Combustion boiler control method, combustion boiler, and boiler calculation system

Abstract

To improve boiler control, a combustion boiler control method has been proposed. This method comprises the steps of: a) determining the current load (Q h ), b) monitoring at least one exhaust gas coefficient (df i ) satisfies the allowable conditions. h,max ) to the number (Q h,candidate ), and a numerical value (Q h,candidate ) to the current calculated maximum boiler instantaneous load (Q h,max ) as the current calculated maximum boiler instantaneous load (Q h、max ) to the operator, and / or the current load (Q h ) c1) The current calculated maximum boiler instantaneous load (Q h,max ) is smaller than c1i) boiler load (Q h c1ii) a process to indicate to the boiler operator that the boiler load (Q h ), and / or c2) automatically increasing the current calculated maximum boiler instantaneous load (Q h,max ) is larger than c2i) boiler load (Q h c2ii) indicating to the boiler operator that the boiler load (Q h ) automatically reducing

Description

[Technical Field]

[0001] The present invention relates to the control of fired boilers, and in particular to the control of fluidized bed boilers, such as circulating fluidized bed (CFB) boilers or bubbling fluidized bed (BFB) boilers. [Background technology]

[0002] Combustion boilers, such as grate boilers and fluidized bed boilers, are commonly utilized to generate steam, which can be used for a variety of purposes, such as generating electricity and heat.

[0003] In a fluidized bed boiler, fuel and solid particulate bed material are introduced into the furnace. The bed material and fuel are fluidized by introducing a fluidizing gas from the bottom of the furnace. The fuel is burned in the furnace. In a BFB combustion, the fluidizing gas passes through the bed to form bubbles within the bed. In a BFB, the fluidized bed can be controlled fairly easily by controlling the fluidizing gas supply and the fuel supply. In addition to the fuel, certain additives may be added to the combustion, such as aluminum silicates (e.g., non-hydrated clays), alkali alkaline earth metal carbonates, and mixtures thereof (e.g., limestone or calcium carbonate), to enhance the sorption of possible heavy metals, sulfur, and also to enhance the sorption of alkali.

[0004] In a CFB, a fluidizing gas is passed through the bed material. Most of the bed particles become entrained in the fluidizing gas and are carried along with the exhaust gas. The particles are separated from the exhaust gas in at least one particle separator and circulated back into the furnace. A fluidized bed heat exchanger is typically located downstream of the particle separator to recover heat from the particles before they are returned to the furnace.

[0005] In all boilers, regardless of combustion technology, combustion conditions such as air and fuel mixing may not be ideal.

[0006] Improbed AB's published international application WO 2016 / 202640A1 discloses a method for controlling the heat load of a fired boiler, in which the heat load of the fired boiler is reduced if the flue gas velocity monitored at at least one location in the boiler exceeds a predetermined maximum flue gas velocity limit. The flue gas velocity is calculated using a set of equations by dividing the flue gas volumetric flow rate by the cross-sectional area of ​​the flue gas duct at a location immediately downstream of the cyclone.

[0007] Fired boilers are conventionally designed for a given load, which is the boiler's respective boiler maximum continuous rating (BMCR), sometimes referred to as the design load level. Summary of the Invention [Problem to be solved by the invention]

[0008] The first object of the present invention is to improve boiler performance, profitability, and flexibility, and to improve boiler load control. The second object of the present invention is to reduce the complexity of combustion boiler control systems. [Means for solving the problem]

[0009] The first object can be achieved by a combustion boiler control method as set forth in claim 1 and a combustion boiler as set forth in claim 19. The second object can be achieved by a combustion boiler calculation system as set forth in claim 24.

[0010] The dependent claims describe advantageous aspects of the combustion boiler control method, the combustion boiler and the combustion boiler calculation system.

[0011] Advantages of the Invention The combustion boiler control method includes the following steps. a) Current load Q of the combustion boiler h monitoring the b) finding a value for the current calculated maximum boiler instantaneous load for which at least one flue gas coefficient calculated using currently monitored process data including a numerical model of the boiler satisfies the acceptance criteria, and identifying this value as the current calculated maximum boiler instantaneous load Q h,max a step of selecting as c) Current calculated maximum boiler instantaneous load Q h、max and / or the current load Q h but, c1) When the load is smaller than the current calculated maximum boiler instantaneous load, c1i) Indicating to the boiler operator that the boiler load may increase; and / or c1ii) automatically increasing the boiler load; and / or c2) When the maximum instantaneous boiler load is greater than the current calculated maximum instantaneous boiler load, c2i) Boiler load Q h Indicating to the boiler operator that the current calculated maximum instantaneous boiler load is exceeded; and / or c2ii) Boiler load Q h automatically reducing the

[0012] In this manner, rather than fixing the boiler's maximum load, by calculating the exhaust gas coefficient and appropriately selecting the allowable exhaust gas coefficient, the fired boiler can be safely operated at or near the fired boiler's current calculated maximum boiler load, which may sometimes be higher than the boiler's fixed maximum load. The current calculated maximum boiler load may be higher than the design load level. Therefore, the overall performance of the boiler can be improved, and power / heat generation can be increased. Furthermore, because the current calculated maximum boiler load may be lower than the design load level, boiler wear caused by exceeding the current calculated maximum boiler load can be more appropriately reduced. In other words, the current calculated maximum boiler load can be considered the maximum allowable boiler load and / or the preferred boiler load.

[0013] In the tests carried out, the Applicant has been able to obtain, on average, a power output from the fired boiler that exceeds the fixed boiler maximum load. In the tests, the Applicant has been able to demonstrate that for fired boilers, the improvement potential can be between 2.5 and 5%. This is the case for example for a 120 MW boiler. th In the case of combustion boilers, 3 to 6 MW th is equivalent to

[0014] In this method, it is preferable that: i) The currently monitored process data of the boiler ia) the current exhaust gas outlet temperature in the exhaust gas flow path; ib) Heat duty for each heat transfer surface in the exhaust gas flow path and ii) The monitored process data from both ia) and ib) are used to calculate the exhaust gas coefficient and the current calculated maximum boiler instantaneous load Q h,max It is used when finding a numerical value for .

[0015] Calculating the heat load of a heat exchanger is known to those skilled in the art, and the heat load can be obtained, for example, by using the following formula: Q fluid,i =q m,fluid,i ×(h fluid,out -h fluid,in ) where q m,fluid,i is the fluid flow rate at the ith heat transfer surface, h fluid,in is the enthalpy of the fluid entering the ith heat transfer surface, h fluid,out is the enthalpy of the fluid leaving the ith heat transfer surface.

