Multi-port waste heat recovery hydrogen storage and supply control system and method

Abstract

The application relates to a multi-end waste heat recovery hydrogen storage and supply control system and method. The system comprises the following steps: boosting and transporting hydrogen, generating inter-stage compression heat and motor waste heat in the boosting process; generating electric energy by consuming hydrogen, generating cell reaction heat, inverter waste heat and condensation latent heat in the power generation process; recovering the inter-stage compression heat, the motor waste heat, the cell reaction heat, the inverter waste heat and the condensation latent heat; obtaining real-time temperature of a heat storage conversion subsystem and a cooling signal of a hydrogen storage and supply subsystem, and controlling the heat storage conversion subsystem to switch between a refrigeration mode and a heat supply mode according to the real-time temperature and the cooling signal. The method can avoid direct waste of heat energy and improve energy utilization efficiency.

Description

Technical Field

[0001] This application relates to the field of integrated energy system management technology, and in particular to a hydrogen storage and supply control system and method for multi-terminal waste heat recovery. Background Technology

[0002] With the development of hydrogen energy utilization technology, hydrogen storage, transportation, and energy conversion have become key links in the hydrogen energy industry chain. In the construction and operation of hydrogen energy infrastructure, hydrogen storage and supply systems and fuel cell power generation systems are two core energy conversion units. Hydrogen storage and supply systems use high-pressure compressor units to pressurize hydrogen to increase storage density, a process that generates significant amounts of interstage compression heat and motor drive waste heat. Simultaneously, fuel cell systems also release stack reaction heat, power electronics conversion heat, and latent heat of condensation in the exhaust gas during the electrochemical reaction power generation process.

[0003] In traditional technologies, the interstage compression heat, motor drive waste heat, fuel cell reaction heat, power electronics conversion heat, and latent condensation heat in the exhaust gas are usually discharged directly using air-cooled radiators or cooling towers. Meanwhile, the compressor unit relies on an electrically driven vapor compression refrigeration unit for forced cooling. The control strategies of each subsystem are independent of each other, using simple threshold control or start-stop logic.

[0004] However, traditional technologies suffer from problems such as a large amount of heat energy being directly wasted, while electricity is consumed for cooling, resulting in unreasonable energy utilization and high operating costs. Summary of the Invention

[0005] Therefore, it is necessary to provide a hydrogen storage and supply control system and method with multi-terminal waste heat recovery to address the above-mentioned technical problems.

[0006] In a first aspect, this application provides a multi-terminal waste heat recovery hydrogen storage and supply control system, comprising:

[0007] The hydrogen storage and supply subsystem is used to pressurize or transport hydrogen, and generates interstage compression heat and motor waste heat during the pressurization process.

[0008] The fuel cell subsystem, connected to the hydrogen storage and supply subsystem, is used to consume hydrogen to generate electricity and generates heat from the fuel cell stack reaction, inverter waste heat, and latent heat of condensation during the power generation process.

[0009] The thermal storage and conversion subsystem is connected to the hydrogen storage and supply subsystem and the fuel cell subsystem, respectively, and is used to recover interstage compression heat, motor waste heat, stack reaction heat, inverter waste heat and condensation latent heat.

[0010] The station control system is connected to the hydrogen storage and supply subsystem, the fuel cell subsystem, and the thermal storage and conversion subsystem. It is used to obtain the real-time temperature of the thermal storage and conversion subsystem and the cooling signal of the hydrogen storage and supply subsystem, and to control the thermal storage and conversion subsystem to switch between cooling mode and heating mode based on the real-time temperature and cooling signal.

[0011] In one embodiment, the thermal energy storage conversion subsystem includes:

[0012] The integrated storage and supply water tank is connected to the hydrogen storage and supply subsystem and the fuel cell subsystem respectively. It is used to recover and store interstage compression heat, motor waste heat, stack reaction heat, inverter waste heat and condensation latent heat according to temperature data.

[0013] The refrigeration unit is connected to the integrated water storage and supply tank and the hydrogen storage and supply subsystem respectively. It is used to convert the heat energy in the integrated water storage and supply tank into cold energy in the refrigeration mode and deliver the cold energy to the hydrogen storage and supply subsystem.

[0014] The circulating pump set is installed between the integrated water storage and supply tank and the chiller to drive the flow of the medium between the integrated water storage and supply tank and the chiller.

[0015] In one embodiment, the aforementioned multi-terminal waste heat recovery hydrogen storage and supply control system further includes:

[0016] The fuel cell subsystem is connected to the top of the integrated water storage and supply tank via the first branch and the second branch, respectively.

[0017] The fuel cell subsystem is connected to the lower middle part of the integrated water storage and supply tank via a third branch.

[0018] The hydrogen storage and supply subsystem is connected to the lower middle part of the integrated storage and supply water tank via the fourth branch.

[0019] In one embodiment, the station control system includes:

[0020] The industrial computer is connected to the hydrogen storage and supply subsystem, the fuel cell subsystem, and the thermal storage and conversion subsystem respectively. It is used to perform day-ahead global planning and intraday real-time rolling scheduling, and to generate equipment start-up and shutdown status sequences and energy storage status reference trajectories.

[0021] The programmable logic controller (PLC) is connected to the industrial computer, hydrogen storage and supply subsystem, fuel cell subsystem, and thermal energy storage conversion subsystem, respectively. It is used to control the thermal energy storage conversion subsystem to switch between cooling mode and heating mode based on the equipment start-stop state sequence, energy storage state reference trajectory, real-time temperature and cooling signals.

[0022] Secondly, this application also provides a hydrogen storage and supply control method with multi-terminal waste heat recovery, including:

[0023] Hydrogen is pressurized or transported, and interstage compression heat and motor waste heat are generated during the pressurization process.

[0024] It consumes hydrogen to generate electricity, and generates heat from the fuel cell reaction, waste heat from the inverter, and latent heat of condensation during the power generation process;

[0025] It recovers interstage compression heat, motor waste heat, fuel cell stack reaction heat, inverter waste heat, and latent heat of condensation;

[0026] The system acquires the real-time temperature of the thermal energy storage and conversion subsystem and the cooling signal of the hydrogen storage and supply subsystem, and controls the thermal energy storage and conversion subsystem to switch between cooling mode and heating mode based on the real-time temperature and cooling signal.

[0027] In one embodiment, the thermal storage conversion subsystem is controlled to switch between cooling mode and heating mode based on real-time temperature and cooling signals, including:

[0028] When the real-time temperature and cooling signal meet the refrigeration conditions, the refrigeration mode is activated, and the heat energy in the integrated storage and supply water tank is converted into cold energy by the refrigeration unit in the hydrogen storage and supply control system and delivered to the compressor.

[0029] If the real-time temperature and cooling signal do not meet the refrigeration requirements, the pipeline to the chiller is cut off, and the heat energy is delivered to the user.

[0030] In one embodiment, the above-mentioned multi-terminal waste heat recovery hydrogen storage and supply control method further includes:

[0031] Based on a pre-trained prediction model, mixed integer linear programming is used to solve the equipment start-stop state sequence and energy storage state reference trajectory of each subsystem in the hydrogen storage and supply control system in the future time period, so as to obtain the equipment start-stop state sequence and energy storage state reference trajectory.

[0032] Based on the equipment start-up and shutdown state sequence and the energy storage state reference trajectory, a model predictive controller is used to adjust the compressor speed and regulating valve opening of the hydrogen storage and supply control system in real time.

[0033] In one embodiment, the constraints of the solution process include at least one of the following:

[0034] The change in the internal hydrogen mass of the hydrogen storage and supply control system is equal to the difference between the input flow rate and the output flow rate.

[0035] The hydrogen consumption rate and the output electrical power of the hydrogen storage and supply control system satisfy a nonlinear mapping relationship, which is obtained from the polarization curve data of the fuel cell.

[0036] The rate of change of internal heat in the hydrogen storage and supply control system is equal to the input power of the heat source minus the output power of the heat load minus the heat dissipation loss.

[0037] In one embodiment, the start-up and shutdown state sequences of each subsystem in the hydrogen storage and supply control system over a future time period and the energy storage state reference trajectory are solved to obtain the equipment start-up and shutdown state sequences and the energy storage state reference trajectory, including:

[0038] Using power balance constraints, energy conservation constraints, and equipment physical limitations as the constraint space, the objective function is solved to obtain the solution results; the objective function aims to minimize the overall cost of the hydrogen storage and supply control system.

[0039] The solution results are parsed into reference trajectory information and sent to the model predictive controller; the reference trajectory information includes the equipment start-up and shutdown state sequence and the energy storage state reference trajectory.

[0040] In one embodiment, a model predictive controller is used to adjust the hydrogen storage and supply control system in real time, including:

[0041] The real-time operating status of the hydrogen storage and supply control system is obtained within the current control cycle, using a preset time period as the control cycle.

[0042] Using the equipment start-up and shutdown state sequence and the energy storage state reference trajectory as reference targets, the optimization function in the finite time domain is solved to obtain the compressor speed adjustment and regulating valve opening adjustment of the hydrogen storage and supply control system.

[0043] Based on the adjustment amount, the compressor speed and regulating valve opening of the hydrogen storage and supply control system are adjusted.

[0044] Thirdly, this application also provides a computer device, including a memory and a processor, wherein the memory stores a computer program, and the processor executes the computer program to perform the following steps:

[0045] Hydrogen is pressurized or transported, and interstage compression heat and motor waste heat are generated during the pressurization process.

[0046] It consumes hydrogen to generate electricity, and generates heat from the fuel cell reaction, waste heat from the inverter, and latent heat of condensation during the power generation process;

[0047] It recovers interstage compression heat, motor waste heat, fuel cell stack reaction heat, inverter waste heat, and latent heat of condensation;

[0048] The system acquires the real-time temperature of the thermal energy storage and conversion subsystem and the cooling signal of the hydrogen storage and supply subsystem, and controls the thermal energy storage and conversion subsystem to switch between cooling mode and heating mode based on the real-time temperature and cooling signal.

[0049] Fourthly, this application also provides a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, performs the following steps:

[0050] Hydrogen is pressurized or transported, and interstage compression heat and motor waste heat are generated during the pressurization process.

[0051] It consumes hydrogen to generate electricity, and generates heat from the fuel cell reaction, waste heat from the inverter, and latent heat of condensation during the power generation process;

[0052] It recovers interstage compression heat, motor waste heat, fuel cell stack reaction heat, inverter waste heat, and latent heat of condensation;

[0053] The system acquires the real-time temperature of the thermal energy storage and conversion subsystem and the cooling signal of the hydrogen storage and supply subsystem, and controls the thermal energy storage and conversion subsystem to switch between cooling mode and heating mode based on the real-time temperature and cooling signal.

[0054] Fifthly, this application also provides a computer program product, including a computer program that, when executed by a processor, performs the following steps:

[0055] Hydrogen is pressurized or transported, and interstage compression heat and motor waste heat are generated during the pressurization process.

[0056] It consumes hydrogen to generate electricity, and generates heat from the fuel cell reaction, waste heat from the inverter, and latent heat of condensation during the power generation process;

[0057] It recovers interstage compression heat, motor waste heat, fuel cell stack reaction heat, inverter waste heat, and latent heat of condensation;

[0058] The system acquires the real-time temperature of the thermal energy storage and conversion subsystem and the cooling signal of the hydrogen storage and supply subsystem, and controls the thermal energy storage and conversion subsystem to switch between cooling mode and heating mode based on the real-time temperature and cooling signal.

