Method for determining leakage in heat transfer fluid channels of a heat transfer reactor system and heat transfer reactor

Abstract

To improve tube leak detection, a tube leak determination method is used in the heat transfer fluid channel of the combustion heat transfer reactor system (10), and this method, - A step of measuring the main heat transfer fluid flow (qMS,M) prevalent in the heat transfer fluid channel of the combustion heat transfer reactor system (10) during operation; - A step of modeling the main heat transfer fluid flow (qMS,C) of the heat transfer fluid channel in operation by using process data in a numerical model of the combustion heat transfer reactor system (10) that provides the main heat transfer fluid (qMS,C) flow rate of the combustion heat transfer reactor system (10) under conditions where there is practically no leakage; - A step of comparing the measured heat transfer fluid flow with the modeled heat transfer fluid flow to obtain an error measurement (ΔMS) for the main heat transfer fluid flow included in the error measurement set; and - Includes a step of determining the presence of a heat transfer fluid circuit tube leak by monitoring the characteristics of the error measurement set and the error measurement set that exceed a predetermined threshold during a predetermined time period while in operation.

Description

Technology Field

[0001] The present invention relates to the detection and evaluation of leakage in heat transfer fluid channels of a heat transfer reactor, particularly a fluidized bed reactor such as a circulating fluidized bed (CFB) reactor or a bubble fluidized bed (BFB) reactor. Background Technology

[0002] Combustion boilers, such as grate boilers and fluidized bed boilers, are generally used to generate steam that can be used for various purposes, such as electricity and heat production.

[0003] In a fluidized bed boiler or gasifier, a high-temperature bed of fuel and solid particulate bed material is introduced into the furnace, and a fluidizing gas is introduced from the bottom of the furnace to fluidize the bed material and fuel. Combustion of the fuel occurs in the fluidized bed. In a bubble fluidized bed reactor, the fluidizing gas passes through the bed so that most of the solid material remains in the bed.

[0004] In a circulating fluidized bed reactor (CFB), fluidizing gas passes through the bed material. Most bed particles are carried along with the fluidizing gas and flue gas. The particles are separated from the flue gas in at least one particle separator, circulated, and returned to the reactor chamber. It is common practice to arrange a fluidized bed heat exchanger downstream of the particle separator(s) to recover heat from the particles before they are returned to the furnace.

[0005] Generally, flow channel leaks in heat transfer reactors cause heat transfer fluid to escape from the heat transfer fluid circuit, allowing the escaped fluid to enter the reactor in an uncontrolled manner. In the worst-case scenario, such leaks can necessitate comprehensive repairs to the reactor. Most leak situations result in much less severe consequences, at least if the leak is detected reasonably quickly.

[0006] Leaks in flow channels typically require shutting down the reactor, locating the leak, and repairing or replacing the leaking tube—or generally the flow channels. From a plant operator's perspective, this can be a costly procedure. In addition to the cost of repairing or replacing the tube after locating the leak, shutting down the reactor stops the production of heat transfer fluid (which can be used to produce commercial goods), so operators generally lose a source of revenue during the shutdown. It is important to avoid unnecessary shutdowns by considering the resulting costs and the loss of heat transfer fluid production capacity. Leak detection must be performed reliably.

[0007] As an example of leak detection, the applicant's CFB boiler leak detection system is disclosed in the December 2018 article "Boiler Technology - SmartBoiler™: how the Internet of Things can improve boiler operating performance" by Modern Power Systems (www.modernpowersystems.com). The boiler leak detection module closely monitors the furnace walls and other boiler heat exchange surfaces and predicts future problems based on actual process data and regression models using self-learning algorithms, allowing maintenance to be planned in advance and restoration time to be minimized. The problem to be solved

[0008] The purpose is to improve leak detection in the heat transfer fluid channels of a heat transfer reactor system.

[0009] This objective can be achieved by the method according to independent claim 1 and the heat transfer reactor according to independent claim 13.

[0010] Dependent terms describe advantageous modes of the method. means of solving the problem

[0011] A method for determining leakage in the heat transfer fluid channels of a heat transfer reactor system is,

[0012] - The main heat transfer fluid flow rate Q prevalent in the heat transfer fluid circuit of the heat transfer reactor system during operation MS,M Step of measuring;

[0013] - Heat transfer fluid q of a heat transfer reactor system under conditions of virtually no leakage MS,C By utilizing process data in a numerical model of a heat transfer reactor system providing flow, the main heat transfer fluid flow rate q of the heat transfer fluid channel during operation MS,C Step of modeling;

[0014] - A step of comparing the measured heat transfer fluid flow rate with the modeled heat transfer fluid flow rate to obtain an error measurement ΔMS for the heat transfer fluid flow rate included in the error measurement set; and

[0015] - Includes the step of determining the presence of heat transfer fluid circuit leakage by monitoring the error measurement set and the characteristics of the error measurement set that exceed a predetermined threshold during a predetermined time period while in operation.

[0016] By using that method, it will be possible to improve leak detection in the heat transfer fluid circuit of a heat transfer reactor system. By using an appropriate numerical model of the heat transfer reactor system, the main heat transfer fluid flow rate can be numerically and quickly calculated under conditions of virtually no leakage, even if the heat transfer fluid flow rate may have large fluctuations between continuous measurements, so that the error measurement ΔMS will indicate the presence of tube leakage with sufficient probability. In a heat transfer reactor, the heat transfer devices and the channels connecting them can generally be referred to as a fluid circuit.

[0017] In addition, by properly preparing the characteristic monitoring, it is possible to select a predetermined threshold such that i) an error measurement ΔMS that is sufficiently large (e.g., exceeding a predefined threshold) determines heat transfer fluid circuit leakage faster than a smaller error measurement ΔMS; and ii) also determine heat transfer fluid circuit leakage when the smaller error measurement ΔMS persists for a predefined time (or number of measurements). This selection of characteristic monitoring developed by the inventors, particularly the selected "boosting factor" approach used for monitoring the set of error measurements and the characteristics of the set of error measurements, contributes significantly to the functionality of the method.

[0018] The "boosting factor" approach reflects the inventors' observation that leakage in the heat transfer fluid circuit of a heat transfer reactor system can occur gradually, that is, it can start as a small leak. If not careful, a small leak can soon become a large leak. Due to large fluctuations or changes in heat transfer fluid measurements, it has been impossible to reliably detect small leaks without using specific markers in the heat transfer fluid channels. Consequently, there has been a tendency to reliably detect leaks only after they have become sufficiently severe, which, however, tends to increase the effort required to repair the heat transfer reactor system. According to the present invention, the reliability of leak detection can be improved, which helps avoid false alarms (leading to unnecessary shutdowns and costly downtime of the heat transfer reactor system) while still enabling rapid detection of leaks.

