JP2013119983A - Operation management system - Google Patents

Abstract

PROBLEM TO BE SOLVED: To provide an operation management system that suitably detects the condition of a heat exchanger to achieve plant management.SOLUTION: The operation management system 10 has a target plant to be managed and an analyzer 32, and the plant includes a heat exchanger 26, front-end units 27 disposed upstream rather than the heat exchanger 26 in a gas flowing direction, and a detection means 28 that detects a deposited condition of ammonium chloride contained in a gas passing through the heat exchanger 26 and the analyzer analyzing data detected by the detection means 28 to determine operation conditions of the front-end units based on a solid phase deposited condition of the ammonium chloride at the heat exchanger 26. In this way, the operation management system can accurately detect the condition of the heat exchanger to achieve plant management.

Description

  The present invention relates to an operation management system that manages an operation state of an exhaust gas treatment system including a heat exchanger.

  Exhaust gas treatment equipment for boilers for thermal power plants and chemical plants, as a general example of system configuration, denitration equipment, air preheater, air heater, gas gas heater heat recovery device for exhaust gas reheating, dry type An electric dust collector, a wet desulfurization apparatus, the gas gas heater reheater, and a chimney are arranged in this order. Here, the heat medium type gas gas heater connects the heat recovery device and the reheater with a cold / hot water circulation line, and feeds the heat medium warm water into the fin tube water pipe by a heat medium circulation pump to exchange heat with the exhaust gas. is there.

  In such a thermal power plant, when the ammonia gas concentration and the hydrogen chloride gas concentration reach predetermined values in the heat exchanger downstream of the denitration device, and the exhaust gas temperature falls to the predetermined value, chlorination occurs in the exhaust gas by a chemical equilibrium reaction. Conditions for solid-phase precipitation of ammonium hold. Ammonium chloride has high adhesion. For this reason, when ammonium chloride is solid-phase precipitated in the heat exchanger, the ammonium chloride deposited in the solid phase adheres to the surface and wall surface of the bundle of the heat exchanger. The adhesion of ammonium chloride may cause a deterioration in the performance of the heat exchanger or a failure.

  On the other hand, Patent Document 1 is a heat exchanger on the side of reheating exhaust gas, the heating amount of the flowing exhaust gas is reduced to a low temperature, and the temperature in the heat exchanger is slightly lower than 45 ° C. In addition, it is described that the mist is generated by making the target liquid below the dew point, and the attached ammonium chloride is removed. Patent document 2 is also a heat exchanger on the side of reheating exhaust gas, and ammonium chloride from the generated gas is generated on the heat transfer surface of the heat exchanger by preheating before reheating with the heat exchanger. It is described that the temperature conditions are set so as not to be deposited by solid phase precipitation.

Japanese Patent No. 4034980 Japanese Patent No. 3764568

  Here, the thermal power plant includes a heat exchanger that reheats the exhaust gas and a gas gas heater heat recovery device that is disposed downstream of the denitration device and recovers the heat of the exhaust gas and cools the exhaust gas. Similarly, ammonium chloride may adhere.

  In this case, if it cools to the state which refine | purifies a liquid from waste gas like the patent document 1, a problem will arise in the process of the downstream equipment of a gas gas heater heat recovery device. Further, when a region where ammonium chloride is solid-phase precipitated and other components are not liquefied in the region where the exhaust gas is cooled, ammonium chloride adheres to the region. Further, as described in Patent Document 2, if the temperature is set so that ammonium chloride does not solid-phase precipitate from the produced gas and adhere to the heat transfer surface of the heat exchanger by preheating, cooling by the heat exchanger May be insufficient. Further, in a thermal power plant, the heat exchanger for reheating exhaust gas may be insufficiently controlled by the methods described in Patent Document 1 and Patent Document 2.

  This invention makes it a subject to provide the operation management system which detects the production | generation state of the ammonium chloride in a heat exchanger, and maintains the operation state of a plant suitably in view of the said problem.

  The operation management system of the present invention for solving the above-described problems distributes the heat exchanger, the upstream device disposed upstream of the heat exchanger in the flow direction of the circulation gas, and the heat exchanger. A detection target device for detecting ammonia gas concentration and hydrogen chloride gas concentration contained in the circulation gas, and a temperature in a heat exchanger, and a management target plant, and analyzing the data detected by the detection means, the heat exchange And an analyzer for determining the operating conditions of the upstream device based on the state of solid phase precipitation of ammonium chloride in the vessel.

  As a preferred embodiment, the analysis device analyzes the data detected by the detection means, detects whether ammonium chloride is solid-phase precipitated in the flow path of the circulation gas of the heat exchanger, When it is determined that solid ammonium chloride is generated, information for changing the operating condition of the upstream device is output. That is, the analysis device outputs information for changing the operating condition of the upstream device when it is determined that ammonium chloride is solid-phase precipitated. The information for changing the operating conditions of the upstream equipment includes the conditions that favorably maintain the influencing factors related to the solid phase precipitation of ammonium chloride, among the operating conditions of the upstream equipment and the operating parameters of the heat exchanger, that is, chloride. The conditions under which ammonium solid-phase precipitation hardly occurs or the generation amount is reduced are output as analysis results. The state where solid ammonium chloride is generated is a state where solid ammonium chloride is deposited. Detecting whether solid ammonium chloride is generated is also referred to as detecting the precipitation state of solid ammonium chloride.

  As a preferred embodiment, the analysis device analyzes data detected by the detection means, detects an ammonium chloride deposition state in the flow path of the circulation gas of the heat exchanger, and detects the flow path of the flow path by the ammonium chloride. When it is determined that the blockage is greater than or equal to the threshold, information for changing the operating condition of the upstream device is output.

  In a preferred embodiment, the upstream device includes a denitration device, and the analysis device determines a concentration of ammonia gas to be mixed by the denitration device as an operating condition of the upstream device.

  Further, as a preferred embodiment, the upstream device includes a denitration device, and the analysis device determines whether or not the catalyst of the denitration device needs to be increased or replaced as an operating condition of the upstream device, that is, the denitration device. It is determined whether it is necessary to increase or replace the catalyst for maintaining the denitration performance of the apparatus.

  As a preferred embodiment, the detection means includes an ammonia gas concentration detection unit that detects the concentration of ammonia gas flowing through the heat exchanger, a temperature detection unit that detects the temperature of the heat exchanger, and the heat exchanger. A hydrogen chloride gas concentration detecting means for detecting a flowing hydrogen chloride gas concentration, and the analysis device satisfies the conditions for the detected ammonia gas concentration, hydrogen chloride gas concentration and temperature to generate ammonium chloride in the body. That is, it is detected whether or not ammonium chloride is in a condition for solid-phase precipitation, and the precipitation state of ammonium chloride is detected.

  Moreover, as a preferable aspect, the detection unit includes a pressure detection unit including a plurality of pressure detection elements for detecting the pressure in the heat exchanger, and the analysis device is based on a detection result of the pressure detection unit. A pressure loss distribution in the heat exchanger is detected, and a deposition state of ammonium chloride in the heat exchanger is detected based on the pressure loss distribution.

  Moreover, as a preferable aspect, the detection means includes a flow rate detection unit including a plurality of flow rate detection elements that detect a flow rate of the circulation gas flowing in the heat exchanger, and the analysis device detects the flow rate detection unit. Based on the result, a flow velocity distribution in the heat exchanger is detected, and based on the flow velocity distribution, a deposition state of ammonium chloride in the heat exchanger is detected.

  Moreover, as a preferable aspect, the first communication device connected to the analysis device is further included, and the managed plant includes a second communication device capable of outputting data detected by the detection unit, One communication device transmits / receives data to / from the second communication device via a public communication line, receives data detected by the detection means, and outputs the data to the analysis device.

  As a preferred embodiment, the analysis device adjusts the operating condition of the upstream device based on the operating condition of the upstream device.

  Further, as a preferred aspect, a plurality of the management target plants are provided, and the analysis device detects the state of the heat exchanger by comparing and analyzing data detected by the detection means supplied from the plurality of management target plants. To do.

  And a reading device that is connected to the analysis apparatus and reads data recorded on the recording medium, and the management target plant is capable of writing the data detected by the detecting means to the recording medium. The reading device reads the recording medium, reads the data written by the writing device on the recording medium, and outputs the data to the analysis apparatus.

  Moreover, the said analysis apparatus outputs warning information to the said management object plant, when it determines with the said ammonium chloride having accumulated in the said heat exchanger.

  Moreover, as a preferable aspect, when it is determined that the ammonium chloride accumulated in the heat exchanger is equal to or greater than a threshold value, the analysis apparatus outputs maintenance information to the management target plant.

  Moreover, as a preferable aspect, the heat exchanger cools the circulation gas.

  Moreover, as a preferable aspect, the management target plant includes a denitration device that is disposed on the upstream side of the heat exchanger in the flow direction of the circulation gas and mixes the circulation gas with ammonia gas.

