KR20130069333A - Calculation method of generator's real time supply capacity - Google Patents

Calculation method of generator's real time supply capacity Download PDF

Info

Publication number
KR20130069333A
KR20130069333A KR1020120095115A KR20120095115A KR20130069333A KR 20130069333 A KR20130069333 A KR 20130069333A KR 1020120095115 A KR1020120095115 A KR 1020120095115A KR 20120095115 A KR20120095115 A KR 20120095115A KR 20130069333 A KR20130069333 A KR 20130069333A
Authority
KR
South Korea
Prior art keywords
value
gas turbine
turbine
supply capability
steam turbine
Prior art date
Application number
KR1020120095115A
Other languages
Korean (ko)
Other versions
KR101423191B1 (en
Inventor
이범제
Original Assignee
이범제
(주)아이피티씨
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 이범제, (주)아이피티씨 filed Critical 이범제
Priority to KR1020120095115A priority Critical patent/KR101423191B1/en
Publication of KR20130069333A publication Critical patent/KR20130069333A/en
Application granted granted Critical
Publication of KR101423191B1 publication Critical patent/KR101423191B1/en

Links

Images

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01D—NON-POSITIVE DISPLACEMENT MACHINES OR ENGINES, e.g. STEAM TURBINES
    • F01D17/00—Regulating or controlling by varying flow
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C9/00—Controlling gas-turbine plants; Controlling fuel supply in air- breathing jet-propulsion plants
    • 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
    • Y02E20/14—Combined heat and power generation [CHP]
    • 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]

Landscapes

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

Abstract

The present invention relates to a method for estimating supply capability of a real-time generator. More specifically, the present invention relates to a method for estimating a supply capability of a real-time generator by using a signal of parallel in- , The rotor rotor contamination degree, etc., and then a method for estimating the supply capability of the generator in real time.

Description

{CALCULATION METHOD OF GENERATOR'S REAL TIME SUPPLY CAPACITY}

More particularly, the present invention relates to a method for determining the availability of electric power by utilizing a signal of parallel in-line (Synchronizing) The present invention relates to a method for estimating electric power supply capability of a generator in real time after actual measurement of atmospheric pressure, humidity, compressor rotor contamination, and the like.

In order to estimate the supply capacity of the combined cycle power gas turbine generator in the electric power demand management, the power generation company predicts the electric power supply capacity of the generator with reference to the weather forecast (temperature) and the generator condition one day before, .

However, in the current demand management system predicted the day before, the reliability of forecasting the generator capacity is inevitably low, and the larger the error of the weather forecast (temperature) is, the more likely it is due to the characteristics of the gas turbine generator The accuracy of the ability is inevitable. As a result, the forecasted supply capacity bidded on September 15, 2011 was 1,170 MW less than the actual supply capacity, resulting in a great social problem of the nation's cyclical blackout, which caused enormous obstacles to the lives of the people.

Combined-Cycle Gas Turbines are heavily influenced by atmospheric temperature because of the density of the air. When the atmospheric temperature rises, the air density decreases and the output decreases. When the temperature rises by 1 ° C, the output decreases by about 0.7% to 1.0%.

Electricity trading with the KPX should be bidded one day before. The bid price should be bidded by reflecting the supply capacity (output) of the generator according to the atmospheric temperature fluctuation as the highest temperature, middle temperature and lowest temperature of Meteorological Agency. And the accuracy of the bidder 's subjective is reflected.

In order to understand the above problems, the combined-cycle power generator and the generator will be described in more detail as follows.

Combined cycle thermal power plant is the process of generating electricity (primary power generation) that drives the gas turbine by using the gas generated in the combustion process of energy (power generation fuel), and then the waste heat from the gas turbine Is a thermal power generation method in which the boiler is heated using the steam generated from the boiler, and the steam is generated again (secondary power generation). More specifically, it refers to the combination of two types of thermal cycles to improve thermal efficiency. A method for recovering a part of a large amount of heat remaining in the exhaust gas (over 500 ° C.) discharged from the gas turbine to the atmosphere as a primary source of electricity by using a Brayton Cycle which is a gas turbine cycle The exhaust gas is sent to a Heat Recovery Steam Generator (HRSG) to generate steam, which is then returned to the steam turbine (Rankine Cycle). An overall schematic diagram of a combined cycle power plant is shown in FIG.

First, the thermal efficiency of the gas turbine of a combined-cycle power generator is examined. The basic cycle of the gas turbine, the Brayton Cycle, sucks air from the compressor and sends it to the combustor. The combustor combusts the fuel with the fuel to a certain temperature 2, which is used as a driving source for driving the compressor, and a part of the obtained work is used for driving the compressor.

2 is a process of adiabatically compressing atmospheric pressure P 1 from a compressor to P 2 (adiabatic compression) in FIG. 2, and steps 2 and 3 are steps of supplying fuel to a combustor to burn (Q 1 ) process (constant pressure heating), and 3-4 process the step of adiabatic expansion in the turbine (adiabatic expansion), and 4-1 process the process is an exhaust gas (Q 2) from the turbine to a pressure P 1 that is released to the atmosphere (static-pressure Heat radiation). More specifically, the relation between the Brayton Cycle and thermal efficiency is Q 1 (kcal / kg), Q 2 (kcal / kg), Q 1 ~ Q 2 If the amount of air absorbed in one second is W (kg) and J is energy unit Joule, the output Ne (unit HP) is

Figure pat00001

.

When the specific heat of static pressure is C p , the supply heat Q 1 and the heat release heat Q 2

Figure pat00002

Figure pat00003

, The theoretical thermal efficiency

Figure pat00004
The

Figure pat00005

, Where the specific-pressure specific heat C p is independent of temperature

Figure pat00006
And,
Figure pat00007
The

Figure pat00008

.

Here, pv = RT where p is the pressure, v is the specific volume, R is the gas constant, and T is the absolute temperature, and at the adiabatic change of 1 to 2 and 3 to 4,

Figure pat00009
And the compression ratio (Pressure Ratio)
Figure pat00010
Lt; / RTI >

Figure pat00011

, Where P 2 = P 3 and P 1 = P 4 ,

Figure pat00012

to be. Where T 1 is the outside temperature and T 2 is the compressor outlet temperature. As can be seen from the equation, the higher the compression ratio, the higher the efficiency, and the higher the compression ratio, the higher the T 2 . In the end, raising T 2 means that you have to do that much, but on the other hand, it will reduce the work (which means electric output in power plants). Therefore, it is necessary to determine T 2 which is optimum (work and efficiency) in a given facility.

As can be seen from the above equation, the thermal efficiency of the Brayton Cycle is higher as the compression ratio Pr is higher, and it is independent of the turbine inlet temperature. However, what affects the actual thermal efficiency is the temperature of the combustion gas at the turbine inlet, and the higher the temperature, the higher the thermal efficiency. The temperature of the combustion gas at the inlet of the turbine can not be increased arbitrarily, and the most suitable inlet temperature of the turbine is determined for the performance of the heat resistant material, the strength of the bucket and the given compression ratio. Other factors that affect the thermal efficiency include flow resistance in compressors, combustors, and turbines, mechanical losses, heat loss, and so on. Consequently, the performance of the gas turbine depends mainly on the air flow rate, the compression ratio, and the gas temperature at the turbine inlet. 3 shows the definition of the gas turbine inlet temperature.