[0019] The heat transfer fluid flow rate is preferably measured in the heat transfer fluid channel after the final or last heat exchanger, indicating the final temperature of the heat transfer fluid.

[0020] The error measurement ΔMS for the main heat transfer fluid flow rate is preferably the measured heat transfer fluid flow rate (q MS, MEASURED) and calculated heat transfer fluid flow rate (q MS, COMPUTED The difference between ) (ΔMS = q MS, MEASURED - q MS, COMPUTED )am.

[0021] Alternatively, the error measurement ΔMS for the main heat transfer fluid flow rate is the measured heat transfer fluid flow rate (q MS, MEASURED ) and calculated heat transfer fluid flow rate (q MS, COMPUTED It can be a ratio between ).

[0022] These embodiments can be combined so that the error measurement ΔMS for the main heat transfer fluid flow rate can be as follows:

[0023] - Measured heat transfer fluid flow rate (q MS, MEASURED ) and calculated heat transfer fluid flow rate (q MS, COMPUTED The difference between ) (ΔMS = q MS, MEASURED - q MS, COMPUTED );

[0024] and / or

[0025] - Measured heat transfer fluid flow rate (q MS, MEASURED ) and calculated heat transfer fluid flow rate (q MS, COMPUTED The ratio between ).

[0026] This method may additionally include the following steps when using the method in a heat transfer fluid channel or a circuit of a heat transfer reactor:

[0027] - A step of measuring at least one process parameter prevalent at at least one location in the reaction chamber of the reactor system;

[0028] - A step of modeling at least one of the corresponding process parameters during the operation of the reactor system by using process data of a numerical model that provides the corresponding process parameters of the reactor system under conditions of practically no leakage;

[0029] - A step of comparing the at least one measured process parameter with the corresponding at least one modeled process parameter and also obtaining an error measurement for at least one process parameter included in the error measurement set.

[0030] Using this approach, measurements taken in the reactor chamber can be utilized to improve the accuracy of the method and / or may also include the detection of reactor system components where leaks are present. Most conveniently, the process parameters include or consist of at least one of temperature and / or pressure.

[0031] The error measurement for at least one process reaction chamber may be the difference between the measured process parameter and the modeled process parameter.

[0032] Alternatively, an error measurement for at least one process reaction chamber parameter may be the ratio between the measured process parameter and the modeled process parameter.

[0033] These can be combined such that the error measurement for at least one process half-layer chamber parameter is the difference between the measured process parameter and the modeled process parameter and / or the ratio between the measured process parameter and the modeled process parameter.

[0034] According to an embodiment of the present invention, the characteristics of an error measurement set may include the number of occurrences exceeding a predetermined threshold during a predetermined time period while in operation.

[0035] An embodiment of the present invention is a circulating fluidized bed (CFB) reactor system, but the present invention can also be implemented among other types of systems.

[0036] In the case of a CFB reactor system, process parameters measured at at least one internal location preferably include or consist of the pressure of a loop seal arranged downstream of the particle separator of the return leg, i.e., the return leg is arranged to return the separated particles into the reaction chamber.

[0037] In this situation, preferably, the method includes a step of monitoring whether the number of occurrences of error measurements for the main heat transfer fluid flow rate exceeds a predetermined threshold, wherein the number of excess occurrences is included in the characteristics of the error measurement, and the method further includes a step of monitoring whether the number of occurrences of error measurements for the pressure of the loop seal exceeds a predetermined threshold, wherein the number of excess occurrences is included in the characteristics of the error measurement. i) if the number of occurrences of error measurements for the heat transfer fluid flow rate and error measurements for the main heat transfer fluid flow rate exceeds a predetermined threshold, and additionally ii) if the number of occurrences of error measurements related to the pressure of the loop seal and the pressure of the loop seal parameter of the loop seal exceeds a predetermined threshold, a heat transfer fluid circuit leakage may be determined to be present in the loop seal.

[0038] In the case of a CFB reactor system, process parameters measured at at least one location inside the reactor preferably include or consist of the product gas temperature at the outlet of the particle separator.

[0039] In this situation, preferably, i) if both the error measurement for the main heat transfer fluid flow rate and the number of occurrences of the error measurement for the main heat transfer fluid flow rate exceed a predetermined threshold for the corresponding error measurement, and additionally ii) if both the error measurement related to the product gas temperature at the outlet of the particle separator and the number of occurrences of the product gas temperature at the outlet of the particle separator exceed a predetermined threshold for the product gas temperature error measurement, it is determined that there is a leak in the particle separator.

[0040] In the case of a CFB reactor system, process parameters measured at at least one location inside the reactor preferably include or consist of the bed temperature of a fluidized bed heat exchanger including a heat exchanger.

[0041] A common feature of all aspects and embodiments of the method is that the characteristics of the error measurement may include or be composed of each occurrence exceeding a predetermined threshold.

[0042] The heat transfer reactor system includes a local control system and / or is connected to a remote control system, and the control system(s) are configured to perform a leak determination method. The heat transfer reactor system further includes display means, such as a display / monitor, for indicating to an operator the presence of a tube leak detected using this method. Brief explanation of the drawing

[0043] Hereinafter, the method and reactor system will be described in more detail with reference to exemplary embodiments disclosed in the attached drawings. FIG. 1 illustrates a CFB reactor system; FIG. 2 illustrates a BFB reactor system; Figure 3 illustrates a calibration method for a numerical model of a CFB reactor system; Figure 4 illustrates the possibilities for training mathematical models and using data; Figure 5 illustrates the calculation of leakage risk; Figures 6a through 6i show selected data from a test in which the method was applied to actual CFB boiler system data to verify the function of the method. Identical drawing symbols indicate identical technical features in all drawings. Specific details for implementing the invention

[0044] FIG. 1 illustrates a heat transfer reactor system (10). More specifically, FIG. 1 discloses a circulating fluidized bed (CFB) boiler in which heat is generated by the combustion of fuel and the heat is transferred to a heat transfer fluid (steam). The reactor (10) includes various heat exchangers and tube walls arranged to allow the heat transfer fluid (steam) to flow to receive the heat obtained from the combustion of fuel, and thus the CFB boiler is an example of a heat transfer reactor. The reactor includes a furnace (12) having a reactor space (12), specifically a tube wall (13) (typically including a front wall, a rear wall, and a side wall) connected to the heat transfer fluid (steam) circuit of the combustion boiler system (10). FIG. 1 illustrates a once-through steam generator case in which water is supplied from a feed water tank (50) to an evaporator (wall of the furnace) and then guided through a superheater to a turbine (not shown in the drawing). Economizers and / or superheaters may be provided in the flue gas channel.

