Multi-stage linkage safety control method and system for phase change liquid-cooled hydrogen storage in energy storage power stations

Abstract

This invention discloses a multi-level linkage safety control method and system for phase change liquid-cooled hydrogen storage in energy storage power stations, relating to the field of liquid cooling data processing technology. The method and system include: S1, periodically collecting liquid-cooled hydrogen storage data and preprocessing the data; S2, assessing and determining the current operating status; when an operational anomaly occurs, the controller issues a level-one alarm and performs a risk level assessment; S3, classifying risk levels and generating cooling strategies; execution units execute cooling commands in stages; after command execution, the heat dissipation capacity of the cooling strategy is assessed to determine whether short-term hydrogen storage zone protection measures are triggered; S4, verifying the residual assessment value of the cooling response and the energy storage status assessment value; if both meet the safety threshold conditions, the protection measures and alarm are lifted. This solves the problem in existing technologies where the lack of coordinated control between phase change liquid cooling and hydrogen storage leads to a disconnect between cooling and hydrogen storage protection responses in energy storage power stations.

Description

TECHNICAL FIELD

[0001] The application relates to the technical field of liquid cooling data processing, in particular to a phase-change liquid cooling hydrogen storage multi-stage linkage safety control method and system for an energy storage power station. BACKGROUND

[0002] With the rapid promotion of large-scale and multi-scenario application of energy storage power stations, the safe and efficient operation of energy storage systems has become the focus of the industry. Traditional thermal management and safety monitoring methods focus on the state perception and protection of single equipment or single energy flow, and there is still a lack of multi-stage linkage response mechanism across media and systems. In the related technical field, a variety of liquid cooling, phase change, data-driven safety management and cooling schemes have appeared.

[0003] For example, the invention with the publication number CN119293564B discloses a power supply safety state monitoring and early warning method and system for liquid cooling cables, which comprises: obtaining historical operation parameters and corresponding temperature field measurement values of the liquid cooling cable, constructing a temperature prediction model of the liquid cooling cable by using Gaussian regression, reading temperature field data in different states to obtain the state change law of the liquid cooling cable; constructing a diagnostic model of the power supply state of the liquid cooling cable, mining the hidden layer features of the temperature field data, training the mapping relationship between the hidden layer features and different abnormal states; obtaining the current operation parameters of the liquid cooling cable by using data sensing and preprocessing, predicting the temperature field data and diagnosing the power supply state by using the temperature prediction model and the diagnostic model, and generating a safety warning according to the diagnostic classification result.

[0004] For example, the invention with the publication number CN120578278A discloses a multi-acting composite server liquid cooling method, which uses a partition to form a sandwich, places the server inside the partition sandwich and immerses it in a flowing liquid cooling liquid for cooling, and at the same time, sets a shower head above the partition to spray phase-change cooling liquid and uses air flow to drive it to vaporize and carry away heat, realizing multi-acting composite cooling. This invention adopts a multi-acting composite cooling method, has better cooling efficiency and cooling effect, and can solve the problem of local heat explosion of the server, better improving the overall working efficiency and safety of the server chip.

[0005] However, although the existing technology has made progress in single liquid cooling, local temperature control or safety monitoring, it still has some problems in complex scenarios, such as the separation of cooling and hydrogen storage control, the lack of energy flow cooperation, the single risk criterion, and the incomplete closed-loop response, which cannot meet the actual needs of energy storage power stations in high power density, long-term energy storage and integrated operation of intrinsic safety.

[0006] Therefore, in view of the above problems, there is an urgent need for a phase-change liquid cooling hydrogen storage multi-stage linkage safety control method and system for an energy storage power station. SUMMARY

[0007] Technical problems to be solved

[0008] In view of the deficiencies of the prior art, the present application provides a phase change liquid cooling hydrogen storage multi-stage linkage safety control method and system for energy storage power stations, which solves the problem of lack of collaborative control of phase change liquid cooling and hydrogen storage control in the prior art, resulting in the fragmentation of cooling and hydrogen storage protection response in energy storage power stations.

[0009] Technical scheme

[0010] To achieve the above object, the present application is implemented by the following technical scheme: a phase change liquid cooling hydrogen storage multi-stage linkage safety control method and system for energy storage power stations, comprising: S1, periodically collecting liquid cooling hydrogen storage data, and performing time synchronization, abnormal data elimination, standardization and normalization processing on the liquid cooling hydrogen storage data to obtain pre-processed liquid cooling hydrogen storage data; S2, based on the pre-processed liquid cooling hydrogen storage data, evaluating and judging the current running state, when an operation anomaly occurs, the controller issues a first alarm and performs risk level evaluation to obtain a liquid cooling heat risk evaluation value; S3, based on the real-time liquid cooling heat risk evaluation value, dividing the risk level and generating a cooling strategy, the execution unit executes the cooling instruction in stages, and after the instruction is executed, the cooling strategy is evaluated for its heat dissipation capacity to determine whether to trigger the short-term hydrogen storage area protection measure; S4, after the short-term hydrogen storage area protection measure responds, the cooling response residual evaluation value and the energy storage state evaluation value are reviewed, and when both meet the safety threshold condition, the protection measure and the alarm are removed, and the collected data during the abnormal period is archived, realizing the closed loop of the cooling strategy.

[0011] Further, the specific steps of periodically collecting liquid cooling hydrogen storage data and performing time synchronization, abnormal data elimination, standardization and normalization processing on the liquid cooling hydrogen storage data to obtain pre-processed liquid cooling hydrogen storage data are as follows: a fixed-width sliding time window is set as a sampling period, liquid cooling hydrogen storage data is periodically collected, and the liquid cooling hydrogen storage data includes battery temperature, phase change liquid inlet temperature, phase change liquid outlet temperature, phase change liquid flow rate, electrolyte flow rate, electrolytic voltage, hydrogen production rate, high-pressure hydrogen tank pressure, high-pressure hydrogen tank temperature, short-term hydrogen storage area temperature, short-term hydrogen storage area hydrogen concentration and nitrogen protection layer pressure; the liquid cooling hydrogen storage data is sampled and time-unified through communication link level optimization and master clock synchronization mechanism; the rapid jump in the liquid cooling hydrogen storage data is dynamically suppressed through an adaptive wave suppression algorithm based on adjacent data change rate limitation; abnormal data caused by local faults, signal drift and control imbalance in the liquid cooling hydrogen storage data is eliminated through a multivariate anomaly detection method based on the Isolation Forest algorithm; and further through interval scaling and distribution normalization method, the dimension unification and normalization of the liquid cooling hydrogen storage data are realized.

[0012] Further, based on the pre-processed liquid-cooled hydrogen storage data, the specific steps for evaluating the current operating state are as follows: extracting the pre-processed liquid-cooled hydrogen storage data, calculating the difference between the phase change liquid inlet temperature and the phase change liquid outlet temperature to obtain the phase change liquid inlet and outlet temperature difference; dividing the battery temperature by the upper limit of the battery safety temperature to obtain the battery temperature rise proportion; multiplying the high-pressure hydrogen tank pressure and the short-time hydrogen storage zone hydrogen concentration, then dividing by the design rated pressure of the high-pressure hydrogen tank, and taking the square root of the comparison result to obtain the hydrogen pressure concentration coupling factor; multiplying the battery temperature rise proportion by the hydrogen pressure concentration coupling factor to obtain the hydrogen pressure concentration risk term; squaring the ratio of the hydrogen production rate to the electrolyte flow rate to obtain the unit flow hydrogen production load; dividing the absolute value of the phase change liquid inlet and outlet temperature difference by the phase change liquid reference temperature difference and adding one to obtain the cooling attenuation coefficient; dividing the unit flow hydrogen production load by the cooling attenuation coefficient to obtain the hydrogen production heat dissipation balance term; dividing the first-order time derivative of the hydrogen concentration in the short-time hydrogen storage zone by a small term and adding one, then taking the natural logarithm to obtain the concentration change response term; adding the hydrogen pressure concentration risk term, the hydrogen production heat dissipation balance term, and the concentration change response term to obtain the energy storage state evaluation value.

