Thermal power plant flue gas synergistic removal method and equipment based on calcium hydroxide enhancement

Abstract

The invention discloses a thermal power plant flue gas synergistic removal method and device based on calcium hydroxide enhancement, and relates to the technical field of flue gas treatment.The method comprises the steps that the sulfur oxide concentration of a dust remover outlet and the sulfur oxide concentration of a desulfurizing tower outlet are monitored in real time, the concentration deviation is calculated, and the removal compensation requirement is output; performing feature classification according to compensation requirements, and determining a compensation type; the reference pump set configuration and the desulfurizing agent proportion are called to serve as scheduling and optimization starting points; on the basis, the dynamic proportion of the desulfurizing agent is optimized, and real-time pump cooperative control parameters and the proportion of calcium hydroxide are generated; finally, the K-layer calcium hydroxide feeding pump and the H-layer limestone slurry circulating pump are driven, and gradient spraying desulfurization cooperative control is achieved. Therefore, the technical effects of improving the desulfurization efficiency, reducing the energy consumption and enhancing the process flexibility are achieved.

Description

Technical Field

[0001] The present invention relates to the technical field of flue gas treatment, and in particular to a method and equipment for collaboratively removing flue gas from a thermal power plant based on calcium hydroxide enhancement. Background Art

[0002] In the field of flue gas treatment in thermal power plants, traditional methods mostly use a single limestone-gypsum wet desulfurization process to remove sulfur oxides, achieving removal through the reaction of limestone slurry with sulfur oxides in the flue gas. On the one hand, traditional desulfurization methods are difficult to respond quickly and accurately to changes in sulfur oxide concentrations, and there is an upper limit to the removal efficiency, making it difficult to meet ultra-low emission standards. On the other hand, the equipment operating mode is relatively fixed, and the pump group configuration and desulfurizer ratio cannot be flexibly adjusted according to real-time removal needs. This leads to high system energy consumption, poor economic efficiency, and a lack of flexibility in dealing with different operating conditions, making it difficult to achieve the unity of efficient synergistic removal and energy efficiency optimization. Summary of the Invention

[0003] The present invention provides a method and equipment for collaborative flue gas removal from thermal power plants based on calcium hydroxide enhancement, so as to solve the technical problems of low desulfurization efficiency, high energy consumption of the desulfurization system and poor process flexibility in the prior art, and achieve the technical effects of improved desulfurization efficiency, reduced energy consumption and enhanced process flexibility.

[0004] In a first aspect, the present invention provides a method for collaboratively removing flue gas from a thermal power plant based on calcium hydroxide enhancement, wherein the method for collaboratively removing flue gas from a thermal power plant based on calcium hydroxide enhancement comprises:

[0005] Real-time monitoring of the input sulfur oxide concentration at the dust collector outlet and the exhaust sulfur oxide concentration at the desulfurization tower outlet.

[0006] The concentration deviation is calculated based on the input sulfur oxide concentration and the discharged sulfur oxide concentration, and a real-time removal compensation demand is output.

[0007] Compensation characteristics are classified according to the real-time compensation removal requirements to obtain a real-time compensation type.

[0008] According to the real-time compensation type, a benchmark pump group configuration and a benchmark desulfurization agent ratio are called from a benchmark desulfurization configuration library.

[0009] The base pump group configuration is used as the pump group scheduling limit, the base desulfurizer ratio is used as the optimization starting point, the desulfurizer dynamic ratio is optimized according to the real-time removal compensation demand, and the real-time pump coordinated control parameters and real-time calcium hydroxide ratio are output.

[0010] The real-time pump coordinated control parameters and the real-time calcium hydroxide ratio are used to jointly drive the K layer calcium hydroxide dosing pump and the H layer limestone slurry circulation pump to collaboratively remove sulfur oxides in the desulfurization tower through gradient spraying.

[0011] In a second aspect, the present invention further provides a thermal power plant flue gas collaborative removal device based on calcium hydroxide enhancement, wherein the thermal power plant flue gas collaborative removal device based on calcium hydroxide enhancement comprises:

[0012] The concentration monitoring module is used to monitor the input sulfur oxide concentration at the dust collector outlet and the exhaust sulfur oxide concentration at the desulfurization tower outlet in real time.

[0013] The demand compensation module is used to calculate the concentration deviation based on the input sulfur oxide concentration and the exhaust sulfur oxide concentration, and output the real-time removal compensation demand.

[0014] The compensation feature classification module is used to classify the compensation features according to the real-time compensation removal requirements to obtain a real-time compensation type.

[0015] The benchmark configuration calling module is used to call the benchmark pump group configuration and the benchmark desulfurization agent ratio from the benchmark desulfurization configuration library according to the real-time compensation type.

[0016] The dynamic ratio optimization module is used to optimize the desulfurizer dynamic ratio based on the real-time removal compensation requirements using the benchmark pump group configuration as the pump group scheduling limit and the benchmark desulfurizer ratio as the optimization starting point, and output the real-time pump coordinated control parameters and the real-time calcium hydroxide ratio.

[0017] The collaborative desulfurization execution module is used to adopt the real-time pump collaborative control parameters and real-time calcium hydroxide ratio to jointly drive the K layer calcium hydroxide dosing pump and the H layer limestone slurry circulation pump to collaboratively remove sulfur oxides in the desulfurization tower through gradient spraying.

[0018] The present invention discloses a method and device for collaboratively removing flue gas from a thermal power plant based on calcium hydroxide enhancement, comprising: obtaining the concentration of sulfur oxides in the air inlet at the outlet of the dust collector and the concentration of sulfur oxides discharged from the outlet of the desulfurization tower in real time; calculating based on the concentration difference between the two to determine the desulfurization compensation amount required by the current system; characteristically classifying the desulfurization compensation amount to identify the corresponding compensation type; extracting the corresponding pump group configuration scheme and desulfurizer basic ratio parameters from a preset benchmark desulfurization configuration library based on the compensation type; using the extracted pump group configuration as the scheduling range and the basic desulfurizer ratio as the optimization starting point, and combining the actual The desulfurizer ratio is dynamically optimized based on the compensation demand, and the coordinated parameters of the pump group and the real-time ratio of calcium hydroxide for control are output; based on the control parameters and the ratio values, the calcium hydroxide dosing pump of the K layer and the limestone slurry circulation pump of the H layer are controlled in conjunction with each other, and a highly efficient and coordinated sulfur oxide removal process is achieved in the desulfurization tower through gradient spraying. The method and equipment for coordinated flue gas removal from thermal power plants based on calcium hydroxide enhancement disclosed in the present invention solve the technical problems of low desulfurization efficiency, high energy consumption of the desulfurization system, and poor process flexibility, and achieve the technical effects of improved desulfurization efficiency, reduced energy consumption, and enhanced process flexibility. BRIEF DESCRIPTION OF THE DRAWINGS

[0019] Figure 1 The figure is a schematic flow chart of the method for collaboratively removing flue gas from thermal power plants based on calcium hydroxide enhancement according to the present invention.

[0020] Figure 2 This is a schematic structural diagram of the calcium hydroxide-enhanced flue gas collaborative removal equipment for thermal power plants according to the present invention.