[0016] This discovery can be implemented such that if at least one exhaust gas coefficient calculated using currently monitored process data, including a numerical model of the boiler, fails to meet the tolerance criteria, a next value is automatically selected. Preferably, the next value is selected iteratively. This can enable the use of computational library functions, specifically iterative solvers (such as Python's FSOLVE function, which solves the roots of a function).

[0017] This finding can be done by performing the following computational steps: - I: A step of calculating an estimate of the boiler exhaust gas outlet temperature, which results in a calculated boiler model when the boiler thermal load is matched with the numerical value; - II: calculating the exhaust gas mass flow rate; - III: calculating the heat load of each heat transfer surface in the exhaust gas flow path using the current heat load corrected by using a numerical boiler model; - IV: Using the calculated heat load for each heat transfer surface in the flue gas flow path, calculate the flue gas temperature at each heat transfer surface, starting with the heat transfer surface in the flue gas flow path closest to the flue gas outlet in the upstream direction of the flue gas flow, using an estimate of the boiler flue gas outlet temperature; - V: A process for calculating the exhaust gas coefficient for each heat transfer surface in the exhaust gas flow path.

[0018] Using this method, the condition of each heat transfer surface (hereinafter, "heat transfer surface" means a heat exchanger, a heat exchanger tube, a heat exchanger tube bundle, a heat exchanger package, and / or a heat exchanger component such as an economizer) in the exhaust gas flow path can be numerically estimated using the exhaust gas coefficients in a situation where the boiler heat load matches the numerical value. The term "heat transfer surface" preferably means a heat exchanger component such as an economizer. Therefore, it is now possible to test whether a specific numerical value, which is a candidate for the current calculated maximum boiler instantaneous load, creates an acceptable condition for the heat transfer surface.

[0019] According to one embodiment of the present invention, in step III), the numerical boiler model is fluid,i,candidate =Qfluid,i,current +Σα j,i (Q h,candidate ) j -Σpar j,i (Q h,current ) j It is a model of the form:

[0020] parameter j,i ) can be fitted manually by a human or automatically by a computer using historical data. Automatic updates of the parameters may occur, for example, monthly. AI and neural network-based algorithms can be used in the automatic updates.

[0021] This makes it possible, on the one hand, to predict the current maximum boiler load that is mathematically permissible without reaching a limit with the current boiler load, unlike the method disclosed in WO 2016 / 202640A1, and, on the other hand, even more importantly, to reach a limit without exceeding the current maximum boiler load that is mathematically permissible.

[0022] Preferably, the exhaust gas coefficients include or are less than or equal to the following: df i =k i (q m,fluegas / (ρ fluegas,i ×A cross,i )) n where: k i is a non-zero parameter, preferably a positive (non-zero) number, that may be selected in particular for a combustion boiler; q m,fluegas is the mass flow rate of the exhaust gas, n is a model parameter, preferably a positive (non-zero) number, that can be specifically selected for a combustion boiler; ρ fluegas,i is the density of the exhaust gas at the ith heat transfer surface, A cross,i is the cross-sectional area of ​​the exhaust gas flow passage on the ith heat transfer surface.

[0023] This is particularly advantageous because the selection of this functional form for the flue gas coefficient allows the flue gas coefficient to be very flexible and easily adapted to suit the needs of various fired boilers, including based on current fuel conditions.

[0024] The model parameter n is particularly advantageous because it can be chosen to be at least one of the following: i) if a calculated exhaust gas velocity is used, it is in the range of 0.9 to 1.1, preferably equal to or about 1.0; ii) When using corrosion-causing exhaust gases, the calculated range is between 2.9 and 3.5, preferably between 3.2 and 3.35; or iii) When pressure drop is used, it is in the range of 1.8 to 2.2, preferably equal to or about 2.0.

[0025] The value of n can be changed over time. This is advantageous because flue gas flow conditions at the heat transfer surface can change over time due to slagging, ash agglomeration, or fuel or bed conditions. The flue gas coefficient can therefore be shifted over time to better reflect actual boiler conditions.

[0026] According to one embodiment of the present invention, when n=2 and the exhaust gas coefficient represents the pressure loss, the exhaust gas coefficient df i and the maximum value of the exhaust gas coefficient df max,i The comparison with can be performed for each heat transfer surface. The acceptable condition, according to one embodiment, is substantially df i =df max,i is.

[0027] According to one embodiment of the present invention, when n=2 and the exhaust gas coefficient represents the pressure loss, the exhaust gas coefficient df i The sum of dp tot =Σdf i and the specified exhaust gas coefficient df max,ior the predetermined flue gas coefficient simply represents the total pressure drop, and thus the comparison represents a comparison of the total pressure drop between the furnace and the chimney. The permissive condition, according to one embodiment, is substantially equal to dp tot =dp max,tot is.

[0028] The exhaust gas factor, according to one embodiment of the present invention, represents the ash deposition factor and can be written in the following form: df i =k ph C(d)q m_fa v p n where k ph is the particle hardness coefficient, C(d) is the particle diameter function, q m_fa is the mass flow rate of fly ash, v p is the particle velocity, and n is a power exponent (0, 3-4). A given exhaust gas coefficient represents the maximum ash deposition value in such cases. The ash deposition coefficient can also be adjusted based on the ash characteristics (softness, etc.).

[0029] The permissive condition, according to one embodiment of the present invention, is substantially df i =df max,i However, in a practical situation, the acceptable conditions can be defined as follows: df max,i -δ <df i ≦df max,i where δ>0 and depends on numerical precision and / or method. max,i -δ <df i ≦df max,i means that at least one exhaust gas coefficient calculated using currently monitored process data including a numerical model of the boiler satisfies the allowable condition, and in such a case, the maximum allowable boiler load is found, and therefore the value Q h,candidate However, the maximum instantaneous boiler load Q h,max is selected as.

[0030] The admissibility condition, according to one embodiment of the present invention, is substantially Σ(df i)=Σ(df max,i ), but in a practical situation, the tolerance condition can be defined using the sum of Σ(df max,i )-δ<Σ(df i )≦Σ(df max,i ) where δ>0 and depends on the numerical precision and / or method. Σ(df max,i )-δ<Σ(df i )≦Σ(df max,i ) means that at least one exhaust gas coefficient calculated using currently monitored process data including a numerical model of the boiler satisfies the allowable condition, and in such a case, the maximum allowable boiler load is found, and therefore the value Q h,candidate However, the maximum instantaneous boiler load Q h,max According to one embodiment, the summation index i is over all of the heat transfer surface. According to another aspect of the invention, the summation index i is over only a portion of the heat transfer surface, preferably within the exhaust gas channel.

[0031] It is particularly useful if the value of n is determined using monitored operational data for each of the boilers from a boiler fleet containing at least two separate boilers. Using a larger number of boilers (two, three, four, etc.) results in a larger data set; therefore, more operational data is monitored. This can produce better results, and may be particularly advantageous in situations where interpolation and / or extrapolation of experimental data is used in the determination.

