NH3 Adjustment Gas Turbine Auxiliary System

Abstract

A power generation system comprising a gas turbine (100), a fuel cell (500), and an NH3 adjustment gas turbine auxiliary system, wherein the NH3 adjustment gas turbine auxiliary system is configured to process an ammonia feed stream to obtain a decomposition gas containing at least hydrogen and nitrogen, preferably an NH3 / H2 / N2 gas mixture, and the NH3 adjustment gas turbine auxiliary system comprises an ammonia cracking reactor (300), which is configured to decompose ammonia into a gas mixture of hydrogen, nitrogen, and residual ammonia. A power generation system comprising a separator coupled to a gas turbine (100) and configured to separate a gas mixture of hydrogen, nitrogen, and residual ammonia into separate flows of hydrogen, nitrogen, and ammonia, wherein the separator comprises at least one of a first separator outlet line (71, 74) connected to the fuel cell (500) for transporting the ammonia flow to the fuel cell (500), and a second separator outlet line (72, 72b) connected to the fuel cell (500) for transporting the hydrogen flow to the fuel cell (500).

Description

[Technical Field]

[0001] This disclosure relates to a power generation system comprising a gas turbine, a fuel cell, and an NH3 regulating gas turbine auxiliary system. [Background technology]

[0002] Gas turbines are generally used in power plants to generate electricity by burning fuel. In particular, the basic operation of a gas turbine is the Brayton cycle, which uses air as the working fluid. Air flows through a compressor, which pressurizes the air to a higher pressure. Fuel is then injected into the air in the combustion chamber and ignited, adding energy by generating a high-temperature fluid through combustion. This high-temperature, pressurized gas enters the turbine and is used to drive the compressor, generating shaft work output in the process. Unused energy is released into the exhaust gas, which can be reused for external work, such as directly generating thrust in a turbojet engine or rotating a second independent turbine (known as a power turbine) that can be connected to a fan, propeller, or generator. The objective of a gas turbine is to determine the design so that the most desirable energy division between thrust and shaft work is achieved. The fourth step of the Brayton cycle (cooling the working fluid) is omitted because the gas turbine is an open system that does not reuse the same air.

[0003] Commonly used fuels include natural gas, propane, diesel, biogas, and biodiesel. One of the main problems associated with burning these fuels in gas turbines is the resulting production of carbon dioxide (CO2) gas. The increase in atmospheric CO2 levels is harmful to the environment and is a known cause of global warming. Therefore, there is a need to provide fuels for use in gas turbines that do not produce CO2 during combustion, or that must have CO2 removed before combustion.

[0004] Carbon-free fuels include ammonia and hydrogen. However, both ammonia and hydrogen have several problems associated with their direct use as fuel in gas turbines. The main problem associated with the direct use of ammonia as fuel in gas turbines is that ammonia oxidizes during the combustion process to form nitrogen oxides, or NOx. x In other words, it becomes a pollutant that contributes to acid rain and global warming. In addition, due to ammonia's low heat capacity and low reactivity with oxygen, ammonia combustion in gas turbines presents stability problems (blowout) across the entire range of gas turbine operating conditions. On the other hand, hydrogen combustion produces NO x Even if contaminants are still generated, the stability problem (blowout) is resolved. Nevertheless, there are many problems associated with the use of hydrogen as a fuel, including storage problems and the fact that hydrogen is an extremely flammable gas. The availability of N2 as an inert substance in the combustion process depends on the type of flame realized in the gas turbine combustor, and NO x It may help reduce emissions.

[0005] Chinese Patent No. 107288780(A) discloses a system for generating electricity using a gas turbine, with ammonia used as fuel. Upstream of the combustion chamber, ammonia is partially decomposed in an ammonia cracking device to produce hydrogen, providing a fuel mixture containing hydrogen and ammonia. Since the combustion point of hydrogen is lower than that of ammonia, the hydrogen first burns in the combustion chamber, releasing heat and igniting the ammonia in the combustion chamber. As a result, the hydrogen can accelerate the combustion process, thus improving the combustion performance of the ammonia fuel. In conclusion, the amount of hydrogen supplied is functionally related to the ignition of NH3. However, the system disclosed in Chinese Patent No. 107288780 does not completely overcome environmental problems due to the formation of nitrogen oxides resulting from the oxidation of ammonia during the combustion process.