[0059] The aforementioned multi-terminal waste heat recovery hydrogen storage and supply control system and method involves pressurizing or transporting hydrogen, generating interstage compression heat and motor waste heat during pressurization; consuming hydrogen to generate electricity, generating fuel cell reaction heat, inverter waste heat, and latent heat of condensation during power generation; recovering interstage compression heat, motor waste heat, fuel cell reaction heat, inverter waste heat, and latent heat of condensation; acquiring the real-time temperature of the thermal energy conversion subsystem and the cooling signal of the hydrogen storage and supply subsystem; and controlling the thermal energy conversion subsystem to switch between cooling and heating modes based on the real-time temperature and cooling signal. This hydrogen storage and supply control system simultaneously recovers multiple types of waste heat generated during hydrogen pressurization and power generation, avoiding direct waste of heat energy and improving energy utilization efficiency; directly using the recovered heat energy for heating or driving cooling reduces dependence on external electric cooling equipment and lowers the system's power load; and automatically switching between cooling and heating modes based on real-time temperature and cooling signal enables on-demand distribution of heat energy, thereby enhancing the system's adaptability to different operating conditions and reducing overall operating costs. Attached Figure Description

[0060] To more clearly illustrate the technical solutions in the embodiments of this application or related technologies, the drawings used in the description of the embodiments of this application or related technologies will be briefly introduced below. Obviously, the drawings described below are only some embodiments of this application. For those skilled in the art, other related drawings can be obtained based on these drawings without creative effort.

[0061] Figure 1 This is one of the structural block diagrams of a hydrogen storage and supply control system with multi-terminal waste heat recovery in one embodiment;

[0062] Figure 2 This is the second structural block diagram of a hydrogen storage and supply control system with multi-terminal waste heat recovery in one embodiment;

[0063] Figure 3 This is the third structural block diagram of a hydrogen storage and supply control system with multi-terminal waste heat recovery in one embodiment;

[0064] Figure 4 This is one of the flowcharts illustrating a hydrogen storage and supply control method for multi-terminal waste heat recovery in one embodiment;

[0065] Figure 5 This is the second flowchart of a hydrogen storage and supply control method for multi-terminal waste heat recovery in one embodiment;

[0066] Figure 6 This is the third flowchart illustrating a hydrogen storage and supply control method for multi-terminal waste heat recovery in one embodiment.

[0067] Figure 7This is the fourth flowchart of a hydrogen storage and supply control method for multi-terminal waste heat recovery in one embodiment;

[0068] Figure 8 This is a schematic diagram illustrating the supply and demand balance of heat-driven refrigeration in one embodiment;

[0069] Figure 9 This is a schematic diagram of water tank temperature stratification in one embodiment;

[0070] Figure 10 This is a schematic diagram comparing the cumulative operating costs in one embodiment.

[0071] Explanation of key component designations:

[0072] 1. A hydrogen storage and supply control system with multi-terminal waste heat recovery;

[0073] 10. Hydrogen storage and supply subsystem; 20. Fuel cell subsystem; 30. Thermal energy storage and conversion subsystem; 40. Station control system; 50. User terminal;

[0074] 11. Hydrogen buffer tank; 12. Compressor unit; 13. Hydrogen storage cylinder group; 14. Hydrogen dispenser;

[0075] 21. Fuel cell stack; 22. Inverter; 211. Cathode tail exhaust treatment device;

[0076] 31. Integrated water storage and supply tank; 32. Refrigeration unit; 33. Circulating pump set;

[0077] 41. Industrial computer; 42. Programmable logic controller. Detailed Implementation

[0078] To make the objectives, technical solutions, and advantages of this application clearer, the following detailed description is provided in conjunction with the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are merely illustrative and not intended to limit the scope of this application.

[0079] It should be noted that the terms "first," "second," etc., used in this application can be used to describe various elements, but these elements are not limited by these terms. These terms are only used to distinguish the first element from the second element. The terms "comprising" and "having," and any variations thereof, used in this application, are intended to cover non-exclusive inclusion. The term "multiple" used in this application refers to two or more. The term "and / or" used in this application refers to one of the embodiments, or any combination of multiple embodiments.

[0080] With the development of hydrogen energy utilization technology, hydrogen storage, transportation, and energy conversion have become key links in the hydrogen energy industry chain. In the construction and operation of hydrogen energy infrastructure, hydrogen storage and supply systems and fuel cell power generation systems are two core energy conversion units. Hydrogen storage and supply systems use high-pressure compressor units to pressurize hydrogen to increase storage density, a process that generates significant amounts of interstage compression heat and motor drive waste heat. Simultaneously, fuel cell systems also release stack reaction heat, power electronics conversion heat, and latent heat of condensation in the exhaust gas during the electrochemical reaction power generation process.

[0081] In traditional technologies, the interstage compression heat, motor drive waste heat, fuel cell reaction heat, power electronics conversion heat, and latent condensation heat in the exhaust gas are usually discharged directly using air-cooled radiators or cooling towers. Meanwhile, the compressor unit relies on an electrically driven vapor compression refrigeration unit for forced cooling. The control strategies of each subsystem are independent of each other, using simple threshold control or start-stop logic.

[0082] However, traditional technologies suffer from problems such as a significant waste of thermal energy and the consumption of electrical energy for cooling, resulting in unreasonable energy utilization and high operating costs.

[0083] In view of the above-mentioned technical problems, this application provides a hydrogen storage and supply control system with multi-terminal waste heat recovery. The following embodiments will specifically describe the hydrogen storage and supply control system with multi-terminal waste heat recovery.

[0084] In one exemplary embodiment, such as Figure 1 As shown, a multi-terminal waste heat recovery hydrogen storage and supply control system 1 is provided. The multi-terminal waste heat recovery hydrogen storage and supply control system 1 includes a hydrogen storage and supply subsystem 10, a fuel cell subsystem 20, a heat storage and conversion subsystem 30, and a station control system 40.

[0085] The hydrogen storage and supply subsystem 10 is used to pressurize or transport hydrogen, generating interstage compression heat and motor waste heat during the pressurization process. Specifically, the hydrogen storage and supply subsystem 10 includes: a hydrogen buffer tank 11, a compressor unit 12, a hydrogen storage cylinder group 13, and a hydrogen dispenser 14. The hydrogen buffer tank 11 is connected to the inlet of the compressor unit 12. The outlet of the compressor unit 12 is connected to the hydrogen storage cylinder group 13. The hydrogen storage cylinder group 13 is connected to the hydrogen dispenser 14. The compressor unit 12 is equipped with an interstage cooler and an aftercooler. The cooling medium inlets of the interstage cooler and aftercooler are connected to the cold energy output end of the heat storage and conversion subsystem 30. The motor cooling circuit of the compressor unit 12 is connected to the waste heat recovery end of the heat storage and conversion subsystem 30.

[0086] The fuel cell subsystem 20, connected to the hydrogen storage and supply subsystem 10, is used to generate electricity by consuming hydrogen, and generates heat from the fuel cell stack reaction, inverter waste heat, and latent heat of condensation during the power generation process. Specifically, the fuel cell subsystem 20 includes a fuel cell stack 21 and an inverter 22. The fuel cell stack 21 is equipped with a stack cooling circuit and a cathode tail exhaust treatment device 211. The inverter 22 is equipped with a power device heat dissipation circuit. The stack cooling circuit, cathode tail exhaust treatment device 211, and power device heat dissipation circuit are connected to the waste heat recovery network of the thermal energy storage and conversion subsystem 30.

[0087] The thermal storage and conversion subsystem 30 is connected to the hydrogen storage and supply subsystem 10 and the fuel cell subsystem 20 respectively, and is used to recover interstage compression heat, motor waste heat, stack reaction heat, inverter waste heat and condensation latent heat.

[0088] The station control system 40 is communicatively connected to the hydrogen storage and supply subsystem 10, the fuel cell subsystem 20, and the thermal energy storage and conversion subsystem 30, respectively. It is used to acquire the real-time temperature of the thermal energy storage and conversion subsystem 30 and the cooling signal of the hydrogen storage and supply subsystem 10, and to control the switching between cooling and heating modes of the thermal energy storage and conversion subsystem 30 based on the real-time temperature and cooling signal. It is also used to control the start and stop of the compressor unit 12, adjust the speed of the circulating pump unit 33, and control the flow distribution from the integrated storage and supply water tank 31 to the chiller 32.

[0089] The physical structure of the multi-terminal waste heat recovery hydrogen storage and supply control system 1 in this application embodiment includes:

[0090] The main equipment of the hydrogen storage and supply subsystem 10 is located in the explosion-proof process area. The hydrogen buffer tank 11 is located at the inlet port, and its outlet is connected to the suction port of the compressor unit 12 via a high-strength austenitic stainless steel pipeline. The compressor unit 12 adopts a skid-mounted structure, integrating a multi-stage compression cylinder, drive motor, interstage cooler, aftercooler, and lubricating oil pump. The interstage cooler and aftercooler of the compressor unit 12 are shell-and-tube or plate-fin heat exchangers, with cooling water interfaces on their shell side (or cooling side), physically connected to the cold energy output end of the heat storage and conversion subsystem 30 via polyurethane foam insulated pipes. The drive motor is externally equipped with a water-cooled jacket or an independent air-cooled radiator, and the circulation loop of the water-cooled jacket is connected to the heat recovery network of the heat storage and conversion subsystem 30. The hydrogen storage cylinder group 13 consists of several high-pressure seamless steel cylinders, divided into low-pressure, medium-pressure, and high-pressure cylinder groups according to pressure levels, and connected to the exhaust port of the compressor unit 12 and the inlet of the hydrogen dispenser 14 via a sequence control valve group. On the branch line from the hydrogen storage and supply subsystem 10 to the fuel cell subsystem 20, there is a two-stage pressure reducing valve group and a mass flow meter, which are used to adjust the high-pressure hydrogen to the low-pressure inlet pressure (usually 0.2MPa to 0.5MPa).

[0091] The fuel cell subsystem 20 is located in a separate power generation compartment or equipment room. The fuel cell stack 21 is a proton exchange membrane fuel cell (PEMFC) with a total installed capacity of 2.5MW or more. This capacity value is selected based on the base load requirements of the microgrid system. The fuel cell stack 21 integrates bipolar plate channels. The coolant outlet in the bipolar plate channels is connected to the primary side of a plate heat exchanger via a pipe. The secondary side of the plate heat exchanger is connected to the circulating medium of the thermal storage and conversion subsystem 30. The cathode exhaust port of the fuel cell stack 21 is connected to a cathode tail exhaust treatment device 211. This device contains a gas-liquid separator and a condenser heat exchanger. The heat medium side of the condenser heat exchanger is supplied with high-temperature humid exhaust gas, and the cold medium side is supplied with low-temperature circulating water from the thermal storage and conversion subsystem 30 to recover the sensible heat and latent heat of condensation of water vapor in the exhaust gas. The inverter 22 is located near the fuel cell stack 21. The IGBT power modules in the inverter 22 are attached to a liquid-cooled heat dissipation substrate. The inlet and outlet of the liquid-cooled heat dissipation substrate are connected to the heat recovery network via pipelines.