In order to know the relation between the air flow rate, the compression ratio, and the gas temperature at the inlet of the turbine, which determines the performance of the gas turbine, it means a unit output per kilogram of the working fluid. If we look at the non-output, let i denote the enthalpy, and denote the non-output w in terms of heat units as follows:

Figure pat00013

, And the mean specific-pressure specific heat

Figure pat00015
In other words,

Figure pat00016

Figure pat00017
Because of,

Figure pat00018

Figure pat00019

Figure pat00020

Figure pat00021

to be.

As in the above equation, the specific power is affected by the compression ratio and the maximum and minimum temperature ratios (turbine inlet temperature and compressor inlet temperature ratio). The relationship between the output power and the compression ratio is that if the compression ratio is increased, the efficiency is continuously increased, but the non-output becomes the maximum value at a certain compression ratio, and the non-output becomes lower at the maximum value and below.

The factors affecting the performance of the gas turbine are Ambient Air Temperature, Barometric Pressure, Site Elevation, Humidity, Inlet & Exhaust Loss, Fuel Fuels, water or steam inflow, air extraction, operation time, compressor pollution, etc. The influence of these factors will be described in detail as follows.

In the case of Ambient Air Tem- perature, the compressor draws a certain volume of air regardless of the ambient temperature, but if the ambient temperature is lower, the air density increases and the mass flow of the incoming air increases. Because of this, the combustor must be heated to a constant turbine inlet temperature, so the fuel consumption increases, eventually increasing the turbine output, and the power increase effect is greater than the fuel consumption increase, so the heat consumption rate decreases as the ambient temperature decreases. In general, when the temperature is raised by 10 ° C from the reference temperature of 15 ° C, the output is reduced by 6.7%, the exhaust gas amount is reduced by 4.0%, and the efficiency is reduced by 1.3% (W501D5 actual value).

Barometric pressure and altitude (Site Elevation) affect gas turbine performance in much the same way as atmospheric temperature. As air pressure increases, air density increases, resulting in an increase in mass flow through the turbine The output rises, but there is little change in the heat consumption rate because the effect of increase in fuel consumption and output rise are the same. Generally, when the atmospheric pressure is increased by 10 mmbar, the gas turbine output and the exhaust gas amount are increased by 1.0%, but there is no efficiency variation. In the high altitude case, when the altitude is increased by 100m, the density of the intake air is reduced, and the gas turbine output and the exhaust gas amount are decreased by 1.03%, but there is no efficiency variation.

In the case of humidity, wetness affects not only the mass flow rate of the intake air but also the enthalpy change, which affects the output and the heat consumption rate. As environmental regulations become more stringent, the effect of direct injection of water or steam on the gas turbine to reduce the amount of NOx in the gas turbine is affected by the humidity. In general, the performance data or calibration curve is based on relative humidity (principle should be absolute humidity), the amount of moisture per kg of air at an ambient temperature of 15 ° C at 60% relative humidity is 0.0064 kg, 0.15% Output reduction and efficiency of 0.35%.

For inlet and exhaust losses, inlet system components such as inlet filters, evaporative coolers, chillers, silencers, and components of the exhaust system that increase the backpressure of the gas turbine, such as batch recovery boilers, Resulting in performance degradation. Generally, the output of the gas turbine inlet conduit (Duct) was reduced by 1.4% and efficiency by 0.5% for every 100 mm H 2 O, and by increasing the exhaust pressure of 100 mmH 2 O, the gas turbine output decreased by 0.5% and the efficiency increased by 0.5% .

Compressor Air Extraction is used for cleaning the stator and rotor, as well as in the cleaning air of the inlet filter and in various applications. Air extraction of less than 5% is possible without improvement of the gas turbine installation. However, as the extraction amount of compressed air increases, the output and efficiency decrease. In general, 1% extraction of compressed air results in an output loss of 2%, so air extraction above the design limit will require equipment improvements.

In the case of compressor contamination, blade contamination and damage reduce both compressor flow rate and efficiency, reduce gas turbine power and increase the rate of heat consumption. At the same time, the compressor pressure ratio is lowered due to the reduction of the mass flow rate through the turbine nozzle. Particles of 20 microns or larger have a deterioration in performance due to their high corrosion rate, while particles below 10 microns do not cause excessive erosion. Typically, when contaminated to a 5% loss range of air flow rate, the output is reduced by 13%, the heat consumption rate is increased by 6%, and the pressure ratio is reduced by 5.5%. Compressor contamination is typically caused by the ingestion of sticky materials such as oil vapor, soot, and salt, and typically 70 to 85 percent of the performance loss is due to compressor blade contamination. Regular monitoring and recording of pressure ratio, output, and heat consumption rate are valuable data for diagnosing compressor performance degradation. However, effective maintenance can be achieved only through actual cleaning experience with proper performance record keeping. .

As to the rated load of the gas turbine, the rating of the gas turbine is generally rated according to ISO (International Standard Organization) standard condition 2314, which is defined as an ambient temperature of 15 ° C, an atmospheric pressure of 1.013 bar, and a relative humidity of 60% do. When defining the gas turbine rating, the term varies depending on the manufacturer, but generally two ratings are defined. The output that can be taken at the design inlet temperature, which is capable of continuous operation, is called the base load rating (Normal Rating or Base Load Rating) The output that can be taken at the inlet temperature one step higher than the load rating is called the Peak Rating.

Some authors also define a third rating for output at higher temperatures called Maximum Peaking or System Reserve. However, the operating hours of this year are strictly limited.

As for the heat recovery steam generator (HRSG), the arrangement recovery boiler is a facility for recovering waste heat generated from a gas turbine to generate steam. In a combined-cycle power plant, a gas turbine It is located at the point of contact between the cycle and the steam turbine cycle on the steam side, and is an important device that converts the thermal energy of the steam into the thermal energy of the steam using the heat energy of the gas turbine exhaust gas. The performance of the batch recovery boiler is shown as efficiency, and the efficiency is obtained by the ratio of the emission to the heat input. The emission amount is the amount of heat absorbed by the working fluid of the batch recovery boiler and the heat input amount is the sum of the heat amount by the combustion of the heat amount auxiliary fuel supplied by the gas turbine exhaust gas and the amount of heat applied to the other boiler.

Figure pat00022

The efficiency of the boiler can also be obtained by calculating various heat losses in the boiler.

Figure pat00023

As the temperature of exhaust gas from the exhaust outlet of the boiler is lowered, the efficiency of the batch recovery boiler is increased but a large heat transfer area is required and the equipment cost is increased. When the exhaust gas of sulfur containing fuel is supplied, The outlet exhaust gas temperature is regulated. Generally, in the case of gaseous fuel, the exhaust temperature of the exhaust gas at the exit of the batch recovery boiler is about 100 ° C., and in the case of heavy oil combustion, it varies depending on the concentration of SOx in the exhaust gas. There are two definitions of boiler efficiency: latent heat of steam in exhaust gas, heat input (HHV), and heat input (LHV). However, in thermal power plants, There are many cases where the plant efficiency is defined.

The relationship between the steam temperature and the pressure of the batch recovery boiler is generally such that when the generated steam temperature is designed to be high, the generated steam flow decreases, but the output of the steam turbine increases, thereby improving the output and efficiency of the entire plant. However, when the steam temperature is increased and the difference from the exhaust gas is small, a larger heat transfer area is required in the batch recovery boiler, and the gas turbine exhaust gas temperature changes as the gas turbine load, the atmospheric temperature and the atmospheric pressure change. Since the steam temperature also changes accordingly, it is necessary to determine the design steam temperature so as to allow the steam temperature to fall within the allowable range of the thermal stress on the steam turbine in consideration of normal and external conditions of the plant.