[0021] Explanation of the reference numerals: concentration monitoring module 11 , demand compensation module 12 , compensation feature classification module 13 , benchmark configuration calling module 14 , dynamic ratio optimization module 15 , collaborative desulfurization execution module 16 . DETAILED DESCRIPTION

[0022] The above technical solution will be described in detail below in conjunction with the accompanying drawings and specific implementation methods of the specification to better understand the above technical solution. Obviously, the described embodiments are only part of the embodiments of the present invention, rather than all the embodiments of the present invention. It should be understood that the present invention is not limited to the example embodiments used only to explain the present invention. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without making creative work are within the scope of protection of the present invention. In addition, it should be noted that, for the convenience of description, only the parts related to the present invention, rather than all, are shown in the drawings.

[0023] Example 1, as Figure 1 The present invention is a flow diagram of a method for collaboratively removing flue gas from a thermal power plant based on calcium hydroxide enhancement, wherein the method for collaboratively removing flue gas from a thermal power plant based on calcium hydroxide enhancement comprises:

[0024] S100: Real-time monitoring of the input sulfur oxide concentration at the dust collector outlet and the exhaust sulfur oxide concentration at the desulfurization tower outlet.

[0025] Specifically, the input sulfur oxide concentration refers to the sulfur oxide (SO ) detected at the outlet of the dust collector before the flue gas enters the desulfurization system (such as the desulfurization tower). x ) concentration, which reflects the initial content of pollutants in the flue gas to be treated; the exhaust sulfur oxide concentration refers to the concentration of sulfur oxides remaining in the flue gas after treatment at the outlet of the desulfurization tower, which is used to evaluate the desulfurization efficiency and emission compliance; sulfur oxides can include sulfur dioxide (SO2), sulfur trioxide (SO3) and other forms, and the concentration unit can be mg / Nm 3 Or ppm, converted and monitored according to relevant standards.

[0026] Through the above-mentioned real-time monitoring, the concentration changes of pollutants before and after treatment can be grasped in real time, the visualization level of the desulfurization system operation status can be improved, and subsequent intelligent control optimization can be supported.

[0027] In some embodiments, real-time monitoring of the input sulfur oxide concentration at the dust collector outlet and the exhaust sulfur oxide concentration at the desulfurization tower outlet includes:

[0028] The input SO2 concentration and input flue gas characteristic parameters are collected by the MGA5 flue gas analyzer installed at the outlet of the dust collector, wherein the input flue gas characteristic parameters include input flue gas flow rate, input operating flow rate, input flue gas temperature, input flue gas humidity and input flue gas oxygen content; the input SO3 concentration is collected by the ESC sulfuric acid mist sampling system installed at the outlet of the dust collector, wherein the input SO2 concentration, input SO3 concentration and input flue gas characteristic parameters constitute the input sulfur oxide concentration; and so on, the exhaust sulfur oxide concentration at the outlet of the desulfurization tower is monitored in real time.

[0029] Specifically, this embodiment realizes real-time monitoring of input and exhaust sulfur oxide concentrations through the following steps. First, an MGA5 flue gas analyzer is installed at the outlet of the dust collector to collect the input SO2 concentration and input flue gas characteristic parameters in real time, wherein the input flue gas characteristic parameters include input flue gas flow rate, input operating flow rate, input flue gas temperature, input flue gas humidity and input flue gas oxygen content; at the same time, an ESC sulfuric acid mist sampling system is installed at the same position to collect the input SO3 concentration, and the above-mentioned SO2 concentration, SO3 concentration and flue gas characteristic parameters are integrated and processed to generate an input sulfur oxide concentration data set; further, a monitoring equipment combination similar to the input end is set at the outlet of the desulfurization tower, that is, an MGA5 flue gas analyzer and an ESC sulfuric acid mist sampling system are configured to collect the exhaust SO2 concentration, exhaust SO3 concentration and exhaust flue gas characteristic parameters after desulfurization treatment in real time, and integrate the relevant parameters to generate an exhaust sulfur oxide concentration data set.

[0030] Optionally, the input and discharge concentration data are synchronously transmitted through a data acquisition system (such as DCS or PLC), thereby providing reliable data support for subsequent intelligent control strategies (such as automatic adjustment of desulfurizers) or environmental alarm mechanisms, thereby improving system operating efficiency and emission compliance.

[0031] S200: Calculating concentration deviation based on the input sulfur oxide concentration and the discharged sulfur oxide concentration, and outputting a real-time removal compensation requirement.

[0032] Specifically, concentration deviation calculation refers to the process of quantitatively evaluating the degree to which the pollutant removal efficiency of the desulfurization system under the current operating conditions deviates from the target pollutant removal efficiency based on the difference between the input sulfur oxide concentration and the exhaust sulfur oxide concentration, combined with the flue gas characteristic parameters for standardization.

[0033] Specifically, the real-time removal compensation demand is a quantitative indicator set to guide the dynamic correction of pollutant removal efficiency and resource allocation under the consideration of the coordinated control goals of multiple pollutants such as SO2 and SO3. It can be considered as the required control amount.

[0034] In some embodiments, calculating the concentration deviation based on the input sulfur oxide concentration and the exhaust sulfur oxide concentration and outputting the real-time removal compensation demand includes:

[0035] Based on the input flue gas characteristic parameters, the input SO2 concentration and the input SO3 concentration are standardized to obtain a first standardized input concentration and a second standardized input concentration; similarly, the discharged sulfur oxide concentration is standardized to obtain a first standardized output concentration and a second standardized output concentration; the first standardized input concentration, the second standardized input concentration, the first standardized output concentration and the second standardized output concentration are substituted into the removal efficiency formula to calculate and output the real-time removal efficiency, wherein the real-time removal efficiency includes the SO2 removal efficiency and the SO3 removal efficiency; the pollutant collaborative control constraint is locally called; according to the pollutant collaborative control constraint, the control deviation of the real-time removal efficiency, the first standardized output concentration and the second standardized output concentration is judged, and the real-time removal compensation demand is output.

[0036] Specifically, input flue gas characteristic parameters refer to the physical and chemical properties of the flue gas before it enters the desulfurization system. These parameters primarily include flue gas temperature, pressure, moisture content (humidity), oxygen content, and flue gas volume flow rate. These parameters directly affect the gaseous stability, absorption reaction rate, and measurement accuracy of SO2 and SO3. Real-time removal efficiency refers to the actual removal ratio of SO2 and SO3 by the desulfurization system under current operating conditions, typically expressed as a percentage.

[0037] Specifically, pollutant coordinated control constraints refer to the logic or optimization rules followed when controlling the emissions of multiple pollutants, such as prioritizing the control of SO3 to suppress plume formation or performing a weighted balance on the removal efficiency of SO2 and SO3 when the total absorbent dosage is limited.

[0038] Specifically, this embodiment implements the calculation and output of the real-time removal compensation demand through the following steps:

[0039] First, based on the input flue gas characteristic parameters (including input flue gas flow rate, temperature, humidity, oxygen content, etc.), the input SO2 concentration and the input SO3 concentration are standardized; a first standardized input concentration (such as SO2 is 295ppm) and a second standardized input concentration (such as SO3 is 37ppm) are obtained; similarly, based on the exhaust flue gas characteristic parameters, the exhaust SO2 concentration and the exhaust SO3 concentration are standardized; a first standardized output concentration (such as SO2 is 20ppm) and a second standardized output concentration (such as SO3 is 12ppm) are obtained. For example, the measured concentration value is converted to the concentration under standard conditions using the standard state correction formula:

[0040]

[0041] Among them, C real is the original measured concentration; P real 、T real are the pressure and temperature of the flue gas during measurement; P ref 、T ref = ...