[0006] U.S. Patent No. 11084719(B2) discloses a process for generating electricity using a gas turbine, the process comprising: (i) vaporizing and preheating liquid ammonia to produce preheated ammonia gas; (ii) introducing the preheated ammonia gas into an ammonia cracking unit suitable for converting the ammonia gas into a mixture of hydrogen and nitrogen; (iii) converting the preheated ammonia gas into a mixture of hydrogen and nitrogen within the unit; (iv) cooling the mixture of hydrogen and nitrogen to obtain a cooled mixture of hydrogen and nitrogen; (v) introducing the cooled mixture of hydrogen and nitrogen into a gas turbine; and (vi) burning the cooled mixture of hydrogen and nitrogen in the gas turbine to generate electricity. U.S. Patent No. 11084719(B2) also discloses a unit in which the composition of the hydrogen and nitrogen mixture exiting the ammonia cracking unit can be adjusted using purification techniques. However, the composition of the mixture produced from the cracking process may be far from optimal for GT operating requirements.

[0007] U.S. Patent No. 11156168(B2) discloses a gas turbine plant comprising a gas turbine, a heating unit, a crackling gas line, and a crackling gas compressor. The heating unit heats ammonia and thermally decomposes it to convert it into crackling gases containing hydrogen and nitrogen gases. The crackling gas line delivers the crackling gases from the heating unit to the gas turbine. The crackling gas compressor increases the pressure of the crackling gases to a pressure equal to or greater than the supply pressure required to supply the crackling gases to the gas turbine. U.S. Patent No. 11156168(B2) also discloses a control device that adjusts the ratio of the flow rate of the crackling gases to the flow rate of the total fuel gases (including natural gas and crackling gases). Such ratio control allows for obtaining and adjusting a mixture of crackling gases and natural gas into the combustion chamber. However, burning natural gas still produces high levels of carbon dioxide, which is released into the atmosphere or requires an additional carbon capture system.

[0008] International Publication No. WO2023281265(A1) relates to a propulsion system for thermally integrating an ammonia-based cracking reactor into an engine, such as an engine, which may be used in aerospace or other vehicle applications. The propulsion system further comprises a fuel cell module, the ammonia cracking module being thermally balanced with both the engine module and the fuel cell module. In addition that the system is suitable only for vehicle or aircraft applications, the integration between the ammonia cracking module and the fuel cell is carried out to thermally equilibrium the system by coupling a heat exchanger downstream of the combustion chamber to exchange heat and power a low-pressure turbine. Furthermore, the cracked ammonia is supplied in a continuous flow first to the combustion chamber and turbine, then to the heat exchanger, and finally to the fuel cell.

[0009] In conclusion, the solutions in prior art either negatively impact the operating cost of the system or have adverse environmental effects. Therefore, to address the problem of real-time NH3 adjustment in order to realize an NH3 / H2 / N2 gas mixture that enables the gas turbine to operate under all conditions, an improved system that generates electricity using ammonia as fuel and a gas turbine would be beneficial and welcome in the technology. NH3 adjustment needs to be performed flexibly along the path to the turbine and adjusted at different levels, and therefore, in addition to improving performance, an NH3 recovery system should also be utilized to achieve NO x To reduce emissions, there is a recognized need for a system that can adjust and supply fuel to the gas turbine at different stages. More generally, it would be desirable to provide methods and systems adapted to more efficiently address the problems that arise from providing an NH3 adjustment auxiliary system to achieve an NH3 / H2 / N2 gas mixture that enables the gas turbine to operate under all conditions. [Overview of the project]

[0010] In one aspect, the subject matter disclosed herein relates to an improved system for generating power, such as mechanical power and / or electrical power, the system comprising a gas turbine, a gas turbine auxiliary system for NH3 regulation, and a fuel cell. Embodiments disclosed herein relate to a gas turbine auxiliary system for NH3 regulation, and particularly, are configured to supply a separated stream of ammonia and / or hydrogen to a fuel cell, while a gas mixture, preferably a mixture containing hydrogen and / or nitrogen, is supplied to the gas turbine.

