Coal-fired unit cooperative mercury removal method and device

Abstract

The invention relates to the technical field of coal-fired power generation, in particular to a coal-fired unit cooperative mercury removal method and device. The method comprises the following steps: acquiring a coal type parameter of a current coal-fired unit, a boiler operation parameter and a first mercury emission concentration of a flue outlet; determining a second mercury emission concentration based on the coal type parameter and the boiler operation parameter; wherein the second mercury emission concentration is the mercury emission concentration of the flue outlet in an ideal state; determining an emission concentration difference based on the first mercury emission concentration and the second mercury emission concentration; determining a target variable quantity based on the emission concentration difference, the coal type parameter and the boiler operation parameter; on the basis of the ammonia spraying variable quantity and the activated carbon spraying variable quantity, the denitration device and the activated carbon spraying device are sequentially controlled to achieve cooperative mercury removal, and therefore the mercury removal efficiency of the coal-fired unit can be improved.

Description

Technical Field

[0001] This invention relates to the field of coal-fired power generation technology, and in particular to a method and apparatus for coordinated mercury removal from coal-fired power units. Background Technology

[0002] In recent years, with the increasing global emphasis on ecological and environmental protection, my country has continuously tightened its emission standards for pollutants from coal-fired power plants. Mercury, a heavy metal pollutant that is biotoxic, easily accumulates, and can be transported over long distances, has made its emission control a crucial aspect of environmental governance in coal-fired power plants.

[0003] In existing technologies, mercury removal technologies are mostly applied using single methods, without fully exploring the synergistic potential between various treatment facilities, resulting in low mercury removal efficiency.

[0004] Based on this, the present invention proposes a method and apparatus for coordinated mercury removal from coal-fired power units to solve the above-mentioned technical problems. Summary of the Invention

[0005] This invention describes a method and apparatus for synergistic mercury removal from coal-fired power units, which can improve the mercury removal efficiency of coal-fired power units.

[0006] According to a first aspect, the present invention provides a method for co-processing mercury removal in coal-fired power units, applied to a controller of a co-processing mercury removal system in coal-fired power units. The system includes the controller and a denitrification device, an activated carbon injection device, and a dust removal device connected in sequence. The denitrification device, the activated carbon injection device, and the dust removal device are all installed in the flue of the coal-fired power unit, and the denitrification device, the activated carbon injection device, and the controller are electrically connected. The method includes: Obtain the coal type parameters, boiler operating parameters, and first mercury emission concentration at the flue outlet of the current coal-fired unit; wherein, the boiler operating parameters include boiler operating temperature, boiler operating pressure, and boiler operating coal consumption; Based on the coal type parameters and the boiler operating parameters, a second mercury emission concentration is determined; wherein, the second mercury emission concentration is the mercury emission concentration at the flue outlet under ideal conditions; The emission concentration difference is determined based on the first mercury emission concentration and the second mercury emission concentration; Based on the emission concentration difference, the coal type parameters, and the boiler operating parameters, a target change is determined; wherein, the target change includes the change in ammonia injection from the denitrification device and the change in activated carbon injection from the activated carbon injection device; Based on the changes in ammonia injection and activated carbon injection, the denitrification device and the activated carbon injection device are controlled sequentially to achieve synergistic mercury removal.

[0007] According to a second aspect, the present invention provides a co-operated mercury removal device for coal-fired power units, which is applied to a controller of a co-operated mercury removal system for coal-fired power units. The system includes the controller and a denitrification device, an activated carbon injection device, and a dust removal device connected in sequence. The denitrification device, the activated carbon injection device, and the dust removal device are all installed in the flue of the coal-fired power unit. The denitrification device, the activated carbon injection device, and the controller are electrically connected. The synergistic mercury removal device includes: The acquisition unit is configured to acquire the coal type parameters, boiler operating parameters, and first mercury emission concentration at the flue outlet of the current coal-fired unit; wherein, the boiler operating parameters include boiler operating temperature, boiler operating pressure, and boiler operating coal consumption; The first data processing unit is configured to determine the second mercury emission concentration based on the coal type parameters and the boiler operating parameters; wherein the second mercury emission concentration is the mercury emission concentration at the flue outlet under ideal conditions; The second data processing unit is configured to determine the emission concentration difference based on the first mercury emission concentration and the second mercury emission concentration; The third data processing unit is configured to determine the target change amount based on the emission concentration difference, the coal type parameters, and the boiler operating parameters; wherein the target change amount includes the change amount of ammonia injection in the denitrification device and the change amount of activated carbon injection in the activated carbon injection device; The fourth data processing unit is configured to control the denitrification device and the activated carbon injection device sequentially based on the changes in ammonia injection and activated carbon injection, so as to achieve synergistic mercury removal.