When the steam pressure rises, the efficiency of the batch recovery boiler is lowered because the amount of generated steam is reduced and the amount of heat exchanged is reduced as the other conditions are the same. However, since the steam condition as the steam turbine is improved, In consideration of the efficiency of the combined-cycle power plant, there is a pressure at which the thermal efficiency becomes maximum, but this varies depending on various conditions.

In actual boiler recovery boiler, it is general to set the high pressure main steam pressure at 50 ~ 80 ata and 40 ~ 50 ata in double pressure type considering the humidity of the final stage of steam turbine.

The relationship between steam temperature and pressure, the relationship between the inlet exhaust gas temperature and the main air temperature, the pinch point temperature difference and the approach point temperature difference, the gas turbine outlet exhaust gas Temperature, gas turbine outlet exhaust gas flow, IGV (Inlet Guide Vane) control, multiple temperature, and the like.

In detail, how the factors influencing the performance of the batch recovery boiler influences,

Generally, in case of the steam temperature and pressure, if the generated steam temperature is designed to be high, the generated steam flow rate is decreased, but the electric power of the steam turbine is increased to improve the output and efficiency of the whole plant. However, If the temperature difference is small, a larger heat transfer area is required in the batch recovery boiler, and the exhaust gas temperature at the exit of the gas turbine changes correspondingly with changes in gas turbine load, atmospheric temperature and atmospheric pressure. Change. Therefore, considering the normal and external conditions of the plant, it is necessary to determine the design steam temperature so that the steam temperature can fall within the allowable range of the thermal stress on the steam turbine. If the steam pressure rises, The efficiency of the batch recovery boiler is lowered, but the efficiency of the steam turbine is improved because the steam condition is improved and the steam of higher heat is supplied. Considering the efficiency of a combined power plant, there is a pressure that maximizes the thermal efficiency, but this changes according to various conditions. In actual batch recovery boilers, considering the humidity of the final stage of the steam turbine, Is generally from 50 to 80 ata, and in the case of the short-circuit pressure, it is usually about 40 to 50 ata.

In the case of the relationship between the inlet exhaust gas temperature and the main air temperature, the temperature difference between the inlet exhaust gas temperature and the main steam temperature is a major design variable when designing the batch recovery boiler. This temperature difference is the difference between the exhaust gas and the steam of the batch recovery boiler It is a variable indicating the amount of heat exchange. A thermodynamically small temperature difference means that the heat absorbed by the superheater is high. However, in order to increase the main steam temperature, the heat transfer area in the superheater must be increased. Generally, the difference between the inlet exhaust gas temperature and the main air temperature is determined in consideration of the heat transfer area and the investment cost in the batch recovery boiler manufacturer.

The temperature difference between the pinch point and the approach point is a very important factor in the design of the batch recovery boiler. The pinch point temperature difference is the temperature difference at which the temperature difference between the exhaust gas and the water or the steam becomes smaller. In a normal arrangement recovery boiler, the point is the point of the evaporator outlet. The approach point temperature difference means the pressure in the drum It is the difference between the equivalent saturation temperature and the temperature difference of the salvage outlet temperature. If the temperature difference between the pinch point and the approach point is small, the generated steam increases and the boiler efficiency increases. However, when the load of the gas turbine is lowered, both the pinch point temperature difference and the approach point temperature difference In particular, when the access point is low, steam phenomenon may occur in the absorber at the time of low-speed operation or start-up. Therefore, in recent years, the two design standards In particular, a method of reducing the steam phenomenon by forcibly raising the saturation temperature by installing the low-pressure feedwater control side at the steam drum inlet side, or recycling the feeder water used in the vertical mode is also adopted. Lowering the PPT (Pinch Point Temperature) increases the overall heat recovery but requires more heat exchanging surface area, resulting in increased equipment costs and increased ventilation loss on the gas side. The PPT change is proportional to the gas flow rate and the gas temperature. Generally, the high efficiency steam cycle is designed for PPT in the range of 8 to 14 ° C. For a somewhat lower design, it is in the range of 15 to 20 ° C and AT (Approach Temperature) The evaporation amount is increased, but the equipment cost and the ventilation loss are increased. If AT is increased, the heat transfer area of the evaporator portion is increased, but stable operation is possible because the possibility of evaporation at the bottom is reduced. Figure 4 is a typical pinch & access point diagram.

In the case of the gas turbine outlet exhaust gas temperature, as the exhaust gas temperature at the gas turbine outlet increases, the efficiency of the batch recovery boiler increases because the amount of heat absorbed by the batch recovery boiler increases, but the rise of the gas turbine outlet exhaust gas temperature means that the gas Which means that the efficiency of the turbine is lowered. Generally, as the exhaust gas temperature increases, the steam flow rate generated from the batch recovery boiler increases, while the efficiency of the combined cycle increases as the exhaust gas temperature becomes lower.

As the flow rate of exhaust gas at the outlet of the gas turbine increases, the flow rate of steam generated at the same heat transfer area increases as the flow rate of exhaust gas increases. As a result, the steam flow rate of the high pressure, reheat, medium pressure and low pressure steam is increased, The efficiency of the batch recovery boiler is improved.

In the case of the IGV (Inlet Guide Vane) control, the IGV opening is controlled at the partial load to increase the HRSG efficiency at a high exhaust temperature setting.

In the case of the plurality of temperatures, the lower the plurality of temperatures, the more heat is recovered in the batch recovery boiler, so that the efficiency of the batch recovery boiler increases, but the heat transfer area must be increased even if the efficiency is increased. On the other hand, the lower the steam temperature, the higher the steam temperature. Generally, when a plurality of feeds are supplied, a plurality of recirculating heat is supplied to the batch recovery boiler at a plurality of elevated temperatures. When a plurality of low temperatures are supplied, low temperature corrosion due to sulfur components occurs on the heat transfer surface of the boiler. Should be supplied.

In order to investigate the thermal efficiency of the steam turbine, the Rankine cycle, which is the basic cycle of the steam turbine, is a theoretical reversible cycle consisting of two isothermal and two adiabatic processes, The most basic cycle of a power plant that uses steam as a working fluid is a cycle in which the ideal cycle of a carnot cycle is adapted to a steam turbine.

Analysis of the thermal cycle process of Figures 5 and 6,

6 ~ 1 is a process of transferring the mechanical energy to the outside by rotating the turbine while expanding the steam in the turbine due to the thermal expansion process.

1 and 2 are isothermal contraction processes due to the phase change of the medium (steam → water) because the latent heat of vapor is discharged to the outside by the isothermal contraction process,

2 ~ 3 is a process of water pressing in a water pump by adiabatic compression process,

3 ~ 4 is a process in which the water in the drum is heated by the boiling water heating by boiling water by equipotential heating process, and the saturated water turns into wet steam at the interface between water and steam in the drum.

4 ~ 5 are isothermal expansion processes, which are in the form of wet steam in the steam trap of the upper drum,

5 ~ 6 show the process of equilibrium process in which the humid air is reheated from the inlet of the superheater to the superheater and the temperature increases to the dry saturated vapor and the superheated steam is present at the outlet of the superheater.