[0042] Then, substitute the above four standardized concentration values into the following removal efficiency calculation formula:

[0043]

[0044] Among them, η i It represents the real-time removal efficiency of the i-th sulfur oxide, in percentage (%), reflecting the removal ability of the desulfurization system to the pollutant under the current operating conditions; for example, when i=1, it represents the removal efficiency of SO2; when i=2, it represents the removal efficiency of SO3.

[0045] Among them, C in,i represents the first standardized input concentration of the i-th sulfur oxide, C out,i It represents the first standardized output concentration of the i-th sulfur oxide.

[0046] For example, the real-time removal efficiencies of SO 2 and SO 3 are calculated respectively: η 1 = (295-20) / 295≈93.22%; η 2 = (37-12) / 37≈67.57%.

[0047] Furthermore, the local pollutant collaborative control constraints are called, including the lower limit of the target removal efficiency, the control deviation threshold, and the upper limit of the system operation. Then, the real-time removal efficiency, the first and second standardized output concentrations are compared with the pollutant collaborative control constraints. It is determined whether there is a control deviation. If the deviation exceeds the threshold, the real-time removal compensation demand is output to guide the dynamic adjustment of parameters such as absorbent dosage and spray intensity. For example, if the collaborative control target is set as: SO2 removal efficiency ≥ 99.5%, SO3 removal efficiency ≥ 65%, then the current SO2 does not meet the standard, but SO3 meets the standard. It is further determined whether the SO3 emission concentration exceeds the emission limit, and the corresponding compensation mechanism is triggered.

[0048] In the above method steps, SO2 and SO3 concentrations are standardized by introducing flue gas characteristic parameters, effectively eliminating measurement errors caused by environmental factors such as temperature, pressure, and humidity, thereby achieving more accurate concentration comparison and removal efficiency assessment. Furthermore, by calculating the SO2 and SO3 removal efficiencies separately and combining them with pollutant collaborative control constraints to determine deviations, the system can distinguish the control priorities and response mechanisms for different pollutants, achieving differentiated and precise compensation control.

[0049] In some implementations, performing control deviation judgment on the real-time removal efficiency, the first standardized output concentration, and the second standardized output concentration based on the pollutant coordinated control constraint, and outputting the real-time removal compensation requirement includes:

[0050] A dual removal efficiency constraint and a dual outlet concentration constraint are extracted from the pollutant coordinated control constraint; a first deviation is calculated for the first standardized output concentration and the second standardized output concentration based on the dual outlet concentration constraint; a second deviation is calculated for the real-time removal efficiency based on the dual removal efficiency constraint; a desulfurization deviation matrix is constructed by fusing the first deviation and the second deviation as the real-time removal compensation demand.

[0051] Specifically, the dual outlet concentration constraint refers to the upper limit requirements set by the system for SO2 and SO3 emission concentrations, respectively, which are used to meet environmental emission standards or corporate internal control objectives; the dual removal efficiency constraint refers to the minimum requirements set by the system for the removal efficiency of SO2 and SO3, which are used to ensure the operating effect of the desulfurization system.

[0052] For example, the constraint expression is:

[0053]

[0054] η1≥99.5%,η2≥65%;

[0055] Specifically, first, the dual outlet concentration constraint and dual removal efficiency constraint are extracted from the pollutant coordinated control constraints and used as the concentration control target and efficiency control target, respectively. Then, the first standardized output concentration (SO2) and the second standardized output concentration (SO3) of the current emission end are subtracted from the corresponding concentration constraints to obtain the concentration deviation value. At the same time, the current real-time removal efficiency (including SO2 and SO3) is obtained and subtracted from the dual removal efficiency constraint to obtain the efficiency deviation value. Then, the above two types of deviations are integrated to construct the desulfurization deviation matrix as follows:

[0056]

[0057] Then, obtain the real-time removal compensation demand.

[0058] The deviation matrix constructed through the above process provides accurate and quantitative compensation target information for subsequent analysis, which helps to quickly identify the source of deviation and perform targeted compensation, thereby improving the accuracy and speed of adjustment.

[0059] In some implementations, the step of normalizing the input SO2 concentration and the input SO3 concentration based on the input flue gas characteristic parameter to obtain a first standardized input concentration and a second standardized input concentration includes:

[0060] According to the input flue gas flow rate and input flue gas humidity, a dry flow conversion calculation is performed to obtain the input dry flow rate; according to the input flue gas temperature, the input operating condition flow rate is temperature-corrected to obtain the input standard flow rate; according to the input flue gas oxygen content, the input dry flow rate and the input standard flow rate are oxygen content-corrected to obtain the input standard dry flow rate; according to the standard dry flow rate and the input flue gas oxygen content, the oxygen content is converted to output the input oxygen-converted flow rate; according to the input SO2 concentration, the input oxygen-converted flow rate and the input standard dry flow rate, the first standardized input concentration is calculated and output; according to the input SO3 concentration, the input oxygen-converted flow rate and the input standard dry flow rate, the second standardized input concentration is calculated and output.

[0061] Specifically, according to the input flue gas flow Q wet (wet state) and input flue gas humidity H, and perform dry state flow conversion:

[0062] Q dry =Q wet ×(1-H);

[0063] Here, humidity H represents the volume fraction of water vapor.

[0064] Furthermore, the input working condition flow is temperature corrected to obtain the input standard flow Q std .

[0065]

[0066] Among them, T ref is the standard temperature (273.15K), T real is the actual flue gas temperature (unit K).

[0067] Furthermore, according to the oxygen content of the input flue gas The dry flow rate and the standard flow rate are corrected for oxygen content to obtain the standard dry flow rate Q std,dry .

[0068]

[0069] in, is the reference oxygen content (e.g. 6%).

[0070] Furthermore, according to the standard dry state flow rate and the oxygen content of the input flue gas, the oxygen content is further converted to obtain the input oxygen content conversion flow rate Q O2-corr , used for concentration conversion, where the calculation formula is the same as the standard dry state flow rate Q std,dry Same, can be regarded as a combined step (two-level conversion)

[0071] Furthermore, according to the input SO2 concentration Calculate the first standardized input concentration based on the oxygen-containing converted flow rate and the standard dry flow rate

[0072]

[0073] Similarly, according to the input SO3 concentration Calculate the second standardized input concentration based on the oxygen-containing converted flow rate and the standard dry flow rate

[0074]

[0075] Through the above-mentioned standardization processing method, the influence of factors such as flue gas temperature, humidity, and oxygen content is taken into consideration, and the measurement error caused by changes in operating conditions can be eliminated. The original concentration value can be converted to a unified standard dry state, which is conducive to direct comparison with emission standards and control thresholds; at the same time, using the standardized concentration as the basic input for subsequent deviation judgment and compensation control helps to improve the accuracy of the control strategy. It is applicable to flue gas characteristics under different boiler types, fuel types and operating conditions, and has strong versatility and engineering adaptability.

[0076] S300: Classifying compensation characteristics according to the real-time compensation removal requirement to obtain a real-time compensation type.

[0077] In some embodiments, the compensation characteristics are classified according to the real-time compensation removal requirements to obtain the real-time compensation type, including:

[0078] Interactively obtain multiple desulfurization compensation matrices of multiple desulfurization compensation types; calculate multiple deviation similarities between the desulfurization deviation matrix and the multiple desulfurization compensation matrices; arrange the multiple deviation similarities in ascending order, and schedule the desulfurization compensation type corresponding to the extreme similarity value as the real-time compensation type.