[0032] The exhaust gas outlet temperature can be substantially estimated in the calculation of step I) by the following formula: T boiler,exit =α0+Σα i Q i h,candidate Alternatively, it is preferable to estimate the coefficient α using a first-, second-, third-, or higher-order approximation of the above equation. The coefficient α can be obtained by measuring the value of the exhaust gas outlet for several individual steam load values ​​and then fitting the measured value. This data can be collected over time and updated as needed, such as periodically. Alternatively or additionally, this data can be collected when performing one or more calibrations of the combustion boiler.

[0033] The coefficient (α) can be applied manually by a human or automatically by a computer using historical data. Automatic updates of the coefficients may be performed, for example, once a month. AI and neural network-based algorithms can be used for the automatic updates.

[0034] According to one embodiment of the present invention, the exhaust gas outlet temperature can be substantially estimated in step I) by utilizing an artificial intelligence tool. According to another embodiment of the present invention, the exhaust gas outlet temperature can be substantially estimated in step I) by utilizing a neural network.

[0035] The exhaust gas outlet temperature can be estimated in step I) according to one embodiment of the present invention by the following formula: T boiler,exit =α0+α1×Q h,candidate +α2×Q h,candidate 2 where α0, α1, and α2 can be predefined constants. Alternatively or additionally, the coefficients (α) can be fitted manually by a human or automatically by a computer using historical data. Automatic updating of the coefficients may be performed, for example, once a month. AI and neural network-based algorithms can be used for the automatic updating.

[0036] According to one embodiment of the present invention, the α 0 term can be solved based on the current state values. α0=T boiler,exit,current-α1×Q h,current -α2×Q h,current 2 where T boiler,exit,current represents the measured exhaust gas outlet temperature.

[0037] The exhaust gas mass flow rate is calculated in step II) according to one embodiment of the present invention using the boiler mass and energy balance equation.

[0038] In step II), the calculation of the flue gas mass flow rate may include taking into account the mass flow rates of the components CO2, H2O, N2, SO2, and O2, the concentrations of which can be reliably measured using relatively simple equipment.

[0039] In step II), the component values ​​can include fuel parameters, which can reflect changes in the fuel properties and / or the type of fuel used in the combustion boiler. For example, for fuels that tend to cause more corrosion, stricter tolerances can be used, while for fuels that tend to cause less corrosion, looser tolerances can be used.

[0040] Step b) may be performed remotely from the combustion boiler, preferably in a cloud-based computing service. This helps simplify maintenance of the combustion boiler, since a remote computing device, such as one configured to run the cloud-based computing service, can be maintained separately from the combustion boiler. Updates to computing software, for example, can thereby be performed centrally in one or a few locations, rather than updating software at each combustion boiler.

[0041] Step b) may alternatively be performed locally at the combustion boiler, preferably at an edge server, which may speed up the computation as data does not need to be transferred to a remote computation location.

[0042] Either the currently monitored process data and / or the current load may be obtained by real-time measurement. Alternatively, or in addition, the currently monitored process data and / or the current load may be processed by filtering, averaging, trend calculation, or any combination thereof. This helps to avoid noisy or outlier measurements that affect the calculation results, thereby facilitating increased stability of the currently calculated maximum boiler instantaneous load.

[0043] The tolerance condition may include a hysteresis condition that requires a predetermined minimum change before changing the current calculated maximum boiler instantaneous load, which is preferable because it can increase the stability of the current calculated maximum boiler instantaneous load and help prevent the current calculated maximum boiler instantaneous load from fluctuating up and down in a short period of time.

[0044] While this method can be used with any type of combustion boiler, the applicant has discovered that it is particularly useful when the combustion boiler is a circulating fluidized bed (CFB) or bubbling fluidized bed (BFB) boiler and step b) is performed on the combustion boiler heat transfer surface. This method is particularly advantageous for CFB or BFB boilers.

[0045] Step b) is, according to one embodiment, carried out on the combustion boiler heat transfer surface between the furnace and the chimney.

[0046] The combustion boiler comprises: - a furnace and associated passages defining an exhaust gas flow path and including several heat transfer surfaces; - Measuring equipment, monitoring the current load of combustion boilers, - separate measuring devices to monitor current process data, as well as - a control system configured to perform a boiler control method.

[0047] A fired boiler, according to one embodiment, includes a furnace and associated passages that define an exhaust gas flow path and include several heat transfer surfaces within the exhaust gas flow path.

[0048] In such a fired boiler, improved boiler control can be achieved. The advantages are the same as those of the method.

[0049] The control system may include an edge server that may be configured to process real-time measurements of currently monitored process data and / or current loads, i.e., by filtering, averaging, and / or calculating trends. The edge server may facilitate reducing the amount of currently monitored process data. This may be particularly useful in light of the fact that in certain installations, there may be 60-90 gigabytes of monitored process data each day.

[0050] The control system may be configured to perform step b) of the method to locally determine the current calculated maximum boiler instantaneous load, which may require less or no data to be transferred from the fired boiler system, facilitating faster decision making at the fired boiler.

[0051] Alternatively or additionally, the control system may be configured to transmit the data to a remote, preferably cloud-based, computing system that may be configured to perform step b) of the method and return the current calculated maximum boiler instantaneous load to the control system. This makes it easier to simplify the combustion boilers and to update the computing system. Updates can be performed centrally in this situation, rather than at each combustion boiler.

[0052] The edge server can be configured to reduce the amount of measurement data passed to the remote computing system. In this way, a smaller bandwidth may be sufficient for data transfer. This can be particularly useful considering the fact that in certain installations, there may be 60-90 gigabytes of monitored process data each day.

[0053] The combustion boiler calculation system includes: - a group of fired boilers comprising a boiler control system, each boiler comprising an edge server system configured to process, i.e., by filtering, averaging, and / or calculating trends, real-time measurements of currently monitored process data and / or current loads and to transmit the processed real-time measurements to a remote computing system; - a remote computing system, preferably a cloud-based computing system, configured to receive processed data from the real-time measurements, calculate the data for each of the boilers using a numerical boiler model, and return the calculated results to the respective boilers.

[0054] In the combustion boiler calculation system, the boiler control system is further configured to adapt a function of the boiler control system based on the calculation results.

[0055] The advantage of this configuration is that it reduces the need for computing devices at the combustion boiler, while still providing efficient and fast computational results from a remote computing system.

[0056] The computing system may be configured to find a numerical value or current calculated maximum boiler instantaneous load for which at least one flue gas coefficient calculated using currently monitored process data including a numerical model of the boiler satisfies an acceptable condition, and select this numerical value as the current calculated maximum boiler instantaneous load, which essentially allows the method of the present invention to be used in a distributed environment.