[0008] Thirdly, embodiments of this specification also provide an electronic device, including a memory and a processor, wherein the memory stores a computer program, and when the processor executes the computer program, it implements the method described in any embodiment of this specification.

[0009] Fourthly, embodiments of this specification also provide a coal-fired unit co-operated mercury removal system. The system includes a controller and a denitrification device, an activated carbon injection device, and a dust removal device connected in sequence. The denitrification device, the activated carbon injection device, and the dust removal device are all installed in the flue of the coal-fired unit. The denitrification device, the activated carbon injection device, and the controller are electrically connected. The controller is used to execute the method described in any embodiment of this specification.

[0010] According to the method and apparatus for coordinated mercury removal from coal-fired power units provided by this invention, the invention first obtains the coal type parameters, boiler operating parameters (including boiler operating temperature, boiler operating pressure, and boiler coal consumption) and the real-time mercury emission concentration at the flue gas outlet of the current coal-fired power unit (denoted as the first mercury emission concentration). Based on the above coal type parameters and boiler operating parameters, the theoretical ideal operating condition mercury emission benchmark concentration (denoted as the second mercury emission concentration) is calculated. Subsequently, the difference between the first mercury emission concentration and the second mercury emission concentration is calculated to determine the concentration deviation between the actual emission and the ideal state. Furthermore, combined with the coal type characteristics and boiler operating parameters, the target adjustment values ​​of the ammonia injection rate of the denitrification device and the injection rate of the activated carbon injection device (i.e., the ammonia injection change and the activated carbon injection change) are dynamically calculated. Finally, based on the target change, the ammonia injection system and the activated carbon injection device of the denitrification device are coordinated and adjusted to achieve efficient removal of mercury pollutants from the flue gas. This method significantly improves the mercury removal efficiency of coal-fired power units through multi-parameter coupled calculation and dynamic control. Attached Figure Description

[0011] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0012] Figure 1 A schematic flowchart of a method for coordinated mercury removal from a coal-fired power unit according to one embodiment is shown; Figure 2 A schematic block diagram of a co-operated mercury removal device for a coal-fired power unit according to one embodiment is shown; Figure 3 A schematic block diagram of a coal-fired unit co-operated mercury removal system according to one embodiment is shown.

[0013] Figure label: 1-Controller; 2-Denitrification device; 3-Activated carbon injection device; 4-Dust removal device. Detailed Implementation

[0014] The solution provided by the present invention will now be described with reference to the accompanying drawings.

[0015] Figure 1A schematic flowchart of a co-processing mercury removal method for a coal-fired power unit according to one embodiment is shown. It is understood that this method can be executed by any device, equipment, platform, or cluster of devices with computing and processing capabilities. A co-processing mercury removal method for a coal-fired power unit is applied to a controller 1 of a co-processing mercury removal system for a coal-fired power unit. The system includes the controller 1 and a denitrification device 2, an activated carbon injection device 3, and a dust removal device 4 connected in sequence. The denitrification device 2, the activated carbon injection device 3, and the dust removal device 4 are all located within the flue of the coal-fired power unit. The denitrification device 2, the activated carbon injection device 3, and the controller 1 are electrically connected, such as... Figure 1 As shown, the method includes: Step 100: Obtain the coal type parameters, boiler operating parameters, and first mercury emission concentration at the flue outlet of the current coal-fired unit; wherein, the boiler operating parameters include boiler operating temperature, boiler operating pressure, and boiler operating coal consumption; Step 102: Determine the second mercury emission concentration based on coal type parameters and boiler operating parameters; wherein, the second mercury emission concentration is the mercury emission concentration at the flue outlet under ideal conditions; Step 104: Determine the emission concentration difference based on the first mercury emission concentration and the second mercury emission concentration; Step 106: Based on the emission concentration difference, coal type parameters, and boiler operating parameters, determine the target change amount; wherein, the target change amount includes the change amount of ammonia injection in denitrification device 2 and the change amount of activated carbon injection in activated carbon injection device 3. Step 108: Based on the changes in ammonia injection and activated carbon injection, control the denitrification device 2 and activated carbon injection device 3 in sequence to achieve synergistic mercury removal.