[0013] Further, the specific steps for determining the current operating state are as follows: real-time comparison of the energy storage state evaluation value and the state threshold value, when the energy storage state evaluation value is greater than the state threshold value, it is determined to be a normal operating state and no processing is performed; when the energy storage state evaluation value is less than or equal to the state threshold value, it is determined to be an abnormal operating state, and the controller issues a level one alarm and extracts real-time liquid-cooled hydrogen storage data to perform a thermal risk evaluation to obtain a liquid-cooled thermal risk evaluation value.

[0014] Further, the specific steps for obtaining the liquid-cooled thermal risk evaluation value are as follows: squaring the first-order time derivative of the battery temperature to obtain the temperature rise speed square term; dividing the temperature rise speed square term by the sum of the phase change liquid flow rate and a constant one to obtain the temperature rise risk coefficient; taking the absolute value of the phase change liquid inlet and outlet temperature difference and adding one, then taking the reciprocal, and taking the exponential power with the natural logarithm base e as the base to obtain the cooling temperature difference attenuation index; calculating the absolute value of the second-order time derivative of the battery temperature and adding one to obtain the temperature rise trend response term; multiplying the temperature rise risk coefficient, the cooling temperature difference attenuation index, and the temperature rise trend response term in turn to obtain the liquid-cooled thermal risk evaluation value.

[0015] Further, based on the real-time liquid cooling and heating risk assessment value, the risk level is divided and the cooling strategy is generated, and the specific steps of the execution unit to execute the cooling instruction are as follows: extracting the real-time liquid cooling and heating risk assessment value S, comparing it with the multi-level risk threshold S1 and S2, determining the risk level and generating the corresponding cooling strategy: when S≤S1, it is determined that the risk is in the first level, the sampling period is shortened, and the monitoring is continued; when S1<S<S2, it is determined that the risk is in the second level, the controller issues a speed-up instruction to the phase-change liquid circulating pump, increases the phase-change flow rate, and synchronously reduces the hydrogen production rate; when S≥S2, it is determined that the risk is in the third level, the controller starts the fluorinated liquid auxiliary cooling loop, opens the deep cooling emergency device, and simultaneously forcibly reduces the electrolysis voltage and the hydrogen production rate; the execution unit receives and executes the corresponding cooling instruction.

[0016] Further, the specific steps of evaluating the cooling capacity of the cooling strategy after the execution of the instruction are as follows: extracting the liquid cooling and heating data in the Nth sampling period after the execution of the instruction, combining the real-time liquid cooling and heating risk assessment value, and evaluating the cooling capacity of the cooling strategy: dividing the high-pressure hydrogen tank pressure by the rated pressure of the high-pressure hydrogen tank, taking the absolute value after subtracting one, taking the natural logarithm after adding one, obtaining the high-pressure pressure deviation coefficient; dividing the high-pressure hydrogen tank temperature by the short-time hydrogen storage zone temperature plus one, taking the square of the comparison value, obtaining the temperature rise risk factor; multiplying the square of the high-pressure pressure deviation coefficient and the temperature rise risk factor, and then multiplying by the liquid cooling and heating risk assessment value, obtaining the cooling pressure thermal coupling term; calculating the absolute value of the first-order time derivative of the hydrogen concentration in the short-time hydrogen storage zone and taking the cube, obtaining the concentration change response term; adding the cooling pressure thermal coupling term and the concentration change response term, and then dividing by the pressure of the nitrogen protection layer plus the minimum term, obtaining the cooling response residual evaluation value.

[0017] Further, the specific steps of determining whether to trigger the short-time hydrogen storage zone protection measure are as follows: real-time comparison of the cooling response residual evaluation value and the residual threshold value, when the cooling response residual evaluation value is less than or equal to the residual threshold value, it is determined that the cooling is sufficient, and the existing cooling strategy is maintained; when the cooling response residual evaluation value is greater than the residual threshold value, it is determined that the cooling is insufficient, and the short-time hydrogen storage zone protection measure is triggered: the pressure of the nitrogen protection layer is increased, the short-time hydrogen storage zone ventilation and exhaust device is opened, and the output valve of the high-pressure hydrogen tank is gradually closed.

[0018] Further, after the short-term hydrogen storage area protection measure responds, the cooling response residual evaluation value and the energy storage state evaluation value are reviewed, both of which meet the safety threshold condition, the protection measure is removed and the alarm is removed, and the collected data during the abnormal period is archived, and the specific steps of the cooling strategy closed loop are as follows: after the short-term hydrogen storage area protection measure is executed, the liquid cooling hydrogen storage data in the M sampling period is extracted, the cooling response residual evaluation value is recalculated; if the cooling response residual evaluation value is still greater than the residual threshold, the hydrogen production and discharge operation is limited, and the alarm information is sent to the superior organization; if the cooling response residual evaluation value is less than or equal to the residual threshold, the short-term hydrogen storage area protection measure is gradually removed, the energy storage state evaluation value is recalculated based on the real-time liquid cooling hydrogen storage data, and when the energy storage state evaluation value is greater than the state threshold, the first level alarm is removed, and the collected data and operation log during the abnormal period are automatically archived.

[0019] The second aspect of the present application provides a multi-level linkage safety control system for phase change liquid cooling hydrogen storage of energy storage power station, comprising: a data acquisition preprocessing module, a state risk evaluation module, a linkage control execution module and a safety closed loop recovery module, wherein: the data acquisition preprocessing module is used for periodically acquiring liquid cooling hydrogen storage data, and performing time synchronization, abnormal data elimination, standardization and normalization processing on the liquid cooling hydrogen storage data to obtain preprocessed liquid cooling hydrogen storage data; the state risk evaluation module is used for evaluating and judging the current running state based on the preprocessed liquid cooling hydrogen storage data, and when a running abnormality occurs, the controller issues a first level alarm and performs risk level evaluation to obtain a liquid cooling heat risk evaluation value; the linkage control execution module is used for dividing risk levels and generating a cooling strategy based on the real-time liquid cooling heat risk evaluation value, executing a cooling instruction by a unit classification, evaluating the heat dissipation capacity of the cooling strategy after the instruction is executed, and judging whether to trigger a short-term hydrogen storage area protection measure; the safety closed loop recovery module is used for reviewing the cooling response residual evaluation value and the energy storage state evaluation value after the short-term hydrogen storage area protection measure responds, both of which meet the safety threshold condition, the protection measure is removed and the alarm is removed, and the collected data during the abnormal period is archived, and the cooling strategy closed loop is realized.

[0020] Advantages

[0021] The present application has the following advantages:

[0022] (1) The multi-level linkage safety control method and system for phase change liquid cooling hydrogen storage of energy storage power station realizes cross-medium and cross-link thermal management and hydrogen storage safety cooperation through unified collection, synchronous processing and state interaction of liquid cooling hydrogen storage data. Unlike existing independent temperature control and hydrogen storage protection, the present application can dynamically link and adjust cooling and short-term hydrogen storage area safety measures according to multivariate real-time state evaluation results, greatly improving the overall risk identification and rapid linkage ability of the energy storage power station.