[0057] The boiler calculation system may be configured to use the processed measurement data of the boiler to calibrate or adapt a numerical model of the boiler, such as an exhaust gas coefficient numerical model, thereby making it easier to remotely calibrate or adapt the numerical model of the boiler control.

[0058] The boiler calculation system may be configured to use collected and processed measurement data from other boilers to adapt or calibrate the numerical model of the boiler, allowing more collected data to be used to adjust the numerical model of the boiler control.

[0059] The combustion boiler and combustion boiler control method are described in more detail below in connection with the embodiments shown in the accompanying drawings of FIGS. [Brief explanation of the drawings]

[0060] [Figure 1] FIG. 1 is a diagram showing a CFB boiler. [Figure 2] FIG. 1 is a diagram showing a BFB boiler. [Figure 3] FIG. 2 is a diagram showing the flow of measurement data from a sensor. [Figure 4] 1 is a flow chart illustrating a first method for finding the current calculated maximum boiler instantaneous load Qh,max. [Figure 5] 10 is a flow chart illustrating a second method for finding the current calculated maximum boiler instantaneous load Qh,max. [Figure 6] FIG. 10 illustrates how the current calculated maximum boiler instantaneous load Qh,max can be presented to the boiler operator. [Figure 7] 1 is a graph showing the boiler instantaneous load Qh and the calculated current maximum calculated boiler instantaneous load Qh, max, and the effect of using the method according to the invention during a test period. [Figure 8]Looking more closely at the data in Figure 7, the effect of using the method of the present invention becomes more apparent. Figure 7 is a graph showing the boiler instantaneous load Qh, the calculated current maximum calculated boiler instantaneous load Qh,max during the 10-day test period. DETAILED DESCRIPTION OF THE INVENTION

[0061] In all figures, the same reference numbers refer to the same technical features.

[0062] 1 shows a combustion boiler 10, which is a CFB boiler, comprising a furnace 12 with tube walls 13 connected to a water steam circuit of the combustion boiler 10. Water is supplied from a water tank (not shown) to an economizer, from which it is supplied to an evaporative heat transfer surface such as the tube walls 13 via a steam drum, and then directed via the steam drum to a superheater and then to a turbine. The exhaust gas channel may be provided with an economizer and / or a superheater.

[0063] Fluidizing gas (such as air and / or oxygen-containing gas) is supplied from a fluidizing gas supply 153 through a wind box (not shown) below the grate (the grate is not shown in FIG. 1 ). Primary fluidizing air enters the furnace from below the grate through a nozzle (not shown) (for fluidizing the bed) and a secondary fluidizing gas supply 152 (which supplies oxygen-containing gas to control combustion). As a result, the bed medium is fluidized and oxygen necessary for combustion is also supplied to the furnace 12. Furthermore, fuel is supplied to the furnace 12 via a fuel supply 22. Combustion can be adjusted by controlling the fuel supply 22 (e.g., by decreasing or increasing the fuel supply) and the fluidizing gas supply (e.g., by decreasing or increasing the amount of oxygen supplied to the furnace 12). The fuel can be supplied together with an additive, specifically, an additive that acts as an alkali sorbent, such as CaCO and / or clay. Additionally or alternatively, a NOx reducing agent, such as ammonium or urea, may be provided in or above the combustion zone of the furnace 12 .

[0064] A bed medium is also provided within the furnace and may include sand, limestone, and / or clay, the latter of which may specifically include kaolin. As a result of the bed, and generally of combustion, in the steam circuit, water and steam are heated within the tube walls 13, converting the water to steam.

[0065] The ash falls to the bottom of the furnace 12 and is removed via an ash chute (omitted from Figure 1 for clarity), and a portion of the ash, the so-called fly ash, is carried away with the exhaust gases.

[0066] Combustion products such as exhaust gas, unburned fuel, and bed media pass from the furnace 12 to a particle separator 17, which may include a vortex finder 103. The particle separator 17 separates the exhaust gas from the solids. Particularly in larger combustion boilers 10, there may be multiple (two, three, ...) separators 17, preferably arranged parallel to one another.

[0067] The solids separated by the separator 17 pass through a loop seal 160, preferably located at the bottom of the separator 17. The solids then proceed to a fluidized bed heat exchanger (FBHE) 100, which also serves as a heat transfer surface, whereby the FBHE 100 collects heat from the solids and further heats the steam in the steam circuit. The chamber within which the FBHE 100 is located can be fluidized, and the FBHE 100 itself comprises heat transfer tubes or other types of heat transfer surfaces. The FBHE 100 can be configured as a reheater or superheater. Steam is sent from the FBHE outlet 101 into a high-pressure turbine (if the FBHE 100 is a superheater) or an intermediate-pressure turbine (if the FBHE 100 is a reheater). For clarity, the turbines are not shown in FIG. 1. The solids can be returned from the FBHE 100 to the furnace 12 through a return channel 102. In particular, in larger combustion boilers 10, there may be multiple (two, three, etc.) loop seals 160 and FBHEs 100, and return channels 102, preferably arranged parallel to one another, so that there is a respective loop seal 160, FBHE 100, and return channel 102 for each separator 17. In practice, some of the FBHEs 100 may be arranged as superheaters and some may be arranged as reheaters.

[0068] From the separator 17 the flue gas is passed into a horizontal passage 15 from which it is passed further into a rear flue 16 (which may preferably be a vertical passage) from which it is passed through a flue gas conduit 18 to a chimney 19 .

[0069] The rear flue 16 is connected to several heat transfer surfaces 21 i (i=1, 2, 3, . . . , k, where k is the number of heat transfer surfaces). k-1 ,twenty one k The heat transfer surface 21 k indicates an air preheater. Heat transfer surface 21 k-1, 212 denote superheaters, and heat transfer surfaces 211, 213 denote reheaters. The actual number of different heat transfer surfaces in each of these components can be selected differently for each combustion boiler, for example, depending on the actual needs. Other components with heat transfer surfaces 21 may also be present.

[0070] Last heat transfer surface 21 k The exhaust gas exiting from the FG,exit This temperature is measured by the temperature sensor 20 k It is measured in

[0071] According to one embodiment, each heat transfer surface 21 i The temperatures before and after (T FG,in,i , T FG,in,i+1 ) are the temperature sensors 20 i (i=1, 2, 3, . . . , k-1, k).

[0072] However, in another embodiment, it is preferable that these temperatures do not necessarily need to be measured. FG,exit It will be sufficient to know the above-mentioned heat transfer surfaces 21 i The temperature before and after (T FG,in,i , T FG,in,i+1 ) can be obtained numerically, as will be explained further below.