[0092] The thermal storage and conversion subsystem 30 serves as a hub for the exchange of heat and cold, and its physical location is between the hydrogen storage and supply subsystem 10 and the fuel cell subsystem 20.

[0093] In terms of overall system layout, the integrated multi-terminal waste heat recovery hydrogen storage and supply control system 1 adopts a compact physical space design based on the shortest path principle. The coordinates of the connecting pipes of the hydrogen storage and supply subsystem 10, fuel cell subsystem 20, and heat storage conversion subsystem 30 are physically aligned and arranged adjacently to each other, ensuring the shortest possible thermal pipeline path. The physical distance from the integrated storage and supply water tank 31 to each heat source point and cold load point is minimized, reducing heat loss and cold energy dissipation along the way during long-distance transportation. Components such as the compressor skid, sequential control valve group, and pressure reducing valve group are modularly integrated and can be quickly installed and connected through prefabricated bases. The sensor probes of the station control system 40, including temperature sensors, pressure transmitters, and flow meters, are directly installed at key nodes of the above-mentioned physical pipelines, and the signal cables are converged to the PLC input module of the central control cabinet.

[0094] The working principle of the hydrogen storage and supply control system 1 for multi-terminal waste heat recovery in this application embodiment includes four stages: hydrogen energy transmission and distribution and heat energy generation stage, electrochemical power generation and multi-dimensional waste heat release stage, heat collection and cold-heat mode conversion stage, and global energy optimization scheduling stage.

[0095] In the hydrogen energy transmission and distribution and heat generation stage, the hydrogen storage and supply subsystem 10 receives hydrogen from the source, the pressure sensor feedback data from the hydrogen storage cylinder group 13 of the station control system 40, and the request signal from the hydrogen dispenser 14, controlling the sequential control valve group to operate and instructing the compressor unit 12 to start. The compressor unit 12 pressurizes the low-pressure hydrogen to a preset pressure (e.g., 35MPa or 70MPa) in stages and fills the hydrogen storage cylinder group 13 or directly delivers it to the hydrogen dispenser 14. During this process, the drive motor of the compressor unit 12 generates motor waste heat, and at the same time, the hydrogen generates interstage compression heat during compression. This heat is transferred to the circulating medium through the cooling channels set in the compressor skid.

[0096] In the electrochemical power generation and multidimensional waste heat release stages, the fuel cell subsystem 20 consumes hydrogen to generate electricity according to load demand. Electrochemical reactions occur inside the fuel cell stack 21, releasing the heat of the stack reaction. This heat is carried away by the circulating coolant inside the stack, and the coolant outlet temperature is typically maintained at 70°C. Up to 85 Between. When the hot, humid exhaust gas after the reaction passes through the cathode tail exhaust treatment device 211, the water vapor condenses and releases the latent heat of condensation. The DC power output from the fuel cell stack 21 is converted into AC power by the inverter 22. The power semiconductor devices in the inverter 22 generate heat of electrical conversion during switching operations, which is transferred to the cooling medium through the liquid-cooled heat sink.

[0097] For the heat collection and hot-cold mode conversion stage, the heat storage conversion subsystem 30 drives the heat medium to flow in the pipeline network through the circulating pump group 33, uses a plate heat exchanger to uniformly couple the heat sources of different temperature grades, and transports the heat to the integrated storage and supply water tank 31. The total heat power recovered by the multi-terminal waste heat recovery hydrogen storage and supply control system 1 satisfies the energy balance relationship shown in equation (1), which is as follows:

[0098] (1);

[0099] in, This indicates the heat power recovered by the cooling circuit of fuel cell stack 21; This represents the heat dissipation from the motor of compressor unit 12 and the heat recovery from compressed air cooling; This indicates the heat recovery power of the inverter 22 heat dissipation circuit; This represents the latent heat power recovered by the cathode tailrace treatment device 211. All of the above heat power items are obtained through heat meters installed on each branch or through flow rate and temperature difference calculations.

[0100] The thermal energy storage conversion subsystem 30 executes a hot-cold mode conversion according to the instructions of the station control system 40. This hot-cold mode conversion is based on the temperature stratification state of the integrated storage and supply water tank 31 and the terminal demand. When the compressor unit 12 is operating at high load and requires external cold source auxiliary heat dissipation, the high-temperature medium in the integrated storage and supply water tank 31 (temperature higher than the chiller start-up threshold, for example 75°C) The heat energy is introduced into the generator of the refrigeration unit 32, driving the refrigeration cycle to generate cold energy. The generated cold energy is fed back to the interstage cooler and aftercooler of the compressor unit 12 to maintain the temperature stability of the compression process. When the compressor unit 12 is shut down or the cooling demand is low, the heat energy in the integrated storage and supply water tank 31 is directly supplied to the user end 50 through the plate heat exchanger. The thermodynamic relationship of the absorption refrigeration process can be expressed by the relationship (2), which is shown below:

[0101] (2)

[0102] in, This is the cooling power output to compressor unit 12; The driving heat power input to the refrigerator 32; The coefficient of performance of the refrigeration unit 32 is determined by the physical characteristics of the refrigeration unit and is usually between 0.7 and 1.2.

[0103] For the global energy optimization scheduling stage, the industrial computer 41 in the station control system 40 performs global energy optimization scheduling. Specifically, based on real-time collected data and prediction models, mixed integer linear programming or genetic algorithms are used to solve and optimize the equipment start-up and shutdown state sequence and energy storage state reference trajectory of each subsystem in the future time period. The programmable logic controller 42 receives the above-mentioned equipment start-up and shutdown state sequence and energy storage state reference trajectory, and uses model predictive control algorithm to adjust the speed of compressor unit 12 and the opening of regulating valve of refrigerator 32 in real time with a preset time period as the control cycle.

[0104] The multi-terminal waste heat recovery hydrogen storage and supply control system 1 in the above embodiment recovers various types of waste heat generated during the hydrogen pressurization process and power generation process, avoiding direct waste of heat energy and improving energy utilization efficiency; and directly uses the recovered heat energy for heating or driving cooling, reducing dependence on external electric cooling equipment and reducing system power load; at the same time, it automatically switches between cooling mode and heating mode according to real-time temperature and cooling signal, realizing on-demand distribution of heat energy, thereby enhancing the system's adaptability to different operating conditions and reducing overall operating costs.

[0105] In one exemplary embodiment, such as Figure 2 As shown, Figure 1 The thermal energy storage conversion subsystem 30 shown includes: an integrated water tank for storage and supply 31, a chiller 32, and a circulating pump set 33.

[0106] The integrated water tank 31 is connected to the hydrogen storage and supply subsystem 10 and the fuel cell subsystem 20 respectively, and is used to recover and store interstage compression heat, motor waste heat, stack reaction heat, inverter waste heat and condensation latent heat according to temperature data; the chiller 32 is connected to the integrated water tank 31 and the hydrogen storage and supply subsystem 10 respectively, and is used to convert the heat energy in the integrated water tank 31 into cold energy in the cooling mode, and deliver the cold energy to the hydrogen storage and supply subsystem 10; the circulating pump group 33 is set between the integrated water tank 31 and the chiller 32, and is used to drive the flow of the medium between the integrated water tank 31 and the chiller 32.

[0107] The thermal storage conversion subsystem 30 in the multi-terminal waste heat recovery hydrogen storage and supply control system 1 of this application embodiment includes: an integrated storage and supply water tank 31, which is a vertical cylindrical pressure-bearing and heat-insulating water tank with an effective volume of 35. The volume is determined based on the integral value of the heat generated during 2 hours of full-load operation of the system, to provide sufficient thermal inertia buffer. The integrated storage and supply water tank 31 is equipped with a porous baffle or radial water distributor as a temperature stratifier to reduce the inlet and outlet water flow rates and minimize fluid disturbance, thereby maintaining a stable vertical thermocline structure inside the tank, ensuring that high-temperature water accumulates at the top and low-temperature water is located at the bottom. The integrated storage and supply water tank 31 has multiple standard flange interfaces pre-installed on its body, corresponding to the four heat recovery branches from the fuel cell stack 21, compressor unit 12, inverter 22, and cathode tail exhaust treatment device 211.

[0108] The chiller 32 is a lithium bromide chiller unit, located beside the integrated storage and supply water tank 31. The generator of the chiller 32 serves as the heat source inlet, connected to the upper high-temperature outlet of the integrated storage and supply water tank 31 via a high-temperature hot water pump. It uses high-temperature hot water to heat the dilute lithium bromide solution, causing it to boil and separating the refrigerant vapor. Its evaporator serves as the cold source outlet, connected to the interstage cooler and aftercooler interface of the compressor unit 12 via a chilled water circulation pipeline, for producing 7... Up to 12 The chilled water. The circulating pump set 33 includes multiple variable frequency centrifugal pumps, which are respectively installed on each heat recovery branch and cooling branch to drive the flow of the medium and regulate the flow rate.

[0109] It is worth noting that the volume selection of the integrated storage and supply water tank 31 follows the heat balance principle of the multi-terminal waste heat recovery hydrogen storage and supply control system 1, and must meet the maximum thermal energy surplus storage requirement within a typical scheduling cycle. The cooling capacity selection of the chiller 32 must cover the maximum heat dissipation power requirement of the compressor unit 12 when operating at full load, ensuring that the compressor's normal operating temperature is maintained without additional electric cooling assistance.

[0110] The working principle of the heat storage conversion subsystem in the multi-terminal waste heat recovery hydrogen storage and supply control system 1 of this application embodiment includes: when the station control system 40 determines that cooling is required, the multi-terminal waste heat recovery hydrogen storage and supply control system 1 enters the cooling mode: that is, the circulating pump group 33 starts, and the high-temperature medium (temperature higher than the chiller start-up threshold, for example 75) in the high-temperature zone of the integrated storage and supply water tank 31 is pumped into the cooling mode. The chilled water is delivered to the generator of the chiller 32, driving the refrigeration cycle to generate cold energy. The generated chilled water is then delivered to the interstage cooler and aftercooler of the compressor unit 12 in the hydrogen storage and supply subsystem 10 to remove the heat generated during hydrogen compression. When the station control system 40 determines that the refrigeration conditions are not met or the compressor has no cooling requirement, the system switches to the heating mode: the circulating pump unit 33 stops delivering the high-temperature medium to the chiller 32, cuts off the pipeline to the chiller 32, and supplies the hot water in the integrated storage and supply water tank 31 directly to the user end 50 through the plate heat exchanger for building heating or domestic hot water.

[0111] In one exemplary embodiment, Figure 1 The multi-terminal waste heat recovery hydrogen storage and supply control system 1 shown also includes a first branch, a second branch, a third branch, and a fourth branch.

[0112] The fuel cell subsystem 20 is connected to the top of the integrated water storage and supply tank 31 via the first branch and the second branch respectively; the fuel cell subsystem 20 is connected to the lower middle part of the integrated water storage and supply tank 31 via the third branch; and the hydrogen storage and supply subsystem 10 is connected to the lower middle part of the integrated water storage and supply tank 31 via the fourth branch.

[0113] The working principle of the multi-terminal waste heat recovery hydrogen storage and supply control system 1 in this application embodiment includes: the first branch, the second branch, the third branch and the fourth branch are physically composed of four independent or partially coupled heat exchange circuits. Through the circulation of the fluid medium, the heat energy of different temperature grades dispersed in the fuel cell subsystem 20 and the hydrogen storage and supply subsystem 10 is collected into the integrated storage and supply water tank 31.