[0016] In this embodiment, the following steps are first taken: obtaining the coal type parameters, boiler operating parameters (including boiler operating temperature, boiler operating pressure, and boiler coal consumption) of the current coal-fired unit, and the real-time mercury emission concentration at the flue outlet (denoted as the first mercury emission concentration). Based on the above coal type parameters and boiler operating parameters, the theoretical ideal operating condition mercury emission baseline concentration (denoted as the second mercury emission concentration) is calculated. Subsequently, the difference between the first and second mercury emission concentrations is calculated to determine the concentration deviation between the actual emission and the ideal state. Further, combining the coal type characteristics and boiler operating parameters, the target adjustment values ​​for the ammonia injection rate of the denitrification device 2 and the injection rate of the activated carbon injection device 3 (i.e., the ammonia injection change and the activated carbon injection change) are dynamically calculated. Finally, based on these target changes, the ammonia injection system of the denitrification device 2 and the activated carbon injection device 3 are coordinated and adjusted to achieve efficient removal of mercury pollutants from the flue gas. This method significantly improves the mercury removal efficiency of coal-fired units through multi-parameter coupled calculation and dynamic control.

[0017] In one embodiment of the present invention, the target change amount is determined by the following formula:

[0018] In the formula, This represents the change in ammonia injection. The first preset coefficient, For emission concentration difference, This refers to the sulfur content corresponding to the coal type parameters. Mercury content corresponding to coal type parameters The first preset impact index, This represents the change in activated carbon injection amount. This is the second preset coefficient. This is the third preset coefficient. The second preset influence index, Cost per unit of mercury removal The unit cost of ammonia, The unit cost of activated carbon, For actual mercury removal efficiency, Based on mercury removal efficiency, The first linear efficiency coefficient, The second linear efficiency coefficient. The coefficient of synergistic effect. To achieve the target mercury removal efficiency, The boiler operating temperature, For boiler operating pressure, The amount of coal consumed during boiler operation. It is a Lagrange multiplier.

[0019] In this embodiment, the adjustment of ammonia injection rate needs to consider the sulfur content, mercury content, and operating parameters such as temperature and pressure in the coal. These factors work together to determine the variation in ammonia injection rate, adapting it to different coal qualities and operating conditions. Secondly, the adjustment of activated carbon injection rate is related to mercury content, sulfur content, and boiler load; based on these factors, a suitable activated carbon input rate is determined. Then, a comprehensive index is used to measure the economics of ammonia injection and activated carbon input, and this index is analyzed to find the optimal balance point between ammonia injection and activated carbon input, ensuring optimal cost or efficiency. Finally, constraints are set on mercury removal efficiency to ensure that the mercury removal efficiency reaches the target value under the combined action of ammonia injection and activated carbon, while also considering the synergistic effect of the two on efficiency. The entire equation system integrates coal quality parameters and operating parameters to construct an adjustment model for ammonia injection and activated carbon. Combining cost optimization and efficiency constraints, it achieves efficient and economical synergistic mercury removal control, ensuring that the mercury removal target can be achieved under different operating conditions.

[0020] In this embodiment, The change in ammonia injection represents the difference between the current ammonia injection amount and the baseline ammonia injection amount (positive values ​​indicate an increase in ammonia injection, and negative values ​​indicate a decrease), which directly affects the oxidation efficiency of mercury in flue gas (ammonia injection can promote the conversion of mercury from its elemental state to its easily absorbed divalent state). The first preset coefficient reflects the basic adjustment intensity of ammonia injection rate per unit concentration difference, and needs to be determined based on historical operating data. For emission concentration difference, This refers to the sulfur content corresponding to the coal type parameters. The higher the sulfur content, the higher the concentration of sulfur dioxide in the flue gas, which competes with ammonia injection for desulfurization. Therefore, the ammonia injection rate needs to be adjusted to balance the needs of desulfurization and mercury removal. The higher the mercury content in the raw coal, the higher the initial mercury concentration in the flue gas after combustion, requiring an increase in ammonia injection to enhance oxidation efficiency. The first preset influence index is the nonlinear influence index (empirical parameter) of mercury content on ammonia injection rate. It reflects the sensitivity of mercury content changes to ammonia injection rate adjustments. The change in activated carbon injection represents the difference between the current activated carbon injection amount and the baseline amount (positive value indicates increased injection, negative value indicates decreased injection), which directly affects the adsorption efficiency of mercury (activated carbon adsorbs divalent mercury through its pores). This is the second preset coefficient, reflecting the basic adjustment intensity of the activated carbon amount per unit concentration difference. This is the third preset coefficient, representing the inhibition coefficient (empirical parameter) of sulfur content on activated carbon. Sulfur content When the concentration is too high, sulfur dioxide will occupy the pores of activated carbon, inhibiting mercury adsorption. This is the second preset influence index, representing the nonlinear influence of sulfur content on activated carbon (an empirical parameter). It reflects the sensitivity of activated carbon to changes in sulfur content. The unit cost of mercury removal represents the cost (or energy consumption) per unit of mercury removal volume. The smaller the value, the more economical the adjustment scheme. The unit cost of ammonia, The unit cost of activated carbon, For actual mercury removal efficiency, Based on mercury removal efficiency, The first linear efficiency coefficient, The second linear efficiency coefficient. This represents the synergistic effect coefficient, the synergistic inhibition coefficient (interaction parameter) between ammonia injection and activated carbon. Excessive ammonia injection and activated carbon can cause mutual interference (e.g., ammonia covering the pores of activated carbon). To achieve the target mercury removal efficiency, the minimum mercury removal efficiency that needs to be achieved. The boiler operating temperature, For boiler operating pressure, The amount of coal consumed during boiler operation. The Lagrange multiplier is used to solve the simultaneous equations for adjusting ammonia injection and activated carbon, in order to find the minimum cost index, i.e., the optimal balance point for the input of ammonia injection and activated carbon.