[0073] The combustion boiler 10 is equipped with a number of sensors and computer units. th ) A combustion boiler 10 may generate 100 million measurements per day, which requires 25 GB of storage space. Figures 1, 2, and 3 show some sensors and computer units. Example sensors include a combustion gas (usually combustion air) volumetric flow sensor 30 (to measure the primary and secondary fluidization gas supply), a fuel supply sensor 650, and a temperature sensor 20. i(i=1, 2, . . . , k), there is a temperature sensor in the FBHE and a pressure sensor 116 in the return channel 102 (both present only in CFB boilers), as well as a sensor 40 in the furnace 12 .

[0074] Process data may be collected from the sensors by a distributed control system (DCS) 201. The data collection may be most conveniently located, for example, via a fieldbus 290. The DCS 201 may include a display / monitor 202 for displaying operational status information to an operator. An edge server 203 may process, such as filtering and smoothing, the measurement data obtained from the sensors. There may be local storage 204 for storing the data.

[0075] The DCS 201, display / monitor 202, edge server 203, and local storage 204 may be within a combustion boiler / network 280 (with local storage 204 preferably connected directly to the edge server). The combustion boiler network 280 is preferably independent of the fieldbus 290 used to communicate measurements from sensors to the DCS 201 and / or edge server 203. There may be an open platform communication server 210 (see FIG. 3) between the DCS 201 and edge server 203 to further enhance system interoperability.

[0076] The combustion boiler network 280 may be connected to the Internet 200, preferably via a gateway 290. Measurement results, in this situation, may be transferred from the combustion boiler network 280 to a cloud service, such as a process intelligence system 205 located in a computational cloud 206. Applicant currently operates a cloud service that runs the analytics platform. The cloud service may be operated in a virtualized server environment, such as Microsoft® Azure®, which is a virtualized, easily scalable environment for distributed computing and cloud storage of data. Other cloud computing services may also be suitable for running the analytics platform. Furthermore, a local or remote server may be used to run the analytics platform instead of or in addition to the cloud computing service.

[0077] Figure 2 shows a fired boiler 10 that is a BFB boiler. BFB boilers differ from CFB boilers in that the fluidized bed is a bubbling bed rather than a circulating bed. Therefore, the separator 17, loop seal 160, FBHE 100, and return channel 102 are not required.

[0078] Typically, there is at least one superheater 14 within the furnace 12, preferably in the upper portion of the furnace 12. The inlet 141 of the superheater 14 is from a steam drum or another superheater, and the outlet 142 is preferably to a high pressure turbine.

[0079] FIG. 4 shows a method for controlling a combustion boiler. a) The current load Q of the combustion boiler 10 h is monitored in step K1 (in the method shown in FIG. 4, the exhaust gas outlet temperature T FG,exit , and the heat transfer surface 21 in the exhaust gas flow path (vertical passage 16) i Heat load Q per fluid,i are also monitored. b) Number Q h,candidate is selected (step K3), and then the heat transfer surface 21 iHeat load at, and Q h,candidate The exhaust gas temperature is calculated for the value Q h,candidate Using currently monitored process data including a numerical model of the boiler that meets the acceptance criteria (tested in step K9), at least one exhaust gas coefficient df i (Step K7) and the value Q h,candidate The current calculated maximum boiler instantaneous load Q h,max (Step K11). c) Current calculated maximum boiler instantaneous load Q h、max is shown to the operator (such as by displaying on the monitor / screen 202), and / or the current load Q h but, c1) Calculated maximum instantaneous boiler load Q h,max If it is less than c1i) Boiler load Q h Indicate to the boiler operator that there may be an increase in c1ii) Boiler load Q h automatically increases, and / or c2) Calculated maximum instantaneous boiler load Q h,max If it is greater than c2i) Boiler load Q h indicates to the boiler operator that the maximum instantaneous boiler load is exceeded, and / or c2ii) Boiler load Q h is automatically reduced.

[0080] Step b) is a process for heating the combustion boiler 10 by heating the heat transfer surface 21 between the furnace 12 and the chimney 19. i Preferably, the method is performed on

[0081] In this method, the currently monitored boiler process data includes: a) the current exhaust gas outlet temperature T FG,exit , and b) the heat transfer surface 21 in the exhaust gas flow path (rear flue 16) i per heat load Q fluid,i may be included.

[0082] The method further includes the step of calculating the monitored process data from both a) and b) to obtain the exhaust gas coefficient df i When calculating the maximum boiler instantaneous load Q h,max For the number Q h,candidate It can be used when discovering

[0083] This finding is supported by at least one exhaust gas coefficient, df, calculated using currently monitored process data including a numerical model of the boiler. i If the following number Q cannot satisfy the tolerance condition, h,candidate is automatically selected. The automatic selection is preferably performed iteratively.

[0084] This finding can be done, as an example, by performing the following calculation steps: - I: The boiler heat load is Q h,candidate The boiler exhaust gas outlet temperature T, which is the boiler model calculated to be consistent with boiler,exit calculating an estimate of - II: Exhaust gas mass flow rate q m,fluegas A process of calculating - III: Heat transfer surface 21 in the exhaust gas flow path (rear flue 16) i Heat load Q per fluid,i,candidate , the numerical boiler model, Q fluid,i,candidate =Q fluid,i,current +Σα j,i (Q h,candidate ) j -Σpar j,i (Q h,current ) j The current heat load Q on the heat transfer surface, corrected by using fluid,i,current The process of calculating using - IV: Heat transfer surface 21 in the exhaust gas flow path (rear flue 16) i Calculated heat load Q per fluid,i,candidate The heat transfer surface 21 closest to the exhaust gas outlet in the upstream direction of the exhaust gas flow in the exhaust gas flow path (rear flue 16) is used. k From this, the estimated boiler exhaust gas outlet temperature T fluegas,out,m =TFG,exit The exhaust gas temperature (T fluegas,in,i , T fluegas,out,i , i=1,...,k). - V: Heat transfer surface 21 in the exhaust gas flow path (rear flue 16) i Exhaust gas coefficient df i , i=1,···, k.

[0085] parameter j,i ) can be fitted manually by a human or automatically by a computer using historical data. Automatic parameter updates may be performed, for example, once a month. AI and neural network-based algorithms can be used for the automatic updates.