The thermal efficiency relationship of the cycle is Q 1 in the TS diagram of Fig. 5, that is, 1-2-3-4-5-6 is the quantity externally worked, Q 2 is the area 1-1 "-2-2" Is the heat released from the latent heat of the steam to the outside. Therefore, when i = C p T, the thermal efficiency

Figure pat00024
silver

Figure pat00026

Figure pat00027

.

Referring to the condenser shown in the first to second steps of FIG. 4 in the Rankine cycle of the steam turbine,

Steam Condenser means that after the Lancin cycle has been promoted, the exhaust gas from the prime mover is condensed into cooling water without throwing it into the atmosphere, thereby increasing the thermal efficiency and reusing it as a boiler feedwater. And it contributes to the stable recovery of the efficiency of the high power generation facility while keeping the back pressure of the turbine at a low pressure close to the vacuum. The condenser is a kind of cross-flow shell-tube type heat exchanger that absorbs the latent heat of the turbine exhaust while the turbine exhaust condenses while flowing on the Shell side and the cooling water flows on the inside side of the tube. The condensed water flowing on the Shell side is collected in the condenser hotwell and recirculated. The cooling water whose temperature has risen through the tube is cooled through the cooling tower and then recycled or discharged to the outside. The exhaust of the turbine flowing into the condenser is in a wet state The specific volume change due to vapor condensation in the condenser is about 30,000: 1 because the condensate is about 467 ft3 / lbm (0.7 psia) and the condensed water volume after condensation is 0.0161 ft3 / lbm. Accordingly, It is possible to maintain a low pressure close to the vacuum. In steam power plants, combined power plants, and nuclear power plants, where steam is used in power generation facilities, these condensers are important facilities, and their role and weight are very large.

Among the factors affecting the performance of the condenser, the degree of vacuum of the condenser has the greatest influence on the performance of the condenser. Accordingly, maintaining the vacuum appropriately maintains the efficiency of the power plant, and there is an efficiency curve according to the degree of vacuum for each power plant.

After working in the turbine, the steam is condensed from the condenser into water and returned to the batch recovery boiler, which is then converted to steam by heat from the batch recovery boiler. If the water from the condenser to the batch recovery boiler has heat, the calories from the boiler will be reduced. This reduction in the amount of heat consumed by the water heater and the boiler will improve cycle efficiency. Thus, preservation of heat in the condenser improves efficiency in the cycle, but heat must be removed from the steam in order to condense the vapor, which means that the performance (efficiency) is to balance between these two purposes, And the remaining heat is saved. Figure 7 is a T-S diagram of the open and closed Landkill cycle.

Lastly, explaining the district heating heat exchanger, in the case of general thermal power generation, a large amount of the energy input is lost in the condenser. In the case of cogeneration, however, most of the heat lost in the condenser is used for process and heating, The heating steam is supplied to the district heating heat exchanger, and the district heating water is heated, collected in the heat exchanger plural storage tank and recovered to the deaerator by the drain pump. The district heating water is heated to about 65 ° C by the heat exchanger And the heat is supplied to the heat consumer by the high temperature water of about 75 ~ 120 ° C. through the heat exchange. The higher the temperature of the feed water and the higher the flow rate, the more heat is supplied. The heat storage tank and the auxiliary boiler are installed on the district heating side in case of an emergency.

The role of the storage tank

1) In the cogeneration operation, the surplus heat is stored during the normal operation,

2) During the emergency boiler operation,

3) Prevent boiling of hot water in pipe network by header pressure

4) Absorption of local heating water volume change by temperature change

5) The temperature of the heat storage tank is kept at about 95 ~ 98 ℃ which is usually below the boiling point.

to be.

As can be seen from the above description, it can be seen that the factors determining the supply capability of the generator are greatly influenced by the atmospheric temperature, the atmospheric pressure, and the humidity. In estimating the power supply capacity demanding precise accuracy, It can be seen that there is a limit in the conventional supply capacity calculation method.

Domestic registered patent KR10-0752765 (Registration date 2007.08.29) Korean Patent Publication No. KR2009-0121248 (published on November 25, 2009) Domestic registered patent KR10-0840101 (Registered on June 14, 2008)

As described above, the present invention is to overcome the problem of the conventional method of estimating the supply capacity of the generator, which reflects only the weather forecast of the weather station. The object of the present invention is to provide a method of estimating the supply capacity of a real time generator.

In order to accomplish the above object, the present invention provides a real-time generator supply capacity calculation method, comprising: measuring a final supply capacity value of a gas turbine by measuring a variable affecting an output capacity of the gas turbine in real time; Estimating a final feed capability value of the steam turbine to a final feed capability value of the gas turbine; Calculating a supply capacity value of the generator in real time by summing a final supply capacity value of the gas turbine and a final supply capacity value of the steam turbine; Characterized in that it comprises a.

Wherein the number of the gas turbines is at least one in the step of measuring variables affecting the output capacity of the gas turbine in real time and calculating a final supply capability value of the gas turbine.

Wherein the step of measuring a variable affecting the output capacity of the gas turbine in real time and calculating a final supply capability value of the gas turbine comprises: determining whether a compression ratio performance correction curve of the gas turbine exists or not, And calculating a gas turbine supply capability value according to the gas turbine supply capability value.

Wherein the gas turbine supply capability value is obtained by calculating a compressor outlet pressure value of the gas turbine when the compression ratio performance correction curve exists and correcting the calculated compressor outlet pressure value through the compression ratio performance correction curve, And if the correction curve does not exist, the correction value of the measured variables in real time and the sum of the compressor rotor tooth contamination value of the gas turbine are obtained, and the sum value is multiplied by the rated load value of the gas turbine .

The step of measuring the parameters affecting the output capacity of the gas turbine in real time and calculating the final supply capability value of the gas turbine includes the step of correcting the supply capability value of the gas turbine according to the operating state of the gas turbine .

Wherein the step of correcting the supply capability value of the gas turbine according to the operating state of the gas turbine includes determining whether or not a compression ratio performance correction curve of the gas turbine exists when the gas turbine is in the normal operation state, And setting the output capacity of the current gas turbine to a value of the supply capacity of the gas turbine until the gas turbine is switched to the normal operation state when the gas turbine is in an abnormal operating state, And FIG.

The step of correcting the supply capability value of the gas turbine may include: when the gas turbine is switched from the abnormal operation state to the normal operation state, the operator operates the Clear button in the human machine interface (HMI) To a value calculated according to the presence or absence of the compression ratio performance correction curve.

Wherein the step of measuring variables affecting the output capacity of the gas turbine in real time and calculating a final supply capability value of the gas turbine comprises calculating a value obtained by correcting the supply capability value of the gas turbine according to the operating state of the gas turbine, And setting a small value as a final supply capability value of the gas turbine.

Wherein the step of calculating the final supply capability value of the steam turbine based on the final supply capability value of the gas turbine is a step of calculating a final supply capability value of the gas turbine by subtracting a value obtained by converting the amount of supply of the local heat- And calculating a supply capacity value of the steam turbine by summing values obtained by correcting output values according to the degree of vacuum of the condenser of the steam turbine.

And a value obtained by correcting the final supply capability value of the gas turbine when the number of the gas turbines is two or more is a value obtained by summing up values obtained by correcting the final supply capability value of each gas turbine.

The step of calculating the final supply capability value of the steam turbine with the final supply capability value of the gas turbine includes the step of correcting the supply capability value of the steam turbine according to the operation state of the steam turbine.