[0114] For the first branch, the primary function is to recover the heat from the fuel cell stack reaction. The coolant outlet of the fuel cell stack 21 is connected to the primary side inlet of a plate heat exchanger via a stainless steel pipe. The plate heat exchanger employs a counter-current heat exchange design, with high-purity deionized water (coolant) flowing through the fuel cell on the primary side and the circulating medium of the thermal storage and conversion subsystem 30 flowing on the secondary side. The heat generated during the electrochemical reaction of the fuel cell stack 21 is transferred to the deionized water through the bipolar plates, and then, via the corrugated metal plate walls of the plate heat exchanger, heat transfer is driven by the temperature difference between the fluids on both sides through conduction and convection to transfer the heat to the circulating medium. The heat source recovered in this branch is a high-grade heat source, and its outlet temperature is typically stable at 75°C. Up to 85 The range is sufficient to meet the minimum drive temperature requirements of the subsequent 32-generator chiller (typically 70°C). -75 This branch line injects high-temperature fluid into the upper high-temperature zone of the integrated storage and supply water tank 31 via a top water distributor.

[0115] For the second branch, the primary function is to recover latent heat of condensation. The cathode exhaust port of the fuel cell stack 21 is connected to a gas-liquid separator condenser. The cathode exhaust contains water generated by the electrochemical reaction and unreacted air, and is in a high-temperature and high-humidity state. The gas-liquid separator condenser is equipped with finned tube bundles, and the circulating medium flows inside the tubes while the high-temperature humid gas passes over the outside of the tubes. When the humid gas comes into contact with the fin surface, which is below its dew point temperature, the water vapor undergoes a phase change and condenses into liquid water, releasing a large amount of latent heat of vaporization in the process. The capture of this latent heat makes the heat recovery efficiency of this branch significantly higher than that of a system that only recovers sensible heat. The recovered condensate, after collection and purification, can be used as system makeup water, realizing the recycling of water resources. This branch also injects high-temperature fluid into the upper high-temperature zone of the integrated storage and supply water tank 31 through a top water distributor, serving as the driving heat source for the chiller 32.

[0116] The third branch primarily recovers waste heat from the inverter. The power modules (IGBTs) of inverter 22 are mounted on a liquid-cooled substrate. The liquid-cooled substrate has microchannels internally, through which the circulating medium flows directly, carrying away heat generated by switching losses. Due to the junction temperature limitations of power electronic devices such as IGBTs, the temperature of the hot water recovered in this branch is relatively low, typically around 50°C. Up to 60 Therefore, the outlet pipe of this branch is connected to the lower middle interface of the integrated water storage and supply tank 31, or switched to a preheating heat source for domestic hot water via a three-way valve, so as to avoid damaging the high-temperature thermocline layer at the top of the water tank.

[0117] For the fourth branch, the main function is to recover interstage compression heat and motor waste heat. For the compressor unit 12 within the hydrogen storage and supply subsystem 10, a water-cooled jacket is installed outside its drive motor. During high-pressure compression operation, the stator and rotor of the compressor unit 12 generate copper and iron losses, which are converted into heat energy and accumulate on the casing. The water-cooled jacket absorbs this heat through forced convection heat transfer. The heat recovered in this branch is a low-grade heat source, injected into the lower middle part of the integrated storage and supply water tank 31 through a middle or bottom water distributor. This is mainly used to maintain the base water temperature of the integrated storage and supply water tank 31 and prevent the medium inside the tank from freezing under extreme winter conditions.

[0118] The circulating pump group 33 in the above four branches is frequency-controlled according to the real-time temperature of each heat source point. The control logic adopts a temperature difference control strategy: only when the outlet temperature on the heat source side is higher than a certain threshold (e.g., the internal temperature of the corresponding temperature zone of the integrated storage and supply water tank 31) will the temperature be controlled. When heat is drawn, the station control system 40 instructs the corresponding circulating pump to start, preventing heat backflow and subsequent heat loss from the water tank. The integrated storage and supply water tank 31 serves as a heat collection center, utilizing the buoyancy effect caused by changes in water density with temperature to achieve natural temperature stratification: the high-temperature fluids generated by the first and second branches are injected into the upper part of the tank through the top water distributor, serving as the driving heat source for the chiller 32; the medium- and low-temperature fluids generated by the third and fourth branches are injected into the lower part of the tank through the middle or bottom water distributors. This tiered physical connection method based on temperature grade achieves refined management and maximized recovery of waste heat at different grades. The selection calculations for heat exchangers used in each branch and the matching of pump head can be implemented by those skilled in the art based on the basic principles of thermal hydraulics and relevant design specifications; these are well-known technologies in the field and will not be elaborated upon here.

[0119] In one exemplary embodiment, such as Figure 3 As shown, Figure 1 The station control system 40 shown includes an industrial computer 41 and a programmable logic controller 42.

[0120] The industrial computer 41 is communicatively connected to the hydrogen storage and supply subsystem 10, the fuel cell subsystem 20, and the thermal storage and conversion subsystem 30, respectively, and is used to perform day-ahead global planning and intraday real-time rolling scheduling, and generate equipment start-up and shutdown state sequences and energy storage state reference trajectories. The programmable logic controller 42 is communicatively connected to the industrial computer 41, the hydrogen storage and supply subsystem 10, the fuel cell subsystem 20, and the thermal storage and conversion subsystem 30, respectively, and is used to control the thermal storage and conversion subsystem 30 to switch between cooling mode and heating mode according to the equipment start-up and shutdown state sequences, energy storage state reference trajectories, real-time temperature and cooling signals; it is also used to collect hydrogen pressure data, temperature data and flow data, control the start-up and shutdown of the compressor unit 12, adjust the speed of the circulating pump unit 33, and control the flow distribution from the integrated storage and supply water tank 31 to the chiller 32. In terms of the overall system layout, the coordinates of the connecting pipe ports of each subsystem are physically aligned and arranged close to each other to ensure the shortest possible path for the heating pipeline; the sensor probes of the station control system 40 are directly installed at the key nodes of each physical pipeline, and the signal cables are converged to the PLC input module of the central control cabinet.

[0121] The physical structure of the station control system 40 in the multi-terminal waste heat recovery hydrogen storage and supply control system 1 of this application embodiment includes:

[0122] The station control system 40 adopts a layered distributed architecture design, which is physically divided into a field device layer, a local control layer and an upper-level optimization and scheduling layer. Data interaction between the layers is realized through industrial Ethernet and fieldbus.

[0123] In terms of hardware architecture implementation, the computing and control platform of the station control system 40 is composed of an industrial computer 41 and a programmable logic controller 42 physically connected by hardwire or industrial Ethernet cable.

[0124] The field equipment layer includes various sensors and actuators distributed in the hydrogen storage and supply subsystem 10, fuel cell subsystem 20, and thermal energy storage and conversion subsystem 30. Temperature data acquisition primarily uses Pt100 resistance temperature detectors (RTDs), connected to the analog input module via a three-wire connection to eliminate the influence of wire resistance on measurement accuracy. Pressure data acquisition uses explosion-proof pressure transmitters, outputting a 4-20mA standard current signal. Flow data acquisition primarily uses Coriolis mass flow meters or turbine flow meters, transmitting data via pulse signals or an RS485 communication interface. Actuators include frequency converters, electric regulating valves, and solenoid valves. The frequency converters connect to the local control layer via hard-wired connections (start / stop signals) and analog inputs (frequency setting), or communicate via the Modbus-RTU protocol. The electric regulating valves receive 4-20mA opening commands to achieve continuous flow regulation of the fluid.

[0125] The local control layer is centered around a programmable logic controller (PLC) 42, with multiple distributed I / O stations. These distributed I / O stations are located in the local control boxes of each subsystem and connect to the main controller via real-time Ethernet communication protocols such as PROFINET (Process Field Network) or EtherCAT (Ethernet Control Automation Technology). To meet the high safety requirements of the hydrogen storage and supply subsystem 10, an independent safety instrumented system logic unit is provided. This unit is physically independent of the conventional control loop and uses fail-safe I / O modules. When a hydrogen leak concentration exceeds the standard or an abnormal pressure change is detected, the power supply to the equipment is directly cut off via a hardware relay circuit, triggering the emergency shut-off valve to close. The fuel cell subsystem 20 is equipped with an independent stack controller. The station control system 40 communicates with the stack controller via a CAN bus or gateway converter, reads the stack voltage, current, and individual cell consistency status, and issues target power (kW) setting commands.

[0126] The upper-level optimization and scheduling layer is deployed in the industrial computer 41. The industrial computer 41 communicates with the programmable logic controller 42 in full-duplex mode via the OPC UA (Open Platform UA) protocol, periodically reads the process variables in the field, and writes the calculated optimal setpoint into the holding register area of ​​the programmable logic controller 42.

[0127] Regarding the PLC model, shielding and grounding treatment of industrial communication cables, and software development environment in the above hardware selection, those skilled in the art can make specific configurations according to the actual scale of the project and anti-interference requirements. These are well-known technologies in the field of industrial automation and will not be elaborated here.

[0128] The working principle of the station control system 40 in the multi-terminal waste heat recovery hydrogen storage and supply control system 1 of this application embodiment includes:

[0129] The industrial computer 41 is responsible for global energy optimization scheduling, including day-ahead global planning and intraday real-time rolling scheduling. Furthermore, when performing global energy optimization scheduling, the industrial computer 41 also needs to satisfy the following physical constraints: the temperature constraint of the integrated storage and supply water tank 31 and the pressure constraint of the hydrogen storage cylinder group 13.

[0130] Regarding the temperature constraints of the integrated water storage and supply tank 31, considering the temperature stratification characteristics of the tank, the constraints can be subdivided into high-temperature zone constraints and low-temperature zone constraints. The temperature of the upper high-temperature zone of the integrated water storage and supply tank 31... It needs to be maintained at the start-up temperature threshold of the refrigeration unit 32. That's all. ,in, It is determined by the generation temperature of the lithium bromide solution inside the refrigeration unit 32, and is usually set to 70. -80 The temperature of the lower low-temperature zone of the integrated water storage and supply tank 31. It needs to be maintained below the return water temperature of the low-grade heat source to ensure effective heat injection into the inverter and motor, i.e. ,in, It is determined by the maximum permissible return water temperature of the inverter and motor, and is usually set to 45°C. -50 .like If this value is exceeded, the system will activate auxiliary cooling devices or limit the recovery of low-grade heat sources.

[0131] Regarding the pressure constraint of hydrogen storage cylinder group 13, the pressure of hydrogen storage cylinder group 13 It needs to be maintained at the minimum safe pressure With maximum design pressure Between, that is .in, To ensure that the hydrogen storage cylinder group does not form a negative pressure and to maintain the minimum retention pressure for basic gas supply capacity, it is usually set to 2MPa-5MPa; The design operating pressure for the hydrogen storage tank assembly is, for example, 45 MPa or 70 MPa.