[0086] In step II), the exhaust gas mass flow rate q m,fluegas,m It may include calculating:

[0087] The exhaust gas temperature at each heat transfer surface can be calculated, for example, using the following formula:

[0088]

number

[0089] Preferably, the exhaust gas coefficients include or are less than or equal to the following: df i =k i (q m,fluegas / (ρ fluegas,I A cross,i )) n where k iis a predetermined non-zero parameter, preferably a positive (non-zero) number, that can be specifically selected for a combustion boiler; q m,fluegas is the mass flow rate of the exhaust gas, n is a positive number (which may be chosen as a natural number, a rational number, a real number, or even a complex number), ρ fluegas,i is the i-th heat transfer surface 21 i Exhaust gas temperature T FG,in,i is the exhaust gas density obtained from A is the i-th heat transfer surface 21 i is the cross-sectional area of ​​the exhaust gas channel at

[0090] Advantageously, n may be chosen to be at least one of the following: i) if a calculated exhaust gas velocity is used, it is in the range of 0.9 to 1.1, preferably equal to or about 1.0; ii) When using corrosion-causing exhaust gases, the calculated range is between 2.9 and 3.5, preferably between 3.2 and 3.35; or iii) When pressure drop is used, it is in the range of 1.8 to 2.2, preferably equal to or about 2.0. The value of n may change over time. Specifically, the value of n may be determined from a group of combustion boilers, the group including at least two separate combustion boilers 10, and thus, the determination uses monitored operational data for each combustion boiler 10.

[0091] In the calculation of step I), an arbitrary value Q selected for the boiler load h,candidate Under this condition, the exhaust gas outlet temperature T FG,exit The calculated value of can be estimated by the following formula: T FG,exit =α0+Σα j (Q h,candidate ) j Alternatively, it is preferable to estimate the above equation using a first-order, second-order, or third-order or higher approximation. The coefficients α0, α1, α2, . . . are the individual boiler loads Q steamThe exhaust gas outlet temperature T FG,exit The values ​​of are measured and then obtained in advance by fitting.

[0092] In step II), the component q is used to determine the mass flow rate of the exhaust gas. m,fluegas,m Preferably, the calculation of m=CO2, H2O, N2, SO2, O2 includes at least some, most preferably all, of the following: In other words, in step IV) of the calculation, q m,fluegas,m As the value of q m,fluegas,CO2 , q m,fluegas,H20 , q m,fluegas,N2 , q m,fluegas,SO2 , q m,fluegas,O2 These are preferably measured in the exhaust gas conduit 18 or longitudinal groove 19, for which purpose suitable sensors are installed in the exhaust gas passage. In step II), the component values ​​can further include fuel parameters.

[0093] The exhaust gas mass flow rate is calculated based on the fuel analysis (proximate and final fuel analysis), combustion air flow rate, and / or the recirculated gas flow rate from the boiler mass and energy balance calculations. m、fluegas、m The calculation may be based on the sum of

[0094] The mass flow rate of the exhaust gas may preferably be calculated by the following formula: q m,fluegas =Σq m,fluegas,i That is, for example, the sum of the following exhaust gas mass flow components CO2, H2O, N2, SO2, and O2.

[0095]

number

[0096] Step b) may be performed remotely to the combustion boiler, such as in the process intelligence system 205. Step b) may alternatively be performed locally at the combustion boiler, preferably at the edge server 203.

[0097] Any currently monitored process data and / or current load may be obtained by real-time measurement, processed by filtering, averaging, calculating trends, or any combination thereof.

[0098] The allowable conditions include the current calculated maximum boiler instantaneous load Q h,max A hysteresis condition may be included that requires a predetermined minimum change before changing .

[0099] The permissible condition is that at least one calculated exhaust gas factor df i The maximum value df max,i Preferably, the method includes comparing the maximum value df max,i is a preset value, preferably a boiler-specific value. h,candidate is the maximum value df max,i If it exceeds, it is discarded.

[0100] In the combustion boiler 10, the furnace 12 and associated passages (horizontal passage 15 and rear flue 16) define a flue gas flow path. The furnace 12 and passages 15, 16 have several heat transfer surfaces 21 within the flue gas flow path. i The combustion boiler 10 is equipped with a current load Q of the combustion boiler. h and another measurement device for currently monitoring current process data.

[0101] The control system (DCS 201 and edge server 203, or possibly with the involvement of edge server 203, remote process intelligence system 205) is configured to execute the boiler control method.

[0102] The edge server 203 may be configured to process, i.e., by filtering, averaging, and / or trending, real-time measurements of currently monitored process data and / or current load.

[0103] The control system executes step b) of the method and calculates the current calculated maximum boiler instantaneous load Q of the combustion boiler 10. h,max locally determining and / or using the data to perform step b) of the method, and determining the current calculated maximum boiler instantaneous load Q h,max to a remote, preferably cloud-based (such as compute cloud 206) computing system (such as process intelligence system 205) that is configured to return the information to the control system. The control system may then present the information to the boiler operator, such as by displaying the information using a display / monitor, as in step c) of the method.

[0104] The edge server 203 may be configured to reduce the amount of measurement data passed to the remote computing system.

[0105] The combustion boiler computing system comprises a group of combustion boilers 10, each of which comprises a boiler control system (CS) comprising an edge server (203) system configured to process, i.e., filter, average, and / or calculate trends, real-time measurements of currently monitored process data and / or current loads and transmit the processed real-time measurements to a remote computing system. The remote computing system is preferably a cloud-based computing system configured to receive the processed data from the real-time measurements, calculate data using a numerical boiler model for each of the combustion boilers 10, and return the calculation results to each of the boilers 10. The boiler control system may be configured to adapt its functionality based on the calculation results.

[0106] The computing system calculates at least one exhaust gas coefficient df using currently monitored process data, including a numerical model of the boiler. i The maximum boiler instantaneous load Q that satisfies the allowable conditions is calculated as follows: h,max The numerical value Q for h,candidate Discover the number Q h,candidate The current calculated maximum boiler instantaneous load Q h,max Preferably, the device is configured to select the

[0107] The boiler calculation system may be configured to use the processed measurement data of the combustion boiler 10 to adapt or calibrate a numerical model of the boiler. Alternatively, or additionally, the boiler calculation system may be configured to use processed measurement data collected from other combustion boilers 10 to adapt or calibrate a numerical model of the combustion boiler 10.

[0108] Figure 5 shows a modification of the method shown in Figure 4. Steps L1, L3, L7, and L9 are the same as steps K1, K3, K9, and K11, respectively, but step L5 involves removing all heat transfer surfaces 20 i Regarding the exhaust gas coefficient dfi can be calculated directly, i.e., T FG,in,i , and each temperature sensor 21 i When the measurement is performed using the method shown in FIG. 5, step K7 can be omitted since back calculation is not necessary.

[0109] Figure 6 shows the available inputs to the numerical boiler model in step N1. h,max is calculated numerically using the boiler model and in step N5 the estimated maximum load Qh,max is presented to the boiler operator via a specific user interface (UI), preferably via a display / monitor 202.