[0079] Specifically, the desulfurization compensation matrix refers to the characteristic deviation matrix corresponding to a specific desulfurization compensation type (such as SO2-dominant compensation, SO3-coordinated compensation, dual-parameter coordinated compensation, etc.), which is used to construct the compensation feature library. Deviation similarity refers to the degree of similarity between the current deviation matrix (i.e., real-time desulfurization compensation demand) and various compensation matrices in the compensation feature library, which can be calculated using methods such as Euclidean distance and cosine similarity.

[0080] For example, as shown in Table 1, the desulfurization compensation types stored in the desulfurization compensation feature library include:

[0081] Table 1 Typical desulfurization compensation types

[0082]

[0083] For example, the desulfurization compensation matrix with the compensation type of SO2 dominant compensation is:

[0084]

[0085] Optionally, similarity calculation is performed between the current deviation matrix generated in real time and various compensation matrices, such as using Euclidean distance to obtain multiple deviation similarities, where the smaller the similarity, the closer they are; then, the similarities of all compensation types are arranged in ascending order, and the compensation type corresponding to the minimum similarity is selected as the real-time compensation type, which is used as the basis for subsequent control strategy selection. For example: if it is "SO2-dominated compensation", the limestone slurry dosage is adjusted first; if it is "dual-parameter synergistic compensation", the reaction temperature and liquid-gas ratio in the tower are optimized at the same time; if it is "efficiency-first compensation", adjustment is intervened in advance to prevent indicators from deteriorating.

[0086] The above compensation classification method, through matrix similarity calculation, can quickly determine the compensation strategy required for the current working conditions at the millisecond level, and then correspond different adjustment methods to different types of deviations, thereby improving the system's adaptability.

[0087] S400: According to the real-time compensation type, a reference pump group configuration and a reference desulfurizing agent ratio are retrieved from a reference desulfurization configuration library.

[0088] Specifically, based on the real-time compensation type, the corresponding pump group configuration and desulfurizer ratio are accurately selected from the preset benchmark configuration library to improve response speed and control accuracy.

[0089] In some embodiments, based on the real-time compensation type, calling a benchmark pump group configuration and a benchmark desulfurization agent ratio from a benchmark desulfurization configuration library includes:

[0090] According to the real-time compensation type, the benchmark pump group configuration is located from the benchmark desulfurization configuration library, wherein the benchmark pump group configuration includes a K-layer calcium hydroxide dosing pump and an H-layer limestone slurry circulation pump; multiple sample desulfurizer ratios of the benchmark pump group configuration are called, wherein the multiple sample desulfurizer ratios have multiple sample deviation matrix identifiers; the desulfurization deviation matrix is used to traverse the multiple sample deviation matrices to perform matrix similarity calculation, so as to locate the benchmark desulfurizer ratio from the multiple sample desulfurizer ratios.

[0091] Specifically, first, based on the real-time compensation type, a corresponding benchmark pump configuration is located from a preset benchmark desulfurization configuration library. The benchmark pump configuration includes: a K-layer calcium hydroxide dosing pump, used to adjust the alkaline absorbent dosage in dry or semi-dry desulfurization systems; and an H-layer limestone slurry circulation pump, used for circulating and spraying limestone slurry in wet desulfurization systems.

[0092] Optional, see Table 2, each pump group configuration corresponds to a specific compensation type, for example:

[0093] Table 2 Exemplary pump group configuration-compensation type correspondence

[0094] Compensation Type Basic pump set configuration (schematic) <![CDATA[SO2-dominated compensation]]> The K layer dosing pump rate is increased, while the H layer remains unchanged <![CDATA[SO3-dominated compensation]]> The circulation pump speed of the H layer is increased, and the K layer remains unchanged Dual parameter collaborative compensation K and H layer pump rates are increased simultaneously Efficiency priority compensation H layer fine-tuning, K layer maintenance, biased towards early response

[0095] Then, based on the configuration of the benchmark pump group, multiple sample desulfurizer ratios associated with its historical operating data are further called, and each group of ratios is associated with a group of historical deviation matrices; among them, the sample desulfurizer ratios include the addition ratios of calcium hydroxide, limestone, additives, etc.; the sample deviation matrix identifier represents the deviation response of this group of ratios under specific operating conditions.

[0096] Furthermore, using the same similarity calculation method as above, matrix similarity is calculated between the real-time desulfurization deviation matrix and the sample deviation matrix to determine the sample ratio that is closest to the current operating conditions. Alternatively, similarity can be calculated using methods such as cosine similarity and structural similarity.

[0097] Finally, the similarity results are sorted in ascending order, and the sample ratio corresponding to the highest similarity (i.e., the smallest distance metric value) is selected as the benchmark desulfurizer ratio under the current working conditions.

[0098] The above method steps can realize condition-driven intelligent desulfurization adjustment through real-time compensation type identification and configuration library matching, making the system response more targeted; through deviation matrix similarity matching, errors caused by empirical rules are avoided; at the same time, the configuration library can be continuously expanded based on historical sample data to provide learning capabilities.

[0099] S500: Taking the benchmark pump group configuration as the pump group scheduling limit and the benchmark desulfurizer ratio as the optimization starting point, the desulfurizer dynamic ratio is optimized according to the real-time removal compensation demand, and the real-time pump collaborative control parameters and real-time calcium hydroxide ratio are output.

[0100] In some embodiments, the baseline pump group configuration is used as the pump group scheduling limit, the baseline desulfurizer ratio is used as the optimization starting point, the desulfurizer dynamic ratio is optimized according to the real-time removal compensation demand, and the real-time pump coordinated control parameters are output, including:

[0101] The real-time removal compensation demand is expanded based on the degradation vector, and a real-time removal compensation threshold is output; the baseline pump group configuration is used as the pump group scheduling limit, and the real-time removal compensation threshold is used to perform a local removal record search to obtain multiple sample pump collaborative control information, wherein the sample pump collaborative control information is composed of sample removal compensation demand, sample calcium hydroxide ratio and sample pump collaborative control parameter; the real-time removal compensation threshold is used as the expansion boundary, and multiple rounds of demand equidistant expansion are performed starting from multiple sample removal compensation demands, and M associated removal compensation demands are output; based on the distance ratio between the M associated removal compensation demands and the multiple sample removal compensation demands, a weighted fusion of multiple sample calcium hydroxide ratios and multiple sample pump collaborative control parameters is performed, and M associated calcium hydroxide ratios and M associated pump collaborative control parameters are output; a removal consumption calculation is performed on the multiple sample calcium hydroxide ratios, the multiple sample pump collaborative control parameters, the M associated calcium hydroxide ratios and the M associated pump collaborative control parameters, and the real-time pump collaborative control parameters are located according to the calculation results.

[0102] Specifically, first, based on the preset degradation vector, the real-time removal compensation demand is expanded outward to generate a real-time removal compensation threshold, which represents the acceptable removal demand boundary range; then, the baseline pump group configuration is used as the pump group scheduling limitation condition, and the search space is limited to only include historical records consistent with or compatible with the configuration. Within the limited space, the historical database is searched based on the condition of meeting the real-time removal compensation threshold, and multiple sample pump collaborative control information is extracted, wherein each sample information includes the sample removal compensation demand, the sample calcium hydroxide ratio (such as Ca / S molar ratio), and the sample pump collaborative control parameters (such as pump speed, flow distribution, etc.).