[0023] (2) The phase change liquid-cooled hydrogen storage multi-level linkage safety control method and system of this energy storage power station innovatively constructs an energy storage status assessment value through a multivariate coupling calculation method. This value can comprehensively reflect the integrated operation status of the energy storage system in terms of heat, electricity, and gas, and quantitatively determine potential hazards such as abnormal status and uneven energy flow in real time. Compared with traditional methods that rely on a single temperature or pressure threshold, the multivariate status assessment of this invention significantly improves the sensitivity of fault identification and the scientific nature of system safety determination, adapting to the real-time online operation and maintenance needs of large-scale complex energy storage scenarios.

[0024] (3) The phase change liquid-cooled hydrogen storage multi-level linkage safety control method and system of this energy storage power station, by constructing a liquid-cooled thermal risk assessment value and using an innovative algorithm to quantify the thermal risk evolution trend, can not only reflect the thermal risk level of the system in real time, but also dynamically trigger multi-level cooling and hydrogen storage protection measures according to the potential for thermal runaway. Compared with the existing technology, which can only passively alarm or simply start cooling, this invention can intelligently allocate cooling resources and adjust the hydrogen storage protection intensity according to different thermal risk levels, realize active prevention and rapid response, and significantly improve the safety and flexibility of energy storage power stations in dealing with complex thermal conditions.

[0025] (4) The phase change liquid-cooled hydrogen storage multi-level linkage safety control method and system of this energy storage power station is designed with a graded linkage upgrade mechanism for cooling strategy and short-term hydrogen storage zone protection measures. When the cooling response is insufficient, it can automatically upgrade to short-term hydrogen storage zone protection operation, and continuously determine whether the protection measures should be lifted or further strengthened based on the dynamic feedback results of subsequent multiple cycles, thereby realizing multi-stage, cross-cycle progressive safety control. Unlike traditional one-time passive protection, this invention realizes a progressive safety response with full-process, multi-level dynamic linkage, which greatly improves the depth of prevention and control and operational safety redundancy of the energy storage power station for complex abnormal operating conditions. Attached Figure Description

[0026] Figure 1 Flowchart of a multi-level linkage safety control method for phase change liquid-cooled hydrogen storage in an energy storage power station;

[0027] Figure 2 A structural diagram of a multi-level linkage safety control system for phase change liquid-cooled hydrogen storage in an energy storage power station;

[0028] Figure 3 A schematic diagram illustrating the classification of liquid cooling thermal risk assessment values;

[0029] Figure 4 This is a schematic diagram of the phase change liquid-cooled hydrogen storage linkage control structure.

[0030] In the diagram, 1 is the battery chamber; 2 is the first plate heat exchanger; 3 is the second plate heat exchanger; 4 is the long-term hydrogen storage area; 5 is the short-term hydrogen storage area; 6 is the fuel cell power generation module; 7 is the emergency hydrogen storage area; 8 is the power pump; 9 is the emergency plate heat exchanger; 10 is the phase change liquid circulation pump; 11 is the battery; and 12 is the temperature sensor. Detailed Implementation

[0031] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0032] Please see Figures 1-4 This invention provides a technical solution: a multi-level linkage safety control method and system for phase change liquid-cooled hydrogen storage in an energy storage power station, comprising: S1, periodically collecting liquid-cooled hydrogen storage data, and performing time synchronization, abnormal data removal, standardization and normalization processing on the liquid-cooled hydrogen storage data to obtain pre-processed liquid-cooled hydrogen storage data; S2, based on the pre-processed liquid-cooled hydrogen storage data, evaluating and judging the current operating status, and when an operating abnormality occurs, the controller issues a level one alarm and performs a risk level assessment to obtain a liquid-cooled thermal risk assessment value; S3, based on the real-time liquid-cooled thermal risk assessment value, classifying risk levels and generating cooling strategies, and executing cooling commands in stages by execution units, evaluating the heat dissipation capacity of the cooling strategy after command execution, and determining whether short-term hydrogen storage zone 5 protection measures are triggered; S4, after the short-term hydrogen storage zone 5 protection measures are responded to, verifying the residual assessment value of the cooling response and the energy storage status assessment value, and when both meet the safety threshold conditions, releasing the protection measures and alarm, and archiving the collected data during the abnormal period to achieve a closed loop of the cooling strategy.

[0033] Specifically, the process involves periodically collecting liquid-cooled hydrogen storage data and performing time synchronization, outlier removal, standardization, and normalization on the pre-processed data. The steps are as follows: A fixed-width sliding time window is set as one sampling period. Liquid-cooled hydrogen storage data is periodically collected, including battery temperature, phase change liquid inlet temperature, phase change liquid outlet temperature, phase change liquid flow rate, electrolyte flow rate, electrolysis voltage, hydrogen production rate, high-pressure hydrogen tank pressure, high-pressure hydrogen tank temperature, short-term hydrogen storage zone temperature, short-term hydrogen storage zone hydrogen concentration, and nitrogen protection layer pressure. Through communication link layer optimization and master clock synchronization mechanisms, the sampling time of the liquid-cooled hydrogen storage data is unified, resolving the data update asynchrony problem caused by measurement frequency differences and protocol transmission delays. This ensures that the time alignment accuracy of the liquid-cooled hydrogen storage data within the same sampling period meets the actual needs of thermal management control and hydrogen storage protection response. During synchronization, the master device broadcasts a reference time and controls the start of synchronous sampling on the slave devices, achieving consistent alignment of timestamps for all data fields throughout the entire link. An adaptive suppression algorithm based on the rate of change of adjacent data is used to dynamically suppress excessively rapid jumps in liquid-cooled hydrogen storage data, eliminating short-cycle physical unsteady-state interference. Specifically, for the jump trends of battery temperature and phase change fluid flow rate, a rate of change threshold is set and a local sliding window smoothing mechanism is introduced. This avoids over-smoothing of real thermal disturbances while enhancing the robustness of disturbance identification and preventing acquisition errors from interfering with subsequent state assessments. A multivariate anomaly detection method based on the isolated forest algorithm is used to remove abnormal data caused by local faults, signal drift, and control misalignment in the liquid-cooled hydrogen storage data, improving the coverage and interpretability of anomaly identification. During anomaly identification, a joint discrimination space is constructed based on the grouping characteristics of the liquid-cooled hydrogen storage data, and the sparsity characteristics of various anomalies in the data distribution are used for screening, effectively identifying and removing complex anomaly samples that are difficult to detect from a univariate perspective. Furthermore, by employing interval scaling and distribution normalization methods, the dimensionality of liquid-cooled hydrogen storage data is unified and normalized. During the normalization process, a stable interval and skewness tolerance are determined for each type of liquid-cooled hydrogen storage data based on the statistical characteristics within historical sliding windows. A joint processing strategy of minimum-maximum scaling and Z-score normalization is adopted, ensuring the comparability of physical variables with different dimensions and scales within the same standard space. This processing effectively improves the stability and adaptability of liquid-cooled hydrogen storage data in subsequent model analysis, state identification, and response strategy generation, ensuring the accuracy and practicality of the control algorithm.