[0132] Meanwhile, the industrial computer 41 is also used to perform day-ahead global planning and intraday real-time rolling scheduling. For day-ahead global planning, the industrial computer 41 obtains the grid time-of-use electricity price forecast data, user heat load forecast data and hydrogen refueling demand forecast data. Based on the forecast model, it adopts mixed integer linear programming with the goal of minimizing the overall operating cost to solve the equipment start-up and shutdown state sequence and energy storage state reference trajectory of each subsystem in the future period. The objective function can be represented by relation (3), which is shown below:

[0133] (3);

[0134] Where T is the scheduling period; For time step; This represents the electrical power exchanged between the system and the power grid. A positive value indicates that the system purchases electricity from the grid, while a negative value indicates that the system sells electricity to the grid. Let be the time-of-use electricity price at time t; This represents the mass consumption rate of hydrogen. Cost per unit mass of hydrogen; To provide 50% effective thermal power to the user end; It is the economic benefit coefficient per unit of heat.

[0135] Subsequently, the industrial computer 41 uses a control cycle of 5 to 15 minutes, with the start-stop state sequence and energy storage state reference trajectory generated in the previous day's plan as the tracking target, to solve the optimization function in the finite time domain, obtain the compressor speed adjustment amount and the regulating valve opening adjustment amount, and send them to the programmable logic controller 42.

[0136] The programmable logic controller (PLC) 42 is mainly used to control the thermal energy storage conversion subsystem 30 to switch between cooling and heating modes based on the equipment start-stop state sequence, energy storage state reference trajectory, real-time temperature, and cooling signals. Specifically, this includes the execution of a thermal energy storage and absorption coupling mechanism. This mechanism is primarily implemented by the PLC 42 through the control of electrically controlled regulating valve groups and variable frequency pump groups in the fluid pipeline network. The thermal energy storage and absorption coupling mechanism uses the integrated storage and supply water tank 31 as a thermal energy buffer, dynamically switching between heat-driven cooling mode and direct heating mode based on the real-time cooling requirements of the hydrogen storage and supply subsystem 10 and the thermal energy level inside the integrated storage and supply water tank 31.

[0137] During the heat energy grade determination stage, the programmable logic controller 42 collects temperature data in real time from the high-temperature zone at the top of the integrated storage and supply water tank 31. and the operating status of compressor unit 12. When compressor unit 12 is in operation and issues a cooling request signal, programmable logic controller 42 will... With the preset cooling start threshold Comparison. Cooling start-up threshold. The setting is determined based on the physical properties of the lithium bromide solution in the refrigerator 32, and is usually set to 75. Up to 80 If the driving heat source temperature is below this range, the desorption efficiency of the lithium bromide dilute solution in the generator will decrease, causing the refrigeration unit to be unable to maintain a stable vacuum and cooling capacity. To prevent the system from oscillating near the threshold, the programmable logic controller 42 employs hysteresis control logic: when Start cooling mode when; Drop to the stopping threshold (e.g.) -5 It will exit the cooling mode only when ( ).

[0138] During the absorption refrigeration cycle execution phase, the programmable logic controller 42 activates the high-temperature hot water pump connecting the integrated storage and supply water tank 31 and the chiller 32. The high-temperature hot water flows into the generator of the chiller 32, heating the dilute lithium bromide solution, causing the water in it to evaporate into refrigerant vapor, and the solution to concentrate into a concentrated solution. The refrigerant vapor enters the condenser and is cooled into liquid water, then passes through a throttling device into the evaporator. Inside the evaporator, utilizing the low boiling point of water under low pressure, the liquid water absorbs heat and evaporates, absorbing the sensible heat of the circulating water flowing through the evaporator coils, thereby producing 7... Up to 12 The generated chilled water is pumped to the interstage cooler and aftercooler of compressor unit 12 to remove the heat generated by hydrogen compression.

[0139] It is worth noting that a cold start bypass mode is provided for the cold start operation of the hydrogen storage and supply control system 1 with multi-terminal waste heat recovery. In this mode, the programmable logic controller 42 controls the three-way valve on the cooling water pipeline to temporarily bypass the chiller 32, switching the cooling circuit of the compressor unit 12 to an air-cooled radiator or using the existing low-temperature water in the water tank for sensible heat exchange. When the heat generated by the fuel cell operation heats the upper part of the water tank to the cold start threshold... Subsequently, the hydrogen storage and supply control system 1 with multi-terminal waste heat recovery automatically and seamlessly switches back to the absorption refrigeration coupling mode described above.

[0140] During this stage, to maintain a constant intake air temperature for compressor unit 12, programmable logic controller 42 employs a target temperature-based feedback control strategy (PID control). Programmable logic controller 42 monitors the outlet water temperature of the cooling circuit of compressor unit 12 and compares it with a set target value (e.g., 35°C). The system compares the output water temperature with the target temperature. When the outlet water temperature is higher than the target value, it indicates insufficient cooling capacity. The programmable logic controller 42 increases the opening of the hot water regulating valve leading to the chiller generator to increase the heat input and improve the cooling capacity; conversely, it decreases the valve opening. This control method can dynamically respond to the fluctuations in heat dissipation demand of the compressor unit 12 due to load changes, achieving dynamic power matching based on heat demand, without relying on complex theoretical formulas.

[0141] During the heating bypass switching phase, when the multi-terminal waste heat recovery hydrogen storage and supply control system 1 determines that the cooling conditions are not met or there is no cooling demand, the programmable logic controller 42 controls the three-way switching valve to cut off the pipeline to the chiller 32 and introduce the hot water in the integrated storage and supply water tank 31 into the heating plate heat exchanger. At this time, the multi-terminal waste heat recovery hydrogen storage and supply control system 1 transfers heat to the building heating terminal or domestic hot water tank by adjusting the speed of the secondary side circulation pump. If the temperature data in the integrated storage and supply water tank 31 is... The number of cases continues to rise and exceeds the system's security limit. (e.g. 95) (This value is determined by the boiling point of water under normal pressure and the temperature resistance rating of the water tank). At this time, there is neither a need for cooling nor a need for heating. The programmable logic controller 42 will turn on the emergency cooling fan and use the air-cooled radiator to force the circulating medium to cool down, preventing cavitation damage caused by excessive pressure inside the water tank or vaporization of the medium, and ensuring the physical safety of the hydrogen storage and supply control system 1 with multi-terminal waste heat recovery.

[0142] Through the above logic, the thermal storage and absorption refrigeration coupling mechanism physically establishes an energy conversion channel for hydrogen, electricity, heat, and cold. It utilizes the heat energy generated by fuel cell power generation to eliminate the heat load during hydrogen pressurization. Within the multi-terminal waste heat recovery hydrogen storage and supply control system 1, energy is utilized and balanced in a cascade manner, eliminating the need for external high-energy-consuming electric refrigeration equipment. Regarding the selection of actuators for regulating valves and the calibration of various temperature transmitters, those skilled in the art can perform conventional configurations based on specific process pipeline dimensions and fluid characteristics; these are well-known technologies in the field and will not be elaborated upon here.

[0143] In one exemplary embodiment, the hydrogen storage and supply control system 1 based on the multi-terminal waste heat recovery described in any of the foregoing embodiments also provides a hydrogen storage and supply control method based on multi-terminal waste heat recovery, such as... Figure 4 As shown, it includes:

[0144] S101 is used to pressurize or transport hydrogen, and generates interstage compression heat and motor waste heat during the pressurization process.

[0145] In this application embodiment, the specific method for pressurizing or transporting hydrogen, and generating interstage compression heat and motor waste heat during the pressurization process, is similar to the aforementioned method. Figures 1-3 The control methods described in any implementation are basically the same. For details, please refer to the foregoing explanation, which will not be repeated here.

[0146] S102 consumes hydrogen to generate electricity, and generates heat from the fuel cell reaction, waste heat from the inverter, and latent heat of condensation during the power generation process.

[0147] In this embodiment of the application, the method for generating electricity by consuming hydrogen, and generating heat from the fuel cell reactor reaction, waste heat from the inverter, and latent heat of condensation during the power generation process, is described above. Figures 1-3 The control methods described in any implementation are basically the same. For details, please refer to the foregoing explanation, which will not be repeated here.

[0148] S103 recovers interstage compression heat, motor waste heat, fuel cell stack reaction heat, inverter waste heat, and latent heat of condensation.

[0149] In this application embodiment, the specific method for recovering interstage compression heat, motor waste heat, fuel cell stack reaction heat, inverter waste heat, and latent heat of condensation is described above. Figures 1-3 The control methods described in any implementation are basically the same. For details, please refer to the foregoing explanation, which will not be repeated here.

[0150] S104: Obtain the real-time temperature of the thermal storage conversion subsystem and the cooling signal of the hydrogen storage and supply subsystem, and control the thermal storage conversion subsystem to switch between cooling mode and heating mode based on the real-time temperature and cooling signal.

[0151] In this embodiment of the application, the method involves acquiring the real-time temperature of the thermal energy storage conversion subsystem and the cooling signal of the hydrogen storage and supply subsystem, and controlling the thermal energy storage conversion subsystem to switch between cooling and heating modes based on the real-time temperature and cooling signal. This method is similar to the aforementioned... Figures 1-3 The control methods described in any implementation are basically the same. For details, please refer to the foregoing explanation, which will not be repeated here.

[0152] The aforementioned multi-terminal waste heat recovery hydrogen storage and supply control method simultaneously recovers various types of waste heat generated during the hydrogen pressurization process and power generation process, avoiding direct waste of heat energy and improving energy utilization efficiency. Furthermore, the recovered heat energy is directly used for heating or driving cooling, reducing reliance on external electric cooling equipment and lowering the system's power load. Simultaneously, the system automatically switches between cooling and heating modes based on real-time temperature and cooling signals, achieving on-demand distribution of heat energy. This enhances the system's adaptability to different operating conditions and reduces overall operating costs.

[0153] In an exemplary embodiment, the above-described multi-terminal waste heat recovery hydrogen storage and supply control method, such as... Figure 5 As shown, it also includes:

[0154] S201, based on a pre-trained prediction model, uses mixed-integer linear programming to solve for the equipment start-stop state sequence and energy storage state reference trajectory of each subsystem in the hydrogen storage and supply control system in the future time period, thus obtaining the equipment start-stop state sequence and energy storage state reference trajectory.

[0155] The constraints in the solution process include at least one of the following: the change in the internal hydrogen mass of the hydrogen storage and supply control system is equal to the difference between the input flow rate and the output flow rate; the hydrogen consumption rate and the output electrical power of the hydrogen storage and supply control system satisfy a nonlinear mapping relationship, which is obtained from the polarization curve data of the fuel cell; the rate of change of internal heat of the hydrogen storage and supply control system is equal to the input power of the heat source minus the output power of the heat load minus the heat dissipation loss.

[0156] In this embodiment, the industrial computer in the hydrogen storage and supply control system first filters, removes outliers, and normalizes the collected raw data (such as temperature, pressure, flow rate, etc.). It also converts data uploaded via different communication protocols into a standardized floating-point format with timestamps to ensure that sensor data from different sampling frequencies are aligned in the time dimension. Simultaneously, the standardized floating-point data is stored in a real-time database. Subsequently, the industrial computer trains an initial time-series prediction model based on long-term operational data from the historical database, obtaining a trained prediction model. Then, based on the trained prediction model, the industrial computer extrapolates the trend of user-end heat load demand and grid electricity price fluctuations within a future scheduling cycle. Simultaneously, it combines the current state of the hydrogen storage and supply control system to generate a system boundary condition vector containing current state variables and future disturbance variables.