[0103] Furthermore, an equidistant expansion strategy is adopted, starting from multiple sample removal compensation requirements, to generate M associated removal compensation requirements within the limited range of the real-time removal compensation threshold to simulate multiple possible control boundary scenarios. Then, for each associated removal compensation requirement, the distance between it and each sample removal compensation requirement is calculated, and based on the inverse distance weighted fusion of the multiple sample removal compensation requirements and the sample calcium hydroxide ratios and pump control parameters of the M associated removal compensation requirements are obtained to obtain the fusion result corresponding to each associated requirement (i.e., M associated calcium hydroxide ratios and M associated pump collaborative control parameters).

[0104] Furthermore, combined with the desulfurizer consumption model (such as alkali consumption per unit SO2 removal) and the control energy consumption model (such as pump power and circulation load), the original sample ratio and the original sample pump parameters, the associated ratio and the associated pump parameters are comprehensively calculated respectively, and the removal consumption calculation under each compensation demand is evaluated, that is, the cost of different process parameters is evaluated, so as to select the ratio and control parameters with the best cost, and the output is the real-time pump coordinated control parameters and the real-time desulfurizer ratio.

[0105] The above method steps improve the adaptability to complex working conditions by expanding the compensation demand boundary in real time; and use historical samples for weighted fusion to avoid the problem of pure rules or model overfitting.

[0106] In some implementations, performing a removal consumption calculation on the multiple sample calcium hydroxide ratios, the multiple sample pump collaborative control parameters, the M associated calcium hydroxide ratios, and the M associated pump collaborative control parameters, and locating the real-time pump collaborative control parameters based on the calculation results, includes:

[0107] Calculate multiple sample unit raw material consumptions and multiple sample unit production consumptions of the multiple sample calcium hydroxide ratios; locally search for multiple sample control energy consumptions of the multiple sample pump collaborative control parameters; map and weightedly fuse the multiple sample unit raw material consumptions, multiple sample unit production consumptions and multiple sample control energy consumptions to obtain multiple sample enhanced removal consumptions; and so on, calculate and output M associated enhanced removal consumptions; fuse and sort the multiple sample enhanced removal consumptions and M associated enhanced removal consumptions, and based on the sorting results, reversely locate the real-time pump collaborative control parameters from the multiple sample pump collaborative control parameters and M associated pump collaborative control parameters; extract the real-time calcium hydroxide ratio according to the real-time pump collaborative control parameter mapping.

[0108] Specifically, after completing the generation of the ratio and control parameters under M associated removal compensation requirements, the candidate control parameters can be further optimized and screened through the removal consumption evaluation mechanism, and finally the optimal real-time pump collaborative control parameters can be inferred.

[0109] Specifically, enhanced removal consumption is a comprehensive removal resource evaluation index formed through weighted fusion based on multiple dimensions such as desulfurizer raw material consumption, unit efficiency output consumption, and pump group control energy consumption. It is used to measure the resource utilization efficiency of a certain desulfurizer ratio and pump coordinated control parameter combination under specific removal requirements.

[0110] Specifically, first, for multiple sample calcium hydroxide ratios, the corresponding sample unit raw material consumption and sample unit production consumption are calculated respectively to quantify the demand for raw materials and production resources for different ratios. Next, the sample control energy consumption of multiple sample pump collaborative control parameters is locally searched, involving the query and collation of energy consumption data under different pump group operating modes. Then, considering the weight of different factors in the overall consumption, the sample unit raw material consumption, sample unit production consumption and sample control energy consumption are comprehensively calculated through the mapping weighted fusion method to obtain multiple sample enhanced removal consumption. The multiple sample enhanced removal consumption is a unified comprehensive evaluation result that can be used for direct quantitative comparison.

[0111] Similarly, the enhanced removal consumption of M associated calcium hydroxide ratios and M associated pump collaborative control parameters is calculated using the same method, and the enhanced removal consumption of multiple samples and the M associated enhanced removal consumption are fused and sorted. According to the sorting results, the pump collaborative control parameter corresponding to the lowest enhanced removal consumption is selected as the real-time pump collaborative control parameter, and the corresponding real-time calcium hydroxide ratio is extracted through the historical mapping relationship between the control parameter and the desulfurizer ratio.

[0112] The above series of steps play a key optimization role in the entire desulfurization plan. By comprehensively evaluating the consumption under different strategies, the optimal desulfurizer ratio and pump group operating parameters under the current operating conditions can be accurately determined, thereby achieving efficient and low-consumption synergistic removal of sulfur oxides.

[0113] S600: The real-time pump coordinated control parameters and the real-time calcium hydroxide ratio are used to jointly drive the K layer calcium hydroxide dosing pump and the H layer limestone slurry circulation pump to collaboratively remove sulfur oxides in the desulfurization tower through gradient spraying.

[0114] Specifically, the K-layer calcium hydroxide dosing pump is used to deliver calcium hydroxide dry powder or slurry according to a set ratio to the spray device on the upper layer of the desulfurization tower. It is usually located in the upper part of the desulfurization tower to quickly respond to the initial removal of high-concentration SO2 gas. The H-layer limestone slurry circulation pump is a pump unit used to extract limestone slurry from the absorption tank at the bottom of the desulfurization tower and circulate it to the middle or lower spray layer of the tower. It is mainly used to maintain slurry circulation, replenish alkaline absorbent, and improve desulfurization efficiency.

[0115] Specifically, after completing the real-time pump coordinated control parameters (such as pump start and stop status, frequency, flow setting) and the real-time calcium hydroxide ratio reverse calculation, perform the following operations:

[0116] K-layer desulfurizer addition: According to the real-time calcium hydroxide ratio, the dry powder or premixed slurry is pumped into the upper part of the desulfurization tower through the K-layer dosing pump, and the spray rate and particle size distribution are controlled so that it reacts preferentially with the high-temperature and high-concentration SO2 gas to form CaSO3 or CaSO4 precipitation.

[0117] H-layer slurry circulation: Start the H-layer limestone slurry circulation pump, extract the slurry from the bottom of the absorption tower and spray it to the middle and lower layers according to the frequency and flow rate set by the real-time control parameters; achieve secondary absorption of incompletely reacted gases and improve removal efficiency.

[0118] By adjusting the operating status of the K-layer and H-layer pump groups through real-time control parameters, a spatial gradient distribution of the desulfurizer can be achieved, forming a synergistic removal mechanism of "rapid reaction in the upper layer + deep absorption in the lower layer." For example, under conditions of a sudden increase in SO2 concentration, the system may set the K-layer pump frequency to 4Hz, the H-layer pump frequency to 38Hz, and the calcium hydroxide ratio to 3.6% to enhance the upper removal capacity and maintain stable absorption in the lower layer.

[0119] The above process avoids excessive or repeated spraying through the precise layered addition of desulfurizer resources, thereby improving the utilization rate of the desulfurizer. At the same time, the coordinated operation of the multi-layer pump group also helps to improve the fluid organization and gas-liquid contact efficiency inside the desulfurization tower.