[0045] A fluidizing gas (e.g., air and / or oxygen-containing gas) is supplied from a fluidizing gas source (153) to the reactor through a primary fluidizing gas feed (151) so that the primary fluidizing gas enters the reactor space through a nozzle of the grid (250) to fluidize the layer material, and through a secondary gas feed (152) to supply gas to control the reaction in the reactor. The effect is that the layer material is fluidized and the gas required for the reaction is supplied to the reactor (12). Additionally, fuel, or reactants, are supplied into the reactor chamber (12) through a supply inlet (22).

[0046] The reaction within the chamber can be controlled by controlling the reactant feed (22) by decreasing or increasing the feed rate, and by controlling the fluidized gas feed by decreasing or increasing the flow rate of the gas into the reactor chamber (12). In particular, if the reactor is used for the combustion of fuel, the fuel may be supplied with an additive, specifically an additive that acts as an alkali adsorbent, such as CaCO3 and / or clay. Additionally or alternatively, a NOx reducing agent, such as ammonium or urea, may be supplied into or over the combustion zone of the furnace (12).

[0047] The bed material can also be fed into or removed from the reactor, and depending on the actual application, the bed material may include sand, limestone, and / or clay, particularly containing kaolin, as well as oxides of alkali metals such as CaO. One effect of beds and generally combustion is that the heat transfer fluid is heated more efficiently when the thermal surface interacts with the fluidized bed.

[0048] The so-called bottom ash (or any particles that cannot be fluidized) falls to the bottom of the reactor (12) and can be removed through a chute (omitted in FIG. 1 for clarity), and some of the solid material, especially lighter particles, will be carried along with the product gas.

[0049] Reaction products, such as product gas and lighter particles, proceed from the reactor (12) to a particle separator (17) which may include a vortex finder (103). The particle separator (17) separates solid particles from the product gas. The product gas may vary depending on the reaction occurring in the reactor system (10).

[0050] In the case where the reactor is a CFB boiler, combustion products such as flue gas, unburned fuel, and bed material proceed from the furnace (12) to a particle separator (17) which may include a vortex finder (103). The particle separator (17) separates the flue gas from the solid. In particular, in a large combustion boiler (10), there may preferably be two or more (two, three, ...) separators (17) arranged in parallel with each other.

[0051] The solid separated by the separator (17) preferably passes through a loop seal (200) located at the bottom of the separator (17). Then, the solid is transferred to a fluidized bed heat exchanger (FBHE) (100) which also includes a heat transfer surface (e.g., tubes and / or heat transfer panels, but not limited thereto) so that the FBHE (100) can receive heat from the solid and further heat the heat transfer fluid of the heat transfer fluid circuit.

[0052] The FBHE (100) can be fluidized and may include heat transfer tubes or other types of heat transfer surfaces and may be arranged as a reheater or superheater. The solid can exit the FBHE (100) back to the reactor (12) through the return channel (102).

[0053] The product gas of the combustion process, referred to as flue gas, is transferred from the separator (17) to the cross duct (15), from there to the reverse path (16) (preferably a vertical path), and from there to the stack (19) via the gas duct (18). If the product gas is used in a different way, the gas is collected and leads to further processing.

[0054] The reverse path (16) includes a plurality of heat transfer surfaces (21i) (where i = 1, 2, 3, ..., k, where k is the number of heat transfer surfaces). In FIG. 1, among the heat transfer surfaces, heat transfer surfaces (211, 212, 213, 214 21k This is exemplified. For example, the actual number of different heat transfer surfaces of each of these components may be selected differently for each combustion boiler according to actual needs. There may also be additional components including heat transfer surfaces (21). The heat transfer devices and the channels connecting them may generally be referred to as fluid circuits.

[0055] The heat transfer reactor system (10) is equipped with a plurality of sensors and computer devices. FIGS. 1 and 2 illustrate some of the sensors and computer devices. Examples of sensors include a heat transfer fluid flow sensor (260) for measuring the heat transfer fluid temperature at the outlet (101) of the FBHE (100), a temperature sensor (280) for measuring the layer temperature in the FBHE (100) chamber, a temperature sensor (270) for measuring the product gas outlet temperature in the separator (17), a temperature sensor (290) for measuring the temperature of the loop seal (200), and / or a pressure sensor (291) for measuring the pressure of the loop seal (200). The FBHE may be provided with a pressure sensor for measuring the pressure in the FBHE chamber. In the embodiment illustrated in FIG. 1, the FBHE (100) is the final heat exchanger through which the heat transfer fluid leads to further processing via the FBHE outlet (101). The final heat exchanger of the heat transfer fluid channel may be located at other locations in the reactor system (10) as desired.

[0056] Process data can be collected from sensors by a distributed control system (DCS) (301). Data collection can be arranged most conveniently, for example, via a field bus (370). The DCS (301) may have a display / monitor (302) for displaying operating status information to an operator. An EDGE server (303) may perform processing such as filtering and smoothing the measurement data acquired from the sensors. There may be a local storage (304) for storing data.

[0057] The DCS (301), display / monitor (302), EDGE server (303), and local storage (304) may be located within the reactor network (380) (the local storage (304) is preferably directly connected to the EDGE server (303)). The reactor network (380) is preferably separated from the field bus (370) used to communicate measurement results from the sensor to the DCS (301) and / or the EDGE server (303). Between the DCS (301) and the EDGE server (303), there may be an open platform communication server to improve the interoperability of the system.

[0058] The reactor network (380) may preferably be connected to the Internet (306) via a gateway (305). In this situation, the measurement results may be transmitted from the reactor network (380) to a cloud service, such as a processing intelligence system (308) located in a computing cloud (207). The applicant currently operates a cloud service that runs the analysis platform. The cloud service may be operated in a virtualized server environment, such as Microsoft® Azure®, which is a virtualized and easily scalable environment for distributed computing and cloud storage for data. Other cloud computing services may also be suitable for running the analysis platform. Additionally, local or remote servers may be used instead of, or in addition to, a cloud computing service to run the analysis platform.