[0021] In this embodiment, the temperature correction function Boiler operating temperature It affects the reaction rate of ammonia and mercury, function Quantitative temperature correction for ammonia injection efficiency (e.g.) Increase by 10° An increase of 5% indicates enhanced ammonia injection effect (pressure correction function). Boiler operating pressure It will affect the uniformity of the mixing of flue gas and ammonia, function Quantification of pressure correction for ammonia injection regulation (e.g., P decreases by 1°, A 3% reduction indicates that the ammonia injection rate needs to be increased to compensate for the decreased mixing efficiency. (Load correction function) ,load The higher the temperature, the greater the flue gas flow rate, and the shorter the contact time between the activated carbon and the flue gas. Quantitative loading corrects for activated carbon adsorption efficiency.

[0022] In one embodiment of the present invention, the system further includes a flue gas reheating device, which is connected to the dust removal device 4 and electrically connected to the controller 1. After controlling the denitrification device 2 and the activated carbon injection device 3 in sequence, the method further includes: After the first preset time period, determine whether the emission concentration difference is greater than zero; If so, control the flue gas reheating device to heat it; If not, after the second preset time period, the step "determine whether the emission concentration difference is greater than zero" will be executed again.

[0023] In this embodiment, the system adds a flue gas reheating device connected to the dust removal device 4 and electrically linked to the controller 1. After completing the coordinated control of the changes in ammonia injection in the denitrification device 2 and the changes in the injection in the activated carbon injection device 3, the system determines in real time whether the emission concentration difference is greater than zero after a first preset time period (e.g., 10 minutes). If the difference is greater than zero (mercury emissions do not meet the standard), the flue gas reheating device is controlled to increase its temperature to enhance the mercury absorption efficiency of the subsequent desulfurization device. If the difference is less than or equal to zero (mercury emissions meet the standard), the concentration difference judgment is re-executed after a second preset time period (e.g., 5 minutes), forming a dynamic control cycle of "adjustment-monitoring-feedback". This mechanism, through multi-device collaboration and precise time-sequence control, ensures that mercury removal efficiency meets the standard while avoiding energy waste, significantly improving the intelligence and economy of mercury removal in coal-fired units.

[0024] In one embodiment of the present invention, the system further includes a desulfurization device and a gate for the mercury complexing agent feed port. The dust removal device 4, the desulfurization device and the flue gas reheating device are connected in sequence. The desulfurization device is connected to the gate for the mercury complexing agent feed port, and the controller 1 is electrically connected to the gate for the mercury complexing agent feed port. After the flue gas reheating device has been used for heating, the method further includes: After the third preset time period, determine whether the emission concentration difference is greater than zero; If so, determine the change in the opening of the gate at the mercury complexing agent feed port based on the emission concentration difference, and control the gate at the mercury complexing agent feed port according to the change in opening. If not, the flue gas reheating device should be stopped.