[0120] In summary, the calcium hydroxide-enhanced synergistic removal method for thermal power plant flue gas provided by the present invention has the following technical effects:

[0121] By obtaining the inlet sulfur oxide concentration at the dust collector outlet and the exhaust sulfur oxide concentration at the desulfurization tower outlet in real time; calculating based on the concentration difference between the two, the desulfurization compensation amount required by the current system is determined; the desulfurization compensation amount is characterized and the corresponding compensation type is identified; according to the compensation type, the corresponding pump group configuration plan and desulfurizer basic ratio parameters are extracted from the preset benchmark desulfurization configuration library; the extracted pump group configuration is used as the scheduling range, and the basic desulfurizer ratio is used as the optimization starting point. The desulfurizer ratio is dynamically optimized in combination with the actual compensation demand, and the pump group coordination parameters and the real-time ratio of calcium hydroxide for control are output; according to the control parameters and ratio values, the calcium hydroxide dosing pump of the K layer and the limestone slurry circulation pump of the H layer are controlled in conjunction, and a highly efficient and coordinated sulfur oxide removal process is realized in the desulfurization tower through gradient spraying, thereby achieving the technical effects of improved desulfurization efficiency, reduced energy consumption and enhanced process flexibility.

[0122] Example 2, as Figure 2This is a schematic diagram of the structure of the calcium hydroxide-enhanced thermal power plant flue gas collaborative removal equipment of the present invention. For example, Figure 1 The schematic flow diagram of the method for collaboratively removing flue gas from thermal power plants based on calcium hydroxide enhancement in the present invention can be shown as follows: Figure 2 The structure shown is implemented.

[0123] Based on the same concept as the method for collaboratively removing flue gas from thermal power plants based on calcium hydroxide enhancement in the above embodiment, the present invention also provides a device for collaboratively removing flue gas from thermal power plants based on calcium hydroxide enhancement, comprising:

[0124] The concentration monitoring module 11 is used to monitor the input sulfur oxide concentration at the dust collector outlet and the exhaust sulfur oxide concentration at the desulfurization tower outlet in real time.

[0125] The demand compensation module 12 is used to calculate the concentration deviation based on the input sulfur oxide concentration and the exhaust sulfur oxide concentration, and output a real-time removal compensation demand.

[0126] The compensation feature classification module 13 is configured to classify compensation features according to the real-time compensation removal requirement to obtain a real-time compensation type.

[0127] The benchmark configuration calling module 14 is used to call a benchmark pump group configuration and a benchmark desulfurization agent ratio from a benchmark desulfurization configuration library according to the real-time compensation type.

[0128] The dynamic ratio optimization module 15 is used to optimize the desulfurizer dynamic ratio based on the real-time removal compensation demand with the benchmark pump group configuration as the pump group scheduling limit and the benchmark desulfurizer ratio as the optimization starting point, and output the real-time pump coordinated control parameters and the real-time calcium hydroxide ratio.

[0129] The collaborative desulfurization execution module 16 is used to adopt the real-time pump collaborative control parameters and the real-time calcium hydroxide ratio to jointly drive the K layer calcium hydroxide dosing pump and the H layer limestone slurry circulation pump to collaboratively remove sulfur oxides in the desulfurization tower through gradient spraying.

[0130] In some embodiments, the concentration monitoring module 11 includes:

[0131] The input parameter collection unit is used to collect input SO2 concentration and input flue gas characteristic parameters through the MGA5 flue gas analyzer installed at the outlet of the dust collector, wherein the input flue gas characteristic parameters include input flue gas flow rate, input operating flow rate, input flue gas temperature, input flue gas humidity and input flue gas oxygen content.

[0132] The input SO3 concentration collection unit is used to collect the input SO3 concentration through the ESC sulfuric acid mist sampling system installed at the outlet of the dust collector, wherein the input SO2 concentration, input SO3 concentration and input flue gas characteristic parameters constitute the input sulfur oxide concentration.

[0133] The exhaust sulfur oxide concentration monitoring unit is used to monitor the exhaust sulfur oxide concentration at the outlet of the desulfurization tower in real time.

[0134] In some embodiments, the demand compensation module 12 includes:

[0135] The input concentration standardization processing unit is used to standardize the input SO2 concentration and the input SO3 concentration according to the input flue gas characteristic parameters to obtain a first standardized input concentration and a second standardized input concentration.

[0136] The discharge concentration standardization processing unit is used to perform standardization processing on the discharge sulfur oxide concentration in a similar manner to obtain a first standardized output concentration and a second standardized output concentration.

[0137] The real-time removal efficiency calculation unit is used to substitute the first standardized input concentration, the second standardized input concentration, the first standardized output concentration and the second standardized output concentration into the removal efficiency formula to calculate and output the real-time removal efficiency, wherein the real-time removal efficiency includes SO2 removal efficiency and SO3 removal efficiency.

[0138] The pollutant collaborative control constraint calling unit is used to locally call the pollutant collaborative control constraints.

[0139] The control deviation judgment and compensation demand output unit is used to perform control deviation judgment on the real-time removal efficiency, the first standardized output concentration and the second standardized output concentration according to the pollutant coordinated control constraint, and output the real-time removal compensation demand.

[0140] In some implementations, the steps performed by the input concentration normalization processing unit in the demand compensation module 12 include:

[0141] According to the input flue gas flow rate and the input flue gas humidity, a dry state flow rate conversion calculation is performed to obtain the input dry state flow rate.

[0142] The input operating flow rate is temperature-corrected according to the input flue gas temperature to obtain the input standard flow rate.

[0143] According to the oxygen content of the input flue gas, the input dry flow rate and the input standard flow rate are corrected for the oxygen content to obtain the input standard dry flow rate.

[0144] The oxygen content is converted according to the standard dry state flow rate and the oxygen content of the input flue gas, and the input oxygen content converted flow rate is output.

[0145] The first standardized input concentration is calculated and outputted according to the input SO2 concentration, the input oxygen-containing converted flow rate and the input standard dry flow rate.

[0146] The second standardized input concentration is calculated and outputted according to the input SO3 concentration, the input oxygen-containing converted flow rate and the input standard dry flow rate.

[0147] In some implementations, the execution steps of the control deviation judgment and compensation demand output unit in the demand compensation module 12 include:

[0148] The dual removal efficiency constraint and the dual outlet concentration constraint are extracted from the pollutant coordinated control constraint.

[0149] A first deviation calculation is performed on the first standardized output concentration and the second standardized output concentration according to the dual outlet concentration constraint.

[0150] A second deviation calculation is performed on the real-time removal efficiency according to the dual removal efficiency constraint.

[0151] A desulfurization deviation matrix is constructed by fusing the first deviation and the second deviation to serve as the real-time desulfurization compensation demand.

[0152] In some embodiments, the compensation feature classification module 13 includes:

[0153] The desulfurization compensation matrix interactive acquisition unit is used to interactively obtain multiple desulfurization compensation matrices of multiple desulfurization compensation types.

[0154] The deviation similarity calculation unit is configured to calculate a plurality of deviation similarities between the desulfurization deviation matrix and the plurality of desulfurization compensation matrices.

[0155] The deviation similarity sorting and compensation type scheduling unit is used to arrange the multiple deviation similarities in ascending order and schedule the desulfurization compensation type corresponding to the extreme similarity value as the real-time compensation type.

[0156] In some embodiments, the baseline configuration calling module 14 includes:

[0157] The benchmark pump group configuration positioning unit is used to locate the benchmark pump group configuration from the benchmark desulfurization configuration library according to the real-time compensation type, wherein the benchmark pump group configuration includes a K layer calcium hydroxide dosing pump and an H layer limestone slurry circulation pump.