[0059] FIG. 2 illustrates a reactor system (10) that may be a bubble fluidized bed BFB reactor. A BFB reactor differs from a CFB reactor in that the fluidization rate is lower than that of a CFB. Therefore, a separator (17), a loop seal (160), an FBHE (100), and a return channel (102) may not be required.

[0060] At least one heat exchanger (14) may be located within the reactor chamber (12), preferably in the upper part of the chamber (12). A temperature sensor (240) measures the temperature at the heat exchanger outlet (144). Specifically, a heat transfer fluid flow sensor (240) measures the heat transfer fluid flow rate at the heat exchanger outlet (144), which is the last heat exchanger of the reactor system (10) from which the heat transfer fluid is guided for further processing.

[0061] A method for determining leakage in the heat transfer fluid circuit of a heat transfer reactor system (10) is,

[0062] - Heat transfer fluid flow rate q prevalent in the heat transfer fluid circuit of the reactor system (10) during operation MS,M Step of measuring;

[0063] - Heat transfer fluid flow rate q of the reactor system (10) under conditions of virtually no leakage MS,C By using process data in a numerical model of a reactor system (10) that provides the heat transfer fluid flow rate q of the heat transfer fluid circuit during operation MS,C Step of modeling;

[0064] - A step of comparing the measured heat transfer fluid flow rate with the modeled heat transfer fluid flow rate to obtain an error measurement ΔMS for the heat transfer fluid flow rate included in the error measurement set; and

[0065] - Includes the step of determining the presence of a heat transfer fluid circuit tube leak by monitoring the error measurement set and the characteristics of the error measurement set that exceed a predetermined threshold during a predetermined time period while in operation.

[0066] This method may further include the following steps:

[0067] - A step of measuring at least one process parameter prevalent at at least one location inside the reactor system (10);

[0068] - A step of modeling at least one of the corresponding process parameters during the operation of the heat transfer reactor system (10) by using process data of a numerical model that provides the corresponding process parameters of the reactor system under conditions where there is practically no leakage;

[0069] - A step of comparing the at least one measured process parameter and the corresponding at least one modeled process parameter with each other and also obtaining an error measurement for the at least one process parameter included in the set of error measurements.

[0070] Process parameters may include at least one of temperature and / or pressure, or consist of at least one.

[0071] CFB reactor, loop sealed (290): The process parameter may include or be composed of the pressure of the loop seal (290) arranged downstream of the particle separator (17) of the return leg arranged to return the separated particles to the reactor chamber (12). Then, the method preferably includes the step of monitoring whether the number of occurrences of error measurements for the main heat transfer fluid flow rate exceeds a predetermined threshold. The number of occurrences of the excess is included in the characteristics of the error measurement. The method further includes the step of monitoring whether the number of occurrences of error measurements for the pressure of the loop seal exceeds a predetermined threshold, and the number of occurrences of the excess is included in the characteristics of the error measurement. If the number of occurrences of error measurements for the main heat transfer fluid flow rate and error measurements for the main heat transfer fluid flow rate exceeds a predetermined threshold, and additionally, if the number of occurrences of error measurements related to the pressure of the loop seal and the pressure of the loop seal parameter of the loop seal exceeds a predetermined threshold, it is determined that a heat transfer fluid circuit leak is present in the loop seal.

[0072] CFB reactor, separator (17): Process parameters may include or be composed of the product gas temperature at the outlet of the particle separator. Subsequently, preferably, if both the error measurement for the heat transfer fluid flow rate and the number of occurrences of the error measurement for the heat transfer fluid flow rate exceed a predetermined threshold for the corresponding error measurement, and additionally, if both the error measurement related to the product gas temperature at the outlet of the particle separator and the number of occurrences of the flue gas temperature at the outlet of the particle separator exceed a predetermined threshold for the product gas temperature error measurement, it is determined that there is a leak in the particle separator.

[0073] FBHE (100): Process parameters may include or be configured with the layer temperature of a heat transfer fluidized bed heat exchanger including a heat exchange surface.

[0074] Steam generation process, superheater (14): Process parameters may include or be configured with the bed temperature of a BFB boiler system, which is a fluidized bed heat exchanger including a superheater heat transfer surface.

[0075] In the following cases, leakage may be determined in a fluidized bed heat exchanger (100) operating as a steam reheater connected between turbine stages:

[0076] When both the error measurement of the bed temperature of the fluidized bed heat exchanger and the number of occurrences of error measurements each exceed a predetermined threshold, and preferably when the error measurement for the main steam (heat transfer fluid) flow rate does not need to exceed each threshold because the reheater is located after the heat transfer fluid circuit.

[0077] A common feature of all embodiments is that the characteristics of the error measurement may include or be configured to include each occurrence exceeding a predetermined threshold.

[0078] A common feature across all embodiments is that the excess is tested within an evaluation time window. This may be an appropriately selected time interval, such as the last 60 minutes.

[0079] As described above, the heat transfer reactor system (10) includes a local control system (301, 303) and / or is connected to a remote control system (308). The control system(s) are configured to perform a leak determination method. The reactor system (10) further includes display means, such as a display / monitor (302), for indicating to the boiler operator the presence of a tube leak detected using this method.

[0080] Figure 3 shows an example of a model building or calibration process.

[0081] After the initiation at the beginning of the model building or calibration (step A1), at step A3, a numerical model for the heat transfer fluid balance of the reactor system (10) is constructed, for example, by regression modeling. Depending on the type of reactor system (10), the model may differ as follows:

[0082] In a steam boiler, the equation for water / steam balance for a drum boiler:

[0083] q ms,c = a0+ a1q fw + a2Dt(q fw ) + a3q cbd + a4q sbd + a5Dt(DL)

[0084] Here:

[0085] q ms, c = Modeled main steam flow rate

[0086] q fw = Water supply flow rate can be measured, for example, before the economizer

[0087] Dt(q fw ) = Dt(feed-out flow rate) is the time derivative of the feed-out flow rate (how much the feed-out flow changes at a specific time).

[0088] q cbd The continuous blowdown flow from the steam is water discharged from the drum.

[0089] q sbd = Soot blow steam flow may be steam from the superheater before the final superheater

[0090] Dt(DL) = Dt(drum level) is the time derivative of the drum level (how much the drum level changes at a specific time).