[0034] In this implementation plan, a standardized preprocessing procedure for liquid-cooled hydrogen storage data is constructed to ensure that battery temperature, phase change liquid inlet temperature, phase change liquid outlet temperature, phase change liquid flow rate, electrolyte flow rate, electrolysis voltage, hydrogen production rate, high-pressure hydrogen tank pressure, high-pressure hydrogen tank temperature, short-term hydrogen storage zone temperature, short-term hydrogen storage zone hydrogen concentration, and nitrogen protection layer pressure from different sources have a unified time reference and stable physical scale within the acquisition period. An adaptive suppression algorithm is used to suppress unsteady-state interference, and a multivariate anomaly detection method is used to remove composite anomaly samples, significantly improving the accuracy and reliability of the liquid-cooled hydrogen storage data. Furthermore, interval scaling and distribution normalization strategies are employed to achieve dimensional unification and normalization, giving the preprocessed liquid-cooled hydrogen storage data good input characteristics and model adaptability. This effectively supports subsequent energy storage state identification and cooling strategy generation, enhancing the robustness and practicality of the entire safety control process.

[0035] Specifically, based on the pre-processed liquid-cooled hydrogen storage data, the specific steps for assessing the current operating status are as follows: Extract the pre-processed liquid-cooled hydrogen storage data; calculate the difference between the phase change liquid inlet temperature and the phase change liquid outlet temperature to obtain the phase change liquid inlet and outlet temperature difference, which is used to characterize the transient heat dissipation capacity change of the liquid cooling system; divide the battery temperature by the battery's safe upper limit temperature to obtain the battery temperature rise percentage, reflecting the proximity of the cell thermal runaway trend to the current operating stage; multiply the high-pressure hydrogen tank pressure by the short-term hydrogen concentration, then divide by the high-pressure hydrogen tank's design rated pressure, and take the square root of the comparison result to obtain the hydrogen pressure-concentration coupling factor; multiply the battery temperature rise percentage by the hydrogen pressure-concentration coupling factor to obtain the hydrogen pressure-concentration risk term, used to quantify the local risks that may be caused by the linkage between gas pressure and hydrogen storage distribution; divide the hydrogen production rate by the electrolyte flow rate... The value is squared to obtain the hydrogen production load per unit flow rate, which characterizes the hydrogen production load intensity carried by a unit electrolyte throughput. The absolute value of the phase change liquid inlet and outlet temperature difference is divided by the phase change liquid reference temperature difference and then added to obtain the cooling attenuation coefficient, which is used to dynamically adjust the coupling efficiency between the hydrogen production heat source and the cooling medium. The hydrogen production load per unit flow rate is divided by the cooling attenuation coefficient to obtain the hydrogen production heat dissipation balance term, which characterizes whether the current hydrogen production heat release has been effectively absorbed by the cooling system. The first time derivative of the hydrogen concentration in the short-term hydrogen storage area is divided by the minimum term, then added to, and the natural logarithm is taken to obtain the concentration change response term, which is used to sensitively reflect the dynamic amplitude of hydrogen concentration fluctuations within the short-term hydrogen storage area. The minimum term is a non-zero minimum positive number, which is used to avoid numerical instability caused by the denominator being too small or approaching zero in division, logarithm, and other calculations. The hydrogen concentration risk term, the hydrogen production heat dissipation balance term, and the concentration change response term are added together to obtain the energy storage status assessment value, which serves as a quantitative indicator for judging the overall operational safety status of the liquid-cooled hydrogen storage system.

[0036] The specific formula for calculating the energy storage status assessment value is as follows:

[0037] ;

[0038] In the formula, This represents the energy storage status assessment value. Indicates battery temperature. Indicates the upper limit of battery safety temperature. Indicates the pressure of the high-pressure hydrogen tank. This indicates the rated pressure of the high-pressure hydrogen tank. This indicates the hydrogen concentration in the short-term hydrogen storage area. Indicates the hydrogen production rate. Indicates electrolyte flow rate. This indicates the temperature difference between the inlet and outlet of the phase change liquid. Indicates the reference temperature difference of the phase change fluid. Indicates a minus term.

[0039] In this implementation plan, by constructing a multi-variable fusion index that includes battery temperature rise ratio, hydrogen concentration risk term, unit flow hydrogen production load, cooling attenuation coefficient, hydrogen production heat dissipation balance term, and concentration change response term, it can accurately characterize the coordinated evolution trend of thermal, electrical, and gaseous multi-physics fields of the liquid-cooled hydrogen storage system of the energy storage power station under different operating cycles. Compared with the judgment method that only relies on a single temperature value, this method, while maintaining the sensitivity to core safety characteristics such as hydrogen production load intensity, cooling performance degradation degree, and short-term gas disturbance amplitude in the hydrogen storage zone, systematically improves the quantitative expression ability of the energy storage status assessment value for nonlinear abnormal states, provides a high-precision input basis for subsequent linkage control strategies, and thus realizes early identification, trend judgment, and hierarchical control of the operating status.

[0040] Specifically, the steps for determining the current operating status are as follows: The energy storage status assessment value and the status threshold are compared in real time. When the energy storage status assessment value is greater than the status threshold, it is determined to be in normal operating condition. At this time, fluctuations in various physical quantities are within acceptable ranges, and thermal management and hydrogen storage functions are stable and coordinated. The controller does not perform any processing, but only continues to perform data acquisition and status tracking. When the energy storage status assessment value is less than or equal to the status threshold, it is determined to be in an abnormal operating condition, indicating potential risks such as insufficient temperature control, hydrogen production thermal imbalance, or short-term deviation of the pressure gradient in the hydrogen storage zone. The controller immediately issues a level one alarm and simultaneously extracts the liquid-cooled hydrogen storage data for the current cycle. A thermal risk assessment algorithm based on multivariate nonlinear weighting and time derivative response fusion is used to obtain the liquid-cooled thermal risk assessment value, which serves as a key basis for subsequent graded linkage of cooling strategies.

[0041] In this implementation scheme, by setting state thresholds and continuously comparing energy storage state assessment values, accurate distinction can be achieved between normal operation and abnormal operation states. In abnormal operation states, a liquid-cooled thermal risk assessment based on liquid-cooled hydrogen storage data is simultaneously performed, ensuring that the controller issues alarms and responds in the early stages of risk. This method achieves tight coupling between operation state identification and cooling strategy linkage, improving the operational safety of liquid-cooled hydrogen storage, the timeliness of thermal management response, and the reliability of short-term hydrogen storage zone protection.

[0042] Specifically, the steps for obtaining the liquid cooling thermal risk assessment value are as follows: Squaring the first-order time derivative of the battery temperature within the current sampling period yields the squared term of the battery temperature rise rate, used to characterize the changing trend of the battery's thermal rise intensity per unit time; dividing the squared term of the temperature rise rate by the sum of the phase change fluid flow rate and a constant, yields the temperature rise risk coefficient, used to reflect the degree of thermal imbalance in battery temperature rise under the current phase change fluid flow conditions; adding one to the absolute value of the temperature difference between the phase change fluid inlet and outlet, taking the reciprocal, and then raising the exponent to the base of the natural logarithm e, yields the cooling temperature difference decay index, used to dynamically measure the degree of decay of the effectiveness of the cooling channel's heat transfer efficiency as the temperature difference fluctuates; calculating the absolute value of the second-order time derivative of the battery temperature and adding one, yields the temperature rise trend response term, used to measure the influence of changes in the battery temperature rise acceleration on the dynamic evolution trend of thermal risk; multiplying the temperature rise risk coefficient, the cooling temperature difference decay index, and the temperature rise trend response term sequentially, yields the liquid cooling thermal risk assessment value, used to characterize the dynamic risk level between the current cooling capacity and the heat load under abnormal operating conditions.

[0043] The specific formula for calculating the liquid cooling thermal risk assessment value is as follows:

[0044] ;

[0045] In the formula, This indicates the liquid cooling thermal risk assessment value. Indicates battery temperature. Indicates the flow rate of the phase change fluid. This indicates the temperature difference between the inlet and outlet of the phase change fluid.