[0025] In this embodiment, the system further integrates the desulfurization device and the mercury complexing agent feeding gate (the two are connected by pipelines, and the desulfurization device, dust removal device 4, and flue gas reheating device are connected in series). The mercury complexing agent feeding gate is directly electrically controlled by the controller 1. After the heating operation of the flue gas reheating device is completed, the control logic continues as follows: After a third preset time (e.g., 15 minutes), the system again collects and calculates the current emission concentration difference (the difference between the actual mercury concentration and the ideal reference concentration); if the concentration difference is still greater than zero (mercury emissions do not meet the standard), the opening change of the mercury complexing agent feeding gate is dynamically calculated based on the concentration difference (the higher the emission concentration, the greater the opening change), and the gate opening is adjusted by the controller 1 to increase the amount of complexing agent added, thereby strengthening the absorption of mercury by the desulfurization device; if the concentration difference is ≤ zero (mercury emissions meet the standard), the flue gas reheating device is controlled to stop heating to avoid unnecessary energy consumption. This extended process further improves the accuracy and economy of mercury removal through the multi-stage coordination of "heating control - complexing agent addition - feedback termination".

[0026] In one embodiment of the present invention, the change in opening degree is determined by the following formula:

[0027] In the formula, The change in opening degree This represents the first mercury emission concentration. This represents the second mercury emission concentration. This is the lower limit of the change in opening degree. The linear adjustment coefficient is... For nonlinear correction coefficients, This represents the upper limit of the change in opening degree.

[0028] In this embodiment, This represents the change in opening degree. A positive value indicates an increase in opening degree (adding more complexing agent), while a negative value indicates a decrease in opening degree (reducing the dosage). This represents the first mercury emission concentration. This represents the second mercury emission concentration. The lower limit of the opening variation is determined by the mechanical limits of the gate. This is a linear adjustment coefficient, reflecting the change in opening degree corresponding to a unit concentration deviation. This is a nonlinear correction coefficient (usually between 0.2 and 0.5). The upper limit of the opening variation is determined by the mechanical limits of the gate. This is a linear term, the baseline adjustment, which is proportional to the concentration deviation. As a non-linear correction term, the larger the concentration deviation, the larger the correction coefficient, and the faster the change in aperture increases.

[0029] In one embodiment of the present invention, determining the second mercury emission concentration based on coal type parameters and boiler operating parameters includes: The coal type parameters and boiler operating parameters are extracted separately to obtain the coal type parameter features and boiler operating parameter features in sequence. The coal type parameter characteristics and boiler operating parameter characteristics are fused to obtain a fused feature matrix; The fused feature matrix is ​​input into a preset mercury emission concentration prediction model to obtain the second mercury emission concentration.

[0030] In this embodiment, when determining the second mercury emission concentration based on coal type parameters and boiler operating parameters, features are first extracted from both parameters to obtain coal type parameter features and boiler operating parameter features. These two types of features are then fused to form a fused feature matrix. Finally, the fused feature matrix is ​​input into a pre-set mercury emission concentration prediction model, and the model calculates the ideal mercury emission concentration at the flue gas outlet, i.e., the second mercury emission concentration. This process, through feature processing of multi-source parameters and model prediction, provides an accurate baseline concentration reference for subsequent mercury removal control.

[0031] In one embodiment of the present invention, the preset mercury emission concentration prediction model is obtained by using the known fusion feature matrix and the mercury emission concentration at the flue outlet under the ideal state corresponding to the known fusion feature matrix as samples to train the classifier.

[0032] In this embodiment, the pre-defined mercury emission concentration prediction model is constructed through sample training: a fusion feature matrix formed by fusing coal type parameter features extracted from historical data with boiler operating parameter features, and the mercury emission concentration at the flue outlet under ideal conditions (i.e., the second mercury emission concentration) corresponding to these feature matrices are used as training samples. Machine learning methods are employed to train a classifier, enabling it to learn the mapping relationship between coal quality characteristics, operating parameters, and ideal mercury emission concentration. Ultimately, a model capable of accurately predicting the second mercury emission concentration based on the real-time input fusion feature matrix is ​​obtained. This model provides crucial benchmark data support for the subsequent formulation of mercury removal control strategies.

[0033] The foregoing has described specific embodiments of the invention. Other embodiments are within the scope of the appended claims. In some cases, the actions or steps described in the claims may be performed in a different order than that shown in the embodiments and may still achieve the desired results. Furthermore, the processes depicted in the drawings do not necessarily require the specific or sequential order shown to achieve the desired results. In some embodiments, multitasking and parallel processing are also possible or may be advantageous.