[0091] a0, a1 ... a5 = correction coefficients determined by the linear regression method.

[0092] Alternatively, the modeled main steam flow can be obtained using artificial intelligence tools and / or neural networks.

[0093] Equation for water / steam balance flow-through boiler:

[0094] q ms,c = a0+ a1q fw + a2DT(q fw ) + a3p fw + a4Dt(p fw )

[0095] Here:

[0096] q ms, c = Modeled main steam flow

[0097] q fw = Water supply flow

[0098] Dt (q fw ) = Dt(series flow)

[0099] p fw = Water supply pressure

[0100] Dt(p fw ) = Dt(water supply pressure)

[0101] a0, a1 ..., a4 = correction coefficients determined by the linear regression method.

[0102] Alternatively, the modeled main steam flow rate can be obtained using artificial intelligence tools and / or neural networks.

[0103] In step A5, each FBHE(100 i Regarding ), FBHE i A numerical model for calculating the temperature is constructed, for example, by the following regression modeling:

[0104] FBHE i Equation for calculating layer temperature

[0105] T i,j,c = b0 + b1T w,i + b2T se,i + b3q ms,m + b4Dt(q ms,m )

[0106] Here:

[0107] T i,j = FBHE(100 i Modeled layer temperature of )

[0108] (Since the number of temperature points is N, j = 1, ..., N)

[0109] T w,i = Loop seal (200 i ) temperature

[0110] T se,i = Separator (17 i Flue gas outlet temperature of )

[0111] q ms, m = Main steam flow

[0112] Dt (q ms, m ) = Dt(main steam flow)

[0113] b0, b1 ... b4 = coefficients determined by the linear regression method.

[0114] Alternatively, the modeled layer temperature can be obtained using artificial intelligence tools and / or neural networks.

[0115] In step A7, each separator (17 i Regarding ), the separator (17 i A numerical model for calculating the temperature of ) is constructed, for example, by the following regression modeling:

[0116] separator i Equation for temperature calculation

[0117] T separator exit,i,c = c0 + c1T inlet,i + c2T msei

[0118] In the formula:

[0119] T separator exit,i,c = Modeled separator (17 i ) Flue gas outlet temperature

[0120] T msei = (separator i All other separators except for, i.e., j ≠ i (17 j Other separators (17 calculated for ) j The average of )

[0121] T separator, inlet, i = Separator (17 i ) Inlet temperature

[0122] c0, c1 ... c2 = coefficients determined by the linear regression method

[0123] Alternatively, the modeled separator flue gas outlet temperature can be obtained using artificial intelligence tools and / or neural networks.

[0124] In step A9, each loop seal (200 i Regarding ), loop sealing (200 i A numerical model for the pressure of ) is constructed, for example, by the following regression modeling:

[0125] Loop seal (200 i Equation for pressure calculation:

[0126] p ws,I,C = d0 + d1p mwsi

[0127] In the formula:

[0128] p wsi, C = Modeled loop seal i enter

[0129] P mwsj= (loop seal (200 i Seal all other loops except for ), i.e., j ≠ i (200 j Average of different loop seal pressures (calculated for )

[0130] d0, d1 = Factors determined by linear regression method

[0131] Alternatively, the modeled layer loop sealing pressure can be obtained using artificial intelligence tools and / or neural networks.

[0132] Generally, a numerical model for the process parameters of a reactor system (10) is constructed, for example, by regression modeling. Depending on the type of reactor system (10), the model may differ, such as the mass balance for at least the major process parameters that characterize the execution of the process. For example, the layer pressure values ​​and their normal fluctuations in space and time in a BFB layer connected to a CFB reactor, such as a CFB layer or a BFB heat exchanger inside the reactor, are very different. Also, an independent BFB reactor layer behaves differently from a CFB reactor layer having individual characteristics.

[0133] FIG. 4 illustrates the operation of a leak detection system in which diagnosis (A) and training (i.e., building or calibrating a model) (B) are separated. In the diagnosis block (A), the leak diagnosis method J1 according to the present invention is preferably executed periodically, such as at predetermined time intervals or once per minute.

[0134] In the training block (B), there are at least two separate sets of training data used for training the model. The first training data set K1 contains process data (data acquired during a period of X2 days) from X1 days prior to the day the model training procedure was executed. The second training data set K3 also contains process data from X1 days prior to the day the model training procedure was executed to X2 days prior. The start and / or end times of the training procedure using the first training data set K1 and the second training data set K3 are different (the difference is indicated by X3 days). The training data sets K1 and K3 may partially overlap or be separated so as not to overlap.

[0135] Model training K5 using the first dataset K1 (see FIG. 3) can be called at predefined intervals or periodically, for example, every X1 day. Likewise, second model training K7 using the second dataset K3 (see FIG. 3) can be called after a predefined interval (X3 days elapsed) after running the first model training K5.

[0136] The purpose of this implementation is that if there is a leak in the heat transfer fluid circuit of the reactor system (10), the leak can damage the calibration data. By running the model training intermittently using different training data at different times, it is possible to detect the possibility of a leak before the data is used for modeling, thereby ignoring such damaged data. Since some leaks occur slowly, this is considered to improve the reliability of the detection algorithm.

[0137] Examples of model usage:

[0138] The model output is a value modeled by comparing it with the following measurements:

[0139] Water / Steam Balance:

[0140] ΔMS = q' ms - qms

[0141] q' ms = Modeled main steam flow rate

[0142] q ms = Measured main steam flow rate

[0143] In a normal process state, ΔMS < ΔMS limit

[0144] ΔMS limit = Process / Model or Reactor-dependent Value

[0145] Separator (17 i ) (where i = 1, 2, ...N, where N is a separator (17) in a combustion boiler system (10) i It is the number of ):

[0146] Δse i = T' se,i - T se,i

[0147] T' se,i = Modeled separator(17 i ) Flue gas outlet temperature

[0148] T se,i = Measured separator(17 i ) Flue gas outlet temperature

[0149] In the normal process state of the separator, Δse i < Δse limit

[0150] Δse limit = Process / Model / Boiler dependent values

[0151] Fluidized bed heat exchanger (FBHE) (100):