Wherein the step of correcting the supply capacity value of the steam turbine according to the operating state of the steam turbine includes the step of adjusting the supply capacity value of the steam turbine to a value obtained by correcting the final supply capability value of the gas turbine when the steam turbine is in a normal operation state, Summing a value obtained by subtracting the converted value and a value obtained by correcting the output value according to the degree of vacuum of the steam turbine, and setting the sum as a supply capacity value of the steam turbine. When the steam turbine is in an abnormal operation state, And setting the output capacity of the current steam turbine as the supply capacity value of the steam turbine until the steam turbine is switched to the normal operation state.

When the steam turbine is switched from the abnormal operation state to the normal operation state, the operator operates the Clear button in the human machine interface (HMI) to adjust the supply capability value of the steam turbine to the corrected value of the final supply capability of the gas turbine And converting the value obtained by subtracting the value obtained by converting the supply amount of the district heating heat of the steam turbine to the electric output and the value obtained by correcting the output value according to the degree of vacuum of the condenser of the steam turbine at a value.

Calculating a final supply capability value of the steam turbine based on the final supply capability value of the gas turbine includes comparing a value obtained by correcting the supply capability value of the steam turbine according to an operation state of the steam turbine and a maximum output value on the steam turbine design And setting a small value as a final supply capability value of the steam turbine.

Calculating a supply capacity value of the generator in real time by summing a final supply capacity value of the gas turbine and a final supply capacity value of the steam turbine, when the number of gas turbines is two or more, And a value obtained by adding the final supply capability values of the respective gas turbines.

As described above, the method for estimating the supply capability of the generator according to the present invention can estimate the supply capability of the generator at a more accurate and detailed level by estimating the supply capability of the generator in real time.

1 is a schematic diagram of a conventional combined-
FIG. 2 shows a conventional Brayton Cycle TS diagram
Figure 3 shows the definition of a conventional gas turbine inlet temperature
Figure 4 shows a typical pinch point and approach point diagram
Figure 5 is a schematic diagram of a conventional Lancin cycle device;
Figure 6 shows the TS curve of a conventional Rankine cycle
Figure 7 is a graphical representation of a conventional open and closed lander cycle (non-superheat) TS diagram
Figure 8 is a graphical illustration of the overall functionality of the present invention
Figure 8a shows a gas turbine 1 detailed functional diagram of the present invention
Figure 8b shows the gas turbine N detailed functional diagram of the present invention
Figure 8c shows the steam turbine detailed functional diagram of the present invention
9 is a flowchart showing the entire steps of the present invention
10 is an example of a calibration curve showing the correlation between the ambient temperature and the output provided by the device supplier
Figure 11 is an example of a calibration curve showing the correlation between relative humidity and output provided by the instrument supplier
12 is a graph showing the correlation between the atmospheric pressure and the output provided by the equipment supplier,
Figure 13 is an example of a calibration curve showing the correlation between ambient temperature and output based on empirical data estimated after actual generator operation
14 shows an example of an empirical data table calculated after actual generator operation
15 is an example of a calibration curve showing the correlation between the exhaust pressure and the steam turbine output provided by the equipment supplier
Figure 16 is an example of a calibration curve showing the correlation between the condenser vacuum level and the steam turbine output provided by the instrument supplier;
17 is an example of a calibration curve showing the correlation between the condenser vacuum degree based on the empirical data calculated after actual generator operation and generator output variation

Hereinafter, a method of calculating a real-time generator supply capability according to a preferred embodiment of the present invention will be described in detail with reference to the accompanying drawings.

8A is a detailed functional diagram of the gas turbine 1 11, FIG. 8B is a detailed functional diagram of the gas turbine N (N), FIG. 8B is a detailed functional diagram of the gas turbine N 8c is a detailed functional diagram of the steam turbine 20. FIG.

Referring to FIG. 8, a method for calculating the real-time generator supply capability according to the present invention will be described. In a combined-cycle power generator composed of one or more gas turbines and a steam turbine, the final supply of gas turbine 1 (11) The capacity value and the final supply capacity value of the steam turbine are summed by the summer 30 to calculate the real-time generator supply capacity value.

Referring to FIG. 8A, the gas turbine 1 11 of the real-time generator supply capacity calculating method according to the present invention will be described. The gas turbine 1 11 is a real-time variable measuring a variable affecting the output of the gas turbine Measuring instrument; A compressor outlet pressure calibrator for calculating a compressor outlet pressure using a compression ratio; Compressor rotor contamination calculator for estimating compressor rotor contamination by dividing the amount of power at which output decreases over time by time; A real time variable compensator (12) for correcting the measured variables in the real time variable measuring machine; A summer 13 for summing the real-time variable correction value and the compressor rotor contamination estimate; A multiplier (14) for multiplying the rated load of the gas turbine (1) by the value summed by the summer (13); A compressor outlet pressure compensator (15) for correcting the value calculated by the compressor outlet pressure calibrator; A first supply capacity value setting unit 16 for setting a supply capacity value of the gas turbine 1 according to the presence or absence of a compression ratio performance correction curve; A second supply capacity value setting unit 17 for setting a supply capacity value of the gas turbine 1 according to whether the gas turbine 1 is abnormal or not; A Clear button operated by the operator when the gas turbine 1 is switched from the abnormal state to the normal state; And a final supply capability value comparator that compares the value set by the second supply capability value setting unit 17 with the maximum output value in the gas turbine design to set the final supply capability value of the gas turbine 1 (11) .

More specifically, the real-time parameter estimator installed in the gas turbine measures the atmospheric temperature, the atmospheric pressure, the humidity, the filter differential pressure, and the compression ratio, and measures the measured atmospheric temperature, atmospheric pressure, The humidity difference and the filter differential pressure are corrected by the real time variable compensator 12 and the correction value corrected by the corrector 12 and the compressor rotor contamination value calculated by the compressor rotor contamination estimator are summed by the summer 13, And the summed value added by the summer 13 is multiplied by the rated load of the gas turbine 1 11 by the multiplier 14. The compression ratio is calculated as a compressor outlet pressure value through a compressor outlet pressure estimator, and the calculated compressor outlet pressure value is corrected through a compressor outlet pressure compensator (15). The first supply capacity value setter 16 of the gas turbine 1 11 outputs a value multiplied by the multiplier 14 when there is no compression ratio performance correction curve in accordance with the presence or absence of the compression ratio performance correction curve in the gas turbine 1 11). If there is a compression ratio performance correction curve, the value corrected by the compressor outlet pressure compensator (15) is set as the supply capability value of the gas turbine 1 (11).

The second supply capacity value setting unit 17 of the gas turbine 1 11 is controlled by the gas turbine 1 11 to stop the gas turbine 1 11 when the gas turbine 1 11 is in a normal state, The supply capacity value of the gas turbine 1 11 is set to a value set by the first supply capacity value setter 16 of the gas turbine 1 11, and when the gas turbine 1 11 is in an abnormal state, To the value of the supply capacity of the gas turbine 1 (11). The abnormality state is detected by the second supply capability value setting unit 17 of the gas turbine 1 11 as a system failure, an output ignition, an exhaust temperature rise, a unit trip, a breaker opening, When a signal such as a run-down signal is input, it is regarded as an abnormal state. When the gas turbine 1 (11) is changed from the abnormal state to the normal state, when the operator operates the Clear button to input a clear signal to the second supply capacity value setting unit 17 of the gas turbine 1 (11) , The second supply capacity value setting unit 17 of the gas turbine 1 11 supplies the supply capacity value of the gas turbine 1 11 set to the current output value of the gas turbine 1 11 to the gas turbine 1 To the value set by the first supply capacity value setting unit 16 of the first supply capacity value setting unit 11. [

The final supply capacity value comparator 18 of the gas turbine 1 11 is connected to the value set by the second supply capacity value setting unit 17 of the gas turbine 1 11 and the value set by the second supply capacity value setting unit 17 of the gas turbine 1 11 And sets a smaller value as the final supply capability value of the gas turbine 1 (11).