[0157] Based on this, industrial computers incorporate the following physical constraints into the solution process;

[0158] For the hydrogen storage and supply subsystem in a hydrogen storage and supply control system, the hydrogen storage cylinder group within the subsystem is considered a high-pressure gas volume node. The change in hydrogen mass within it is equal to the difference between the input and output flow rates during that period. The input flow rate includes the injection flow rate from an external hydrogen source or electrolyzer; the output flow rate includes the consumption flow rate supplied to the fuel cell and the refueling flow rate from the hydrogen dispenser. Specifically, the hydrogen consumption of the fuel cell... Its output power There exists a non-linear mapping relationship, which can be expressed as: .in, The lower calorific value of hydrogen is 120 MJ / kg. This represents the power generation efficiency function of the fuel cell. This efficiency function is not a fixed value, but rather a curve obtained by fitting piecewise linearization data based on polarization curves provided by the fuel cell manufacturer. It reflects the actual hydrogen consumption characteristics of the fuel cell stack under different load rates. Using this constraint, an industrial computer can calculate the hydrogen consumption rate under different power generation commands.

[0159] For the thermal energy conversion subsystem in a hydrogen storage and supply control system, the integrated storage and supply water tank can be considered a thermal energy buffer. The change in its internal thermal energy depends on the input power of the heat source, the output power of the heat load, and the heat loss of the tank itself. That is, the rate of change of internal heat is equal to the input power of the heat source minus the output power of the heat load minus the heat loss. The input power of the heat source includes the sum of the four sources of thermal power recovered from the fuel cell stack, cathode tailpipe, inverter, and compressor. The heat recovery power of the compressor unit... Its operating power They are positively correlated, and their conversion coefficient is determined by the heat loss characteristics of the compressor motor. The heat load output power includes the driving heat power supplied to the refrigeration unit. And the heating power supplied directly to users.

[0160] In addition, regarding the coupling relationship between the chiller and compressor in the hydrogen storage and supply control system, the cooling capacity generated by the chiller... The heat dissipation requirements of the compressor unit under the current operating conditions must be met. This constraint is expressed as follows: .in, This is the coefficient of performance of the refrigeration unit, which is dynamically obtained by looking up a table based on the cooling water temperature and the heat source temperature. The overall electromechanical efficiency of the compressor unit; This represents the cooling safety margin coefficient. This inequality constraint clarifies the physical linkage between the electrical system (compressor power consumption) and the thermal system (refrigeration unit heat consumption), ensuring that any compressor action during the optimization calculation is accompanied by a corresponding heat energy deduction.

[0161] Since the objective function J (i.e., relation (3)) is the weighted sum of grid interaction cost, hydrogen consumption cost and equipment aging cost within a scheduling cycle, the grid interaction cost is calculated based on the time-of-use electricity price curve and the net exchange power of the microgrid, the hydrogen consumption cost is calculated based on the external hydrogen purchase price and the total hydrogen consumption, and the equipment aging cost is calculated by adding a penalty factor when the fuel cell switches between start-up and shutdown states. To achieve this, whenever a fuel cell starts or stops in the control sequence, a fixed virtual cost is added to the objective function, thereby suppressing frequent starts and stops.

[0162] Therefore, industrial computers, in addition to satisfying the aforementioned mass conservation constraints, energy conservation constraints, and thermal coupling constraints, also need to meet power ramping constraints and energy storage state constraints. Regarding the power ramping constraint, it primarily limits the rate of change of fuel cell output power within adjacent time steps. This ensures that the flow rate does not exceed 10% of the stack's rated power to prevent hydrogen starvation damage to the proton exchange membrane due to delayed reactant gas supply. For energy storage state constraints, the main settings are upper and lower limit thresholds for the hydrogen storage tank pressure and water tank temperature. The upper limit threshold is determined based on the safety design specifications for pressure vessels and water tanks; the lower limit threshold is determined based on the process requirements for maintaining the minimum operating pressure of the system.

[0163] Ultimately, under the premise of satisfying the above-mentioned mass conservation constraints, energy conservation constraints, thermal coupling constraints, power ramp-up constraints, and energy storage state constraints, the industrial computer solves for the equipment start-up and shutdown state sequence and energy storage state reference trajectory that minimize the objective function J.

[0164] S202, based on the equipment start-up and shutdown state sequence and the energy storage state reference trajectory, uses a model predictive controller to adjust the compressor speed and regulating valve opening of the hydrogen storage and supply control system in real time.

[0165] The model predictive controller runs on an industrial computer, and its control cycle is set to 5 to 15 minutes.

[0166] In this embodiment of the application, within each control cycle, the model predictive controller first obtains the real-time operating status of the hydrogen storage and supply control system in the current control cycle, including the real-time pressure of the hydrogen storage cylinder group, the real-time temperature stratification data of the integrated storage and supply water tank, the current output power of the fuel cell, and the real-time opening degree of each regulating valve.

[0167] Then, the model predictive controller constructs an optimization function in the finite time domain, using the equipment start-up and shutdown state sequence and the energy storage state reference trajectory as tracking targets. Simultaneously, under the premise of satisfying the equipment's physical constraints, it solves for the optimal control increment sequence. This control increment sequence can adjust the compressor speed and regulating valve opening of the hydrogen storage and supply control system in real time.

[0168] In addition, the model predictive controller has a built-in watchdog program and communication heartbeat detection mechanism. When a communication interruption with the upper-layer optimization and scheduling layer is detected to exceed a preset time limit (e.g., 5 seconds), it automatically switches to a safety backup mode. In safety backup mode, the model predictive controller ignores instructions sent from the upper layer and executes locally pre-stored conservative control strategies, or maintains the valid output value of the actuator from the previous moment until communication is restored, thereby avoiding system loss of control due to upper-layer computational failures.

[0169] In an exemplary embodiment, the above-mentioned S201, "solving the equipment start-stop state sequence and energy storage state reference trajectory of each subsystem in the hydrogen storage and supply control system in the future time period to obtain the equipment start-stop state sequence and energy storage state reference trajectory", is as follows: Figure 6 As shown, it includes:

[0170] S301 uses power balance constraints, energy conservation constraints, and equipment physical limitation constraints as the constraint space to solve the objective function and obtain the solution result.

[0171] The objective function aims to minimize the overall cost of the hydrogen storage and supply control system.

[0172] In this embodiment, the operating cycle of the industrial computer is set to 24 hours, and the time resolution is set to 15 minutes to 1 hour. The main technical objective is to determine the equipment start-up and shutdown sequence and energy storage state reference trajectory of each subsystem in the hydrogen storage and supply control system based on predictive information over a long-term time scale. This allows for the optimization of the operating cost of the hydrogen storage and supply control system by utilizing the time-of-use electricity price difference and the fluctuation characteristics of the heat load. The specific solution process is as follows:

[0173] First, the industrial computer reads the grid time-of-use electricity price curve and the external hydrogen source price for the next day. Simultaneously, it obtains the hydrogen refueling demand forecast sequence and the user-side heat load forecast sequence for the next 24 hours, and reads the current hydrogen storage cylinder pressure status and the integrated storage and supply water tank temperature status as the initial state point for the optimization problem. To ensure the feasibility of continuous operation of the hydrogen storage and supply control system, a cycle-end state constraint is set. This constraint mandates that at the end of the scheduling cycle, the state of the energy storage unit (hydrogen storage capacity and water tank heat) must be restored to a preset nominal level or no lower than the level at the beginning of the cycle. This prevents the optimization algorithm from excessively consuming energy storage resources in pursuit of minimizing daily costs, which could lead to the system failing to start normally the next day.

[0174] Subsequently, considering the significant nonlinear characteristics of the efficiency curve of the fuel cell and the energy consumption curve of the compressor, the industrial computer employs piecewise linearization technology to reduce the order of the equipment model. Specifically, based on the curvature variation characteristics of the fuel cell polarization curve and the compressor performance curve, several key inflection points are selected as segmentation nodes, approximating the originally smooth nonlinear curves as multiple line segments connected end-to-end. Simultaneously, special ordered set variables or auxiliary binary variables are introduced to describe the activation logic of these line segments, thereby transforming the nonlinear programming problem into a standard mixed-integer linear programming problem. This makes it possible to find the global optimum within a finite time using commercial solvers.

[0175] Ultimately, the industrial computer, within a constraint space that satisfies power balance, energy conservation, and equipment physical limitations, aims to minimize the overall operating cost by solving for the optimal solution of the objective function J, yielding the solution results. During the solution process, the results physically correspond to: a sequence of equipment start-up and shutdown states (determining the start-up and shutdown states of the fuel cell, chiller, and compressors at each stage in each future time step) and a sequence of equipment operating power (determining the target power value of each device under its operating state). Based on these solution results, a peak-shaving and valley-filling operation strategy can be generated. For example, during periods of low electricity prices, the planning strategy tends to start the compressor for hydrogen storage operations and utilize the compression heat to preheat the integrated storage and supply water tank; during periods of high electricity prices, the planning strategy tends to start the fuel cell to generate electricity to replace grid-purchased electricity, while utilizing waste heat to drive the chiller.

[0176] S302, the solution results are parsed into reference trajectory information and sent to the model predictive controller; the reference trajectory information includes the equipment start-up and shutdown state sequence and the energy storage state reference trajectory.

[0177] In this embodiment, the industrial computer parses the solution results into reference trajectory information and sends it to the model predictive controller running in the industrial computer. The reference trajectory information specifically includes two key pieces of information: first, the equipment start-up and shutdown state sequence, which clearly defines the allowable operating time window of each main device in each subsystem of the hydrogen storage and supply control system within the next 24 hours, serving as a hard constraint condition for the programmable logic controller running at the lower level of the station control system; second, the energy storage state reference trajectory, which gives the ideal values ​​of the hydrogen storage cylinder pressure and the integrated storage and supply water tank temperature at each moment, serving as the tracking target of the programmable logic controller.

[0178] The purpose of setting reference trajectory information is to decouple long-cycle economic efficiency from short-cycle real-time performance. In actual operation, load forecasting inevitably contains errors. The programmable logic controller (PLC) needs to fine-tune power based on real-time load disturbances, guided by the reference trajectory, within the framework of the upper-level start-up and shutdown plan, thereby balancing global economic optimization and local dynamic equilibrium. For the specific node selection methods and solver parameter configurations involved in piecewise linearization, those skilled in the art can perform conventional configurations according to the application specifications of operations research in power system dispatching, which will not be elaborated here.

[0179] In an exemplary embodiment, the phrase "using a model predictive controller to make real-time adjustments to the hydrogen storage and supply control system" in S202 above, such as... Figure 7 As shown, it includes:

[0180] S401 acquires the real-time operating status of the hydrogen storage and supply control system during the current control cycle, using a preset time period as the control cycle.

[0181] In this embodiment, the model predictive controller collects the system state vector for the current control cycle at a control cycle of 5 to 15 minutes. The system state vector includes: the real-time pressure of the hydrogen storage tank group, the real-time temperature stratification data of the integrated storage and supply water tank (including the temperature of the upper high-temperature zone and the lower low-temperature zone), the current output power of the fuel cell, and the real-time opening degree of each regulating valve.

[0182] Meanwhile, the model predictive controller updates disturbance variables (such as fluctuations in user heat load and changes in renewable energy output) in the future prediction time domain based on the latest meteorological data and historical load data from the most recent hour. To eliminate steady-state errors caused by model inaccuracies, the model predictive controller calculates the deviation between the measured state value at the current moment and the model prediction value at the previous moment, and adds this deviation as a constant bias term to all predicted values ​​for future moments, ensuring that the prediction starting point is consistent with the current physical reality.