[0152] ΔT i1 … n = T' i1 … n - T i1 … n

[0153] T' i1 … n = FBHE(100 i Modeled layer temperatures of ) 1...n

[0154] Ti1 … n = FBHE(100 i Modeled layer temperatures of ) 1...n

[0155] ΔT in the normal process state for FBHE i1 ... n < ΔT limit

[0156] ΔT limit = Process / Model / Boiler dependent values

[0157] Loop seal (200 i ) (where i = 1, 2, ...N, where N is a loop seal (200) in a combustion boiler system (10) i It is the number of ):

[0158] Δp i = p' ws, i - p ws, i

[0159] p' ws, i = Modeled loop seal (200i) pressure

[0160] p ws, i = Measured loop seal (200i) pressure

[0161] Δp in the normal process state of the separator i < Δp limit

[0162] Δp limit = Process / Model / Boiler dependent values

[0163] Superheater (14):

[0164] ΔT sh = T' SH - T SH

[0165] T' SH = Modeled temperature of the superheater (14)

[0166] T SH = Measured temperature of the superheater (14)

[0167] In the normal process state of the superheater (14) ΔT SH < ΔT SH,limit

[0168] ΔT SH,limit = Process / Model / Boiler dependent values

[0169] Generally, a reactor- and / or process-dependent process parameter X affected by leakage in the fluid channel is selected. The process parameter is modeled, and the modeled value is compared with the measured value of the process parameter. The difference ΔX = X'(modeled value) - X(measured value) implies ΔX < ΔX limit In this case, it is used to evaluate the leakage condition to ensure that normal conditions exist.

[0170] ΔX limit is the threshold value for the allowed value of the difference with respect to parameter X.

[0171] Figure 5 illustrates the leak diagnosis step (J1 in Figure 4), specifically the calculation of the risk of tube leakage.

[0172] In step J13, deltas (the difference between the modeled value and the measured value) are calculated.

[0173] Initially in the CFB boiler system, ΔMS, and optionally Δse i and / or ΔT i1...n and / or Δp i (And in each BFB boiler system, ΔMS and optionally also ΔT sh ) can be calculated for a predefined time interval, such as the last 60 minutes.

[0174] In the next step J15, the delta is compared to the respective warning threshold. The warning threshold is set as a constant for each model, and if the delta is lower than the respective warning threshold, the process is in a steady state. Then, the diagnostic calculates the warning threshold exceedance in step J17. FBHE(100 i In the case of a multi-model such as ), for example, ΔT i1...n When x, if the respective process / model / boiler dependency values ​​are exceeded, the component is set to abnormal.

[0175] The risk level of tube leakage can be calculated using the equation (internal value):

[0176] If n e * BF > t u :

[0177] R = 100 + (n e * BF - t u ) / t r 100

[0178] otherwise:

[0179] R c = (n e * BF - t l ) / (t u - t l ) * 100

[0180] Here:

[0181] R c = Leakage risk level of component (location) or water / vapor balance

[0182] n e = Number of excesses in the reference period

[0183] t r = Length of reference period (minutes)

[0184] t l = lower limit

[0185] t u = Upper limit

[0186] BF = Boost Factor

[0187] BF = 1 + (E s / (WL * N) - 1) * B

[0188] Here:

[0189] BF = Boosting Factor

[0190] B = Boosting gradient

[0191] WL = Warning limit for error

[0192] N: Number of excesses

[0193] err > If it is a warning limit, E s = sum(err)

[0194] The leakage index can be calculated using the following equation:

[0195] R c If < 100, I c = R c ; R c If > 100, I c = 100

[0196] In the formula:

[0197] I c = Component Leakage Index (Location) or Water / Vapor Balance Index

[0198] R c = Leakage risk level component (location) or water / steam balance

[0199] If the leak index is 50 or higher but below 100, a "yellow" warning for location or water / steam balance.

[0200] If the leak index is greater than 100, a "red" warning for the location or water / steam balance.

[0201] Total Leakage Index:

[0202] I cm If < 50:

[0203] I = R ws / 2

[0204] I cm If >= 50:

[0205] I = R ws / 2 + I cm / 2

[0206] Here:

[0207] I = Total leakage index

[0208] R ws = Leakage risk level of water / steam balance

[0209] I cm = Maximum Component Leakage Index

[0210] The inventors verified the functionality of the method for actual data collected from a stored CFB combustion boiler system. The data is disclosed in FIGS. 6a through 6i and exemplarily shows how the method can be used to notify a boiler operator of the presence of a tube leak in the steam circuit of a combustion boiler system (as can be understood as simulating the DCS (301) and EDGE systems with the participation of a remote process intelligence system (308) and displayed to the boiler operator on a display / monitor (302).

[0211] Figure 6A shows the total leakage index I calculated during the test cycle as described above. As can be seen, the index reaches 100 in the rightmost cycle column. Boiler leakage is present. In the actual situation where process data is collected from the boiler, operation was stopped.

[0212] FIG. 6b shows the delta of the water / steam balance, i.e., ΔMS calculated for the same combustion boiler system (10) process data. Somewhat large fluctuations can be seen. There is a significant increase in the rightmost time cycle column. FIG. 6c shows the leakage index I calculated only for the water / steam balance. MS It shows.

[0213] FIG. 6d is the delta for FBHE (1003), i.e., ΔT calculated for the same combustion boiler system (10) process data. 3 1-n It plots. The increase in delta is somewhat slow. Fig. 6e is the leakage index I FBHE 3 , that is, the leakage index calculated only for component FBHE (1003) is shown.

[0214] FIG. 6f shows the delta for the separator (173), i.e., Δse3 calculated for the same combustion boiler system (10) process data. FIG. 6g shows the leakage index I SE, 3, that is, the leakage index calculated only for the component separator (173) is shown.

[0215] FIG. 6h shows the delta for the loop seal (2003), i.e., Δws3 calculated for the same combustion boiler system (10) process data. FIG. 6i shows the leakage index I ws, 3 , that is, the leakage index calculated only for the component loop seal (2003) is shown.

[0216] From the total leakage index I, the presence of tube leakage in the steam circuit of the combustion boiler system (10) can be reliably detected, and if possible, detected sooner than in the applicant's previous realization of the combustion boiler system.

[0217] A component-specific leak index (in this example, each FBHE (100)) preferably calculated for all components of the combustion boiler system (10) prone to leakage. i For each separator (17) i For ), and each loop seal (200 i From the leakage index for ), the location of the component with the tube leak can be reliably detected.