The final feed capacity value of the gas turbine 1 (11) is input to the steam turbine (20) and the summer (30).

N in the gas turbine N (N) shown in FIG. 8B means the number of gas turbines, and each gas turbine has the same configuration as the system structure of the gas turbine 1 (11), and thus its detailed description is omitted.

Referring to FIG. 8C, a steam turbine 20 of a real time generator supply capacity calculation method according to the present invention will be described. The steam turbine 20 includes a gas turbine 20 for correcting a final supply capacity value of the gas turbine 1 11, 1 (11); A final feed capability value corrector 23 of a gas turbine N (N) that corrects the final feed capability value of the gas turbine N (N); A gas turbine final feed capability value adder 23 for summing the corrected values through the final feed capability value corrector 21, 22 of the gas turbine 1 (11) to the gas turbine N (N); A local heating heat supply quantity converter 25 for converting the supply amount of the district heating heat of the steam turbine 20 to an electric output; An output corrector 27 according to the degree of vacuum of the condenser for correcting the output to the value of the condenser degree of vacuum of the steam turbine 20; A cold winder 24 for subtracting the electric output value converted by the local heating heat supply amount converter 25 from the summed value through the gas turbine final supply capability value adder 23; A summer 26 for summing the value subtracted by the subtractor 24 and the correction value corrected through the output corrector 27 according to the degree of vacuum of the condenser; A supply capacity value setting unit 28 for setting a supply capacity value of the steam turbine 20 according to whether the steam turbine 20 is abnormal or not; A Clear button operated by the operator when the steam turbine 20 is switched from the abnormal state to the normal state; And a final value of the steam turbine (20) is set to a small value by comparing the value set by the supply capacity value setter (28) with the maximum output value in design of the steam turbine (20) And a supply capability value comparator (29).

More specifically, referring to the configuration of the steam turbine 20, the final supply capability value of the gas turbine 1 (11) and the final supply capability value of the gas turbine N (N) (21, 22), and the correction values corrected through the correlators (21, 22) are added up through a summer (23). The local heating heat supply amount of the steam turbine 20 is converted into an electric output value through the district heating heat supply amount converter 25 and the electric output value converted through the local heating heat supply amount converter 25 is supplied to the summer 23) by a summed value obtained by subtracting the summed value from the summed value through the subtracter (24). The value of the degree of vacuum of the steam turbine 20 is corrected by the output corrector 27 according to the degree of vacuum of the condenser and the correction value corrected through the output corrector 27 according to the degree of vacuum of the condenser, The subtracted values are summed up through a summer 26. [ The supply capacity value setter 28 of the steam turbine 20 is configured to set the supply capacity value of the steam turbine 20 based on whether the steam turbine 20 is in an abnormal state or not, And sets the current output value of the steam turbine (20) as the supply capability value of the steam turbine (20) when the steam turbine (20) is in an abnormal state.

The abnormality state may be determined by a systematic fault, an output ignition, an exhaust temperature rise, a unit trip, a breaker opening, a bypass opening, a runback-run-down, or the like in the supply capacity value setter 28 of the steam turbine It is regarded as an abnormal state.

When the steam turbine 20 is switched from the abnormal state to the normal state, when the operator operates the Clear button to input a clear signal to the supply capacity value setting unit 28 of the steam turbine 20, The supply capacity value setter 28 of the steam turbine 20 adjusts the supply capacity value of the steam turbine 20 set as the current output value of the steam turbine 20 to the summed value by the summer 26 .

The final supply capacity value comparator 29 of the steam turbine 20 compares the value set by the supply capacity value setter 28 of the steam turbine 20 with the maximum design value of the steam turbine 20, And sets a small value to the final supply capability value of the steam turbine 20. [

The final feed capability value of the steam turbine 20 is input to the summer 30.

9 is a flow chart showing the entire steps of the present invention.

The method for estimating the supply capacity of the real-time generator according to the present invention will be described in more detail with reference to FIG. 9, Calculating a final supply capacity value of at least one or more gas turbines constituting the generator, calculating a final supply capacity value of the steam turbine constituting the generator, And summing the supply capability values (S33) to calculate the supply capability of the generator (S34).

[Estimation of Final Supply Capacity of Gas Turbine]

(S1) variables such as atmospheric temperature, atmospheric pressure, humidity, filter differential pressure, and compression ratio affecting the output capacity of the generator are measured in real time (S1) through various measurement equipments and measurement methods, and the gas turbine It is confirmed whether or not the compression ratio performance correction curve exists (S2).

Since the correction curve of the compression ratio of the gas turbine is not necessarily provided by the equipment supplier, it is often not provided in most power plants.

When the compression ratio performance correction curve exists, the compressor outlet pressure value is calculated through the measured compression ratio (S7), and the compressor outlet pressure value is corrected through the compression ratio performance correction curve (S8) to obtain the gas turbine supply capability value.

However, if the compression ratio performance correction curve does not exist, the remaining variables excluding the compression ratio among the real-time variables measured in the real time (S1) are corrected (S3) using the correction factor tables of the respective variables, (S4), the sum value (S5) obtained by summing the correction values of the respective parameters and the compressor rotor contamination value is multiplied by the gas turbine rated load value (S9) (S6) to obtain the gas turbine supply capability value.

As shown in FIGS. 10, 11, and 12, when the generator is introduced, the correction factor table used for the correction of each of the above-described variables is set such that, The calibration curve provided by the supplier of the apparatus may be changed due to deterioration of the generator and the like, so that a more accurate correction value is calculated 13 and 14, a variable correction factor table is created based on the calibration curve provided by the device supplier and the experience data obtained while operating the generator from the time of installation of the generator for the first time. In addition, since the compressor rotor contamination value can not be measured actually, the output power reduction amount over time is calculated by dividing by the time.

(S10), and when the gas turbine is in a normal operation state, a value (S6) calculated through the step (S6) is determined as a value of the supply capacity of the gas turbine It is impossible to increase the output of the generator when the gas turbine is in an abnormal operation state, so that the present output capacity of the gas turbine is set as the supply capacity value of the gas turbine (S11 )do.

When the gas turbine is switched from the abnormal operation state to the normal operation state, the operator operates the Clear button in the human machine interface (HMI) (S14), and the supply capacity value of the gas turbine is calculated through the above steps To the value S6 (S15).

If the value of the set gas turbine supply capacity is smaller than the preset value of the capacity of the gas turbine, (S18). When the maximum output capacity value of the gas turbine is small, the maximum output capacity value of the gas turbine is set to the final supply capacity value (S17) of the gas turbine. . Further, when the number of the gas turbines is two or more, the final supply capability values of the gas turbine each add up the final supply capability values of the gas turbine estimated through the same step as the above step.

[Estimation of Final Supply Capacity Value of Steam Turbine]

As shown in FIG. 1, in order to calculate the supply capacity value of the steam turbine, the value of the final supply capacity of the gas turbine should be corrected and used in view of the power generation principle and structure of the combined-cycle power generator.