  As a preferred embodiment, the managed plant is a power plant, and the circulating gas is an exhaust gas generated when fuel is burned in the power plant.

  According to the present invention, the state of the heat exchanger can be suitably detected and managed.

FIG. 1 is a block diagram illustrating a schematic configuration of an operation management system according to the present embodiment. FIG. 2 is a schematic diagram of the power generation unit of the power plant of the operation management system according to the present embodiment. FIG. 3 is an explanatory diagram showing a schematic configuration of the heat exchanger unit of the exhaust gas treatment system of the power generation unit. FIG. 4 is a perspective view showing a schematic configuration of the heat exchanger. FIG. 5 is an explanatory diagram showing a schematic configuration of the heat exchanger. FIG. 6 is an explanatory diagram showing a schematic configuration of the heat exchanger. FIG. 7 is a block diagram showing a schematic configuration of the detection means of the power generation unit. FIG. 8 is an explanatory diagram showing a schematic configuration of a part of the detection means. FIG. 9 is an explanatory diagram showing a schematic configuration of an example of a pressure detector. FIG. 10 is an explanatory diagram showing a schematic configuration of an example of the flow velocity detector. FIG. 11 is an explanatory diagram for explaining the behavior of solid ammonium chloride. FIG. 12 is an explanatory diagram for explaining the behavior of solid ammonium chloride. FIG. 13A is an explanatory diagram for explaining the behavior of solid ammonium chloride. FIG. 13B is an explanatory diagram for explaining the behavior of solid ammonium chloride. FIG. 14 is a graph showing an example of the relationship among temperature, hydrogen chloride gas concentration, and ammonia gas concentration. FIG. 15 is a graph for explaining the relationship between the driving conditions and the behavior of ammonia chloride gas. FIG. 16 is a graph for explaining the relationship between driving conditions and behavior of ammonia chloride gas. FIG. 17 is a flowchart illustrating an example of a control operation of the operation management system. FIG. 18 is a flowchart illustrating an example of a control operation of the operation management system. FIG. 19 is a flowchart illustrating an example of a control operation of the operation management system. FIG. 20 is a block diagram illustrating a schematic configuration of another example of the operation management system.

  Hereinafter, the present invention will be described in detail with reference to the drawings. In addition, this invention is not limited by this Example, Moreover, when there exists multiple Example, what comprises combining each Example is also included. In addition, constituent elements in the following embodiments include those that can be easily assumed by those skilled in the art or those that are substantially the same.

  FIG. 1 is a block diagram illustrating a schematic configuration of an operation management system according to the present embodiment. The operation management system 10 includes a plurality of power plants 12 and one analysis unit 14. Since the power plant 12 has basically the same configuration, only the configuration of one power plant 12 is shown as a representative. In the operation management system 10, a plurality of power plants 12 and one analysis unit 14 communicate via a communication line 16. Here, various lines for communicating data can be applied to the communication line 16, but a public line such as an Internet network or a telephone communication network is preferable. The communication line 16 may be a dedicated line.

  The power plant 12 includes a power generation unit 20, a control device 22, and a communication device 24. The power generation unit 20 is a power generation unit that converts thermal energy generated by burning fuel into electric power. The power generation unit 20 includes at least a heat exchanger 26, a upstream device 27, and detection means 28. In this embodiment, the heat exchanger 26 is a heat recovery unit that performs heat exchange with the exhaust gas (circulation gas) generated in the power generation unit 20, recovers heat contained in the exhaust gas, and cools the exhaust gas. The upstream device 27 is a device that is arranged upstream of the heat exchanger 26 (on the upstream side) in the flow direction of the exhaust gas. The detection means 28 includes detectors attached to various mechanisms of the power generation unit 20 and detects the operating state of the power generation unit 20 with the detector. The configuration of the power generation unit 20 will be described later.

  The control device 22 is a calculation mechanism having a calculation unit such as a CPU and a storage unit such as a ROM and a RAM, controls the detection unit 28 based on various conditions, and acquires the result detected by the detection unit 28. The control device 22 also controls each part of the power generation unit 20. Note that the power plant 12 may be provided with a control device that controls each part of the power generation unit 20 other than the detection means 28, separately from the control device 22. The control device 22 also detects the operating condition of the upstream device 27.

  The communication device 24 communicates with other communication devices via the communication line 16 to transmit / receive data. The communication device 24 may communicate with the communication line 16 by wireless communication or may communicate with the communication line 16 by wired communication. The communication device 24 is connected to the control device 22 and outputs a result detected by the detection means 28 output from the control device 22 to another communication device. Further, the communication device 24 outputs the operating condition of the upstream device 27 to other communication devices according to the setting.

  Next, the analysis unit 14 includes a communication device 30 and an analysis device 32. The communication device 30 communicates with another communication device, that is, the communication device 24 of each power plant 12 via the communication line 16, and transmits and receives data. The communication device 30 receives the result detected by the detection means 28 output from the communication device 24 and transmitted via the communication line 16 and the operating conditions of the upstream device 27. The communication device 30 is connected to the analysis device 32, and outputs the received result detected by the detection means 28 to the analysis device 32. The communication device 30 may communicate with the communication line 16 by wireless communication or may communicate with the communication line 16 by wired communication.

  The analysis device 32 is a calculation mechanism having a calculation unit such as a CPU, and a storage unit such as a ROM and a RAM, analyzes the result detected by the detection means 28 received via the communication device 30, and The state of the exchanger 26 is detected. Specifically, the analysis device 32 detects the precipitation state of ammonium chloride contained in the exhaust gas passing through the heat exchanger 26 based on the result detected by the detection means 28. Moreover, the analyzer 32 determines the operating state of the upstream device 27 based on the state of ammonium chloride precipitation. The control operation of the analysis device 32 will be described later.

  Next, the power generation unit 20 will be described with reference to FIG. FIG. 2 is a schematic diagram of the power generation unit of the power plant of the operation management system according to the present embodiment. In FIG. 2, the detection means 28 is not shown. The detection means 28 will be described separately.

  As shown in FIG. 2, the power generation unit 20 includes a boiler 100 that burns fuel and an exhaust gas treatment system 101 that processes exhaust gas discharged from the boiler 100. The boiler 100 burns fuel or the like to generate heated gas. The gas heated by the boiler 100 absorbs heat by a mechanism that converts thermal energy into electric power. The gas whose heat has been absorbed is discharged to the exhaust gas treatment system 101 as exhaust gas.

  The exhaust gas treatment system 101 removes nitrogen oxide (NOx), dust, and sulfur oxide (SOx) contained in the exhaust gas in the process in which the exhaust gas discharged from the boiler 100 is released from the chimney 111. The exhaust gas treatment system 101 includes a denitration device 102, an air heater 103, a heat exchanger (heat recovery device) 26, an electric dust collector 105, a ventilator 106, a desulfurization device 107, and a heat exchanger (reheater) 108. A circulation pump 109, a circulation pipe 110, and a chimney 111. In the power generation unit 20, the boiler 100, the denitration device 102, and the air heater 103 are disposed on the upstream side of the heat exchanger 26 in the flow direction of the exhaust gas G. Therefore, the boiler 100, the denitration device 102, The air heater 103 is the upstream device 27.

The exhaust gas G ₀ discharged from the boiler 100 is introduced into a denitration device 102 filled with a catalyst. In the denitration apparatus 102, ammonia gas (NH ₃ ) injected as a reducing agent reduces nitrogen oxides contained in the exhaust gas G ₀ to water and nitrogen and renders them harmless.

The exhaust gas G ₁ discharged from the denitration apparatus 102 is generally cooled to a temperature of 130 ° C. to 150 ° C. via an air heater (AH) 103.

The exhaust gas G _{2 that} has passed through the air heater 103 is introduced into the heat exchanger 26 of the gas gas heater that serves as a heat recovery device, and exchanges heat with a heat medium (for example, hot water) that flows through the fin tube 115 inserted therein. Heat recovered. The temperature of the exhaust gas G ₃ that has passed through the heat exchanger 26 serving as a heat recovery device is generally 85 to 110 ° C., and for example, the dust collection capability of the electric dust collector (EP) 105 is improved.

The exhaust gas G _{3 that} has passed through the heat exchanger 26 is introduced into the electrostatic precipitator 105 to remove the dust.

The exhaust gas G ₄ passing through the electric dust collector 105 is boosted by the ventilator 106 driven by the electric motor. Note that the ventilator 106 may not be provided, or may be disposed at a position where the purified gas G ₇ that is the downstream of the gas gas heater reheater flows.

The exhaust gas G ₅ pressurized by the ventilator 106 is introduced into the desulfurizer 107. In the desulfurization apparatus 107, for example, by limestone slurry elaborate dissolved in alkaline or weakly alkaline absorbing solution, sulfur oxides in the exhaust gas G ₅ are absorbed and removed. When the desulfurization apparatus 107 uses an absorbing solution in which limestone is dissolved in a slurry, gypsum is generated as a by-product. Then, the temperature of the exhaust gas G ₆ passed through the desulfurization apparatus 107 is lowered to degree generally about 50 ° C..