[0110] Figure 7 shows the boiler instantaneous load Q h , and the calculated current maximum boiler instantaneous load Q h、max The results show the effect of using the method according to the present invention during the test period. th The boiler output was 3 to 6 MW on average during the test period. th Large loads were obtained. Figure 8 shows the 10-day test period in more detail.

[0111] In other words, in the boiler control method, a numerical model is used to calculate the current calculated maximum boiler instantaneous load Q of the combustion boiler using the determined operating parameters of the fluidized bed combustion boiler. h,max The current boiler load Q is estimated. h is calculated using measured data from the steam circuit.

[0112] Next, the boiler load Q h is the current calculated maximum boiler instantaneous load Q h,max If the boiler load Q is less than 0.001, then: i) indicate to the boiler operator that the boiler load may be increased; and / or ii) automatically increase the boiler load. Alternatively or additionally, h is the boiler maximum instantaneous load Q h,maxIf the value is greater than 0.05, then: i) indicate to the boiler operator that the boiler load is exceeding the boiler maximum instantaneous load; and / or ii) automatically reduce the boiler load.

[0113] It is obvious to those skilled in the art that with the advancement of technology, the basic idea of ​​the present invention can be implemented in many ways. The present invention and its embodiments are therefore not limited to the examples and samples described above, but can be modified within the scope of the claims and their legal equivalents.

[0114] In addition to or instead of using the specific empirical formulas referred to above, it is possible to utilize artificial intelligence tools and / or neural networks in the numerical model calculations.

[0115] In the following claims and in the foregoing description of the invention, unless the context otherwise requires, either by express wording or necessary implication, the word "comprise" or variations such as "comprises" or "comprising" are used in the inclusive sense, i.e., used to specify the presence of stated features but not to exclude the presence or addition of other features in various embodiments of the invention. [Explanation of symbols]

[0116] T FG,in,i heat exchanger 21 i Exhaust gas temperature at the inlet of (i=1, 2, k) T FG,exit heat exchanger 21 k Exhaust gas temperature at the outlet Sensor 20 Temperature sensor (FBHE) 20 i Temperature sensor (i=1, 2,...k) 30 Gas volume flow sensor 40 Sensor inside the furnace 165 Pressure sensor (loop seal) 650 fuel supply sensor 10 Combustion boiler 12 Furnace 13 Pipe wall 14 Superheater 15 horizontal passage 16 Rear flue 17 Particle separator 18 Exhaust gas pipe 19 Vertical grooves twenty one i Heat transfer surface (i=1, 2,...k) 22 Fuel supply section 100 Fluidized bed heat exchanger (FBHE) 101 FBHE Exit 102 Return Channel 103 Vortex Finder 141 Superheater inlet 142 Superheater outlet 151 Primary fluidization gas supply section 152 Secondary fluidization gas supply section 153 Fluidizing Gas Supply Source 161 Reheater output 200 Internet 201 Distributed Control System 202 Display / Monitor 203 Edge Server 204 Local Storage 205 Process Intelligence Systems 206 Computational Cloud 210 Open Platform Communication Server 280 Combustion Boiler Network 290 Fieldbus

Claims

1. A combustion boiler control method, comprising: a) The boiler load (Q ｈ ) monitoring the b) at least one exhaust gas coefficient (df ｉ ) satisfies the allowable conditions, the current calculated maximum boiler instantaneous load (Q ｈ，ｍａｘ ) to the numerical value (Q ｈ，ｃａｎｄｉｄａｔｅ ), and finding the value (Q ｈ，ｃａｎｄｉｄａｔｅ ) to the current calculated maximum boiler instantaneous load (Q ｈ，ｍａｘ ) as c) The current calculated maximum boiler instantaneous load (Q ｈ、ｍａｘ ) to an operator, and / or ｈ )but, c1) The current calculated maximum boiler instantaneous load (Q ｈ，ｍａｘ ), c1i) the boiler load (Q ｈ and / or c1ii) The boiler load (Q ｈ ) automatically increasing the and / or c2) The current calculated maximum boiler instantaneous load (Q ｈ，ｍａｘ ), c2i) the boiler load (Q ｈ ) exceeds the current calculated maximum boiler instantaneous load; and / or c2ii) The boiler load (Q ｈ ) automatically reducing A method comprising:

2. i) the currently monitored process data of the combustion boiler, ia) The current exhaust gas outlet temperature (T ｆｌｕｅ ｇａｓ，ｅｘｉｔ，ｃｕｒｒｅｎｔ )and, ib) the heat load (Q ｆｌｕｉｄ，ｉ )and and ii) monitored process data from both ia) and ib) is used in calculating the flue gas coefficient, and the current calculated maximum boiler instantaneous load (Q ｈ，ｍａｘ ) to the numerical value (Q ｈ，ｃａｎｄｉｄａｔｅ ) is used when discovering The method of claim 1.

3. The at least one exhaust gas coefficient (df ｉ ) does not satisfy the tolerance condition, the discovery is ｈ，ｃａｎｄｉｄａｔｅ 3. The method of claim 1, wherein the method is performed so that the first and second selections are automatically selected.

4. The next numerical value (Q ｈ，ｃａｎｄｉｄａｔｅ 4. The method of claim 3, wherein:

5. The discovery - I: The thermal load of the combustion boiler is the value (Q ｈ，ｃａｎｄｉｄａｔｅ ) is consistent with the boiler exhaust gas outlet temperature (T ｂｏｉｌｅｒ，ｅｘｉｔ ) calculating an estimate of II: When the thermal load of the combustion boiler matches the value (Q h,candidate ), the exhaust gas mass flow rate (q ｍ，ｆｌｕｅｇａｓ ) -III: Heat load (Q ｆｌｕｉｄ，ｉ，ｃａｎｄｉｄａｔｅ ) to (Q ｆｌｕｉｄ，ｉ，ｃａｎｄｉｄａｔｅ =Q ｆｌｕｉｄ，ｉ，ｃｕｒｒｅｎｔ +Σα ｊ，ｉ (Q ｓｔｅａｍ，ｍａｘ ) ｊ -Σα ｊ，ｉ (Q ｓｔｒｅａｍ，ｃｕｒｒｅｎｔ ) ｊ ) the current heat load (Q ｆｌｕｉｄ，ｉ，ｃｕｒｒｅｎｔ ) calculating using - IV: The calculated heat load (Q ｆｌｕｉｄ，ｉ，ｃａｎｄｉｄａｔｅ ) is used, and the heat transfer surface 21 in the exhaust gas flow path is closest to the boiler exhaust gas outlet in the upstream direction of the exhaust gas flow. ｋ From the above, the estimated value of the boiler exhaust gas outlet temperature (T ｆｌｕｅｇａｓ，ｏｕｔ，ｋ = T boiler, exit) at each heat transfer surface. ｆｌｕｅｇａｓ，ｉｎ，ｉ , T ｆｌｕｅｇａｓ，ｏｕｔ，ｉ , i=1, ..., k), - V: exhaust gas coefficient (df ｉ , i=1, . . . , k) The method according to any one of claims 1 to 4, which is carried out by performing the following steps.