[0158] The sample desulfurizer ratio calling unit is used to call a plurality of sample desulfurizer ratios configured by the reference pump group, wherein the plurality of sample desulfurizer ratios have a plurality of sample deviation matrix identifiers.

[0159] The reference desulfurizing agent ratio positioning unit is configured to use the desulfurization deviation matrix to traverse the plurality of sample deviation matrices to perform matrix similarity calculation, so as to locate the reference desulfurizing agent ratio from the plurality of sample desulfurizing agent ratios.

[0160] In some embodiments, the dynamic ratio optimization module 15 includes:

[0161] The real-time removal compensation threshold expansion unit is configured to expand the real-time removal compensation requirement based on the degradation vector and output a real-time removal compensation threshold.

[0162] The sample pump collaborative control information search unit is used to use the reference pump group configuration as the pump group scheduling limit, adopt the real-time removal compensation threshold to perform local removal record search, and obtain multiple sample pump collaborative control information, wherein the sample pump collaborative control information is composed of sample removal compensation requirements, sample calcium hydroxide ratio and sample pump collaborative control parameters.

[0163] The associated removal compensation demand expansion unit is used to use the real-time removal compensation threshold as the expansion boundary, perform multiple rounds of equidistant demand expansion with multiple sample removal compensation demands as the starting point, and output M associated removal compensation demands.

[0164] The associated calcium hydroxide ratio and pump collaborative control parameter weighted fusion unit is used to perform weighted fusion of multiple sample calcium hydroxide ratios and multiple sample pump collaborative control parameters based on the distance ratio of the M associated removal compensation requirements and the multiple sample removal compensation requirements, and output M associated calcium hydroxide ratios and M associated pump collaborative control parameters.

[0165] The consumption removal calculation and parameter positioning unit is used to perform consumption removal calculation on the multiple sample calcium hydroxide ratios, multiple sample pump collaborative control parameters, M associated calcium hydroxide ratios and M associated pump collaborative control parameters, and to position the real-time pump collaborative control parameters according to the calculation results.

[0166] In some implementations, the consumption calculation and parameter positioning unit in the dynamic ratio optimization module 15 includes:

[0167] The sample unit raw material consumption and production consumption calculation unit is used to calculate multiple sample unit raw material consumption and multiple sample unit production consumption of the multiple sample calcium hydroxide ratios.

[0168] The sample control energy consumption search unit is configured to locally search for a plurality of sample control energy consumptions of the plurality of sample pump coordinated control parameters.

[0169] The sample enhancement removal consumption mapping weighted fusion unit is used to map and weightedly fuse the multiple sample unit raw material consumption, the multiple sample unit production consumption and the multiple sample control energy consumption to obtain multiple sample enhancement removal consumptions.

[0170] The association enhancement removal consumption calculation unit is used to calculate and output M association enhancement removal consumptions by analogy.

[0171] The sample and associated enhancement removal consumption fusion sorting unit is used to fuse and sort the multiple sample enhancement removal consumptions and M associated enhancement removal consumptions, and according to the sorting results, reversely locate the real-time pump collaborative control parameters from the multiple sample pump collaborative control parameters and M associated pump collaborative control parameters.

[0172] A real-time calcium hydroxide ratio extraction unit is used to extract the real-time calcium hydroxide ratio according to the real-time pump collaborative control parameter mapping.

[0173] It should be understood that the embodiments mentioned in this specification focus on their differences from other embodiments. The specific embodiments in the aforementioned embodiment one are also applicable to the calcium hydroxide-enhanced thermal power plant flue gas collaborative removal equipment described in embodiment two. For the sake of brevity of the specification, no further elaboration will be given here.

[0174] It should be understood that the embodiments disclosed in the present invention and the above description can enable those skilled in the art to use the present invention to implement the present invention. At the same time, the present invention is not limited to the embodiments mentioned above. It should be understood that those skilled in the art can still modify the technical solutions described in the above embodiments or replace some of the technical features therein with equivalents; and such modifications or replacements do not deviate from the essence of the corresponding technical solutions from the spirit and scope of the technical solutions of the embodiments of the present invention and are all included in the scope of protection of the present invention.

Claims

1. A method for collaboratively removing flue gas from thermal power plants based on calcium hydroxide enhancement, characterized in that: include: Real-time monitoring of the input sulfur oxide concentration at the dust collector outlet and the exhaust sulfur oxide concentration at the desulfurization tower outlet; Calculating concentration deviation based on the input sulfur oxide concentration and the discharged sulfur oxide concentration, and outputting real-time removal compensation requirements; Classifying compensation characteristics according to the real-time compensation removal requirements to obtain a real-time compensation type; According to the real-time compensation type, calling a benchmark pump group configuration and a benchmark desulfurization agent ratio from a benchmark desulfurization configuration library; Taking the benchmark pump group configuration as the pump group scheduling limit and the benchmark desulfurizer ratio as the optimization starting point, the desulfurizer dynamic ratio is optimized according to the real-time removal compensation demand, and the real-time pump coordinated control parameters and the real-time calcium hydroxide ratio are output; The real-time pump coordinated control parameters and the real-time calcium hydroxide ratio are used to jointly drive the K layer calcium hydroxide dosing pump and the H layer limestone slurry circulation pump to collaboratively remove sulfur oxides in the desulfurization tower through gradient spraying.

2. The method for collaboratively removing flue gas from a thermal power plant based on calcium hydroxide enhancement as claimed in claim 1, wherein: Real-time monitoring of the input sulfur oxide concentration at the dust collector outlet and the exhaust sulfur oxide concentration at the desulfurization tower outlet, including: The MGA5 flue gas analyzer installed at the outlet of the dust collector is used to collect input SO2 concentration and input flue gas characteristic parameters, wherein the input flue gas characteristic parameters include input flue gas flow rate, input operating flow rate, input flue gas temperature, input flue gas humidity and input flue gas oxygen content; The input SO3 concentration is collected by an ESC sulfuric acid mist sampling system installed at the outlet of the dust collector, wherein the input SO2 concentration, the input SO3 concentration and the input flue gas characteristic parameters constitute the input sulfur oxide concentration; Similarly, the concentration of the discharged sulfur oxides at the outlet of the desulfurization tower is monitored in real time.

3. The method for collaboratively removing flue gas from a thermal power plant based on calcium hydroxide enhancement as claimed in claim 2, wherein: Calculate the concentration deviation based on the input sulfur oxide concentration and the discharged sulfur oxide concentration, and output the real-time removal compensation demand, including: Standardizing the input SO2 concentration and the input SO3 concentration according to the input flue gas characteristic parameters to obtain a first standardized input concentration and a second standardized input concentration; Similarly, the standardization process of the discharged sulfur oxide concentration is performed to obtain a first standardized output concentration and a second standardized output concentration; Substituting the first standardized input concentration, the second standardized input concentration, the first standardized output concentration, and the second standardized output concentration into the removal efficiency formula, calculates the output real-time removal efficiency, wherein the real-time removal efficiency includes SO2 removal efficiency and SO3 removal efficiency; Locally invoked pollutant collaborative control constraints; According to the pollutant coordinated control constraint, a control deviation judgment is performed on the real-time removal efficiency, the first standardized output concentration, and the second standardized output concentration, and the real-time removal compensation demand is output.