The exhaust gas G _{6 that} has passed through the desulfurization apparatus 107 is introduced into a heat exchanger 108 of a gas gas heater that serves as a reheater. The heat exchanger 108 serving as a reheater is a process of circulating the heat medium 83 between the heat exchanger 26 serving as the heat recovery unit and the heat medium circulation pump 109 through the pair of heat medium circulation pipes 110. Then, the exhaust gas G ₆ is heated by the recovered heat recovered by the heat exchanger 26. Here, the temperature of the outlet exhaust gas G ₆ of the desulfurization apparatus 107 at about 50 ° C. is reheated to about 85 to 110 ° C. by the heat exchanger 108 and discharged from the chimney 111 to the atmosphere.

  FIG. 3 is an explanatory diagram showing a schematic configuration of the heat exchanger unit of the exhaust gas treatment system of the power generation unit. As shown in FIG. 3, the heat exchange unit includes a heat medium circulation pipe 110 through which a heat medium 83 circulates between a heat exchanger 26 serving as a heat recovery unit and a heat exchanger 108 serving as a reheater. The heat medium 83 circulates between the heat exchanger 26 and the heat exchanger 108 via the heat medium circulation pipe 110. A plurality of fins are provided on the fin tube 115 on the surface of the heat medium circulation pipe 110 provided inside each of the heat exchanger 26 and the heat exchanger 108. The heat medium circulation pipe 110 is provided with a heat exchanging portion 86, which compensates for the energy corresponding to the temperature drop taken away by heat radiation when the heat medium 83 circulates by heating with the steam 87, and maintains the medium temperature of the heat medium 83. Can be adjusted.

The heat medium 83 is supplied from the heat medium tank 88 to the heat medium circulation pipe 110. The heat medium 83 is circulated in the heat medium circulation pipe 110 by the circulation pump 109. Further, the supply amount of the steam 87 is adjusted by the control valve V ₁ in accordance with the gas temperature of the purified gas G ₆ from the desulfurizer 107, and the control valve is adjusted in accordance with the gas temperature of the exhaust gas G ₃ discharged from the heat recovery unit 26. The heat medium 83 supplied to the reheater 108 by V ₂ is supplied to the heat exchanger 26, and the supply amount of the heat medium 83 supplied to the heat exchanger 108 is adjusted. The purified gas G ₇ discharged from the reheater 108 is supplied to the chimney 111. The gas supplied to the chimney 111 is discharged to the outside as the purified gas G _8.

  Hereinafter, the structure of the heat exchanger 26 according to the present embodiment will be described with reference to FIGS. 4 to 6. FIG. 4 is a perspective view showing a schematic configuration of the heat exchanger. 5 and 6 are explanatory views showing the schematic configuration of the heat exchanger, respectively. In addition, although a present Example demonstrates the structure of the heat exchanger 26 used as a heat recovery device, the heat exchanger 108 used as a reheater is also the same structure. 4 to 6, the exhaust gas G is an arrow indicating the flow direction of the exhaust gas. 4 to 6, the X direction is the exhaust gas flow direction, the Y direction is the insertion direction of the heat transfer tube bundle, and the Z direction is the stacking installation direction of the heat transfer tube bundle.

  As shown in FIG. 4, the heat exchanger 26 includes a heat transfer tube bundle storage duct 120 that stores a heat transfer tube bundle that is an aggregate of the fin tubes 115 described above. The heat transfer tube bundle storage duct 120 serves as a housing of the heat exchanger 26, and a duct inlet 120a and an extended portion 120b are provided on one side surface (surface having a large area) of a rectangular parallelepiped box. The duct inlet 120 a is an inlet through which the exhaust gas G flows into the rectangular parallelepiped box of the heat transfer tube bundle storage duct 120. The duct inlet 120a is an opening having a smaller area than one side surface of a rectangular parallelepiped box facing each other. The expansion part 120b is a hollow member that connects the duct inlet 120a and a rectangular parallelepiped box. The extended part 120b is a cylinder whose opening diameter increases from the duct inlet 120a toward the rectangular parallelepiped box. In the heat transfer tube bundle storage duct 120, the exhaust gas G flowing from the duct inlet 120a spreads along the extended portion 120b, and flows into the entire surface of the rectangular parallelepiped box facing the duct inlet 120a.

  In addition, the heat transfer tube bundle storage duct 120 has a plurality of openings 126 formed on a surface orthogonal to a surface facing the duct inlet 120a of the rectangular parallelepiped box. The opening 126 is a part for carrying a heat transfer tube bundle described later into the heat transfer tube bundle housing duct 120. In addition, it is preferable that the opening 126 is closed when the heat exchanger 26 is driven. A frame stage 125 is provided on the surface of the heat transfer tube bundle housing duct 120 where the opening 126 is formed. The frame stage 125 is a passage through which people come and go as necessary.

  As shown in FIGS. 5 and 6, in the heat exchanger 26, a plurality of heat transfer tube bundles that are aggregates of the fin tubes 115 are arranged in the heat transfer tube bundle housing duct 120. As shown in FIG. 5, in the heat exchanger 26, a plurality of heat transfer tube bundles for heat recovery are arranged at three positions at regular intervals in the exhaust gas flow direction in the exhaust gas flow direction. The heat transfer tube bundles arranged at three locations respectively become the high temperature bundle 122A, the medium temperature bundle 122B, and the low temperature bundle 122C from the upstream side in the inflow direction of the exhaust gas, that is, from the duct inlet 120a side. That is, since the heat exchanger 26 is a mechanism that collects heat from the exhaust gas G and cools it, the temperature of the exhaust gas G is the highest on the duct inlet 120a side and passes through the region where the heat transfer tube bundle is disposed. Heat is recovered and the temperature drops. For this reason, the heat exchanger 26 becomes a high-temperature bundle 122A because the heat transfer tube bundle on the upstream side in the inflow direction of the exhaust gas recovers heat from the exhaust gas G having the highest temperature. Further, since the temperature of the exhaust gas G decreases as the heat exchanger 26 moves away from the upstream side in the exhaust gas inflow direction, the heat transfer tube bundle downstream of the high temperature bundle 122A is from the exhaust gas G having a lower temperature than the high temperature bundle 122A. In order to recover heat, the middle temperature bundle 122B is obtained. The heat transfer tube bundle downstream of the intermediate temperature bundle 122B is a low temperature bundle 122C that recovers heat from the exhaust gas G having a temperature lower than that of the intermediate temperature bundle 122B.

In addition, when the heat exchanger 26 is viewed from the direction of FIG. 5, the high temperature bundle 122 </ b> A appears as one, but as illustrated in FIG. 6, a plurality of high temperature bundles 122 </ b> A _{1 to} 122 </ b> A ₃ are stacked in the Z direction. Has been placed. Similarly, in the heat exchanger 26, three medium temperature bundles 122B _{1 to} 122B ₃ are stacked in the Z direction, and three low temperature bundles 122C _{1 to} 122C ₃ are stacked in the Z direction. The heat transfer tube bundle of the heat exchanger 26 has a plate-like shape in which the shape of the YZ plane is a rectangle with the Y direction as the long side, and the Z direction (thickness direction) is thin. The heat transfer tube bundles are arranged so as to substantially block the entire ZY plane of the rectangular parallelepiped shape of the heat transfer tube bundle storage duct 120 by being stacked in the Z direction. Moreover, another heat exchanger tube bundle is arrange | positioned in the heat transfer tube bundle in the position away from the predetermined space | interval of the X direction. The arrangement position and the number of arrangement of the heat transfer tube bundle of the heat exchanger 26 are not limited to this, and various configurations can be adopted.

  The heat exchanger 26 of the present embodiment is a horizontal flow heat exchanger in which the exhaust gas G flows in the horizontal direction, but the same applies to a vertical flow heat exchanger in which the exhaust gas G flows in the vertical direction. .

  Next, the detection means 28 will be described with reference to FIGS. FIG. 7 is a block diagram showing a schematic configuration of the detection means of the power generation unit. FIG. 8 is an explanatory diagram showing a schematic configuration of a part of the detection means. FIG. 9 is an explanatory diagram showing a schematic configuration of an example of a pressure detector. FIG. 10 is an explanatory diagram showing a schematic configuration of an example of the flow velocity detector. Moreover, below, the same matter in the high temperature bundle 122A, the medium temperature bundle 122B, and the low temperature bundle 122C will be described using the heat transfer tube bundle 122.

  As shown in FIG. 7, the detection means 28 is an aggregate of a plurality of detection units that detect various operation parameters of the power generation unit 20, and includes an ammonia gas concentration detection unit 40, a hydrogen chloride gas concentration detection unit 42, a temperature A detection unit 44, a pressure detection unit 46, and a flow velocity detection unit 48 are included. The detection means 28 basically detects various parameters in the heat exchanger 26 and in the regions before and after the heat exchanger 26. Each detection unit sends a detection result to the control device 22.