6. The exhaust gas coefficient includes or is the following formula: [Equation 1] Here, k ｉ is a non-zero parameter that may be selected in particular for a combustion boiler, q ｍ，ｆｌｕｅｇａｓ is the mass flow rate of the exhaust gas, n is a model parameter that can be specifically selected for a combustion boiler, and ρ ｆｌｕｅｇａｓ，ｉ 6. The method of claim 5, wherein ∑ i = ∑ i ...

7. n is i) in the range of 0.9 to 1.1 when taking into account the calculated exhaust gas velocity; ii) in the range of 2.9 to 3.5 when taking into account calculated exhaust gas induced corrosion; or iii) When pressure loss is taken into consideration, the range is 1.8 to 2.2 The method of claim 6 , wherein the selected value is at least one of:

8. The method of claim 7 , wherein the value of n is varied over time.

9. 9. The method of claim 7 or 8, wherein the value of n is determined using operational data monitored for each of the fired boilers from a group of boilers including at least two separate boilers.

10. In the calculation of step I), the boiler exhaust gas outlet temperature is substantially calculated by the formula T ｂｏｉｌｅｒ，ｅｘｉｔ =a ０ +Sa ｊ (Q) ｈ，ｃａｎｄｉｄａｔｅ ) ｊ Alternatively, the coefficients (α ０ , α １ , α ２ , ...) are divided into several individual boiler loads (Q ｓｔｅａｍ 10. The method according to any one of claims 5 to 9, wherein the boiler exhaust gas outlet temperature (Tboiler,exit) is measured relative to the value of the boiler exhaust gas temperature (Tboiler,exit), and then a predetermined function is applied to the measured value, and the boiler exhaust gas outlet temperature (Tboiler,exit) is previously obtained by the applied function.

11. In step II), the exhaust gas mass flow rate is calculated using the mass flow rate (q ｍ，ｆｌｕｅｇａｓ，ｍ ) is used, and the exhaust gas components include CO ２ , H ２ O, N ２ , S.O. ２ , O ２ The method according to any one of claims 5 to 10, comprising:

12. 12. The method according to any one of claims 5 to 11, wherein in step II) the calculation of exhaust gas mass flow rate includes fuel parameters.

13. The method according to any one of claims 1 to 12, wherein step b) is performed remotely with respect to the combustion boiler.

14. The method according to any one of claims 1 to 12, wherein step b) is carried out locally in the combustion boiler.

15. The currently monitored process data and / or current load are both obtained by real-time measurement, processed by filtering, processed by averaging, calculating trends, or any combination thereof; The method according to any one of claims 1 to 14.

16. The allowable conditions include the maximum boiler instantaneous load (Q ｈ，ｍａｘ The method of any one of claims 1 to 15, including a hysteresis condition requiring a predetermined minimum change in the at least one exhaust gas coefficient (df i ) before changing the at least one exhaust gas coefficient (df i ).

17. The permissive condition is determined based on the calculated at least one exhaust gas coefficient (df ｉ ) to respective design values, wherein the method ｈ，ｃａｎｄｉｄａｔｅ 17. The method according to claim 1, wherein the amount of the molten metal is discarded if the amount of the molten metal exceeds the design value.

18. 18. The method according to any one of claims 1 to 17, wherein the combustion boiler is a circulating fluidized bed (CFB) boiler or a bubbling fluidized bed (BFB) boiler, and step b) is performed on a heat transfer surface of the combustion boiler, optionally including a furnace (12), located between the furnace (12) and a chimney (19).

19. - several heat transfer surfaces (21) defining an exhaust gas flow passage and located within said exhaust gas flow passage; ｉ a furnace (12) and associated passages (15, 16) comprising - the current load of the combustion boiler (10) (Q ｈ ) and a measuring device for monitoring the - sensors (20, 20) that monitor current process data ｉ , 30, 40, 116, 165, 650) and another measuring device, a control system (CS 201, 203, 205) configured to implement the boiler control method according to any one of claims 1 to 18; A combustion boiler comprising:

20. 20. The combustion boiler (10) according to claim 19, wherein the control system (CS) comprises an edge server (203) configured to process real-time measurements of currently monitored process data and / or current load, i.e. by filtering, averaging and / or calculating trends.

21. The control system executes step b) of the method to calculate the current calculated maximum boiler instantaneous load (Q ｈ、ｍａｘ 21. The combustion boiler of claim 19 or 20, configured to locally determine

22. The control system executes step b) of the method to calculate the current calculated maximum boiler instantaneous load (Q ｈ、ｍａｘ 21. The combustion boiler of claim 19 or 20, configured to transmit data to a remote computing system configured to return a signal to the control system.

23. The control system is configured to transmit data to a remote computing system configured to perform step b) of the method and return the current calculated maximum boiler instantaneous load (Q h,max ) to the control system; The combustion boiler of claim 20 , wherein the edge server is configured to reduce the amount of process data passed to the remote computing system.

24. a group of fired boilers (10) according to any one of claims 19 to 22, comprising at least two separate boilers, each boiler comprising a boiler control system (DCS) comprising an edge server (203) system configured to process, i.e. by filtering, averaging and / or calculating trends, said real-time measurements of currently monitored process data and / or current loads and to transmit said processed real-time measurements to a remote computing system (205); a remote computing system (205) configured to receive processed data from the real-time measurements, calculate the data for each of said combustion boilers (10) using a numerical boiler model, and return the calculation results to each of said combustion boilers (10); A combustion boiler calculation system comprising: the boiler control system is configured to adapt its functioning based on the results of the calculations, and the remote computing system calculates at least one exhaust gas coefficient (df ｉ ) satisfies the allowable conditions, the current calculated maximum boiler instantaneous load (Q ｈ，ｍａｘ ) to the numerical value (Q ｈ，ｃａｎｄｉｄａｔｅ ) and find the value (Q ｈ，ｃａｎｄｉｄａｔｅ ) to the current calculated maximum boiler instantaneous load (Q ｈ，ｍａｘ ) as the combustion boiler calculation system.

25. 25. The combustion boiler calculation system of claim 24, wherein the combustion boiler calculation system is configured to use processed measurement data of the combustion boiler to adapt or calibrate a numerical model of the combustion boiler.

26. The combustion boiler calculation system according to any one of claims 24 to 25, wherein the combustion boiler calculation system is configured to adapt or calibrate a numerical model of the combustion boiler (10) using processed measurement data also collected from other combustion boilers (10).

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