[0046] In this embodiment, Table 1 is a data table of liquid cooling thermal risk assessment values, listing the key variables and liquid cooling thermal risk assessment values ​​for five sampling periods. The key variables used include: battery temperature, phase change fluid flow rate, and phase change fluid inlet and outlet temperature difference. The specific data are as follows: In sampling period 1, the battery temperature was 69.9°C, the phase change fluid flow rate was 8.5 liters per second, the inlet and outlet temperature difference was 4.2°C, and the corresponding liquid cooling thermal risk assessment value was 0.190; in sampling period 2, the battery temperature was 69.3°C, the phase change fluid flow rate was 8.2 liters per second, the inlet and outlet temperature difference was 3.7°C, and the corresponding liquid cooling thermal risk assessment value was 0.222; in sampling period 3, the battery temperature was 68.5°C, the phase change fluid flow rate was 8.0 liters per second, the inlet and outlet temperature difference was 4.0°C, and the corresponding liquid cooling thermal risk assessment value was 0.250; in sampling period 4, the battery temperature was 67.8°C, the phase change fluid flow rate was 7.5 liters per second, the inlet and outlet temperature difference was 3.5°C, and the corresponding liquid cooling thermal risk assessment value was 0.315; in sampling period 5, the battery temperature was 67.0°C, the phase change fluid flow rate was 7.0 liters per second, the inlet and outlet temperature difference was 3.2°C, and the corresponding liquid cooling thermal risk assessment value was 0.435.

[0047] Table 1. Data Table of Liquid Cooling Thermal Risk Assessment Values

[0048]

[0049] like Figure 3 The figure shows the liquid cooling thermal risk assessment values ​​and risk level determination results for five sampling periods, used to identify the thermal risk classification status of energy storage power stations under different operating conditions. The figure uses a color bar chart to represent the liquid cooling thermal risk assessment value S for each sampling period, where green represents Level 1 risk, blue represents Level 2 risk, and red represents Level 3 risk, visually clearly distinguishing the risk level changes in each period. Two dashed threshold lines are set in the figure as references for risk level division: the orange dashed line represents the Level 1 risk threshold S1, and the purple dashed line represents the Level 2 risk threshold S2. As can be seen from the figure, the liquid cooling thermal risk assessment value for sampling period 1 is 0.190, lower than S1, corresponding to Level 1 risk; the assessment values ​​for sampling periods 2 and 3 are 0.222 and 0.250 respectively, between S1 and S2, corresponding to Level 2 risk; the assessment values ​​for sampling periods 4 and 5 are 0.315 and 0.435 respectively, higher than S2, corresponding to Level 3 risk. Figure 3 It effectively reflects the dynamic evolution of risk levels under different sampling periods, providing intuitive data support for multi-level linkage cooling control and safety strategy optimization.

[0050] In this implementation scheme, a liquid-cooled thermal risk assessment value is constructed based on battery temperature, phase change fluid flow rate, and the temperature difference between the inlet and outlet of the phase change fluid, enabling real-time quantitative identification of thermal runaway risks. Specifically, the square term of the battery temperature rise rate reflects the change in heat source intensity; the temperature rise risk coefficient, combined with cooling capacity, dynamically reflects the risk of insufficient cooling; the cooling temperature difference decay index characterizes the heat transfer decay trend; and the temperature rise trend response term reflects the trend of thermal evolution rate changes. Multiplying and fusing multiple dynamic response factors effectively enhances the accuracy of identifying potential thermal hazards in liquid-cooled hydrogen storage data. Compared to traditional static threshold triggering mechanisms, this method exhibits higher risk sensitivity and response foresight under dynamic fluctuations in thermal management status, providing quantifiable real-time risk data for the subsequent graded and coordinated execution of cooling strategies.

[0051] Specifically, the steps for classifying risk levels and generating cooling strategies based on real-time liquid cooling thermal risk assessment values, and for the execution unit to execute cooling commands in stages, are as follows: Extract the real-time liquid cooling thermal risk assessment value S within the current sampling period, compare it with the multi-level risk thresholds S1 and S2, determine the thermal risk level of the liquid-cooled hydrogen storage operation based on the comparison results, and simultaneously generate a matching cooling strategy. Specifically, when the real-time liquid cooling thermal risk assessment value S is less than or equal to the first-level risk threshold S1, it is determined to be at the first-level risk level, indicating that the system thermal disturbance is in a low-level stable state. The controller issues a command to shorten the sampling period, improve the time resolution of state tracking, and maintain a high-frequency monitoring mode to ensure proactive response. When the real-time liquid cooling thermal risk assessment value S is greater than the first-level risk threshold S1 and less than the second-level risk threshold S2, it is determined to be at the second-level risk level, indicating that the liquid-cooled hydrogen storage state has experienced a certain thermal deviation but has not yet become unstable. The controller issues an acceleration control command to the phase change liquid circulation pump 10 to dynamically increase the phase change liquid level. The flow rate is adjusted to enhance the heat exchange capacity of the cooling circuit and simultaneously modulate the hydrogen production rate to mitigate the heat source intensity of the electrolysis reaction, achieving bidirectional regulation of heat at the source and cooling at the end. When the real-time liquid cooling thermal risk assessment value S is greater than or equal to the secondary risk threshold S2, it is determined to be at the tertiary risk level, and the system enters a high-risk operating state. The controller immediately activates the fluorinated liquid auxiliary cooling circuit, adding an extra heat channel to share the burden by increasing the evaporation and condensation paths of the fluorinated liquid, and simultaneously activates the cryogenic emergency device to form a redundant cooling capacity guarantee. At the same time, the electrolysis voltage and hydrogen production rate are forcibly reduced to significantly suppress the heat source growth rate and power input level. Among them, the cryogenic emergency device refers to the low-temperature cooling equipment activated under the tertiary risk level, which introduces a cryogenic working fluid to quickly absorb heat and cool down in order to deal with the risk of local overheating. The cooling strategies corresponding to all risk levels are received and precisely executed by the execution unit according to a hierarchical priority mechanism, constructing a multi-level linkage thermal control and disposal link.

[0052] This implementation plan establishes a tiered cooling strategy system encompassing monitoring, regulation, and emergency response by introducing a multi-level risk assessment mechanism based on liquid cooling thermal risk assessment values. The liquid cooling thermal risk assessment value serves as a comprehensive indicator dynamically reflecting the temperature rise trend of battery 11, changes in cooling capacity, and potential thermal runaway, providing a quantitative basis for risk level classification. The phase change liquid circulation pump 10 speed-up control, combined reduction of electrolysis voltage and hydrogen production rate, and the fluorinated liquid auxiliary cooling circuit and cryogenic emergency device respond in a tiered manner, constructing a full-spectrum cooling regulation pathway covering mild thermal disturbances to severe thermal imbalances. Compared to traditional single-level heat dissipation control methods based on static temperature thresholds, this method achieves dynamic identification and refined response to the thermal safety status of liquid-cooled hydrogen storage, effectively improving the adaptability, linkage, and reliability of thermal control strategies, and providing crucial support for the stable operation of energy storage power stations in multiple scenarios.