The ammonia gas concentration detection unit 40 detects the concentration of ammonia gas (NH ₃ ) gas contained in the exhaust gas G flowing through the heat exchanger 26. That is, the ammonia gas concentration detection unit 40 measures the concentration of so-called leaked ammonia gas that is supplied to the exhaust gas by the denitration apparatus 102 and does not contribute to the reaction with nitrogen oxides. The ammonia gas concentration detector 40 only needs to be able to detect the concentration of ammonia gas (NH ₃ ) contained in the exhaust gas G flowing through the heat exchanger 26, and the flow path of the heat exchanger 26, the heat exchanger 26 and the air heater 103 are connected. What is necessary is just to arrange | position to the pipe line etc. to connect.

  The hydrogen chloride gas concentration detector 42 and the concentration of hydrogen chloride (HCl) gas contained in the exhaust gas G flowing through the heat exchanger 26 are detected. The hydrogen chloride gas concentration detector 42 only needs to be able to detect the concentration of hydrogen chloride (HCl) contained in the exhaust gas G flowing through the heat exchanger 26, and the flow path of the heat exchanger 26, the heat exchanger 26 and the air heater 103 are connected. What is necessary is just to arrange | position to the pipe line etc. to connect.

  The temperature detection unit 44, the pressure detection unit 46, and the flow rate detection unit 48 each include a plurality of detection elements, and are arranged in a distributed manner in a casing surrounding the heat transfer tube bundle 122 of the heat exchanger 26. As shown in FIG. 8, the temperature detection unit 44 includes a plurality of temperature detection elements 130a, 130b, and 130c. The pressure detection unit 46 includes a plurality of pressure detection elements 132a, 132b, and 132c. The flow velocity detection unit 48 includes a plurality of flow velocity detection elements 134a, 134b, and 134c. The plurality of temperature detection elements 130a, the plurality of pressure detection elements 132a, and the plurality of flow velocity detection elements 134a are arranged in a region where the high temperature bundle 122A of the heat exchanger 26 is installed. In addition, one temperature detection element 130a, one pressure detection element 132a, and one flow velocity detection element 134a are arranged in the vicinity as one unit. The units composed of one temperature detection element 130a, one pressure detection element 132a, and one flow velocity detection element 134a are distributed and arranged in the region where the high temperature bundle 122A is installed.

  The plurality of temperature detection elements 130b, the plurality of pressure detection elements 132b, and the plurality of flow velocity detection elements 134b are arranged in a region where the intermediate temperature bundle 122B of the heat exchanger 26 is installed. In addition, one temperature detection element 130b, one pressure detection element 132b, and one flow velocity detection element 134b are also arranged as a single unit, and the units are arranged in a distributed manner. The plurality of temperature detection elements 130c, the plurality of pressure detection elements 132c, and the plurality of flow velocity detection elements 134c are arranged in a region where the low temperature bundle 122C of the heat exchanger 26 is installed. In addition, one temperature detection element 130c, one pressure detection element 132c, and one flow velocity detection element 134c are also arranged as one unit, and these units are arranged in a distributed manner.

  As described above, in the temperature detection unit 44, a plurality of temperature detection elements 130a, 130b, and 130c are arranged in the respective regions of the high temperature bundle 122A, the intermediate temperature bundle 122B, and the low temperature bundle 122C. Here, various temperature detection mechanisms can be used as the temperature detection elements 130a, 130b, and 130c, for example, thermocouples can be used. The temperature detection elements 130a, 130b, and 130c detect the temperature of the region in which the measurement unit is inserted into the heat exchanger 26 and the heat transfer tube bundle 122 is disposed. The temperature detection unit 44 detects the temperature at each position with the temperature detection elements 130 a, 130 b, and 130 c and sends the detection result to the control device 22. Thus, the temperature distribution of the heat exchanger 26 can be detected by detecting the temperature at each position by the temperature detection unit 44.

  As described above, in the pressure detection unit 46, a plurality of pressure detection elements 132a, 132b, and 132c are arranged in the respective regions of the high temperature bundle 122A, the intermediate temperature bundle 122B, and the low temperature bundle 122C. Here, as the pressure detection elements 132a, 132b, and 132c, for example, the pressure detection element 132 shown in FIG. 9 can be used. In the heat transfer tube bundle 122 shown in FIG. 9, the fin tube 115 is supported by the frame 140. In addition, a casing 142 is disposed outside the frame 140 of the heat transfer tube bundle 122 so as to cover a region where the heat transfer tube bundle 122 is disposed. The pressure detection element 132 passes through the casing 142, and a measurement point is exposed between the casing 142 and the frame 140. The pressure detection element 132 detects the pressure of the exhaust gas G flowing through the casing 142 and the frame 140. The pressure detection unit 46 detects the pressure at each position by the pressure detection elements 132 a, 132 b, and 132 c and sends the detection result to the control device 22. Thus, the pressure distribution of the heat exchanger 26 can be detected by detecting the pressure at each position by the pressure detector 46.

  As described above, in the flow velocity detection unit 48, a plurality of flow velocity detection elements 134a, 134b, and 134c are arranged in the respective regions of the high temperature bundle 122A, the intermediate temperature bundle 122B, and the low temperature bundle 122C. Here, as the flow velocity detection elements 134a, 134b, and 134c, for example, the flow velocity detection element 134 shown in FIG. 10 can be used. In the heat transfer tube bundle 122 shown in FIG. 10, the fin tube 115 is indicated by the frame 140 as in FIG. 9. In addition, a casing 142 is disposed outside the frame 140 of the heat transfer tube bundle 122 so as to cover a region where the heat transfer tube bundle 122 is disposed. The flow velocity detection element 134 passes through the casing 142, and a measurement point is exposed between the casing 142 and the frame 140. Here, a Pitot tube can be used as the flow velocity detection element 134. An example of a Pitot tube is a Western type Pitot tube. The flow velocity detection element 134 detects the flow velocity of the exhaust gas G flowing through the casing 142 and the frame 140. The flow velocity detection unit 48 detects the flow velocity at each position with the flow velocity detection elements 134 a, 134 b, and 134 c, and sends the detection result to the control device 22. Thus, the flow velocity distribution of the heat exchanger 26 can be detected by detecting the flow velocity at each position by the flow velocity detector 48. The operation management system 10 is configured as described above.

  In the operation management system 10, the analysis device 32 acquires the detection result of the detection unit 28 using the communication line 16. The analysis device 32 detects the state of parameters related to the production of ammonium chloride in the heat exchanger 26 from the detection result of the detection means 28, and analyzes the state of whether or not it is in the region where ammonium chloride is produced. In addition, the analyzing device 32 detects the closed state of the heat exchanger 26 by detecting the pressure at each location and the flow velocity between the casing and the frame.

  The production | generation behavior of the ammonium chloride in the heat exchanger 26 is demonstrated using FIGS. First, FIG. 11 to FIG. 13B are explanatory diagrams for explaining the generation behavior of solid ammonium chloride, respectively.

  The left figure of FIG. 11 shows a state where dust particles 160 and ammonium chloride particles 162 which are solidified ammonium chloride, that is, ammonium chloride particles solid-phase precipitated from the exhaust gas, are suspended in the exhaust gas G. Here, the dust particles 160 are particles having an average particle size larger than about 1 μm. The dust particles 160 may be particles having an average particle size larger than about 3 μm. The ammonium chloride particles 162 are fine fumed particles having an average particle size of 0.5 μm or less. When the ammonium chloride particles 162 are solidified in the exhaust gas, they are adsorbed on the dust particles 160 around the ammonium chloride particles 162 as shown in the right diagram of FIG. For this reason, when the ammonium chloride particles 162 are generated in the exhaust gas G, the ammonium chloride particles 162 are attached to the surroundings of the dust particles 160.

  The dust particles 160 to which the ammonium chloride particles 162 are attached are attached to a member 164 such as a casing or a frame as shown in the left diagram of FIG. Further, when the dust particles 160 with the ammonium chloride particles 162 attached to the periphery adhere to the member 164, the dust particles 160 with the ammonium chloride particles 162 attached to the periphery further adhere to the periphery of the ammonium chloride particles 162 and the dust particles 160. . As described above, when the dust particles 160 having the ammonium chloride particles 162 attached to the surroundings are repeatedly attached to the member 164, as shown in the right diagram of FIG. The particles are narrowed by the dust particles 160 to which the ammonium particles 162 are attached.

  As described above, when the dust particles 160 to which the ammonium chloride particles 162 are attached are attached to the respective parts of the heat exchanger 26 and the amount of attachment is changed, the distance between the casing 142 and the frame 140 is changed, that is, blocked. The rate changes, and the pressure and flow velocity in the region change.