[0011] Advantageously, the power generation system disclosed herein may also include a Selective Catalytic Reduction (SCR) system for reducing NOx emissions, and / or may include one or more storage units for storing NH3, H2, heat, electricity, and / or N2 for external use. BRIEF DESCRIPTION OF THE DRAWINGS

[0012] Many of the disclosed embodiments of the present invention, and the attendant advantages thereof, will be better understood and more fully appreciated when considered in connection with the accompanying drawings. Referring to the following description of the embodiments for carrying out the invention, a more complete understanding can be readily obtained. [Figure 1] Illustrates a schematic diagram of a power generation system using a gas turbine and comprising an ammonia cracking device according to a first exemplary non-claimed embodiment. [Figure 2] Illustrates a block diagram of the control architecture of the power generation system of FIG. 1. [Figure 3] Illustrates a schematic diagram of a power generation system using a gas turbine and comprising an ammonia cracking device according to a second exemplary non-claimed embodiment. [Figure 4] Illustrates a block diagram of the control architecture of the power generation system of FIG. 3. [Figure 5] Illustrates a schematic diagram of a power generation system using a gas turbine and comprising an ammonia cracking device according to a third exemplary non-claimed embodiment. [Figure 6] Illustrate a schematic diagram of a power generation system using a gas turbine and comprising an ammonia cracking device according to a fourth illustrative non-claimed embodiment. [Figure 7] Illustrate a schematic diagram of a power generation system using a gas turbine and comprising an ammonia cracking device according to a fifth illustrative non-claimed embodiment. [Figure 8] Illustrate a schematic diagram of a power generation system using a gas turbine and comprising an ammonia cracking device according to a sixth illustrative non-claimed embodiment. [Figure 9] Illustrate a schematic diagram of a power generation system using a gas turbine and comprising an ammonia cracking device and a fuel cell according to a first embodiment. [Figure 10] Illustrate a schematic diagram of a power generation system using a gas turbine and comprising an ammonia cracking device and a fuel cell according to a second embodiment. [Figure 11] Illustrate a schematic diagram of a power generation system using a gas turbine and comprising an ammonia cracking device and a fuel cell according to a third embodiment. [Figure 12] Illustrate a schematic diagram of a power generation system using a gas turbine and comprising an ammonia cracking device and a fuel cell according to a fourth embodiment.

Mode for Carrying Out the Invention

[0013] According to one aspect, the subject matter relates to a system for generating electricity using a gas turbine, the system comprising an ammonia cracking device for converting at least a portion of an NH3 stream into H2 and N2 to achieve an NH3 / H2 / N2 gas mixture that enables the gas turbine to operate under all conditions.

[0014] In another embodiment, the subject disclosed herein relates to an NH3 regulating gas turbine auxiliary system, wherein an NH3 supply stream is split into two separate NH3 streams, the first NH3 stream is cracked into H2 and N2 through a catalytic cracking reactor or a thermal cracking reactor to obtain an H2 and N2 stream, and the second NH3 stream is directed to a bypass line. In particular, downstream of the cracking reactor, the H2 and N2 streams are mixed with the second NH3 stream to obtain an NH3 / H2 / N2 gas mixture having controlled ratios of NH3 on one side and H2 and N2 on the other. Optionally, downstream of the cracking reactor, N2 can be separated from the H2 gas in the H2 and N2 stream to obtain an NH3 / H2 / N2 gas mixture having controlled ratios of NH3, H2, and N2, and in addition, N2 can be used as a purge gas.

[0015] Hereinafter, embodiments of the present disclosure are referenced in detail. One or more of these embodiments are illustrated in the figures. Each example is provided for illustrative purposes only and is not limiting to the present disclosure. It will be apparent to those skilled in the art that various modifications and variations can be made to the present disclosure without departing from the scope or spirit of the present disclosure. Throughout this specification, any reference to “one embodiment,” “one embodiment,” or “several embodiments” means that a particular feature, structure, or characteristic described in relation to one embodiment is included in at least one embodiment of the subject matter disclosed. Thus, the appearance of phrases “in one embodiment,” “in one embodiment,” or “in several embodiments” in various places throughout this specification does not necessarily refer to the same embodiment. Furthermore, certain features, structures, or characteristics can be combined in any preferred manner in one or more embodiments.

[0016] When presenting elements of various embodiments, the articles "a," "an," "the," and "said" are intended to indicate that there is one or more of those elements. The terms "comprising," "including," and "having" are intended to be non-exclusive, meaning that additional elements other than those listed may exist.