4. The method for collaboratively removing flue gas from a thermal power plant based on calcium hydroxide enhancement as claimed in claim 3, wherein: According to the pollutant coordinated control constraint, performing control deviation judgment on the real-time removal efficiency, the first standardized output concentration, and the second standardized output concentration, and outputting the real-time removal compensation demand, including: Extracting dual removal efficiency constraints and dual outlet concentration constraints from the pollutant coordinated control constraints; performing a first deviation calculation on the first standardized output concentration and the second standardized output concentration according to the dual outlet concentration constraint; performing a second deviation calculation on the real-time removal efficiency according to the dual removal efficiency constraint; A desulfurization deviation matrix is constructed by fusing the first deviation and the second deviation to serve as the real-time desulfurization compensation demand.

5. The method for collaboratively removing flue gas from a thermal power plant based on calcium hydroxide enhancement as claimed in claim 4, wherein: Compensation characteristics are classified according to the real-time compensation removal requirements to obtain real-time compensation types, including: Interactively obtain multiple desulfurization compensation matrices of multiple desulfurization compensation types; By calculating a plurality of deviation similarities between the desulfurization deviation matrix and the plurality of desulfurization compensation matrices; The multiple deviation similarities are arranged in ascending order, and the desulfurization compensation type corresponding to the extreme value of the similarity is scheduled as the real-time compensation type.

6. The method for collaboratively removing flue gas from a thermal power plant based on calcium hydroxide enhancement as claimed in claim 4, wherein: According to the real-time compensation type, the benchmark pump group configuration and the benchmark desulfurization agent ratio are called from the benchmark desulfurization configuration library, including: According to the real-time compensation type, locating the reference pump group configuration from the reference desulfurization configuration library, wherein the reference pump group configuration includes a K layer calcium hydroxide dosing pump and an H layer limestone slurry circulation pump; Calling a plurality of sample desulfurizer ratios configured for the reference pump group, wherein the plurality of sample desulfurizer ratios have a plurality of sample deviation matrix identifiers; The desulfurization deviation matrix is used to traverse the multiple sample deviation matrices to perform matrix similarity calculation, so as to locate the reference desulfurization agent ratio from the multiple sample desulfurization agent ratios.

7. The method for collaboratively removing flue gas from a thermal power plant based on calcium hydroxide enhancement as claimed in claim 3, wherein: The input SO2 concentration and the input SO3 concentration are standardized according to the input flue gas characteristic parameters to obtain a first standardized input concentration and a second standardized input concentration, including: Performing dry state flow conversion calculation according to the input flue gas flow rate and the input flue gas humidity to obtain the input dry state flow rate; Performing temperature correction on the input working condition flow rate according to the input flue gas temperature to obtain the input standard state flow rate; According to the oxygen content of the input flue gas, the input dry flow rate and the input standard flow rate are corrected for oxygen content to obtain the input standard dry flow rate; Perform oxygen content conversion based on the standard dry state flow rate and the input flue gas oxygen content, and output the input oxygen content converted flow rate; Calculate and output the first standardized input concentration according to the input SO2 concentration, the input oxygen-converted flow rate, and the input standard dry flow rate; The second standardized input concentration is calculated and outputted according to the input SO3 concentration, the input oxygen-containing converted flow rate and the input standard dry flow rate.

8. The method for collaboratively removing flue gas from a thermal power plant based on calcium hydroxide enhancement as claimed in claim 1, wherein: The reference pump group configuration is used as the pump group scheduling limit, the reference desulfurizer ratio is used as the optimization starting point, the desulfurizer dynamic ratio is optimized according to the real-time removal compensation demand, and the real-time pump collaborative control parameters are output, including: Expanding the real-time compensation removal requirement based on the degradation vector and outputting a real-time compensation removal threshold; Using the reference pump group configuration as a pump group scheduling limit, using the real-time removal compensation threshold to perform a local removal record search, and obtaining a plurality of sample pump collaborative control information, wherein the sample pump collaborative control information is composed of a sample removal compensation requirement, a sample calcium hydroxide ratio, and a sample pump collaborative control parameter; Using the real-time removal compensation threshold as the expansion boundary, multiple rounds of demand equidistant expansion are performed starting from multiple sample removal compensation requirements, and M associated removal compensation requirements are output; performing weighted fusion of multiple sample calcium hydroxide ratios and multiple sample pump collaborative control parameters according to the distance ratio between the M associated removal compensation requirements and the multiple sample removal compensation requirements, and outputting M associated calcium hydroxide ratios and M associated pump collaborative control parameters; A removal consumption calculation is performed on the multiple sample calcium hydroxide ratios, multiple sample pump collaborative control parameters, M associated calcium hydroxide ratios and M associated pump collaborative control parameters, and the real-time pump collaborative control parameters are located according to the calculation results.

9. The method for collaboratively removing flue gas from a thermal power plant based on calcium hydroxide enhancement as claimed in claim 8, characterized in that: Performing a removal consumption calculation on the multiple sample calcium hydroxide ratios, the multiple sample pump collaborative control parameters, the M associated calcium hydroxide ratios, and the M associated pump collaborative control parameters, and locating the real-time pump collaborative control parameters according to the calculation results, including: Calculating the raw material consumption per unit of the plurality of sample calcium hydroxide proportions and the production consumption per unit of the plurality of sample calcium hydroxide proportions; locally searching for a plurality of sample control energy consumptions of the plurality of sample pump coordinated control parameters; Mapping and weighting the plurality of sample unit raw material consumptions, the plurality of sample unit production consumptions, and the plurality of sample control energy consumptions to obtain the plurality of sample enhanced removal consumptions; Similarly, calculate and output M correlation enhancement removal consumptions; Fusion sorting the multiple sample enhancement removal consumptions and the M associated enhancement removal consumptions, and reversely locating the real-time pump collaborative control parameters from the multiple sample pump collaborative control parameters and the M associated pump collaborative control parameters according to the sorting results; The real-time calcium hydroxide ratio is extracted according to the real-time pump collaborative control parameter mapping.

10. The equipment for collaboratively removing flue gas from thermal power plants based on calcium hydroxide enhancement is characterized in that: The method for implementing the calcium hydroxide-enhanced synergistic removal of flue gas from a thermal power plant according to any one of claims 1 to 9 comprises: Concentration monitoring module, used to monitor the input sulfur oxide concentration at the dust collector outlet and the exhaust sulfur oxide concentration at the desulfurization tower outlet in real time; a demand compensation module, configured to calculate a concentration deviation based on the input sulfur oxide concentration and the discharged sulfur oxide concentration, and output a real-time removal compensation demand; A compensation feature classification module is used to classify compensation features according to the real-time compensation removal requirements to obtain a real-time compensation type; A benchmark configuration calling module, configured to call a benchmark pump group configuration and a benchmark desulfurizer ratio from a benchmark desulfurization configuration library according to the real-time compensation type; A dynamic ratio optimization module is used to optimize the desulfurizer dynamic ratio based on the real-time removal compensation demand, using the benchmark pump group configuration as the pump group scheduling limit and the benchmark desulfurizer ratio as the optimization starting point, and output real-time pump coordinated control parameters and real-time calcium hydroxide ratio; The collaborative desulfurization execution module is used to adopt the real-time pump collaborative control parameters and real-time calcium hydroxide ratio to jointly drive the K layer calcium hydroxide dosing pump and the H layer limestone slurry circulation pump to collaboratively remove sulfur oxides in the desulfurization tower through gradient spraying.

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