  Using this relationship, the operation management system 10 detects at least one of a change in pressure distribution or a change in flow rate distribution from the detection results of the pressure detection unit 46 and the flow rate detection unit 48, so that ammonium chloride is fixed by an equilibrium reaction. Whether or not phase precipitation has occurred, that is, the solid phase precipitation state of ammonium chloride in the heat exchanger 26 can be detected. Further, the operation management system 10 can detect whether the dust particles 160 to which the ammonium chloride particles 162 are attached are attached to each part of the heat exchanger 26, or the amount of the attached ammonium chloride. . Similarly, the operation management system 10 uses this relationship to detect a change in temperature distribution from the detection result of the temperature detection unit 44, so that ammonium chloride is solid-phase precipitated by an equilibrium reaction, that is, heat. The solid phase precipitation state of ammonium chloride in the exchanger 26 can be detected. Further, the operation management system 10 can detect whether the dust particles 160 to which the ammonium chloride particles 162 are attached are attached to each part of the heat exchanger 26, or the amount of the attached ammonium chloride. .

  Here, as shown in the left diagram of FIG. 13A, when the ammonium chloride particles 162 in the exhaust gas G are small, the number of ammonium chloride particles 162 attached to one dust particle 160 is also small as shown in the right diagram of FIG. 13A. Become. The dust particles 160 to which the ammonium chloride particles 162 are attached are less adhered to the casing 142 and the frame 140 when the number of the ammonium chloride particles 162 attached to the periphery is small.

  On the other hand, as shown in the left diagram of FIG. 13B, when there are many ammonium chloride particles 162 in the exhaust gas G, the number of ammonium chloride particles 162 attached to one dust particle 160 as shown in the right diagram of FIG. 13B. Will increase. The dust particles 160 to which the ammonium chloride particles 162 are attached have a strong adhesion as particles when the number of the ammonium chloride particles 162 attached to the periphery is large, and are easily attached to the casing 142 and the frame 140. Therefore, the operation management system 10 calculates the amount of solidified ammonium chloride so that the dust particles 160 to which the ammonium chloride particles 162 are attached are attached to each part of the heat exchanger 26 and the amount to be attached. It can also be calculated.

  Next, FIG. 14 is a graph showing an example of the relationship among temperature, hydrogen chloride gas concentration, and ammonia gas concentration. FIG. 15 and FIG. 16 are graphs for explaining the relationship of the equilibrium reaction of ammonia chloride gas under the operating conditions of a certain plant. FIG. 14 shows boundary conditions under which ammonium chloride is solid-phase precipitated as a solid phase when the ammonia gas concentration is changed from sample A to H. Specifically, the hydrogen chloride gas concentration and the ammonia gas are shown. The relationship between the concentration and the equilibrium reaction between the gas temperature was obtained through experiments and theoretical studies. It should be noted that free ammonia gas and hydrogen chloride gas are present under conditions where ammonium chloride is not solid-phase precipitated. Here, ammonium chloride does not sublime unless it is heated to a temperature near the sublimation point of 335 ° C. of ammonium chloride even if the ambient temperature rises after solid-phase deposition. However, some ultrafine particles of ammonium chloride may sublimate even if they are not heated to near the sublimation point of 335 ° C. A region 180 in FIG. 14 is an example of the operating range of the temperature detected at the exhaust gas outlet of the heat exchanger 26, that is, the temperature of the exhaust gas of the heat exchanger 26. The line segment 182 is the average value of the temperature detected at the exhaust gas outlet of the heat exchanger 26, that is, the detected temperature of the lowest part of the exhaust gas of the heat exchanger 26.

  Based on the relationship shown in FIG. 14, the operation management system 10 determines whether ammonium chloride is in a solid-phase precipitation state or a gas state based on the relationship between temperature, hydrogen chloride gas concentration, and ammonia gas concentration. be able to. For example, when the operation management system 10 is operated at a point 190 where the relationship between the gas temperature and the hydrogen chloride gas concentration is plotted at the point 190 as shown in FIG. Then, it can be determined that ammonium chloride is solid-phase precipitated. Also, as shown in FIG. 16, when the ammonia gas concentration is operated at the concentration indicated by the line segment 192, it can be determined that hydrogen chloride gas and ammonia gas exist in a gaseous state under the conditions.

  As shown in FIGS. 15 and 16, the operation management system 10 determines the precipitation state of ammonium chloride based on the equilibrium data of FIG. 14 actually measured in advance through experiments and the operation state of the power plant 12 at the time of determination. Therefore, it is possible to predict the precipitation state of ammonium chloride with high accuracy from the operating state. That is, since the operation management system 10 uses the equilibrium data of FIG. 14 actually measured by experiments or the like, the determination system can be made higher than the case of calculating from only the theoretical values.

  Thereby, the operation management system 10 analyzes based on the detection results of the ammonia gas concentration detection unit 40, the hydrogen chloride gas concentration detection unit 42, and the temperature detection unit 44 (states of operation parameters related to the generation of ammonium chloride contained in the exhaust gas). By performing the above, the precipitation state of ammonium chloride in the heat exchanger 26 can be detected. The operation parameters related to the production of ammonium chloride contained in the exhaust gas include parameters related to conditions for solid-phase precipitation of ammonium chloride, and parameters that change due to solid-phase precipitation and deposition of ammonium chloride. Further, the operation management system 10 accumulates the detection results of the precipitation state of ammonium chloride in the heat exchanger 26 so that the dust particles 160 to which the ammonium chloride particles 162 are attached adhere to each part of the heat exchanger 26. In addition, it is possible to detect the amount of the dust particles 160 to which the ammonium chloride particles 162 are attached to each part of the heat exchanger 26.

  Hereinafter, the processing of the analysis device 32 of the operation management system 10 will be described with reference to FIG. Here, FIG. 17 is a flowchart showing an example of the control operation of the operation management system. The operation management system 10 repeatedly executes the process shown in FIG. 17 while the power plant 12 is driven. For example, the operation management system 10 executes the process shown in FIG. 17 at regular intervals, or executes the process shown in FIG. 17 every time measurement information is acquired.

  The analysis apparatus 32 acquires measurement information as step S12. That is, the analysis device 32 acquires the result detected by the detection means 28 via communication.

  After acquiring the measurement information in step S12, the analysis device 32 detects the precipitation state of ammonium chloride as step S14, and determines whether ammonium chloride is solid-phase precipitated as step S16. If it is determined in step S16 that ammonium chloride is solid-phase precipitated (Yes), the analysis device 32 detects an operation condition for reducing solid-phase precipitation of ammonium chloride in step S18, and the operation determined in step S19. The condition is notified, maintenance information is output, and this process is terminated. Here, the operating condition is at least one operating condition of the devices constituting the upstream device 27. Various methods can be used as the notification method. You may contact by e-mail etc., and you may make it output to the control apparatus 22 and be displayed on the display apparatus of the power plant 12. In addition, it is preferable that the analyzer 32 detects an operating condition in consideration of the current operating condition and a detection value for the upstream device 27. If the analysis device 32 determines in step S16 that ammonium chloride is not solid-phase precipitated (No), the analysis device 32 ends this processing.

  The analysis device 32 can quickly detect whether solid ammonium chloride is in a state of solid-phase precipitation by executing the processing shown in FIG. 17 each time measurement information is acquired. If it is detected that ammonium chloride is in a state of solid phase precipitation, the operating condition of the upstream device 27 that reduces solid phase precipitation of ammonium chloride is detected and the determined operating condition of the upstream device 27 is notified. The power generation unit 20 can be suitably operated.

  Here, the analysis device 32 can execute the processing of FIG. 17 using various detection units of the detection means 28. The analysis device 32 uses the detection results of the ammonia gas concentration detection unit 40, the hydrogen chloride gas concentration detection unit 42, and the temperature detection unit 44, that is, the operation parameter states related to the generation of ammonium chloride, to determine the ammonium chloride concentration. When detecting the solid-phase precipitation state, it is determined whether or not solid ammonium chloride is in a state of solid-phase precipitation based on the relationship shown in FIG. 14 described above, that is, based on the equilibrium reaction conditions. can do.

  When the analysis device 32 uses the detection result of the pressure detection unit 46, the amount of precipitation of ammonium chloride adhering to the heat exchanger 26 increases when the detected pressure distribution changes more than a threshold value. It can be determined that ammonium chloride is in a state of solid phase precipitation.

  When the analysis device 32 uses the detection result of the flow velocity detection unit 48, when the detected flow velocity distribution changes more than a threshold value, for example, the flow velocity at some measurement points increases compared to other measurement points. When it is, it can be determined that the amount of ammonium chloride adhering to the heat exchanger 26 has increased, and it can be determined that solid ammonium chloride is being generated.

  When the analysis device 32 uses the detection result of the temperature detection unit 44, when the detected temperature distribution changes more than a threshold, for example, when some temperature rises or falls, the heat exchanger 26, it can be determined that the amount of ammonium chloride adhering to 26 has increased, and it can be determined that solid ammonium chloride is being generated.

