by raising the sliding pressure characteristic.
  • the required pressure difference ( ⁇ p) 8 depends on the predetermined primary control reserve and the time behavior of the steam generation. For block power changes, an additional power 9 is calculated in the sliding pressure range in order to obtain the necessary vapor pressure change.
  • the power setpoint for the gas turbine must be overdriven or understeered in order to influence the generation of steam via the path of the gas turbine waste heat. sen.
  • the sliding pressure setpoint generated from the block power setpoint and limited upwards and downwards is still dynamically adjusted to correspond to the time response of the steam generation 10 and the storage time behavior 11.
  • the subsequent comparison of this dynamic pressure setpoint with the measured live steam pressure results in a control difference which is superposed with a gain 12 superimposed on the power setpoint.
  • the operating mode of the turbine controller remains in power control mode.
  • the primary control changes the block performance in the second range.
  • the change in the power output due to the weighted frequency deviation 13 takes place independently in the systems involved.
  • the evaluation is carried out with the system-specific proportionality factor (statics or K x ⁇ f) and is applied to the block power setpoint without delay.
  • K x ⁇ f system-specific proportionality factor
  • the reaction time of the gas turbine to a sudden change in load takes longer than in the steam turbine, which can follow faster within the setting speed of the turbine control valves and bridges the time delay of the gas turbine.
  • the storage tank of the waste heat boiler is discharged or charged.
  • a frequency reduction the evaluated deviation (K x .DELTA.f) completely and instantaneously switched to the power setpoint of the steam turbine 14. At frequency reduction, it reacts immediately with a corresponding opening of the turbine control valves and the following increase in the generator power, resulting in the storage of
  • the modules used to form the desired power values, the dynamic pressure setpoint and the additional power which are designed as circuits in the present exemplary embodiment, are free of feedback and contain only intrinsically stable structures. Instead of circuits, the modules can also be designed as software modules.
  • the control described with reference to FIG. 2 is designed to regulate the live steam pressure in the high-pressure turbine part 111.
  • a further desired value formation module such as the module 202, which is assigned to a further sub-turbine, for example the medium-pressure sub-turbine 112
  • Partial turbine 112 is determined and output. In principle, a separate pre-pressure setpoint can be determined for each sub-turbine.
  • the control device or regulation described with reference to FIG. 2 is based on a power-controlled steam turbine operation.
  • the underlying control method can also be implemented with a closed-loop control concept based on the regulation of the opening of the steam turbine control valves.
  • the control concept is then composed of the modules shown in FIG. 2 and in FIG. 3, which are designed as circuits in both embodiments. However, instead of circuits, the two modules can also be designed as software modules.
  • the mode of operation of the turbine controller i.e., the steam turbine regulator 115 in Fig. 1
  • the mode of operation of the turbine controller is the regulation of the valve opening of the control valves.
  • the formation of the steam turbine opening setpoint takes place on the basis of the steam turbine power setpoint value, the conversion factor from the conversion module 204 and the setpoint value of the live steam pressure to be obtained from the live steam module 202, and is illustrated in FIG.
  • the opening control module 300 shown in FIG. 3 comprises a multiplication unit 302 which receives the live steam pressure setpoint from the live steam module 202 of FIG. 2 and the conversion factor from the conversion module 204 of FIG. Furthermore, the opening control module 300 comprises a division unit 304 to which the steam turbine power setpoint from the power setpoint module 200 as a counter and the result of the multiplication in the multiplication unit 302 as a denominator.
  • the result of the division in the division unit 304 is fed to a further multiplication unit 306 with the aid of which the result of the division is converted in a percentage.
  • a limiting unit 308 connected downstream of the second multiplication unit 306 ensures that the result of the multiplication in the multiplication unit 306 does not exceed the value 100% and does not fall below the value 0%.
  • the thus-limited multiplication result is output to a characteristic module 310 which converts the embedded multiplication result based on the characteristic into an opening target value for the steam turbine control valves, which is the output of the opening target value module 300.
  • the formation of the steam turbine opening setpoint value thus takes place with the aid of the division of the steam turbine power setpoint value in megawatts by the setpoint value for the live steam pressure, which is converted into electrical power.
  • the resulting ratio is multiplied by the factor 100% and serves in this way, limited to the range 0% to 100%, as a linear opening setpoint for the steam turbine control valves.
  • the characteristic curve for the control valve characteristic is stored in the turbine controller. Any deviations from this can be subsequently adjusted via a function generator.
  • Table 1 shows the distribution of the control power reserve to the individual turbine sets together with the achievable base load for the system without and with the control method according to the invention.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)
  • Control Of Turbines (AREA)