[0034] According to another embodiment, the present invention provides a co-operated mercury removal device for coal-fired power units, which is applied to a controller 1 of a co-operated mercury removal system for coal-fired power units. The system includes the controller 1 and a denitrification device 2, an activated carbon injection device 3, and a dust removal device 4 connected in sequence. The denitrification device 2, the activated carbon injection device 3, and the dust removal device 4 are all installed in the flue of the coal-fired power unit. The denitrification device 2, the activated carbon injection device 3, and the controller 1 are electrically connected. Figure 2 A schematic block diagram of a co-operated mercury removal device for a coal-fired power unit according to one embodiment is shown. It will be understood that this device can be implemented by any apparatus, device, platform, or cluster of devices with computing and processing capabilities. Figure 2 As shown, the device includes: an acquisition unit 200, a first data processing unit 202, a second data processing unit 204, a third data processing unit 206, and a fourth data processing unit 208. The main functions of each component are as follows: The acquisition unit 200 is configured to acquire the coal type parameters, boiler operating parameters, and first mercury emission concentration at the flue outlet of the current coal-fired unit; wherein, the boiler operating parameters include boiler operating temperature, boiler operating pressure, and boiler operating coal consumption; The first data processing unit 202 is configured to determine a second mercury emission concentration based on the coal type parameters and the boiler operating parameters; wherein the second mercury emission concentration is the mercury emission concentration at the flue outlet under ideal conditions; The second data processing unit 204 is configured to determine the emission concentration difference based on the first mercury emission concentration and the second mercury emission concentration. The third data processing unit 206 is configured to determine the target change amount based on the emission concentration difference, the coal type parameters, and the boiler operating parameters; wherein the target change amount includes the change amount of ammonia injection of the denitrification device 2 and the change amount of activated carbon injection of the activated carbon injection device 3. The fourth data processing unit 208 is configured to control the denitrification device 2 and the activated carbon injection device 3 sequentially based on the changes in ammonia injection and activated carbon injection to achieve synergistic mercury removal.

[0035] In one embodiment of the present invention, the target change amount is determined by the following formula:

[0036] In the formula, The change in ammonia injection amount, The first preset coefficient, The emission concentration difference is... The sulfur content corresponding to the parameters of the coal type. The mercury content corresponding to the coal type parameters. The first preset impact index, The change in activated carbon injection amount, This is the second preset coefficient. This is the third preset coefficient. The second preset influence index, Cost per unit of mercury removal The unit cost of ammonia, The unit cost of activated carbon, For actual mercury removal efficiency, Based on mercury removal efficiency, The first linear efficiency coefficient, The second linear efficiency coefficient. The coefficient of synergistic effect. To achieve the target mercury removal efficiency, The boiler operating temperature is... The boiler operating pressure is... The amount of coal consumed during the operation of the boiler. It is a Lagrange multiplier.

[0037] In one embodiment of the present invention, the system further includes a flue gas reheating device, which is connected to the dust removal device 4 and electrically connected to the controller 1; The synergistic mercury removal device further includes a fifth data processing unit, which is used to perform the following operations: After a first preset time period, determine whether the emission concentration difference is greater than zero; If so, control the flue gas reheating device to heat it; If not, after the second preset time period, the step "determine whether the emission concentration difference is greater than zero" will be executed again.

[0038] In one embodiment of the present invention, the system further includes a desulfurization device and a gate for the mercury complexing agent feed port. The dust removal device 4, the desulfurization device and the flue gas reheating device are connected in sequence. The desulfurization device is connected to the gate for the mercury complexing agent feed port. The controller 1 is electrically connected to the gate for the mercury complexing agent feed port. The synergistic mercury removal device further includes a sixth data processing unit, which is used to perform the following operations: After a third preset time period, it is determined whether the emission concentration difference is greater than zero; If so, the opening change of the gate of the mercury complexing agent feed port is determined according to the emission concentration difference, and the gate of the mercury complexing agent feed port is controlled according to the opening change. If not, control the flue gas reheating device to stop heating.

[0039] In one embodiment of the present invention, the change in opening degree is determined by the following formula:

[0040] In the formula, The change in opening degree is the amount of change. This represents the first mercury emission concentration. This represents the second mercury emission concentration. This is the lower limit of the change in opening degree. The linear adjustment coefficient is... For nonlinear correction coefficients, This represents the upper limit of the change in opening degree.

[0041] In one embodiment of the present invention, when the first data processing unit 202 determines the second mercury emission concentration based on the coal type parameters and the boiler operating parameters, it performs the following operations: The coal type parameters and the boiler operating parameters are respectively extracted to obtain the coal type parameter features and the boiler operating parameter features in sequence. The coal type parameter features and the boiler operating parameter features are fused to obtain a fused feature matrix; The fused feature matrix is ​​input into a preset mercury emission concentration prediction model to obtain the second mercury emission concentration.