  The analysis device 32 can appropriately grasp the state of the heat exchanger by determining whether solid-phase precipitation of ammonium chloride is present. Further, by referring to the maintenance information during regular maintenance, it is possible to focus on a position where a failure is likely to occur and a mode where the failure is likely to occur. In addition, parts can be exchanged before a failure actually occurs. Further, even when a failure actually occurs, the cause of the failure can be easily clarified.

  Further, the analysis device 32 can output the operating condition to operate the upstream device 27 under an appropriate condition, and appropriately grasp the state of the upstream device 27 while preventing a failure of the heat exchanger. be able to. In addition, the state of the upstream device 27 can be properly grasped. Further, by referring to the maintenance information during regular maintenance of the upstream device 27, it is possible to focus on the position where the failure is likely to occur and the mode where the failure is likely to occur. In addition, parts can be exchanged before a failure actually occurs. Further, even when a failure actually occurs, the cause of the failure can be easily clarified.

  As described above, the operation management system 10 detects the state of the heat exchanger 26, that is, whether solid ammonium chloride is generated or whether solid ammonium chloride is attached and clogged. By outputting the detection result as maintenance information, it is possible to suppress performance deterioration of the heat exchanger and occurrence of failure. Specifically, the operation management system 10 causes air column resonance inside the heat exchanger to generate vibrations, increases the pressure loss of the heat exchanger, and ammonium chloride adheres to the heat exchanger 26 and adheres. It can suppress that the metal of the part which is doing corrodes or does. The operation management system 10 can appropriately predict whether or not these states are reached, so that the operation condition of the upstream device 27 is notified based on the detection result (prediction result). 26 can suppress solid-phase precipitation of ammonium chloride. As a result, the operation management system 10 can prevent the state of the heat exchanger 26 from affecting the operation of the power plant 12 to limit the generation load or cause the power plant 12 to stop unexpectedly. it can. Moreover, it is possible to suppress the occurrence of power loss in the power plant 12.

  In the operation management system 10, the temperature of the outlet of the heat exchanger 26 is such that the temperature of the exhaust gas G is lowered, so that the temperature range near the boundary between the solid region and the gas region shown in FIGS. To 95 ° C.). Here, the operation management system 10 has a low concentration of ammonia gas (leaked ammonia gas) that reaches the heat exchanger 26 at a normal time if the concentration of hydrogen chloride gas in a general coal burning plant is about (from 1). 2 ppm), solid phase precipitation of ammonium chloride can be suppressed. However, when the catalyst of the denitration device is aged, the power generation plant 12 may increase the ammonia gas concentration in order to maintain the denitration performance. In this case, when the ammonia gas supplied by the depulping apparatus increases, the concentration of ammonia gas (leaked ammonia gas) reaching the heat exchanger 26 also increases (for example, 5 ppm or more), and ammonium chloride undergoes an equilibrium reaction in the exhaust gas. May be a condition for solid phase precipitation. As described above, the operation management system 10 can appropriately detect the case where ammonium chloride is generated depending on the operation state. Therefore, the operation management system 10 can appropriately monitor the state of the heat exchanger 26.

  Here, various conditions can be applied as operating conditions of the upstream device 27. For example, the analysis device 32 may use the concentration of ammonia gas supplied to the denitration device as the operating condition for the denitration device 102 in the upstream device 27. The analysis device 32 may target the denitration device 102 of the upstream equipment 27 and determine whether or not the catalyst of the denitration device 102 needs to be added or replaced.

The analysis device 32 can detect a change in the performance of the denitration device 102 by detecting the solid phase precipitation state of ammonium chloride in the heat exchanger. Changes in the performance of the denitration apparatus 102 include aging and deterioration of the catalyst. Based on the detection result of the precipitation state of ammonium chloride and the detection result of the detection means, the analysis device 32 determines the rate of change over time of the performance change of the denitration device 102 and supplies the denitration rate of nitrogen oxides and ammonia (NH ₃ ). By accumulating quantity correlation data and the like, the performance of the denitration apparatus 102 can be accurately determined. The analysis device 32 detects the performance of the denitration device 102, and outputs the operating condition based on the detection result, so that the maintenance for the denitration device 102 can also be accurately performed.

  Here, coal for power generation combustion that is landed and used in the power plant 12 is periodically subjected to industrial analysis, and its composition analysis is periodically performed. The operation management system 10 accumulates the analysis result of the coal for power generation combustion in the database, performs the boiler combustion calculation by the control device 22 or the analysis device 32 based on the information of the database, and the HCl concentration in the exhaust gas for each coal type By performing this calculation, the concentration of hydrogen chloride gas can be estimated and used instead of the detected value.

  Moreover, the analysis apparatus 32 is good also considering the fuel burned with the boiler 100 as an operating condition for the boiler 100 among the upstream equipment 27. FIG. The analysis device 32 selects an appropriate fuel type based on the detection result of the solid phase precipitation state of ammonium chloride in the heat exchanger and the detection result of the hydrogen chloride gas concentration, thereby the amount of chlorine concentration in the fuel. And the concentration of hydrogen chloride gas contained in the combustion exhaust gas can be adjusted. Thereby, it can suppress that solid ammonium chloride precipitates with the heat exchanger 26. FIG.

  Next, another example of processing of the analysis device 32 of the operation management system 10 will be described with reference to FIG. Here, FIG. 18 is a flowchart showing an example of the control operation of the operation management system. A part of the processing in FIG. 18 is the same as the processing in FIG. Further, the operation management system 10 repeatedly executes the process shown in FIG. 18 while the power plant 12 is driven, similarly to the process of FIG. The analysis apparatus 32 acquires measurement information as step S12. That is, the analysis device 32 acquires the result detected by the detection means 28 via communication.

  After obtaining the measurement information in step S12, the analysis device 32 detects the precipitation state of ammonium chloride as step S14, and determines whether ammonium chloride is solid-phase precipitated as step S16. If the analysis device 32 determines in step S16 that ammonium chloride is not solid-phase precipitated (No), the analysis device 32 ends this processing.

  If it is determined in step S16 that ammonium chloride is solid-phase precipitated (Yes), the analyzer 32 detects a clogged state due to ammonium chloride in step S20. That is, the blockage state of the flow path caused by the accumulation of ammonium chloride on the heat exchanger is detected. If the analysis device 32 detects a closed state in step S20, it determines whether the blockage is equal to or greater than a threshold value in step S22. That is, it is determined whether or not the flow path is in a state of being blocked more than a threshold. If the analysis device 32 determines in step S22 that the blockage is not greater than or equal to the threshold value, that is, less than the threshold value (No), the analysis device 32 ends this processing. When it is determined in step S22 that the blockage is equal to or greater than the threshold (Yes), the analysis device 32 detects an operation condition that reduces solid-phase precipitation of ammonium chloride as step S24, and determines the determined operation condition as step S26. Notify and end this process.

  The analysis device 32 executes the processing shown in FIG. 18 every time measurement information is acquired, so that clogging with solid ammonium chloride has occurred, that is, whether the amount of solid ammonium chloride deposited is greater than a certain level. Can be detected quickly. If it is detected that the clogging caused by solid ammonium chloride is greater than or equal to the threshold value, the operating condition of the upstream device 27 that reduces solid-phase precipitation of ammonium chloride is detected, and the determined operating condition of the upstream device 27 is notified. By doing so, the power generation unit 20 can be suitably operated.

  Here, the analysis device 32 can execute the processing of FIG. 18 using various detection units of the detection means 28. The processes in steps S14 and S16 in FIG. 18 are the same as described above. Hereinafter, an example of the determination method of step S20 and step S22 is shown.

  The analysis device 32 uses the detection results of the ammonia gas concentration detection unit 40, the hydrogen chloride gas concentration detection unit 42, and the temperature detection unit 44 to detect a blockage state based on the above-described relationship of FIG. In other words, by making a determination based on the equilibrium reaction conditions and accumulating the solid-phase precipitation amount of ammonium chloride, the amount of ammonium chloride deposited can be detected, and the occlusion state can be detected. Further, the analysis device 32 determines the ease of attachment of ammonium chloride based on the solid-phase precipitation amount of ammonium chloride based on the relationship of FIG. 13A and FIG. 13B, and deposits based on the generation amount and the ease of attachment. The amount may be calculated.

  When the analysis device 32 uses the detection result of the pressure detection unit 46, the detected pressure distribution changes more than a threshold value, and when a pressure difference equal to or more than a predetermined value occurs, an obstruction exceeding the threshold value occurs. Can be determined.

  When the analysis device 32 uses the detection result of the flow velocity detection unit 48, the detected flow velocity distribution changes more than a threshold value, and when the flow velocity change exceeds a predetermined value, an obstruction exceeding the threshold value occurs. Can be determined.