For example, in the case of a combined-cycle power plant consisting of four gas turbines and one steam turbine, when one of the four gas turbines is stopped and operated with three gas turbines, the steam turbine output is divided into four gas turbines The 75% output during operation is not output, but comes out at a lower output. In addition, when two gas turbines are in operation, the output is not 50% but much less than 50% depending on the manufacturer and model. Therefore, a correction factor table considering these various portions is created, and the final supply capability value of each gas turbine is corrected (S19), and the values are added.

Also, in order to calculate the supply capacity value of the steam turbine, the local heating heat and the degree of vacuum of the condenser must be considered.

Since the zone heating heat is heat supplied to the outside as described in the background art of the present invention, it is converted into an electric output (S22), and subtracted from the gas turbine final supply capacity value correction sum value S19 (S20) In the case of the condenser vacuum degree, there is an efficiency curve according to the degree of vacuum for each power plant. The correction curve showing the correlation between the condenser vacuum level and the steam turbine output provided by the apparatus supplier as shown in FIG. 17, an output correction factor table according to the degree of vacuum of the condenser is created in consideration of the correction curve created based on operational experience data, the output correction value S24 is calculated using the correction factor table, It should be added to the final supply capability value summed value S19 (S21).

Therefore, if the output power conversion value S22 of the zone heating heat is subtracted from the gas turbine final supply capability value correction sum S19 and the output correction value S23 corresponding to the vacuum degree of the condenser is added, The turbine supply capability value can be calculated.

At this time, the operation state of the steam turbine is sensed (S24) in the same manner as the step of calculating the value of the final gas supply capability of the gas turbine. When the steam turbine is in a normal operation state, the steam turbine supply capability value is calculated (S25). When the steam turbine is in an abnormal operation state, it is impossible to increase the output of the generator. Therefore, the present output capacity of the steam turbine is set to the supply capacity value of the steam turbine (S26).

When the steam turbine is switched from the abnormal operation state to the normal operation state, the operator operates the Clear button (S28) in the human-machine interface (HMI) to switch to the supply capacity value of the steam turbine estimated through the above- (S29).

Then, the supply capacity of the steam turbine is compared with the maximum output capacity of the steam turbine (S30), and a small value is set as the final supply capacity of the steam turbine (S31 or S32).

The value of the shortest supply capacity of the gas turbine and the value of the shortest supply capacity of the steam turbine are summed (S33) to calculate the real-time generator supply capacity value (S34).

Variables that affect the output capacity of the generator include atmospheric temperature, atmospheric pressure, humidity, compression ratio, compressor rotor contamination, filter differential pressure, IGV (Inlet Guide Vane) opening, Temperature, atmospheric pressure, humidity, filter differential pressure, and compression ratio are important factors in the operation of the facility.

The correction factor table for calculating the correction value of each of the above variables may include a performance correction curve or function when the equipment supplier provides a performance correction curve or function based on the current operating condition of the generator, And if the device supplier does not provide the performance correction curve or function, it is created by referring to the experience data obtained while operating the generator. However, even if there is a performance correction curve or function provided by the device supplier, And may be created in consideration of the empirical data for accuracy.

The abnormal operation state of the gas turbine and the steam turbine refers to a state in which the power generation facility can not have the capability of 100%. The abnormal operation state of the gas turbine and the steam turbine means that the power generation facility is not capable of 100% State), a breaker open, a bypass open, and a runback-rundown state.

Although the technical spirit of the present invention has been described in detail according to the above-described preferred embodiment, it should be noted that the above-described embodiment is for the purpose of description and not of limitation. In addition, those skilled in the art will understand that various embodiments are possible within the scope of the technical idea of the present invention.

11: Gas turbine 1
12: Real-time variable compensator of gas turbine 1
15: Compressor outlet pressure compensator of gas turbine 1
16: First supply capacity value setting device of gas turbine 1
17: second supply capacity value setting device of gas turbine 1
18: Final supply capability value comparator of gas turbine 1
N: Gas turbine N
N2: Real-time variable compensator of gas turbine N
N5: Compressor outlet pressure compensator of gas turbine N
N6: First supply capacity value setter of the gas turbine N
N7: second supply capacity value setter of the gas turbine N
N8: Final supply capability value comparator of gas turbine N
20: Steam turbine
21: final supply capacity value compensator of gas turbine 1
22: final supply capacity value compensator of gas turbine N
23: Gas turbine final supply capacity value totalizer
25: Local heating heat supply conversion unit 27: Output compensator according to the condenser vacuum degree
28: Value of supply capacity of steam turbine 29: Value of supply capacity of steam turbine
30: Gas turbine and steam turbine final supply capacity value totalizer

Claims (16)