[0053] Specifically, the steps for evaluating the heat dissipation capacity of the cooling strategy after command execution are as follows: Extract liquid-cooled hydrogen storage data within the Nth sampling period after command execution. Divide the high-pressure hydrogen tank pressure by the rated pressure of the high-pressure hydrogen tank, subtract one, and take the absolute value. Then, add one to the absolute value and take the natural logarithm to obtain the high-pressure pressure deviation coefficient, which characterizes the degree of recovery of the hydrogen storage pressure in the system after cooling. Divide the high-pressure hydrogen tank temperature by the short-term hydrogen storage zone temperature plus one to obtain the temperature ratio between the two temperature zones. Squaring the ratio yields the temperature rise risk factor, used to characterize the thermal inertia of hydrogen storage and the degree of local thermal accumulation. Multiply the high-pressure deviation coefficient by the square of the temperature rise risk factor, and further multiply by the liquid-cooled thermal risk assessment value to obtain the cooling pressure-thermal coupling term, reflecting the response strength of the cooling strategy to the coordinated control of the pressure and thermal fields. Calculate the absolute value of the first-order time derivative of the hydrogen concentration in the short-term hydrogen storage zone and cube the absolute value to obtain the concentration change response term, used to evaluate the concentration fluctuation amplitude and gas diffusion behavior of hydrogen after cooling execution. Finally, the cooling pressure thermal coupling term and the concentration change response term are added together, and the result is divided by the sum of the nitrogen protection layer pressure and the minimum term to obtain the residual evaluation value of the cooling response. This value serves as a criterion for the actual effectiveness of the current cooling command, providing direct support for subsequent protection decisions and strategy optimization.

[0054] The specific formula for calculating the residual evaluation value of the cooling response is as follows:

[0055] ;

[0056] In the formula, This represents the residual evaluation value of the cooling response. This indicates the liquid cooling thermal risk assessment value. Indicates the pressure of the high-pressure hydrogen tank. This indicates the rated pressure of the high-pressure hydrogen tank. Indicates the temperature of the high-pressure hydrogen tank. This indicates the temperature of the short-term hydrogen storage zone. This indicates the hydrogen concentration in the short-term hydrogen storage area. Indicates the pressure of the nitrogen protective layer. Indicates a minus term.

[0057] In this implementation plan, a quantitative assessment of the actual heat dissipation capacity of the cooling strategy is achieved by constructing a residual cooling response evaluation value. This residual cooling response evaluation value comprehensively reflects the thermo-pressure linkage regulation effect after command execution and the short-term gas state change trend in the hydrogen storage zone 5, accurately identifying the risk of insufficient cooling under dynamic operating conditions. Compared to single-variable monitoring methods, this multi-factor fusion criterion has higher thermal response sensitivity and heat dissipation failure early warning capability, significantly enhancing the reliability of the closed-loop evaluation of the cooling strategy driven by liquid-cooled hydrogen storage data and the accuracy of protection measure triggering.

[0058] Specifically, the steps for determining whether to trigger the protection measures for short-term hydrogen storage zone 5 are as follows: Real-time comparison of the residual assessment value of the cooling response with the residual threshold. If the current residual assessment value of the cooling response is less than or equal to the residual threshold, it indicates that the current cooling strategy has effectively suppressed the evolution of thermal risk, and cooling is deemed sufficient. The controller maintains the existing cooling strategy and continues to track the thermal stability change trend of the liquid-cooled hydrogen storage data. If the residual assessment value of the cooling response is greater than the residual threshold, it indicates that there is a thermal-pressure imbalance and poor heat dissipation, and cooling is deemed insufficient. The controller immediately triggers the protection measures for short-term hydrogen storage zone 5: increasing the pressure of the nitrogen protective layer to enhance the outer insulation and isolation capabilities, opening the ventilation and exhaust device of short-term hydrogen storage zone 5 to quickly reduce the concentration of combustible gases, and gradually closing the output valves of the high-pressure hydrogen tank to control the hydrogen release path, thereby achieving active defensive protection for short-term hydrogen storage zone 5. Specifically, the step-by-step closure of the high-pressure hydrogen tank's output valves includes: first, controlling the primary electrically controlled valve on the main hydrogen pipeline to enter flow-limiting mode to reduce the instantaneous release rate; then, sequentially executing the zonal valve closure commands for each branch hydrogen passage, prioritizing the cutting off of channels to non-real-time hydrogen supply demand and end-use hydrogen channels that are not currently in operation; and finally, closing the main hydrogen supply channel, forming a progressive gas release on / off management process to prevent secondary risks caused by sudden pressure drops or backflow, thereby ensuring the isolation safety and controllable release of the short-term hydrogen storage area 5.

[0059] In this implementation plan, by comparing the residual assessment value and the residual threshold of the cooling response in real time, the actual heat dissipation effect after the cooling strategy is implemented can be accurately identified. When the residual assessment value of the cooling response exceeds the residual threshold, the short-term hydrogen storage zone 5 protection measures are triggered in a timely manner. These measures include increasing the pressure of the nitrogen protection layer, opening the ventilation and exhaust device of the short-term hydrogen storage zone 5, and gradually closing the high-pressure hydrogen tank output valve. This enables the construction of multiple physical isolation mechanisms before the system's thermal state continues to deteriorate, thereby achieving rapid intervention and graded mitigation of potential thermo-pressure offset risks in the liquid-cooled hydrogen storage system. This mechanism significantly improves the cooling compensation capability and hydrogen storage protection accuracy of the energy storage power station under complex thermal conditions, laying a real-time and reliable thermal management foundation for subsequent safe closed-loop control.

[0060] Specifically, after the short-term hydrogen storage zone 5 protection measures are implemented, the residual assessment value of the cooling response and the energy storage status assessment value are reviewed. If both meet the safety threshold conditions, the protection measures and alarms are lifted, and the collected data during the abnormal period is archived. The specific steps to achieve a closed-loop cooling strategy are as follows: After the short-term hydrogen storage zone 5 protection measures are implemented, the liquid-cooled hydrogen storage data within the Mth sampling period is extracted, and the residual assessment value of the cooling response is recalculated to ensure the effectiveness and accuracy of the assessment indicators under the latest operating conditions. If the residual assessment value of the cooling response is still greater than the residual threshold, the controller will automatically limit the hydrogen production rate and discharge power output, construct a heat source input constraint boundary, and report to the superior group. The system sends alarm information to ensure cross-platform visibility of thermal risks and event linkage response. If the residual assessment value of the cooling response is less than or equal to the residual threshold, the controller initiates a phased removal of the short-term hydrogen storage zone 5 protection measures and recalculates the energy storage status assessment value based on real-time liquid-cooled hydrogen storage data. When the recalculated energy storage status assessment value is greater than the status threshold, the first-level alarm is lifted, and the normal operating condition is restored. At the same time, all liquid-cooled hydrogen storage data, electrical control command records, cooling strategy execution logs, and historical assessment value curves collected during the abnormal period are automatically archived to the local safety database and remote monitoring platform, forming a complete closed-loop cooling control link and operational traceability basis.

[0061] In this implementation plan, a closed-loop control mechanism for the cooling strategy, from abnormal response to normal recovery, is achieved by jointly verifying the residual cooling response assessment value and the energy storage status assessment value after the short-term hydrogen storage zone 5 protection measures are activated. This method dynamically assesses the residual cooling response assessment value while simultaneously integrating the real-time energy storage status assessment value for dual determination. When both assessment values ​​meet their respective safety threshold conditions, the orderly deactivation of the short-term hydrogen storage zone 5 protection measures and the intelligent elimination of the first-level alarm are realized. Furthermore, all liquid-cooled hydrogen storage data and control operation logs collected during the abnormal phase are automatically archived, thereby significantly improving the controllability of the closed-loop management of the cooling strategy, the traceability of abnormal handling, and the scientific rigor of multi-variable recovery determination.