[0183] S402, using the equipment start-up and shutdown state sequence and the energy storage state reference trajectory as reference targets, solves the optimization function in the finite time domain to obtain the compressor speed adjustment and regulating valve opening adjustment of the hydrogen storage and supply control system.

[0184] In this embodiment, the model predictive controller uses the equipment start-stop state sequence and the energy storage state reference trajectory as tracking targets to construct an optimization function in the finite time domain. The core of this optimization function is to find a balance between two competing objectives: first, to make the state of the hydrogen storage and supply control system (hydrogen storage cylinder pressure, integrated storage and supply water tank temperature) as close as possible to the reference trajectory; and second, to make the power adjustment range of the equipment as small as possible. This optimization function can be represented by relation (4), which is shown below:

[0185] (4);

[0186] in, The current moment; To predict the time domain length, the value is selected based on the time constant of the component with the greatest thermal inertia in the system (usually covering 3 to 4 hours). To control the length of the time domain; and These are the predicted values ​​for hydrogen storage status and water tank temperature, respectively. and These are the reference trajectory values ​​issued in the recent global planning strategy. This refers to the power adjustment amount for the fuel cell; This refers to the adjustment amount of the valve opening. , , , These are dimensionless weighting coefficients used to adjust the importance of various sub-objectives. In actual engineering implementation, these coefficients are determined using a method of order-of-magnitude normalization and on-site calibration: first, different physical dimensions (pressure, temperature, power) are normalized to the same order of magnitude; then, through on-site step response testing, the coefficients are gradually increased while meeting the system response speed requirements. and The value is maintained until the smoothness of the equipment's operation meets the mechanical life requirements of the actuator.

[0187] When solving the above relation (4), the optimization solver needs to comply with strict real-time physical constraints, including: action rate constraint: the rate of change of fuel cell power must be less than the safe ramp rate specified by the stack manufacturer to prevent stack reverse polarity failure caused by insufficient supply of reactant gas; safety boundary constraint: the pressure of the hydrogen storage tank and the temperature of the water tank must not exceed the safety limit threshold of the equipment at any prediction time; multi-physics coupling hard constraint: logical judgment conditions are introduced into the mathematical programming model. If the prediction result shows that the compressor will start at a future time, the refrigerator must be forced to be in the on state, and its cooling capacity can cover the expected heat generation of the compressor. This ensures that the physical linkage of cooling, heating and electricity is strictly executed at the control algorithm level, avoiding the risk of compressor overheating and shutdown. Finally, the model predictive controller obtains the compressor speed adjustment amount and regulating valve opening adjustment amount of the hydrogen supply system.

[0188] It is worth noting that, in the selection of the optimization solver in the model predictive controller, the embodiment of this application adopts an interior-point method solver optimized for quadratic programming problems, and uses sparse matrix technology to accelerate the operation, ensuring that a single iteration calculation is completed within hundreds of milliseconds, thus meeting the timing requirements of the real-time scheduling cycle.

[0189] S403, based on the adjustment amount, adjusts the compressor speed and regulating valve opening of the hydrogen storage and supply control system.

[0190] In this embodiment, after the model predictive controller obtains the compressor speed adjustment and regulating valve opening adjustment of the hydrogen supply system (i.e., a set of optimal control increment sequences covering the future control time domain), since the station control system follows the rolling time domain control principle, it only selects the first element of the optimal control increment sequence and sends it to the programmable logic controller. The programmable logic controller then superimposes the first element of the optimal control increment sequence onto the current operating point to form a new execution instruction. .

[0191] At the next sampling time, the hydrogen storage and supply control system will repeat the above optimization process based on the new measured conditions.

[0192] In summary, the hydrogen storage and supply control system in this application also includes a global safety interlocking and protection system. This global safety interlocking and protection system is based on the conventional process control layer and employs physically independent sensors, logic controllers, and execution loops to prevent hydrogen leaks and explosions, high-pressure vessel overpressure, and thermal runaway accidents in thermoelectric coupling systems. The specific implementation of the global safety interlocking and protection system includes hydrogen leak monitoring and emergency shutdown mechanisms, thermoelectric coupling safety interlocking mechanisms, and electrical insulation and grounding protection mechanisms.

[0193] In the hydrogen leak monitoring and emergency shutdown process, the hydrogen storage and supply control system deploys multiple hydrogen concentration detectors in the valve groups, compressor room, and hydrogen dispenser of the hydrogen storage and supply subsystem. These detectors employ catalytic combustion or electrochemical sensors to detect the volumetric concentration of hydrogen in the environment. To prevent false system shutdowns due to single sensor drift or malfunction, a two-out-of-three voting logic is used in critical detection areas. That is, the Safety Instrumented System (SIS) will only recognize a genuine leak and trigger interlocks when at least two of the three independent sensors in the same area simultaneously report concentrations exceeding the alarm threshold. The alarm thresholds are strictly set according to the "Design Standard for Alarm Detection of Combustible and Toxic Gases in Petrochemical Industry" (GB / T 50493-2019): the low alarm threshold is set at 20% of the lower explosive limit (LEL) of hydrogen, triggering the forced ventilation system to operate at maximum power; the high alarm threshold is set at 50% of the LEL, triggering an emergency shutdown (ESD) of the entire station. When an ESD command is triggered, the SIS system directly cuts off the power supply to the solenoid coil of the pneumatic shut-off valve at the site via an independent hard-wired circuit, without going through an intermediate communication protocol. Because the pneumatic shut-off valve uses a fail-safe actuator, after the solenoid valve loses power and causes the gas source pressure to release, the valve will be forcibly reset and closed under the mechanical force of the built-in spring, thus physically blocking the flow of hydrogen. At the same time, the vent valve at the top of the hydrogen storage cylinder group uses a fail-safe actuator, which automatically opens after power failure, allowing the high-pressure hydrogen remaining in the pipeline to be discharged to a safe area through a flame arrester.

[0194] In the thermoelectric coupling safety interlocking mechanism, a dedicated process safety interlocking logic is set up for the heat-cooling and combined heat and power processes in the embodiments of this application. The purpose of this logic is to address the risk of thermal hysteresis in strongly coupled systems, i.e., to prevent the compressor unit from overheating and being damaged due to loss of cooling source caused by refrigerator failure. The hydrogen storage and supply control system monitors the temperature of the integrated storage and supply water tank in real time. Chilled water outlet temperature of the chiller and the lubricating oil temperature of compressor unit 12 The process safety interlock logic adopts a composite criterion that includes state variables and rates of change. This composite criterion can be represented by relation (5), which is shown below:

[0195] (5);

[0196] in, Represents a logical OR operation; The upper limit threshold for the chiller's water supply temperature (set to 25) (Exceeding this value indicates refrigeration failure). The maximum operating temperature of the compressor lubricating oil (set to 85°C) Exceeding this value will lead to oil carbonization. This represents the real-time rate of change of the water tank temperature. The safe threshold for the rate of temperature rise (set to 5) ( / min). Introducing a temperature rise rate criterion. The technical significance lies in: utilizing the predictive nature of the differential term, protection is triggered in advance when the water tank temperature has not yet reached the absolute high temperature threshold but the heating rate is abnormally fast, preventing uncontrolled heat accumulation. Once the above logical conditions are met, the safety instrument system will interlock and cut off the main power supply of the compressor unit with the highest priority, and simultaneously shut off the hydrogen supply valve of the fuel cell, forcing the system into a natural cooling state.

[0197] In the electrical insulation and grounding protection aspects, an insulation monitoring device (IMD) is installed to address the high-voltage characteristics of the fuel cell and DC bus. This device monitors the insulation resistance of the high-voltage DC bus to ground in real time. The logic for determining the insulation status is as follows: when insulation is detected... When the value falls between the alarm value and the normal value, the system issues a warning signal; when a value is detected... Below the action threshold If this occurs, the trip protection will be triggered immediately. (Action threshold) The tripping threshold is determined based on safety standards for electric vehicles and fuel cell systems (such as GB 18384-2020), typically set at 100Ω / V or 500Ω / V of the system's nominal voltage. For a 500V DC bus system, the tripping threshold is set to 50kΩ. Once triggered, the system will control the DC contactors located at the fuel cell output and DC / DC converter input to disconnect, physically isolating the high-voltage source. Furthermore, all hydrogen-related equipment enclosures, pipe flanges, and instrument cabinets within the station are connected to the equipotential bonding busbar (MEB) via yellow-green copper wire with a cross-sectional area of ​​not less than 16 square millimeters, and connected to an independent instrument grounding network, ensuring a grounding resistance of less than 4 ohms. This measure aims to rapidly discharge the electrostatic charge generated by the high-speed flow of fluid within the pipeline, eliminating potential ignition sources.

[0198] Regarding the selection of explosion-proof electrical equipment, the requirements for sealing cable laying conduits, and the specific installation location of flame arresters involved in the above-mentioned steps, those skilled in the art can strictly implement them in accordance with the current mandatory standards such as the "Design Code for Hydrogen Stations". These are well-known technical and regulatory requirements in this field and will not be elaborated here.

[0199] This embodiment is verified based on a complete 24-hour (0:00 to 24:00) operating cycle. The system configuration parameters are derived from the attached data as follows:

[0200] Compressor unit cooling requirements (heat load): The base noise level is 20kW, exhibiting a typical bi-peak characteristic during the day. Thermal storage conversion subsystem capacity: Based on... Figure 8 The gray area shown indicates that the system's maximum cooling potential is constant at 400kW (during periods of sufficient waste heat). Temperature threshold settings: The absorption cooling start-up threshold is 75℃, and the low-grade return water temperature limit is 50℃.

[0201] Detailed explanation of runtime data: Based on Figure 8 , 9 Based on monitoring data from 10, the operating status of the hydrogen storage and supply control system at different time periods is as follows: dynamic matching of supply and demand driven by heat (corresponding to...). Figure 8 Nighttime low-load period (0:00-06:30): The compressor unit's cooling demand remains at a baseline noise level of 20kW. At this time, the system's maximum cooling potential is 0 (not shown in the gray area), and the actual absorption cooling output is 0kW. Daytime waste heat recovery operation period (06:30-19:30): Cooling potential activated: Around 06:30, the system's maximum cooling potential rises to 400kW (gray background area) and continues until 19:30, indicating sufficient high-temperature waste heat input during this period. Demand double-peak matching: The compressor cooling demand curve (solid line) shows two peaks during this period. The first peak occurs around 10:00, with cooling demand reaching a peak of 370kW. At this time, the actual cooling output (dashed line) completely overlaps with the demand curve and does not exceed the potential upper limit of 400kW; the trough occurs around 13:30, with cooling demand falling back to 175kW; the second peak occurs around 16:00, with cooling demand reaching a secondary peak of 320kW. Precise Tracking: Throughout the entire time window from 06:30 to 19:30, the actual absorption cooling output (dashed line) and compressor unit cooling demand (solid line) completely overlapped, achieving 100% heat-driven cooling coverage. Evening Decline Period (19:30-24:00): After 19:30, the system's cooling potential returned to zero. Compressor cooling demand slowly decreased to a noise floor level of 20kW.