Abstract

L'invention concerne un procédé et un dispositif de production d'une puissance de régulation au moyen d'un système combiné (100) de turbine à gaz et de turbine à vapeur, comportant au moins une turbine à gaz (130) et au moins une turbine à vapeur (111). La puissance électrique produite par le système de turbine à gaz et de turbine à vapeur est distribuée à un réseau fonctionnant à une fréquence réseau. Selon l'invention, la turbine à vapeur (11) participe à une régulation de fréquence pour le maintien de la fréquence de consigne ; une réserve de régulation est conservée pour la turbine à vapeur (111) ; et, en cas d'écart de la fréquence réseau par rapport à la fréquence de consigne, une puissance de régulation positive ou négative est distribuée au réseau, celle-ci étant au moins partiellement produite par chargement ou déchargement de la réserve de régulation. Le chargement ou déchargement de la réserve de régulation permet d'obtenir une répartition coordonnée de la puissance de régulation sur la turbine à gaz (130) et la turbine à vapeur (111).
EP06725082A 2005-03-18 2006-03-15 Procede et dispositif de production d'une puissance de regulation au moyen d'un systeme combine de turbine a gaz et de turbine a vapeur Withdrawn EP1861586A2 (fr)

Applications Claiming Priority (2)

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DE102005012671 2005-03-18
PCT/EP2006/060765 WO2006097495A2 (fr) 2005-03-18 2006-03-15 Procede et dispositif de production d'une puissance de regulation au moyen d'un systeme combine de turbine a gaz et de turbine a vapeur

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EP1861586A2 true EP1861586A2 (fr) 2007-12-05

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EP (1) EP1861586A2 (fr)
CN (1) CN101142375B (fr)
WO (1) WO2006097495A2 (fr)

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EP2450535A1 (fr) 2008-06-27 2012-05-09 Alstom Technology Ltd Procédé de régulation primaire d'une centrale à cycle combiné
IT1398631B1 (it) * 2009-08-10 2013-03-08 Ansaldo Energia Spa Metodo e dispositivo di controllo per controllare un impianto a ciclo combinato e impianto a ciclo combinato
DE102011078195A1 (de) * 2011-06-28 2013-01-03 Siemens Aktiengesellschaft Sollwertanpassung bei einem Dampfkraftwerk
DE102011078205A1 (de) * 2011-06-28 2013-01-03 Siemens Aktiengesellschaft Hilfsdampferzeuger als zusätzliche Frequenz- bzw. Primär- und/oder Sekundärregelmaßnahme bei einem Dampfkraftwerk
EP2568128B1 (fr) 2011-09-07 2016-04-06 Alstom Technology Ltd Procédé destiné au fonctionnement d'une centrale électrique combinée
EP2592241A1 (fr) * 2011-11-14 2013-05-15 Siemens Aktiengesellschaft Procédé de fonctionnement d'une installation de turbine à gaz et à vapeur pour la stabilisation de fréquence
DE102012204218A1 (de) * 2012-03-16 2013-09-19 Siemens Aktiengesellschaft Leistungsregelung und/oder Frequenzregelung bei einem solarthermischen Dampfkraftwerk
EP3192985A1 (fr) * 2016-01-18 2017-07-19 General Electric Technology GmbH Procédé pour faire fonctionner une centrale électrique et ladite centrale électrique
CN108565854B (zh) * 2018-04-20 2024-01-23 华北电力科学研究院有限责任公司 用于复现电力系统频率特性的模拟方法及系统
WO2019236193A1 (fr) * 2018-06-04 2019-12-12 Wellhead Power Solutions, Llc Système et procédé énergétique hybride
US11591955B2 (en) 2018-06-22 2023-02-28 Siemens Energy Global GmbH & Co. KG Method for operating a power plant
DE102018212876A1 (de) * 2018-08-02 2020-02-06 KSB SE & Co. KGaA Steuerungsverfahren für Maschine mit umrichterbetriebenem elektrischem Antrieb
CN110162870B (zh) * 2019-05-16 2022-10-28 苏州西热节能环保技术有限公司 一种基于季节的节流调节汽轮机最优滑压曲线确定方法
CN112003300B (zh) * 2020-08-18 2024-07-19 国网天津市电力公司电力科学研究院 燃气蒸汽联合循环型式汽轮机组参与电网一次调频的方法

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CN101142375B (zh) 2010-05-26
WO2006097495A2 (fr) 2006-09-21
CN101142375A (zh) 2008-03-12
WO2006097495A3 (fr) 2007-04-26

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