[0062] like Figure 2As shown, the second aspect of this invention provides a multi-level linkage safety control system for phase change liquid-cooled hydrogen storage in an energy storage power station, comprising: a data acquisition and preprocessing module, a state risk assessment module, a linkage control execution module, and a safety closed-loop recovery module. The data acquisition and preprocessing module is used to periodically acquire liquid-cooled hydrogen storage data and perform time synchronization, abnormal data removal, standardization, and normalization processing on the liquid-cooled hydrogen storage data to obtain preprocessed liquid-cooled hydrogen storage data. The state risk assessment module is used to assess and determine the current operating state based on the preprocessed liquid-cooled hydrogen storage data. When an operating abnormality occurs, the controller issues a warning. A Level 1 alarm is triggered and a risk level assessment is performed to obtain the liquid cooling thermal risk assessment value. The linkage control execution module is used to classify the risk level based on the real-time liquid cooling thermal risk assessment value and generate a cooling strategy. The execution unit executes the cooling command in stages. After the command is executed, the heat dissipation capacity of the cooling strategy is evaluated to determine whether the short-term hydrogen storage area 5 protection measures are triggered. The safety closed-loop recovery module is used to review the residual assessment value of the cooling response and the energy storage status assessment value after the short-term hydrogen storage area 5 protection measures are responded to. When both meet the safety threshold conditions, the protection measures and alarm are released, and the collected data during the abnormal period is archived to realize the cooling strategy closed loop.

[0063] like Figure 4As shown, the functional coupling relationship and module connection path of the phase change liquid-cooled hydrogen storage linkage control structure are illustrated. This structure covers three major functional modules: liquid-cooled battery thermal management, hydrogen energy storage zone control, and emergency cooling linkage, reflecting the system coupling and control characteristics in the liquid-cooled hydrogen storage scenario. Specifically, the battery chamber 1 houses a battery 11 and is equipped with a temperature sensor 12 for real-time monitoring of the battery 11's operating temperature. The battery chamber 1 is connected to the first heat exchange path through the first plate heat exchanger 2 to achieve primary heat transfer from the battery. The heat exchange path is further connected to the second plate heat exchanger 3, which connects the long-term hydrogen storage zone 4 and the short-term hydrogen storage zone 5, respectively, to bear hydrogen storage loads at different time scales. Among them, the short-term hydrogen storage zone 5 is a temporary hydrogen storage unit built based on a high-pressure hydrogen tank, used to temporarily store hydrogen produced by electrolysis, and features fast response speed and stable hydrogen release pressure. The long-term hydrogen storage zone 4 is suitable for large-capacity, low-frequency hydrogen storage, mainly undertaking periodic storage and release tasks, realizing time-dimensional decoupling of the hydrogen storage strategy. In this staged hydrogen storage structure, hydrogen is first generated through electrolysis and then purified and dried before being preferentially stored in the short-term hydrogen storage zone 5. When the short-term hydrogen storage zone 5 enters the load switching phase, redundant hydrogen is diverted to the long-term hydrogen storage zone 4 to buffer the system load. The emergency hydrogen storage zone 7 is a vacuum-insulated tank that is only activated in emergency situations such as cooling anomalies and failure of the main storage zone, and does not participate in the regular cooling strategy linkage. The heat exchanger 3 is also coupled to the fuel cell power generation module 6 to regulate the indirect impact of hydrogen storage temperature on power generation efficiency. During operation, if the liquid cooling thermal risk assessment value exceeds the secondary risk threshold, the controller will trigger the emergency path, start the phase change liquid circulation pump 10, guide the heat flow to the emergency plate heat exchanger 9, and cooperate with the power pump 8 to deliver the cooling medium to the emergency hydrogen storage zone 7, forming a rapid thermal response loop to suppress local overheating.

[0064] This implementation plan constructs a multi-level linkage safety control system for phase change liquid-cooled hydrogen storage power stations, comprising a data acquisition and preprocessing module, a state risk assessment module, a linkage control execution module, and a safety closed-loop recovery module. This system achieves full-link closed-loop management of liquid-cooled hydrogen storage data throughout the cooling control and hydrogen storage response processes. The system uses periodically collected data such as battery temperature, phase change liquid inlet temperature, phase change liquid outlet temperature, phase change liquid flow rate, electrolyte flow rate, electrolysis voltage, hydrogen production rate, high-pressure hydrogen tank pressure, high-pressure hydrogen tank temperature, short-term hydrogen storage zone temperature, short-term hydrogen storage zone hydrogen concentration, and nitrogen protective layer pressure as core data sources. Based on a preprocessing mechanism, it improves data quality and uses energy storage state assessment values ​​and liquid cooling thermal risk assessment values ​​as a basis for state identification, risk determination, and generation of tiered cooling strategies. After executing the cooling command, the system further evaluates the actual heat dissipation capacity and makes a closed-loop judgment on the safety status of the short-term hydrogen storage area by jointly verifying the residual evaluation value of the cooling response and the evaluation value of the energy storage status. This achieves refined linkage control of the entire process from risk identification and emergency response to recovery judgment, significantly improving the real-time performance, safety and intelligence level of the energy storage power station in the process of thermal management and hydrogen storage coordination.

[0065] It should be noted that, in this document, relational terms such as "first" and "second" are used only to distinguish one entity or operation from another, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Furthermore, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such process, method, article, or apparatus.

[0066] The preferred embodiments of the present invention disclosed above are merely illustrative of the invention. These preferred embodiments do not exhaustively describe all details, nor do they limit the invention to the specific implementations described. Clearly, many modifications and variations can be made based on the content of this specification. This specification selects and specifically describes these embodiments to better explain the principles and practical applications of the invention, thereby enabling those skilled in the art to better understand and utilize the invention. The invention is limited only by the claims and their full scope and equivalents.

Claims

1. A multi-stage linkage safety control method for a phase change liquid-cooled hydrogen storage of an energy storage power station, characterized in that, The method comprises the following steps: S1, periodically collecting liquid-cooled hydrogen storage data, and performing time synchronization, abnormal data elimination, standardization and normalization processing on the liquid-cooled hydrogen storage data to obtain pre-processed liquid-cooled hydrogen storage data; S2, based on the pre-processed liquid-cooled hydrogen storage data, evaluating and judging the current running state, when the running state is abnormal, the controller issues a first alarm and performs risk level evaluation to obtain a liquid-cooled heat risk evaluation value; The specific steps of evaluating the current running state based on the pre-processed liquid-cooled hydrogen storage data are as follows: extract the pre-processed liquid-cooled hydrogen storage data, calculate the difference between the phase change liquid inlet temperature and the phase change liquid outlet temperature to obtain the phase change liquid inlet and outlet temperature difference; divide the battery temperature by the battery safety upper limit temperature to obtain the battery temperature rise proportion; multiply the high-pressure hydrogen tank pressure and the short-time hydrogen storage area hydrogen concentration, then divide by the design rated pressure of the high-pressure hydrogen tank, and take the square root of the comparison value result to obtain the hydrogen pressure and concentration coupling factor; multiply the battery temperature rise proportion by the hydrogen pressure and concentration coupling factor to obtain the hydrogen pressure and concentration risk term; square the ratio of the hydrogen production rate to the electrolyte flow to obtain the unit flow hydrogen production load; divide the absolute value of the phase change liquid inlet and outlet temperature difference by the phase change liquid reference temperature difference and add one to obtain the cooling attenuation coefficient; divide the unit flow hydrogen production load by the cooling attenuation coefficient to obtain the hydrogen production heat dissipation balance term; divide the first-order time derivative of the short-time hydrogen storage area hydrogen concentration by a small term and add one, then take the natural logarithm to obtain the concentration change response term; add the hydrogen pressure and concentration risk term, the hydrogen production heat dissipation balance term and the concentration change response term to obtain the energy storage state evaluation value; S3, based on the real-time liquid-cooled heat risk evaluation value, dividing the risk level and generating a cooling strategy, executing the cooling instruction in units, and evaluating the cooling capacity of the cooling strategy after executing the instruction to determine whether to trigger the short-time hydrogen storage area (5) protection measure; S4, after the short-time hydrogen storage area (5) protection measure responds, review the cooling response residual evaluation value and the energy storage state evaluation value, and when both meet the safety threshold condition, remove the protection measure and alarm, and archive the collected data during the abnormal period to realize the cooling strategy closed loop.