[0042] In one embodiment of the present invention, the preset mercury emission concentration prediction model is obtained by using a known fusion feature matrix and the mercury emission concentration at the flue outlet under ideal conditions corresponding to the known fusion feature matrix as samples to train the classifier.

[0043] According to another embodiment, a computer-readable storage medium is also provided, on which a computer program is stored, which, when executed in a computer, causes the computer to perform a combination Figure 1 The method described.

[0044] According to another embodiment, a coal-fired unit co-operated mercury removal system is also provided. Figure 3A schematic block diagram of a coal-fired power unit's coordinated mercury removal system according to one embodiment is shown. The system includes a controller 1 and a denitrification device 2, an activated carbon injection device 3, and a dust removal device 4 connected in sequence. The denitrification device 2, the activated carbon injection device 3, and the dust removal device 4 are all located within the flue of the coal-fired power unit. The denitrification device 2, the activated carbon injection device 3, and the controller 1 are electrically connected. The controller 1 is used to execute the executable code to achieve the combined... Figure 1 The method described.

[0045] The various embodiments in this invention are described in a progressive manner. Similar or identical parts between embodiments can be referred to mutually. Each embodiment focuses on describing the differences from other embodiments. In particular, the apparatus embodiments are basically similar to the method embodiments, so the description is relatively simple; relevant parts can be referred to the descriptions of the method embodiments.

[0046] Those skilled in the art will recognize that, in one or more of the examples above, the functions described in this invention can be implemented using hardware, software, firmware, or any combination thereof. When implemented in software, these functions can be stored in a computer-readable medium or transmitted as one or more instructions or code on a computer-readable medium.

[0047] The specific embodiments described above further illustrate the purpose, technical solution, and beneficial effects of the present invention. It should be understood that the above description is only a specific embodiment of the present invention and is not intended to limit the scope of protection of the present invention. Any modifications, equivalent substitutions, improvements, etc., made on the basis of the technical solution of the present invention should be included within the scope of protection of the present invention.

Claims

1. A method for coordinated mercury removal from a coal-fired unit, the method comprising: The application relates to a controller (1) applied to a coal-fired unit collaborative mercury removal system, wherein the system comprises the controller (1) and a denitration device (2), an activated carbon injection device (3) and a dust removal device (4) connected in sequence, the denitration device (2), the activated carbon injection device (3) and the dust removal device (4) are arranged in a flue of the coal-fired unit, and the denitration device (2), the activated carbon injection device (3) and the controller (1) are electrically connected. The method comprises the following steps: obtaining coal type parameters, boiler operation parameters and a first mercury emission concentration at an outlet of a flue of a current coal-fired unit; wherein the boiler operation parameters comprise a boiler operation temperature, a boiler operation pressure and a boiler operation coal consumption; determining a second mercury emission concentration based on the coal type parameters and the boiler operation parameters; wherein the second mercury emission concentration is a mercury emission concentration at the outlet of the flue under an ideal state; determining an emission concentration difference based on the first mercury emission concentration and the second mercury emission concentration; determining a target change amount based on the emission concentration difference, the coal type parameters and the boiler operation parameters; wherein the target change amount comprises an ammonia injection change amount of the denitration device (2) and an activated carbon injection change amount of the activated carbon injection device (3); controlling the denitration device (2) and the activated carbon injection device (3) in sequence based on the ammonia injection change amount and the activated carbon injection change amount, so as to realize collaborative mercury removal.

2. The method of claim 1, wherein, The target change amount is determined by the following formula: In the formula, is the ammonia injection variation amount, is a first preset coefficient, is the emission concentration difference, is the sulfur content corresponding to the coal type parameter, is the mercury content corresponding to the coal type parameter, is a first preset influence index, is the activated carbon injection variation amount, is a second preset coefficient, is a third preset coefficient, is a second preset influence index, is the unit mercury removal cost, is the unit cost of ammonia, is the unit cost of activated carbon, is the actual mercury removal efficiency, is the basic mercury removal efficiency, is a first linear efficiency coefficient, is a second linear efficiency coefficient, is a synergistic effect coefficient, is the target mercury removal efficiency, is the boiler operating temperature, is the boiler operating pressure, is the amount of coal burned by the boiler, is a Lagrange multiplier.