[0017] Referring here to the drawings, Figure 1 shows a schematic diagram of an exemplary power generation system comprising a gas turbine 100. The gas turbine 100 includes a compressor, a combustion chamber, and an expander. The gas turbine 100 is supplied with an NH3 / H2 / N2 gas mixture flow and an NH3 gas flow. The NH3 / H2 / N2 gas mixture flow is guided to the primary stage of the gas turbine 100 through a gas turbine supply line 1, and the NH3 gas flow is guided to the secondary stage of the gas turbine 100 through an NH3 gas supply flow line 2. Furthermore, an NH3 regulating gas turbine auxiliary system is located upstream of the gas turbine 100, and the gas turbine auxiliary system includes an NH3 heater / vaporizer / pressurizer 200 for heating and then vaporizing the NH3 liquid flow from an NH3 flow line 4, and a cracking reactor 300 connected to the NH3 heater / vaporizer / pressurizer through an NH3 heater / vaporizer / pressurizer gas outlet line 5 and a cracking reactor supply line 6. In alternative embodiments, the NH3 heater / vaporizer / pressurizer consists of a shell-and-tube heat exchanger or a plate heat exchanger. In some embodiments, the heat transfer fluid for the heater / vaporizer / pressurizer is gas turbine exhaust gas or another intermediate fluid (such as steam or heat transfer oil). In one embodiment, the heat exchanger is constructed in two stages, one for heating and vaporizing liquid ammonia, and the other for restoring the initial pressure or ultimately increasing the ammonia gas pressure. In some embodiments, a storage tank for high-pressure ammonia gas is also included in the heater / vaporizer / pressurizer system.

[0018] According to one embodiment shown in Figure 1, the NH3 cracking reactor 300 is a catalytic reactor or a thermal reactor configured to process ammonia in the presence of a catalyst or under temperature control, according to the following reaction, and to dissociate it into at least its basic components, namely hydrogen and nitrogen.

[0019]

number

[0020] The mixture of hydrogen and nitrogen produced from the cracking reaction, along with any remaining unreacted ammonia, is then guided to the gas turbine 100 through the NH3 / H2 / N2 gas mixture outlet line 7, which is connected downstream of the gas turbine supply line 1.

[0021] The NH3 bypass flow is separated from the NH3 gas flow from the heater / vaporizer / pressurizer through the NH3 gas bypass flow line 11, which is connected upstream to the heater / vaporizer / pressurizer gas outlet line 5 and downstream to the NH3 gas supply flow line 2 of the gas turbine 100, specifically to the secondary stage of the gas turbine 100.

[0022] This system allows the gas turbine control loop to control the ratio of NH3 burned along with H2 and N2 from the cracking reactor, according to the operational needs of the gas turbine.

[0023] The exhaust gas from the gas turbine 100 is sent to the exhaust gas flow line 15, from where a portion of the exhaust gas flow is separated and sent through the exhaust gas heat recovery line 12 to the cracking reactor 300 and / or the NH3 heater / vaporizer / pressurizer 200. Referring to Figure 1, the exhaust gas heat recovery line 12 is divided into a first heat recovery subline 13 that leads to the cracking reactor 300 and a second heat recovery subline 14 that leads to the NH3 heater / vaporizer / pressurizer 200.

[0024] An emergency system (not shown) is located along the gas turbine supply line 1 and includes a vent and an emergency valve to prevent overpressure.