  When the analysis device 32 uses the detection result of the temperature detection unit 44, the detected temperature distribution changes more than a threshold, and when a temperature difference more than a predetermined value temperature occurs, the analysis device 32 is blocked more than the threshold. Can be determined. In this case, it is preferable that the analysis device 32 compares the temperature within the bundle in the same temperature range.

  Moreover, the analysis apparatus 32 detects the blockage state of the heat exchanger 26, thereby predicting replacement calculated by integrating the detection value of the blockage state, necessity of replacement of the heat transfer tube bundle 122, and the predicted value of the accumulation amount. Time information can be grasped appropriately. Moreover, the analysis apparatus 32 can grasp | ascertain required maintenance exactly. Further, by referring to the maintenance information during regular maintenance, it is possible to focus on a position where a failure is likely to occur and a mode where the failure is likely to occur. In addition, parts can be exchanged before a failure actually occurs. Further, even when a failure actually occurs, the cause of the failure can be easily clarified. Further, the analysis device 32 can grasp the clogged state due to ammonium chloride, so that vibration due to air column resonance due to the influence of exhaust gas flowing in the heat exchanger 26, increase in pressure loss in the heat exchanger due to adhesion of ammonium chloride, The progress of corrosion in the heat exchanger due to the corrosiveness of the ammonium chloride can be suppressed, and failure can be made difficult to occur.

  Further, the analysis device 32 can output the operating condition to operate the upstream device 27 under an appropriate condition, and appropriately grasp the state of the upstream device 27 while preventing a failure of the heat exchanger. be able to. That is, since the state of the upstream device 27 can be grasped, the maintenance necessary for the upstream device 27 can be accurately grasped. Further, by referring to the maintenance information during regular maintenance, it is possible to focus on a position where a failure is likely to occur and a mode where the failure is likely to occur. In addition, parts can be exchanged before a failure actually occurs. Further, even when a failure actually occurs, the cause of the failure can be easily clarified. Further, the analysis device 32 can grasp the clogged state due to ammonium chloride, so that vibration due to air column resonance due to the influence of exhaust gas flowing in the heat exchanger, increase in pressure loss in the heat exchanger due to adhesion of ammonium chloride, The progress of corrosion in the heat exchanger due to the corrosiveness of ammonium chloride can be suppressed, and failure can be made difficult to occur.

  The operation management system 10 can prevent parts from being shut down due to unforeseen circumstances by replacing parts before the actual failure of the heat exchanger 26 and the upstream device 27 occurs. it can.

  Further, by determining the replacement time based on the acquired data, the parts can be replaced at an appropriate time. In other words, by accurately grasping the state, it is possible to replace only the parts that need to be replaced while keeping the parts that can be used until the next maintenance based on the maintenance interval. Thereby, components can be exchanged efficiently.

  The operation management system 10 can easily elucidate the cause of the failure, thereby shortening the period from several weeks to several months, which is the time taken to implement the cause investigation, countermeasure discussion, and countermeasure construction. . In addition, the operation management system 10 can easily elucidate the cause of the occurrence of the failure, so that the power plant 12 can perform repair after the manager prepares the equipment necessary for the countermeasure work.

  In addition, the operation management system 10 can perform comparative analysis by acquiring and analyzing information of the plurality of power plants 12 with a single analysis device 32, and can provide a more accurate detection result (state estimation result). ) Can be calculated. Note that one analysis device 32 does not mean one arithmetic device, but means that processing is performed by one system while sharing information. Therefore, one analysis device 32 may be composed of a plurality of arithmetic devices, and a plurality of arithmetic devices may be arranged at physically separated positions as long as they can share information. .

  Here, in the said embodiment, although driving conditions were output, it is not limited to this. The operation management system 10 may control driving of the power plant 12 based on the detected operating condition. FIG. 19 is a flowchart illustrating an example of a control operation of the operation management system. Note that the flowchart shown in FIG. 19 can be executed in place of step S19 of the process shown in FIG. 17 or step S26 shown in FIG. The operation management system 10 can execute the processing of FIG. 19 by the control device 22 performing various calculations using the results detected by the analysis device 32. Further, the operation management system 10 may execute the processing of FIG.

  The operation management system 10 detects the operation condition by the analysis device 32 as step S30, and adjusts the operation state of the upstream device 27 based on the operation condition as step S32. The operation management system 10 adjusts various operating states of the upstream device 27 that can be adjusted by the control device 22 according to control conditions. Here, the operating state includes the amount of ammonia gas supplied by the denitration device 102 of the upstream device 27, the temperature of the exhaust gas reaching the heat exchanger 26, the concentration of hydrogen chloride gas, and the like. The temperature of the exhaust gas reaching the heat exchanger 26 can be adjusted by controlling the combustion conditions in the boiler 100 and the driving conditions of the air heater 103. Further, the concentration of hydrogen chloride gas can be adjusted by selecting a fuel type containing a suitable chlorine concentration as described above, or by changing the ratio of combustion supplied to the boiler 100. The change in the ratio of combustion supplied to the boiler 100 includes a mechanism for supplying power to the boiler 100 from a supply device in which the power plant 12 stores a plurality of fuels, and the control device 22 supplies fuel to the boiler 100 from the supply device. This can be realized by driving a device that can adjust timing and amount.

  After adjusting the operation state in step S32, the operation management system 10 detects the precipitation state (solid phase precipitation state) of ammonium chloride as step S34, and determines whether the solid phase precipitation of ammonium chloride is improved as step S36. To do. That is, it is determined whether the solid state precipitation amount of ammonium chloride has been reduced by adjusting the operation state in step S32. For example, the analysis device 32 of the operation management system 10 determines that the plotted point is improved when the plotted point moves from the solid phase precipitation region to the gas region side in the relationship of FIG. 14 described above. The analysis device 32 of the operation management system 10 may determine that ammonium chloride is not newly deposited when the flow velocity and pressure do not change, and may determine that the ammonium chloride has improved.

  If the operation management system 10 determines that the improvement has been made in Step S36 (Yes), the operation management system 10 ends this processing. If the operation management system 10 determines that the improvement has not been made (No) in step S36, the operation management system 10 outputs a notification (guidance notification, maintenance notification, warning information) that the catalyst needs to be added or replaced. Also, the warning information includes the possibility that ammonium chloride has accumulated or may have occurred in the heat exchanger other than the notification that the catalyst needs to be added or replaced, or that the performance has deteriorated. Information indicating that this may or may have occurred may be output. If the operation management system 10 determines that ammonium chloride is deposited, the operation management system 10 may improve the operation conditions and consider warning information at the same time.

  As shown in FIG. 19, the operation management system 10 can operate the power plant 12 under more appropriate conditions by adjusting the operation state of the upstream device 27 based on the operation conditions, and the heat exchanger 26. The frequency of maintenance can be reduced, and the occurrence of failures can be suppressed. In addition, as shown in FIG. 19, the operation management system 10 notifies the addition or replacement of the catalyst when the solid state precipitation state of ammonium chloride is not improved, and when the state cannot be improved by adjusting the operation state. It can cope with it suitably. In FIG. 19, a notification that catalyst addition or replacement is necessary is taken as an example, but notification of execution of various operations that can be actually performed in the power plant 12 to improve the solid phase precipitation state of ammonium chloride. Can be targeted. Moreover, you may make it notify that the check of a heat exchanger is required as a process of step S38.

  When the operation management system 10 performs the process of FIG. 19, the process detected in step S <b> 30 detects various operating conditions that can detect the precipitation state (solid phase precipitation state) of ammonium chloride using the relationship of FIG. 14 described above. It is preferable to do. Thereby, the precipitation state of ammonium chloride in the heat exchanger 26 can be detected more suitably.

  Moreover, the operation management system 10 can detect a change in the state of the heat exchanger 26 quickly by acquiring a measurement result at any time using a communication line and making a determination based on the acquired result. Thereby, the precision which manages the heat exchanger 26 can be made higher, and the reliability of the determination result of a state can also be made high. For example, based on the accumulation of a large amount of data acquired in real time, it is possible to execute an analysis that takes into account variations, deviations, and the like with higher accuracy.

  Here, although the operation management system 10 of the said embodiment performed transmission / reception of the data acquired by the detection part using the communication line, it is not limited to this. Here, FIG. 20 is a block diagram illustrating a schematic configuration of another example of the operation management system. Similar to the operation management system 10, the operation management system 200 includes a plurality of power plants 212 and one analysis unit 214. Here, in the operation management system 200, a plurality of power plants 12 and one analysis unit 14 exchange data via the recording medium 240. In FIG. 20, only one recording medium 240 is shown, but a plurality of recording media 240 may be used. Further, as the recording medium 240, various portable devices and media such as a magnetic disk, an optical disk, a flash memory, and an HDD (Hard disk drive) can be used.

  The power plant 212 includes a power generation unit 20, a control device 22, and a writing device 224. The power generation unit 20 and the control device 22 have the same configuration as each part of the power plant 12.