3. The method of claim 1, wherein, The system further comprises a flue gas reheating device, the flue gas reheating device is connected with the dust removal device (4) and is electrically connected with the controller (1); after the denitration device (2) and the activated carbon injection device (3) are controlled in sequence, the method further comprises the following steps: after a first preset time length, judging whether the emission concentration difference is greater than zero; if yes, controlling the flue gas reheating device to heat; if no, after a second preset time length, re-executing the step of judging whether the emission concentration difference is greater than zero.

4. The method of claim 3, wherein, The system further comprises a desulfurization device and a gate of a mercury complexing agent feeding port, the dust removal device (4), the desulfurization device and the flue gas reheating device are connected in sequence, the desulfurization device is connected with the gate of the mercury complexing agent feeding port, and the controller (1) is electrically connected with the gate of the mercury complexing agent feeding port; after the flue gas reheating device is controlled to heat, the method further comprises the following steps: after a third preset time length, judging whether the emission concentration difference is greater than zero; if yes, determining an opening change amount of the gate of the mercury complexing agent feeding port according to the emission concentration difference, and controlling the gate of the mercury complexing agent feeding port according to the opening change amount; if no, controlling the flue gas reheating device to stop heating.

5. The method of claim 4, wherein, The opening change amount is determined by the following formula: wherein is the opening variation amount, is the first mercury emission concentration, is the second mercury emission concentration, is the opening variation amount lower limit, is the linear adjustment coefficient, is the non-linear correction coefficient, is the opening variation amount upper limit.

6. The method of claim 1, wherein, The method further comprises the following steps: performing feature extraction on the coal type parameters and the boiler operation parameters respectively, and sequentially obtaining coal type parameter features and boiler operation parameter features; The coal type parameter features and the boiler operation parameter features are fused to obtain a fused feature matrix; The fused feature matrix is input into a preset mercury emission concentration prediction model to obtain a second mercury emission concentration.

7. The method of claim 6, wherein, The preset mercury emission concentration prediction model takes a known fused feature matrix and a mercury emission concentration of a flue outlet in an ideal state corresponding to the known fused feature matrix as samples to train a classifier.

8. A coal-fired unit co-ordinated mercury removal device, characterized in that, The application relates to a controller (1) applied to a coal-fired unit cooperative mercury removal system, wherein the system comprises the controller (1) and a denitration device (2), an activated carbon injection device (3) and a dust removal device (4) connected in sequence, the denitration device (2), the activated carbon injection device (3) and the dust removal device (4) are arranged in a flue of the coal-fired unit, and the denitration device (2), the activated carbon injection device (3) and the controller (1) are electrically connected. The cooperative mercury removal device comprises: An acquisition unit is configured to acquire coal type parameters, boiler operation parameters and a first mercury emission concentration of a flue outlet of a current coal-fired unit; wherein the boiler operation parameters comprise a boiler operation temperature, a boiler operation pressure and a boiler operation coal consumption; A first data processing unit is configured to determine a second mercury emission concentration based on the coal type parameters and the boiler operation parameters; wherein the second mercury emission concentration is a mercury emission concentration of the flue outlet in an ideal state; A second data processing unit is configured to determine an emission concentration difference based on the first mercury emission concentration and the second mercury emission concentration; A third data processing unit is configured to determine a target change amount based on the emission concentration difference, the coal type parameters and the boiler operation parameters; wherein the target change amount comprises an ammonia injection change amount of the denitration device (2) and an activated carbon injection change amount of the activated carbon injection device (3); A fourth data processing unit is configured to control the denitration device (2) and the activated carbon injection device (3) in sequence based on the ammonia injection change amount and the activated carbon injection change amount to realize cooperative mercury removal.

9. An electronic device, comprising: The system comprises a controller (1) and a denitration device (2), an activated carbon injection device (3) and a dust removal device (4) connected in sequence, the denitration device (2), the activated carbon injection device (3) and the dust removal device (4) are arranged in a flue of a coal-fired unit, the denitration device (2), the activated carbon injection device (3) and the controller (1) are electrically connected, and the controller (1) is used for executing the method according to any one of claims 1-7.

10. A coal-fired unit coordinated mercury removal system, characterized in that, The system comprises a controller (1) and a denitration device (2), an activated carbon injection device (3) and a dust removal device (4) connected in sequence, the denitration device (2), the activated carbon injection device (3) and the dust removal device (4) are arranged in a flue of a coal-fired unit, the denitration device (2), the activated carbon injection device (3) and the controller (1) are electrically connected, and the controller (1) is used for executing the method according to any one of claims 1-7.

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