[0218] That is, in the leak detection method according to the first aspect of the present invention, a risk level is calculated using time-series measurements between a model-based quantity estimated for actual bed conditions using determined fluidized bed combustion boiler operating parameters and each quantity calculated from measurements, wherein the measurements describe the risk level in an excessively proportional manner relative to their magnitude. The risk level may be displayed to the boiler operator. If the risk level exceeds a preset limit, the exceedance is displayed to the boiler operator, an alarm is sounded to the boiler operator, and / or a boiler shutdown is automatically suggested or initiated.

[0219] In a leak detection method according to a second aspect of the present invention, a risk level is calculated using time-series measurements between a model-based quantity estimated for actual bed conditions and each quantity calculated from measurements using determined fluidized bed combustion boiler operation parameters, wherein the measurements are evaluated in at least two overlapping time windows of different lengths, and the narrower time window requires a proportionally larger number of measurements exceeding a threshold than the wider time window. The risk level may be displayed to the boiler operator. If the risk level exceeds a preset limit, the exceedance is displayed to the boiler operator, an alarm is sounded to the boiler operator, and / or a boiler shutdown is automatically suggested or initiated.

[0220] In a leak detection method according to a third aspect of the present invention, a risk level is calculated using time-series measurements between a model-based quantity estimated for actual bed conditions and each quantity calculated from measurements, using determined fluidized bed combustion boiler operation parameters, wherein the model-based quantities are estimated using corrected values, and the corrected values ​​are obtained by analyzing historical data from a time further in the past than the time series used to calculate the risk level as training data. The risk level may be displayed to the boiler operator. If the risk level exceeds a preset limit, the exceedance is displayed to the boiler operator, an alarm is sounded to the boiler operator, and / or a boiler shutdown is automatically suggested or initiated.

[0221] Each quantity calculated from the model-based quantities estimated for actual bed conditions and measurements using the determined fluidized bed combustion boiler operating parameters preferably includes one or more of the following: steam balance, flue gas outlet temperature, bed temperature, pressure, and advantageously, steam balance is used.

[0222] The risk level is preferably calculated as a weighted sum of any different measurements, optionally requiring each measurement to be included in the calculation exceeding a specific threshold. If the risk level exceeds 100%, the risk level may be further calculated so that it is displayed as 100% only.

[0223] The difference between the model-based quantities and the respective quantities calculated from measurements can be somewhat large. This stems from the fact that combustion conditions are constantly changing and certain fluctuations always occur in the combustion boiler. In the case of a combustion boiler generating superheated steam at a rate of 400 kg / s, the steam flow can actually fluctuate up or down by 5 - 10 kg / s.

[0224] The finding behind the first aspect of the present invention is that, given somewhat large variations between the model-based quantity and the respective quantity calculated from the measurement, smaller measurements occur very frequently with high probability in the time-series analysis, whereas larger measurements are not very likely to appear multiple times in the time-series analysis without a just cause. Therefore, larger tube leaks in combustion boilers can be detected significantly faster than in the background technology (Modern Power Systems December 2018 article), and occur in an excessively proportional manner to the exceedance of the threshold for size, where the number of threshold exceedances in time-window measurements describes the risk level in proportion to the sum of the measurement sizes. For example, refer to the results on page 38 of the Modern Power Systems article in I11.6. The applicant's previous method was able to detect a leak in the furnace wall about 30 minutes after the onset of the leak (first arrow from the left) (second arrow from the left). Using the present method, the inventors were able to reliably detect the same leak within about 2-4 minutes based on the same data.

[0225] The finding behind the second aspect of the invention is that, given somewhat large fluctuations between the model-based quantity and the respective quantity calculated from the measurement, smaller measurements occur very frequently with high probability in time-series analysis, whereas it is not very likely that smaller measurements will appear over longer time periods without a legitimate cause. Therefore, smaller tube leaks in combustion boilers can be detected much more reliably than in the background technology (Modern Power Systems December 2018 article), and if measurements are evaluated in at least two overlapping time windows of different lengths, the narrower time window will require a greater number of small measurements exceeding the threshold than the wider time window in proportion to the time window length. Using this method, the inventors were able to more frequently rule out suspected tube leaks as leak-free, even in situations where false leak alarms would occur using the background technology method.

[0226] The finding behind the third aspect is that somewhat large fluctuations in model-based quantities and each quantity calculated from measurements may exhibit some time-shifting characteristics in time-series analysis. In the presence of time-shifting, calculations of estimates using numerical models provide inaccurate results that are no longer reliable. In such situations, since model-based quantities are estimated using a mathematical model corrected with coefficient values ​​obtained through numerical fitting, the influence of time-shifting characteristics can be suppressed or even eliminated if corrected values ​​are obtained by analyzing training data—historical data from a much further past than the time series used to calculate the current risk level—through repeated numerical fitting. Preferably, the historical data is from at least a few days ago, and even better, from one or two weeks ago. Using this method allows for the more reliable detection of slow-progressing tube leaks compared to the method described in the background technology (Modern Power Systems December 2018 article).

[0227] In a tube leak detection method according to a fourth aspect of the present invention, a risk level is calculated using time-series measurements between a model-based quantity estimated for actual bed conditions and each quantity calculated from measurements using determined fluidized bed combustion boiler operating parameters, and comprises at least one, but preferably all, of the following: at least one separator, at least one solid return chamber heat exchanger, and one low-risk loop seal. The risk level may be displayed to the boiler operator. If the risk level exceeds a preset limit, the exceedance is displayed to the boiler operator, an alarm is sounded to the boiler operator, and / or a boiler shutdown is automatically suggested or initiated.

[0228] The finding following the fourth aspect is that tube leakage in a fluidized bed boiler can generally cause an effect similar to sandblasting, where the abrasive bed material is pressurized against other tube-like boiler structures by high-pressure steam or water. Therefore, CFB boiler leakage detection performed on at least one separator, at least one solid return chamber heat exchanger (FBHE), and / or at least one loop seal can help reduce damage to these parts of the boiler.

[0229] In the event of a leak in the furnace wall water tubes, the tube leak does not necessarily lead to very bad consequences for the furnace; however, the situation will be significantly different in certain CFB boiler structures (separators, solid return chamber heat exchangers, loop seals) where heat exchanger tubes are relatively close to each other. For example, in a solid return chamber heat exchanger, the spacing between adjacent heat exchanger tubes may be only 10 cm, and a leak in a component with a higher layer material density can lead to rapid deterioration of the leak due to the increasing abrasive effect on the layer material caused by the leak. For instance, the layer material density in the lower part of a CFB furnace may be in the range of tens of kg / m³, whereas in a solid return chamber heat exchanger, it may be in the range of 1,000 to 1,500 kg / m³. Furthermore, a leak in the furnace tube wall generally does not damage neighboring tubes because the adjacent tubes are not in the direction of the layer material blasting caused by the leak.