[0202] Dynamic temperature stratification characteristics of integrated water storage and supply tanks (corresponding to) Figure 9High-temperature zone at the top of the water tank (cooling drive source): 0:00-06:30: Temperature stabilizes at around 70℃, below the cooling start-up threshold (75℃). Figure 3 The chiller is not running. 06:30-07:30 (Heating up): Affected by the waste heat injection, the water temperature rises rapidly, exceeding the 75℃ threshold, and reaches the first peak of 84℃ around 07:30. 07:30-18:30 (Fluctuation): The water temperature remains within the effective cooling range above 75℃. It is worth noting that around 10:00 (corresponding to the first peak of cooling load) and 16:00 (corresponding to the second peak of cooling load), due to the increased heat consumption of the chiller, the water temperature shows a slight downward trend, falling back to around 80℃ and 81℃ respectively, verifying the energy consumption logic of cooling with heat. 18:30-19:30 (Cooling down): As the waste heat input stops, the water temperature drops rapidly to 70℃. Low-temperature zone at the bottom of the water tank (return water heat recovery): Shows a slow and smooth upward trend throughout the day, with an initial temperature (0:00) of 35℃ and an ending temperature (24:00) rising to around 47℃. The curve remained below the 50℃ return water temperature limit line throughout the entire process, proving that the low-temperature environment at the bottom of the water tank was not damaged, ensuring the continuous and effective recovery of low-grade heat sources (such as motor heat dissipation).

[0203] Cumulative comparative analysis of operating costs (corresponding to) Figure 10 The cumulative operating costs over 24 hours for Scheme B (traditional system) and Scheme A (the system of this invention) were recorded: Scheme B (traditional system): The cost curve shows a steep, almost linear upward trend. The cumulative cost for 0-5 hours reaches approximately 500 yuan, the cumulative cost for 16 hours exceeds 2000 yuan, and the final cumulative operating cost for 24 hours reaches 3050 yuan, with the end of the curve marked as a high-cost zone. Scheme A (the system of this invention): The cost curve grows extremely gently. The cumulative cost for 0-10 hours is only about 200 yuan, and the final cumulative operating cost for 24 hours is only about 600 yuan, with the end of the curve marked as a low-cost zone. Comparison conclusion: Based on the 24-hour final value calculation, the daily operating cost of the system of this invention is reduced by approximately 80.3% compared to the traditional system = (3050 − 600) / 3050.

[0204] It should be understood that although the steps in the flowcharts of the embodiments described above are shown sequentially according to the arrows, these steps are not necessarily executed in the order indicated by the arrows. Unless explicitly stated herein, there is no strict order restriction on the execution of these steps, and they can be executed in other orders. Moreover, at least some steps in the flowcharts of the embodiments described above may include multiple steps or multiple stages. These steps or stages are not necessarily completed at the same time, but can be executed at different times. The execution order of these steps or stages is not necessarily sequential, but can be performed alternately or in turn with other steps or at least some of the steps or stages in other steps. It is understood that the steps in different embodiments can be freely combined as needed, and all non-contradictory solutions formed by such combinations are within the scope of protection of this application.

[0205] Those skilled in the art will understand that all or part of the processes in the methods of the above embodiments can be implemented by a computer program instructing related hardware. The computer program can be stored in a non-volatile computer-readable storage medium, and when executed, it can include the processes of the embodiments of the above methods. Any references to memory, databases, or other media used in the embodiments provided in this application can include at least one of non-volatile memory and volatile memory. Non-volatile memory can include read-only memory (ROM), magnetic tape, floppy disk, flash memory, optical memory, high-density embedded non-volatile memory, resistive random access memory (ReRAM), magnetic random access memory (MRAM), ferroelectric random access memory (FRAM), phase change memory (PCM), graphene memory, etc. Volatile memory can include random access memory (RAM) or external cache memory, etc. By way of illustration and not limitation, RAM can take many forms, such as Static Random Access Memory (SRAM) or Dynamic Random Access Memory (DRAM). The databases involved in the embodiments provided in this application may include at least one type of relational database and non-relational database. Non-relational databases may include, but are not limited to, blockchain-based distributed databases. The processors involved in the embodiments provided in this application may be general-purpose processors, central processing units, graphics processing units, digital signal processors, programmable logic devices, quantum computing-based data processing logic devices, artificial intelligence (AI) processors, etc., and are not limited to these.

[0206] The technical features of the above embodiments can be combined in any way. For the sake of brevity, not all possible combinations of the technical features in the above embodiments are described. However, as long as there is no contradiction in the combination of these technical features, they should be considered to be within the scope of this application.

[0207] The embodiments described above are merely illustrative of several implementation methods of this application, and while the descriptions are specific and detailed, they should not be construed as limiting the scope of this patent application. It should be noted that those skilled in the art can make various modifications and improvements without departing from the concept of this application, and these all fall within the protection scope of this application. Therefore, the protection scope of this application should be determined by the appended claims.

Claims

1. A hydrogen storage and supply control system with multi-terminal waste heat recovery, characterized in that, The system includes: A hydrogen storage and supply subsystem is used to pressurize or transport hydrogen, and generates interstage compression heat and motor waste heat during the pressurization process. The fuel cell subsystem is connected to the hydrogen storage and supply subsystem and is used to consume the hydrogen to generate electricity, and generates stack reaction heat, inverter waste heat and condensation latent heat during the power generation process. The thermal energy storage and conversion subsystem is connected to the hydrogen storage and supply subsystem and the fuel cell subsystem, respectively, and is used to recover the interstage compression heat, the motor waste heat, the stack reaction heat, the inverter waste heat, and the latent heat of condensation. The station control system is communicatively connected to the hydrogen storage and supply subsystem, the fuel cell subsystem, and the thermal storage and conversion subsystem, respectively. It is used to acquire the real-time temperature of the thermal storage and conversion subsystem and the cooling signal of the hydrogen storage and supply subsystem, and control the thermal storage and conversion subsystem to switch between cooling mode and heating mode according to the real-time temperature and the cooling signal.

2. The system according to claim 1, characterized in that, The thermal storage and conversion subsystem includes: An integrated water tank for storage and supply is connected to the hydrogen storage and supply subsystem and the fuel cell subsystem, respectively, and is used to recover and store the interstage compression heat, the motor waste heat, the fuel cell stack reaction heat, and the inverter waste heat and the latent heat of condensation according to temperature data. A refrigeration unit is connected to the integrated water storage and supply tank and the hydrogen storage and supply subsystem, respectively, and is used to convert the heat energy in the integrated water storage and supply tank into cold energy in the refrigeration mode, and to deliver the cold energy to the hydrogen storage and supply subsystem. A circulating pump unit is installed between the integrated water storage and supply tank and the chiller to drive the flow of the medium between the integrated water storage and supply tank and the chiller.

3. The system according to claim 2, characterized in that, The system also includes; The fuel cell subsystem is connected to the top of the integrated water storage and supply tank via a first branch and a second branch, respectively. The fuel cell subsystem is connected to the lower middle part of the integrated water storage and supply tank via a third branch. The hydrogen storage and supply subsystem is connected to the lower middle part of the integrated storage and supply water tank via a fourth branch.

4. The system according to claim 1, characterized in that, The station control system includes: An industrial computer is communicatively connected to the hydrogen storage and supply subsystem, the fuel cell subsystem, and the thermal storage and conversion subsystem, respectively, and is used to perform day-ahead global planning and intraday real-time rolling scheduling, and generate equipment start-up and shutdown status sequences and energy storage status reference trajectories. The programmable logic controller (PLC) is communicatively connected to the industrial computer, the hydrogen storage and supply subsystem, the fuel cell subsystem, and the thermal energy storage and conversion subsystem, respectively, and is used to control the thermal energy storage and conversion subsystem to switch between cooling mode and heating mode according to the equipment start-stop state sequence, the energy storage state reference trajectory, the real-time temperature, and the cooling signal.

5. A method for controlling hydrogen storage and supply with multi-terminal waste heat recovery, characterized in that, The method, applied to a multi-terminal waste heat recovery hydrogen storage and supply control system as described in any one of claims 1-4, comprises: Hydrogen is pressurized or transported, and interstage compression heat and motor waste heat are generated during the pressurization process; The hydrogen is consumed to generate electricity, and during the power generation process, the heat generated by the fuel cell reaction, the waste heat of the inverter, and the latent heat of condensation are generated. The interstage compression heat, the motor waste heat, the fuel cell reaction heat, the inverter waste heat, and the latent heat of condensation are recovered. The system acquires the real-time temperature of the thermal storage conversion subsystem and the cooling signal of the hydrogen storage and supply subsystem, and controls the thermal storage conversion subsystem to switch between cooling mode and heating mode based on the real-time temperature and the cooling signal.

6. The method according to claim 5, characterized in that, The step of controlling the thermal storage conversion subsystem to switch between cooling mode and heating mode based on the real-time temperature and the cooling signal includes: When the real-time temperature and cooling signal meet the refrigeration conditions, the refrigeration mode is activated, and the heat energy in the integrated storage and supply water tank is converted into cold energy by the refrigeration unit in the hydrogen storage and supply control system and delivered to the compressor. If the real-time temperature and cooling signal do not meet the cooling conditions, the pipeline leading to the refrigerator is cut off, and the heat energy is delivered to the user.

7. The method according to claim 6, characterized in that, The method further includes: Based on a pre-trained prediction model, mixed integer linear programming is used to solve the equipment start-stop state sequence and energy storage state reference trajectory of each subsystem in the hydrogen storage and supply control system in the future time period, so as to obtain the equipment start-stop state sequence and the energy storage state reference trajectory. Based on the equipment start-stop state sequence and the energy storage state reference trajectory, a model predictive controller is used to adjust the compressor speed and regulating valve opening of the hydrogen storage and supply control system in real time.

8. The method according to claim 7, characterized in that, The constraints in the solution process include at least one of the following: The change in the internal hydrogen mass of the hydrogen storage and supply control system is equal to the difference between the input flow rate and the output flow rate. The hydrogen consumption rate and the output electrical power of the hydrogen storage and supply control system satisfy a nonlinear mapping relationship, which is obtained from the polarization curve data of the fuel cell. The rate of change of internal heat in the hydrogen storage and supply control system is equal to the input power of the heat source minus the output power of the heat load minus the heat dissipation loss.

9. The method according to claim 7, characterized in that, The process of solving for the equipment start-up and shutdown state sequences and energy storage state reference trajectories of each subsystem in the hydrogen storage and supply control system over a future time period to obtain the equipment start-up and shutdown state sequences and the energy storage state reference trajectories includes: Using power balance constraints, energy conservation constraints, and equipment physical limitations as the constraint space, the objective function is solved to obtain the solution result; the objective function aims to minimize the overall cost of the hydrogen storage and supply control system. The solution results are parsed into reference trajectory information and sent to the model prediction controller; the reference trajectory information includes the equipment start-up and shutdown state sequence and the energy storage state reference trajectory.

10. The method according to claim 7, characterized in that, The method of using a model predictive controller to make real-time adjustments to the hydrogen storage and supply control system includes: The real-time operating status of the hydrogen storage and supply control system is obtained within the current control cycle, using a preset time period as the control cycle. Using the equipment start-stop state sequence and the energy storage state reference trajectory as reference targets, the optimization function in the finite time domain is solved to obtain the compressor speed adjustment amount and regulating valve opening adjustment amount of the hydrogen storage and supply control system. Based on the adjustment amount, the compressor speed and regulating valve opening of the hydrogen storage and supply control system are adjusted.

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