  The writing device 224 exchanges data with other devices via the recording medium 240. The writing device 224 is connected to the control device 22 and records the result detected by the detection means 28 output from the control device 22 on the recording medium 240. Note that the writing device 224 may have a reading function.

Next, the analysis unit 214 includes a reading device 230 and an analysis device 32. The analysis device 32 is the same as the analysis device 32 of the analysis unit 14.
The reading device 230 exchanges data via the recording medium 240. The reading device 230 reads the data written on the recording medium 240 by the writing device 224, and acquires the result detected by the detection unit 28. The reading device 230 is connected to the analysis device 32 and outputs the acquired result detected by the detection unit 28 to the analysis device 32. Note that the reading device 230 may have a writing function.

  The analysis device 32 of the operation management system 200 performs the same processing as that of the operation management system 10 by using the result detected by the detection means 28 acquired via the recording medium 240. Thereby, the operation management system 200 can appropriately detect the state of the heat exchanger 26 similarly to the operation management system 10, and can obtain the same effect as described above. In this case, the driving condition is notified in a state where there is a time difference from the actual driving. Even in this case, appropriate control can be performed by controlling the operation of the power generation unit 20 based on the information of the appropriate operation condition. Further, the replacement of the catalyst of the denitration apparatus can be performed at an appropriate time by predicting the operating condition and notifying the replacement time ahead for a certain period.

  The operation management system 200 can acquire continuous operation data by acquiring data stored in the control device 22 of the power plant 212 via the recording medium 240. Further, since the operation management system 200 can be realized without using a communication line, safety can be increased as compared with the case where a public communication line is used, and the system configuration can be simplified as compared with the case where a communication line is used. it can.

  The operation management system may only accumulate the analysis results without outputting the operation condition information. The operation management system may output information indicating that the operation is stopped because the failure may occur as the operation condition, and may output warning information indicating that immediate replacement of parts is necessary. .

  In the above-described embodiment, the analysis device 32 notifies the operation condition, and the operation condition can be changed by any operation of the operator. However, the analysis apparatus 32 changes the operation condition of the power generation unit 20 based on the calculated operation condition. May be.

  Moreover, in the said Example, although the countermeasure with respect to the influence of ammonium chloride was difficult to take, the heat exchanger by which the heat exchanger of the heat recovery side was controlled was controlled, but it is not limited to this. The operation management system may control various facilities in a range where the ammonia gas concentration, the hydrogen chloride gas concentration, and the temperature fall within the equilibrium curve. In other words, the operation management system prevents ammonium chloride from solid-phase depositing or depositing on various facilities where the ammonia gas concentration, hydrogen chloride gas concentration and temperature fall within the equilibrium curve, thereby affecting the facility. To be able to.

  The operation management system according to the present embodiment will be described in the case where the management target plant is a power plant. However, the present invention is not limited to this, and any power plant including a heat exchanger may be used. In addition, it is preferable that the management object plant is equipped with the denitration apparatus which mixes ammonia with waste gas (circulation gas) upstream of a heat exchanger, and removes nitrogen oxide from waste gas like this embodiment. In this way, the plant to be managed having a configuration equipped with a denitration device is more likely to precipitate ammonium chloride, so the state of the heat exchanger is monitored by monitoring the precipitation state of ammonium chloride with the operation management system of this embodiment. Can be properly monitored and managed.

  The operation management system may be configured such that the analysis device 32 is provided for one plant and the analysis device 32 is directly connected to the control device 22. In this case, the operation management system can exchange data with an inexpensive and safe line.

DESCRIPTION OF SYMBOLS 10 Operation management system 12 Power generation plant 14 Analysis unit 16 Communication line 20 Power generation unit 24, 30 Communication device 26 Heat exchanger 27 Upstream equipment 28 Detection means 32 Analysis device 40 Ammonia gas concentration detection part 42 Hydrogen chloride gas concentration detection part 44 Temperature Detection unit 46 Pressure detection unit 48 Flow rate detection unit 120 Heat transfer tube bundle housing duct 122 Heat transfer tube bundle 125 Frame stage 126 Opening portion 130 Temperature detection element 132 Pressure detection element 134 Flow rate detection element 140 Bundle frame (frame)
142 Casing 160 Dust particles 162 Ammonium chloride particles

Claims (17)

A heat exchanger, a upstream device disposed upstream of the heat exchanger in the flow direction of the flow gas, and a state of operation parameters related to the generation of ammonium chloride contained in the flow gas flowing through the heat exchanger. A management target plant comprising detection means for detecting;
Analyzing the data detected by the detection means, and having an analysis device for determining the operating conditions of the upstream device based on the solid phase precipitation state of ammonium chloride in detecting the state of the heat exchanger. A featured operation management system.   The analysis device analyzes the data detected by the detection means, detects whether solid ammonium chloride is generated in the flow path of the circulation gas of the heat exchanger, and generates the solid ammonium chloride. 2. The operation management system according to claim 1, wherein when it is determined that the operation condition is determined, information for changing an operation condition of the upstream device is output.   The analysis device analyzes the data detected by the detection means, detects the accumulation state of ammonium chloride in the flow path of the circulation gas of the heat exchanger, and the blockage of the flow path by the ammonium chloride is equal to or greater than a threshold value. 3. The operation management system according to claim 1, wherein, when it is determined, information for changing an operation condition of the upstream device is output. The upstream device includes a denitration device,
The operation management system according to any one of claims 1 to 3, wherein the analysis device determines a concentration of ammonia gas mixed by the denitration device as an operation condition of the upstream device. The upstream device includes a denitration device,
The operation management system according to any one of claims 1 to 4, wherein the analysis device determines whether or not the catalyst of the denitration device needs to be increased or replaced as an operation condition of the upstream device. . The detection means includes an ammonia gas concentration detection unit for detecting the concentration of ammonia gas flowing through the heat exchanger, a temperature detection unit for detecting the temperature of the heat exchanger, and a hydrogen chloride gas concentration flowing through the heat exchanger. A hydrogen chloride gas concentration detecting means for detecting,
The analysis device detects whether the detected ammonia gas concentration, hydrogen chloride gas concentration, and temperature satisfy the conditions for generating solid ammonium chloride, and detects the precipitation state of ammonium chloride. The operation management system according to any one of claims 1 to 5. The detection means includes a pressure detection unit including a plurality of pressure detection elements for detecting the pressure in the heat exchanger,
The analysis device detects a pressure loss distribution in the heat exchanger based on a detection result of the pressure detection unit, and detects a deposition state of ammonium chloride in the heat exchanger based on the pressure loss distribution. The operation management system according to any one of claims 1 to 6, wherein: The detection means has a flow velocity detection unit comprising a plurality of flow velocity detection elements for detecting the flow velocity of the circulating gas flowing in the heat exchanger,
The analysis device detects a flow velocity distribution in the heat exchanger based on a detection result of the flow velocity detector, and detects a deposition state of ammonium chloride in the heat exchanger based on the flow velocity distribution. The operation management system according to any one of claims 1 to 7, wherein A first communication device connected to the analysis device;
The managed plant includes a second communication device capable of outputting data detected by the detection means,
The first communication device transmits and receives data to and from the second communication device via a public communication line, receives data detected by the detection means, and outputs the data to the analysis device. The operation management system according to any one of 1 to 8.   The operation management system according to claim 9, wherein the analysis device adjusts an operation condition of the upstream device based on an operation condition of the upstream device. A plurality of the managed plants are provided,
The said analysis apparatus carries out comparative analysis of the data detected by the said detection means supplied from the said some management object plant, and detects the state of the said heat exchanger, The Claim 9 or 10 characterized by the above-mentioned. Operation management system. A reading device connected to the analysis device and reading data recorded on a recording medium,
The managed plant includes a writing device capable of writing the data detected by the detecting means to the recording medium,
9. The read device according to claim 1, wherein the reading device reads the recording medium, reads the data written by the writing device on the recording medium, and outputs the data to the analyzing apparatus. Operation management system.   The said analysis apparatus outputs warning information to the said management object plant, when it determines with the said ammonium chloride having accumulated in the said heat exchanger, It is any one of Claim 1 to 12 characterized by the above-mentioned. Operation management system.   The said analysis apparatus outputs a maintenance information to the said management object plant, when it determines with the said ammonium chloride deposited on the said heat exchanger being more than a threshold value, The any one of Claim 1 to 13 characterized by the above-mentioned. The operation management system described in 1.   The operation management system according to claim 1, wherein the heat exchanger cools a circulation gas.   The said management object plant is arrange | positioned in the upstream of the said heat exchanger in the flow direction of circulation gas, and has the denitration apparatus which mixes ammonia with the said circulation gas, The any one of Claim 1 to 15 characterized by the above-mentioned. The operation management system described in 1. The managed plant is a power plant,
The operation management system according to any one of claims 1 to 16, wherein the circulating gas is an exhaust gas generated when fuel is burned in the power plant.

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