[0230] In a corresponding manner, the present invention and its embodiments can be utilized to determine leakage in various reactors and processes where a heat transfer fluid carries heat and a heat transfer surface receives or extracts heat between the process and the heat transfer fluid. Suitable processes and reactors are thermochemical reactors, gasifiers, and autothermal reactors in relation to CO2 capture, in processes that convert waste into reusable products, involving heat generation and its recovery.

[0231] It is obvious to those skilled in the art that the basic concept of the present invention can be implemented in various ways depending on technological advancements. The present invention and its embodiments are not limited to the examples and samples described above, and various modifications are possible according to the claims and their legal equivalents.

[0232] In the following claims and foregoing description of the present invention, variations such as the word “include,” “comprising,” or “comprising” are used in an inclusive sense, except where otherwise required by context due to expressive language or necessary impliation; that is, they specify the presence of the mentioned features but do not exclude the presence or addition of additional features in various embodiments of the present invention.

Claims

Claim 1 A method for determining leakage in a heat transfer fluid channel of a heat transfer reactor system (10), - the heat transfer fluid flow rate (q) prevalent in the heat transfer fluid channel of the heat transfer reactor system (10) during operation. MS,M A step of measuring ) - the heat transfer fluid (q) of the heat transfer reactor system (10) under leak-free conditions. MS,C By using process data in a numerical model of the heat transfer reactor system (10) that provides the ) flow rate, the heat transfer fluid flow rate (q) of the heat transfer fluid channel during operation MS,C Step of modeling ) - Error measurement for heat transfer fluid flow rate included in the error measurement set (Δ MS A step of comparing the measured heat transfer fluid flow rate within the heat transfer fluid channel with the modeled heat transfer fluid flow rate to obtain ); - a step of monitoring the error measurement set and the number of occurrences of the error measurement set during operation; and - error measurements (Δ MS A method for determining leakage in a heat transfer fluid channel of a heat transfer reactor system (10), comprising the step of determining the presence of leakage in a heat transfer fluid channel when the number of occurrences of the set of errors exceeds a predetermined threshold, or when the number of occurrences of the set of errors exceeds a predetermined threshold during a predetermined time period. Claim 2 A method for determining leakage in a heat transfer fluid channel of a heat transfer reactor system (10), further comprising: - measuring at least one process parameter prevalent at at least one location within the reaction chamber of the reactor system (10); - modeling at least one of the corresponding process parameters during the operation of the heat transfer reactor system (10) by using process data in a numerical model that provides the corresponding process parameter of the heat transfer reactor system (10) under leak-free conditions; and - comparing the at least one measured process parameter with the corresponding at least one modeled process parameter to obtain an error measurement for the at least one process parameter included in the set of error measurements. Claim 3 A method for determining leakage in a heat transfer fluid channel of a heat transfer reactor system (10), wherein, in claim 2, the process parameters include or consist of at least one of temperature and pressure. Claim 4 A method for determining leakage in a heat transfer fluid channel of a heat transfer reactor system (10), wherein, in any one of claims 1 to 3, the heat transfer reactor system (10) is a fluidized bed reactor system. Claim 5 A method for determining leakage in a heat transfer fluid channel of a heat transfer reactor system (10), wherein the process parameter comprises or consists of the pressure of a loop seal (290) arranged downstream of the particle separator (17) in the return leg (102), and the return leg (102) is arranged to return the separated particles to the reaction chamber (12). Claim 6 In claim 5, the method comprises the step of monitoring whether the number of occurrences of error measurements for the heat transfer fluid flow exceeds a predetermined threshold, said number of occurrences of excesses is included in the characteristics of the error measurements; and the method is the pressure (p) of the loop seal (200). w,i A method for determining leakage in a heat transfer fluid channel of a heat transfer reactor system (10), wherein leakage in the heat transfer fluid channel is determined to exist in the loop seal (200) when the error measurement for the main heat transfer fluid flow and the error measurement for the main heat transfer fluid flow rate exceed a predetermined threshold, and additionally, when the error measurement related to the pressure of the loop seal (200) and the number of occurrences of the pressure in the loop seal (200) parameters of the loop seal exceed the predetermined threshold. Claim 7 In claim 2 or 6, the process parameter is the product gas temperature (T) at the outlet of the particle separator (17). se,i A method for determining leakage in a heat transfer fluid channel of a heat transfer reactor system (10) comprising or composed of ). Claim 8 In claim 7, a method for determining leakage in a heat transfer fluid channel of a heat transfer reactor system (10), wherein leakage is determined to exist in the particle separator in the following cases: when both the error measurement for the main heat transfer fluid flow and the number of occurrences of the error measurement for the main heat transfer fluid flow each exceed the predetermined threshold value for the corresponding error measurement, and additionally when both the error measurement related to the product gas temperature at the outlet of the particle separator and the number of occurrences of the product gas temperature at the outlet of the particle separator each exceed the predetermined threshold value for the product gas temperature error measurements. Claim 9 A method for determining leakage in a heat transfer fluid channel of a heat transfer reactor system (10), wherein, in claim 2 or 6, the process parameter includes or is composed of the fluid bed temperature of a heat transfer fluid bed heat exchanger. Claim 10 In claim 9, a method for determining leakage in a heat transfer fluid channel of a heat transfer reactor system (10), wherein leakage in the heat transfer fluid channel of the heat transfer fluidized bed heat exchanger is determined in the following cases: when both the error measurement of the fluidized bed temperature of the heat transfer fluidized bed heat exchanger and the number of occurrences of the error measurement each exceed a predetermined threshold value. Claim 11 A method for determining leakage in a heat transfer fluid channel of a heat transfer reactor system (10), wherein, in any one of claims 1 to 3, 5 and 6, the characteristics of the error measurement include or consist of each occurrence exceeding a predetermined threshold value. Claim 12 A heat transfer reactor system (10), wherein the heat transfer reactor system (10) comprises a control system (301, 303, 308) configured to perform a method according to any one of claims 1 to 3, 5 and 6. Claim 13 In claim 12, the heat transfer reactor system (10) comprises a display means including a display / monitor (302) for indicating to an operator the presence of a flow channel leak detected using the method.

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