2. The method of claim 1, wherein the method further comprises: The specific steps of periodically collecting liquid-cooled hydrogen storage data, and performing time synchronization, abnormal data elimination, standardization and normalization processing on the liquid-cooled hydrogen storage data to obtain pre-processed liquid-cooled hydrogen storage data are as follows: Set a fixed-width sliding time window as a sampling period to periodically collect liquid-cooled hydrogen storage data, which includes battery temperature, phase change liquid inlet temperature, phase change liquid outlet temperature, phase change liquid flow, electrolyte flow, electrolysis voltage, hydrogen production rate, high-pressure hydrogen tank pressure, high-pressure hydrogen tank temperature, short-time hydrogen storage area temperature, short-time hydrogen storage area hydrogen concentration and nitrogen protection layer pressure; The liquid-cooled hydrogen storage data is sampled and unified in time by optimizing the communication link level and the master clock synchronization mechanism; the adaptive wave suppression algorithm based on the adjacent data change rate limit is used to dynamically suppress the rapid jump in the liquid-cooled hydrogen storage data; the multivariate anomaly detection method based on the isolation forest algorithm is used to eliminate the abnormal data caused by local faults, signal drift and control imbalance in the liquid-cooled hydrogen storage data; and the interval scaling and distribution normalization method is further used to realize the dimension unification and normalization of the liquid-cooled hydrogen storage data.

3. The method of claim 1, wherein the method further comprises: The specific steps of judging the current running state are as follows: The energy storage state evaluation value and the state threshold value are compared in real time, when the energy storage state evaluation value is greater than the state threshold value, it is determined that the normal running state is normal, and no processing is performed; when the energy storage state evaluation value is less than or equal to the state threshold value, it is determined that the running abnormal state is abnormal, and the controller issues a first alarm, and the real-time liquid-cooled hydrogen storage data is extracted to perform thermal risk evaluation, and a liquid-cooled thermal risk evaluation value is obtained.

4. The phase change liquid cooling hydrogen storage multi-stage linkage safety control method of the energy storage power station according to claim 3, characterized in that: The specific steps of obtaining the liquid-cooled thermal risk evaluation value are as follows: The first-order time derivative of the battery temperature is squared to obtain a temperature rise speed square term; the temperature rise speed square term is divided by the sum of the phase change liquid flow and the constant one to obtain a temperature rise risk coefficient; the absolute value of the phase change liquid inlet and outlet temperature difference is taken, and one is added, and the reciprocal is taken, and the reciprocal is taken to the exponential power with the natural logarithm base e as the base to obtain a cooling temperature difference attenuation index; the absolute value of the second-order time derivative of the battery temperature is calculated, and one is added to obtain a temperature rise trend response term; the temperature rise risk coefficient, the cooling temperature difference attenuation index and the temperature rise trend response term are multiplied in turn to obtain the liquid-cooled thermal risk evaluation value.

5. The method of claim 4, wherein the method further comprises: The specific steps of the execution unit for dividing the risk level based on the real-time liquid-cooled thermal risk evaluation value and generating the cooling strategy and executing the cooling instruction in stages are as follows: The real-time liquid-cooled thermal risk evaluation value S is extracted, compared with the multi-level risk threshold values S1 and S2, the risk level is determined, and the corresponding cooling strategy is generated: When S≤S1, it is determined that the first-level risk is normal, the sampling period is shortened, and the monitoring is continued; When S1<S<S2, it is determined that the second-level risk is normal, the controller issues a speed-up instruction to the phase change liquid circulating pump (10), increases the phase change flow rate, and simultaneously reduces the hydrogen production rate; When S≥S2, it is determined that the third-level risk is normal, the controller starts the fluorinated liquid auxiliary cooling circuit, starts the deep cooling emergency device, and simultaneously forcibly reduces the electrolysis voltage and the hydrogen production rate; The execution unit receives and executes the corresponding cooling instruction.

6. The phase change liquid cooling hydrogen storage multi-stage linkage safety control method of energy storage power station according to claim 5, characterized in that: The specific steps of evaluating the cooling capacity of the cooling strategy after the instruction execution are as follows: The liquid-cooled hydrogen storage data in the Nth sampling period after the execution of the extraction instruction is combined with the real-time liquid-cooled thermal risk assessment value to evaluate the heat dissipation capacity of the cooling strategy: the high-pressure hydrogen tank pressure is divided by the rated pressure of the high-pressure hydrogen tank, the absolute value of the result after subtraction by one is taken, the natural logarithm of the result after addition by one is taken, and the high-pressure pressure deviation coefficient is obtained; the high-pressure hydrogen tank temperature is divided by the short-time hydrogen storage area temperature plus one, and the square of the comparison value is taken to obtain the temperature rise risk factor; the square of the high-pressure pressure deviation coefficient and the temperature rise risk factor is multiplied, and then multiplied by the liquid-cooled thermal risk assessment value to obtain the cooling pressure thermal coupling term; the absolute value of the first-order time derivative of the hydrogen concentration of the short-time hydrogen storage area is calculated and cubed to obtain the concentration change response term; the cooling pressure thermal coupling term and the concentration change response term are added and then divided by the pressure of the nitrogen protection layer plus the minimum term to obtain the cooling response residual evaluation value.

7. The method of claim 6, wherein the method further comprises: The specific steps of determining whether to trigger the short-time hydrogen storage area (5) protection measure are as follows: The cooling response residual evaluation value and the residual threshold value are compared in real time, and when the cooling response residual evaluation value is less than or equal to the residual threshold value, it is determined that the cooling is sufficient, and the existing cooling strategy is maintained; when the cooling response residual evaluation value is greater than the residual threshold value, it is determined that the cooling is insufficient, and the short-time hydrogen storage area (5) protection measure is triggered: the nitrogen protection layer pressure is increased, the short-time hydrogen storage area (5) ventilation and exhaust device is started, and the output valve of the high-pressure hydrogen tank is gradually closed.

8. The method of claim 7, wherein the method further comprises: After the short-time hydrogen storage area (5) protection measure is responded, the cooling response residual evaluation value and the energy storage state evaluation value are reviewed, and when both meet the safety threshold condition, the protection measure and the alarm are removed, and the collected data during the abnormal period is archived, and the specific steps of realizing the cooling strategy closed loop are as follows: After the short-time hydrogen storage area (5) protection measure is executed, the liquid-cooled hydrogen storage data in the Mth sampling period is extracted, and the cooling response residual evaluation value is recalculated; If the cooling response residual evaluation value is still greater than the residual threshold value, the hydrogen production and discharge operations are limited, and the alarm information is sent to the superior organization; If the cooling response residual evaluation value is less than or equal to the residual threshold value, the short-time hydrogen storage area (5) protection measure is gradually removed, the energy storage state evaluation value is recalculated based on the real-time liquid-cooled hydrogen storage data, and when the energy storage state evaluation value is greater than the state threshold value, the first alarm is removed, and the data and operation logs collected during the abnormal period are automatically archived.

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