Calculating a final supply capacity value of the gas turbine by measuring in real time a variable affecting the output capacity of the gas turbine;
Estimating a final feed capability value of the steam turbine to a final feed capability value of the gas turbine; And
Calculating a supply capacity value of the generator in real time by summing a final supply capacity value of the gas turbine and a final supply capacity value of the steam turbine;
Wherein the real-time generator supply capability estimating means estimates the supply capacity of the real-time generator. The method of claim 1,
Wherein the number of the gas turbines is at least one or more than one in the step of measuring a variable affecting an output capacity of the gas turbine in real time and calculating a final supply capability value of the gas turbine. The method of claim 1,
Wherein the step of measuring a variable affecting the output capacity of the gas turbine in real time and calculating a final supply capability value of the gas turbine comprises: determining whether a compression ratio performance correction curve of the gas turbine exists or not, And calculating a value of the gas turbine supply capability according to the value of the gas turbine supply capability value. The method of claim 3,
Wherein the gas turbine supply capability value is obtained by calculating a compressor outlet pressure value of the gas turbine if the compression ratio performance correction curve exists and correcting the calculated compressor outlet pressure value through the compression ratio performance correction curve, And if the curves do not exist, calculate the sum of the correction values of the variables measured in the real time and the compressor rotor tooth contamination value of the gas turbine, and multiply the sum value by the rated load value of the gas turbine. Method of estimating supply capacity. The method of claim 1,
Wherein the step of measuring a parameter affecting the output capacity of the gas turbine in real time and calculating a final supply capability value of the gas turbine comprises the step of correcting the supply capability value of the gas turbine according to the operating state of the gas turbine Wherein the real-time generator supply capacity calculating means calculates the real-time generator supply capacity. The method of claim 5,
Wherein the step of correcting the supply capability value of the gas turbine according to the operating state of the gas turbine includes determining whether or not a compression ratio performance correction curve of the gas turbine exists when the gas turbine is in the normal operation state, Calculating a gas turbine supply capability value, and setting an output capacity of the current gas turbine as a supply capacity value of the gas turbine until the gas turbine is switched to a normal operation state when the gas turbine is in an abnormal operation state Wherein the real-time generator supply capacity calculation unit calculates the actual supply capacity of the real-time generator. The method according to claim 6,
The step of correcting the supply capability value of the gas turbine may include: when the gas turbine is switched from the abnormal operation state to the normal operation state, the operator operates the Clear button in the human machine interface (HMI) To a value calculated according to the presence or absence of the compression ratio performance correction curve. The method of claim 1,
Wherein the step of measuring variables affecting the output capacity of the gas turbine in real time and calculating a final supply capability value of the gas turbine comprises calculating a value obtained by correcting the supply capability value of the gas turbine according to the operating state of the gas turbine, And setting a small value as a final supply capability value of the gas turbine. The method of claim 1,
Wherein the step of calculating the final supply capability value of the steam turbine based on the final supply capability value of the gas turbine is a step of calculating a final supply capability value of the gas turbine by subtracting a value obtained by converting the amount of supply of the local heat- And calculating a supply capacity value of the steam turbine by summing values obtained by correcting an output value according to the degree of vacuum of the condenser of the steam turbine. 10. The method of claim 9,
Wherein a value obtained by correcting a final supply capability value of the gas turbine is a value obtained by summing up values obtained by correcting a final supply capability value of each gas turbine when the number of gas turbines is two or more. The method of claim 1,
Wherein the step of calculating the final supply capability value of the steam turbine based on the final supply capability value of the gas turbine comprises the step of correcting the supply capability value of the steam turbine according to the operation state of the steam turbine Calculation method. The method of claim 11,
Wherein the step of correcting the supply capacity value of the steam turbine according to the operating state of the steam turbine includes the step of adjusting the supply capacity value of the steam turbine to a value obtained by correcting the final supply capability value of the gas turbine when the steam turbine is in a normal operation state, Summing a value obtained by subtracting the converted value and a value obtained by correcting an output value according to the degree of vacuum of the steam turbine, and setting the sum value as the supply capacity value of the steam turbine. In the case where the steam turbine is in an abnormal operating state, And setting an output capacity of the current steam turbine as a supply capacity value of the steam turbine until the turbine is switched to the normal operation state. The method of claim 12,
When the steam turbine is switched from the abnormal operation state to the normal operation state, the operator operates the Clear button in the human machine interface (HMI) to adjust the supply capability value of the steam turbine to the corrected value of the final supply capability of the gas turbine And converting the value obtained by subtracting the value obtained by converting the supply amount of the district heating heat of the steam turbine to the electric output and the value obtained by correcting the output value according to the degree of vacuum of the condenser of the steam turbine, Method of estimating generator capacity. The method of claim 1,
Calculating a final supply capability value of the steam turbine based on the final supply capability value of the gas turbine includes comparing a value obtained by correcting the supply capability value of the steam turbine according to an operation state of the steam turbine and a maximum output value on the steam turbine design And setting a small value as a final supply capability value of the steam turbine. The method of claim 1,
When the number of gas turbines is two or more in the step of calculating the supply capability value of the generator in real time by summing the final supply capability value of the gas turbine and the final supply capability value of the steam turbine, And the final supply capability values of the gas turbines. The method according to claim 1, wherein
The variable measured in real time is the air temperature, atmospheric pressure, humidity, filter differential pressure, compression ratio calculation method of the real-time generator, characterized in that.
KR1020120095115A 2012-08-29 2012-08-29 Calculation method of generator's real time supply capacity KR101423191B1 (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
KR1020120095115A KR101423191B1 (en) 2012-08-29 2012-08-29 Calculation method of generator's real time supply capacity

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
KR1020120095115A KR101423191B1 (en) 2012-08-29 2012-08-29 Calculation method of generator's real time supply capacity

Publications (2)

Publication Number Publication Date
KR20130069333A true KR20130069333A (en) 2013-06-26
KR101423191B1 KR101423191B1 (en) 2014-07-28

Family

ID=48864734

Family Applications (1)

Application Number Title Priority Date Filing Date
KR1020120095115A KR101423191B1 (en) 2012-08-29 2012-08-29 Calculation method of generator's real time supply capacity

Country Status (1)

Country Link
KR (1) KR101423191B1 (en)

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
KR101501376B1 (en) * 2013-10-08 2015-03-10 주식회사 삼천리 Method for determining the operation of co-generation system
KR20170037724A (en) 2015-09-25 2017-04-05 한국전력공사 Apparatus, system and method for calculating supply capacity of combined cycle power generator
WO2020031532A1 (en) * 2018-08-06 2020-02-13 三菱日立パワーシステムズ株式会社 Performance evaluation device, performance evaluation method, and performance influence output method

Family Cites Families (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JP2010169064A (en) 2009-01-26 2010-08-05 Toshiba Corp Combined cycle power plant

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
KR101501376B1 (en) * 2013-10-08 2015-03-10 주식회사 삼천리 Method for determining the operation of co-generation system
KR20170037724A (en) 2015-09-25 2017-04-05 한국전력공사 Apparatus, system and method for calculating supply capacity of combined cycle power generator
WO2020031532A1 (en) * 2018-08-06 2020-02-13 三菱日立パワーシステムズ株式会社 Performance evaluation device, performance evaluation method, and performance influence output method
JP2020024119A (en) * 2018-08-06 2020-02-13 三菱日立パワーシステムズ株式会社 Performance evaluation device, performance evaluation method and performance impact level output method

Also Published As

Publication number Publication date
KR101423191B1 (en) 2014-07-28

Similar Documents

Publication Publication Date Title
Persichilli et al. Supercritical CO2 power cycle developments and commercialization: why sCO2 can displace steam ste
US9003763B2 (en) Compressed air energy system integrated with gas turbine
US20140223918A1 (en) Compressed air energy system integrated with gas turbine
JP5400969B2 (en) Gas turbine system, control device for gas turbine system, and control method for gas turbine system
US9957954B2 (en) Solar thermal power generation system
Murehwa et al. Energy efficiency improvement in thermal power plants
KR101423191B1 (en) Calculation method of generator's real time supply capacity
Stoppato et al. Assessment of stresses and residual life of plant components in view of life-time extension of power plants
Plis et al. Modelling and simulation of the effect of ambient parameters on the performance of a combined cycle gas turbine power plant
Gülen et al. Second law efficiency of the Rankine bottoming cycle of a combined cycle power plant
Baughn et al. A comparison of the predicted and measured thermodynamic performance of a gas turbine cogeneration system
Guédez et al. Techno-economic comparative analysis of innovative combined cycle power plant layouts integrated with heat pumps and thermal energy storage
In et al. Optimization of heat recovery steam generator through exergy analysis for combined cycle gas turbine power plants
Galashov et al. Thermal efficiency of three-cycle utilization-type steam-gas units
Wagner et al. The impact of hybrid wet/dry cooling on concentrating solar power plant performance
JP5667435B2 (en) Cogeneration nuclear power generation system
CN114934825B (en) Carbon dioxide energy storage system and method coupled with coal motor group
CN113673778B (en) Operation optimization method and system of gas-electricity cogeneration unit of coupling industrial gas supply system
Najjar et al. Steam turbine bottoming cycle deterioration under different load conditions
Leslie et al. Recovered Energy Generation Using an Organic Rankine Cycle System.
Shabani et al. Performance assessment and leakage analysis of feed water pre-heaters in natural gas-fired steam power plants.
Kumar et al. Off Design Performance Analysis of a Triple Pressure Reheat Heat Recovery Steam Generator
Milić et al. Analysis of operation of the condenser in a 120 MW thermal power plant
Banaszkiewicz et al. Numerical investigations of transient thermal loading of steam turbines for SMR plants
CN214664331U (en) Load control system of supercritical heat supply unit

Legal Events

Date Code Title Description
A201 Request for examination
G15R Request for early opening
E902 Notification of reason for refusal
E701 Decision to grant or registration of patent right
GRNT Written decision to grant
FPAY Annual fee payment

Payment date: 20170628

Year of fee payment: 4

FPAY Annual fee payment

Payment date: 20180625

Year of fee payment: 5

FPAY Annual fee payment

Payment date: 20190514

Year of fee payment: 6