[0025] The NH3 adjustment gas turbine auxiliary system shown in Figure 1 operates as follows: The system is started by heating / vaporizing / pressurizing liquid ammonia inside the NH3 heater / vaporizer / pressurizer 200 and supplying it in gaseous form to the NH3 cracking reactor 300. A portion of the gaseous ammonia from the NH3 heater / vaporizer / pressurizer 200 leaks into the NH3 gas bypass flow line 11 and is sent to the gas turbine 100 through the NH3 gas supply flow line 2. A portion of the heat generated by the gas turbine 100 is sent to the NH3 heater / vaporizer / pressurizer 200 and the NH3 cracking reactor 300. Furthermore, the liquid ammonia is heated, vaporized, and pressurized within the vaporizer / pressurizer 200, and the NH3 cracking reactor 300 begins to supply the gaseous mixture into the NH3 / H2 / N2 gas mixture outlet line 7. A storage drum (not shown) may optionally be placed along the NH3 / H2 / N2 gas mixture outlet line 7. When the pressure in the NH3 / H2 / N2 gas mixture outlet line 7 reaches a threshold, the gas turbine starting sequence may begin. Gas turbine ignition is achieved by using the flow supplied through gas turbine supply line 1 or NH3 gas supply flow line 2 as fuel and receiving NH3 gas flow from NH3 gas bypass flow line 11. If energy is not available to start the NH3 heater / vaporizer / pressurizer 200 and NH3 cracking reactor 300, a starting fuel such as natural gas may be connected to gas turbine supply line 1 or NH3 gas supply flow line 2 and used for gas turbine ignition and for the end of the gas turbine sequence or rise to full speed no-load state. Once the gas turbine is ignited, exhaust gas heat begins to supply energy to both the NH3 heater / vaporizer / pressurizer 200, which heats, vaporizes, and pressurizes liquid ammonia into gaseous ammonia, and the NH3 cracking reactor 300, which cracks the gaseous ammonia into a mixture of hydrogen, nitrogen, and final unreacted ammonia. Once the appropriate mixture is created, the flow of the NH3 / H2 / N2 gas mixture inside the gas turbine supply line 1 is controlled according to the gas turbine control schedule.Throughout the entire sequence of the gas turbine (startup, load operation, and normal shutdown), the gas turbine auxiliary control unit 37 manages the composition requirements of the mixture of hydrogen, nitrogen, and residual ammonia in the gas turbine supply line 1, acts on the parameters of the NH3 cracking reactor 300, and manages the flow rate ratio between the gas turbine supply line 1 and the NH3 gas supply flow line 2. The parameters of the NH3 cracking reactor managed by the gas turbine auxiliary control unit 37 are strictly dependent on the NH3 cracking reactor technology. In some embodiments, the parameters of the NH3 cracking reactor include the temperature of the reactive ammonia gas in a specific section of the reactor (e.g., in the inlet section) and the NH3 cracking reactor recycling ratio. Emergency shutdown of the gas turbine 100 allows for the immediate isolation of the NH3 adjustment gas turbine auxiliary system from the gas turbine 100, as well as the power cutoff of the NH3 heater / vaporizer / pressurizer 200 and the NH3 cracking reactor 300 in accordance with their specific safety requirements.

[0026] The operation of the NH3 regulating gas turbine auxiliary system in Figure 1 is controlled through a number of control valves that operate according to the control methods described below herein. A gas flow valve 21 is located along the gas turbine supply line 1 to control the flow of the NH3 / H2 / N2 gas mixture flow within the gas turbine supply line 1. An NH3 gas bypass flow valve 22 is located along the NH3 gas supply flow line 2, downstream of the NH3 gas bypass flow line 11, to control the flow of the NH3 gas bypass flow directed to the gas turbine 100, and conversely, the flow of the NH3 gas flow directed to the cracking reactor 300 through the cracking reactor supply line 6. Finally, a heat recovery flow valve 26 is located on the first heat recovery subline 13 to control a portion of the exhaust gas from the gas turbine 100 directed to the NH3 cracking reactor 300, and conversely, a portion of the exhaust gas directed to the NH3 heater / vaporizer / pressurizer 200. The gas flow valve 21, the NH3 gas bypass flow valve 22, and the heat recovery flow valve 26 may be electrically operated valves, pneumatically operated valves, or hydraulically operated valves.

[0027] Continuing to refer to FIG. 1, in accordance with the block diagram of the control architecture of the power generation system shown in FIG. 2, the flow rate valves 21 and 22, and the heat recovery flow rate valve 26 operate as follows. For example, a gas turbine control unit 30, such as a computer or a programmable logic controller (PLC), receives the following input parameters: gas turbine parameters 31, combustion parameters 32, and NOx requirements 33. In particular, the gas turbine parameters 31 depend on the gas turbine technology. In some embodiments, the gas turbine parameters 31 include the gas turbine generated power, the gas turbine speed, and the gas turbine exhaust gas temperature. The combustion parameters 32 depend on the combustion technology employed by the gas turbine. In some embodiments, the combustion parameters 32 include the fuel-to-air ratio in a specific zone of the combustor, the distribution of the heat load along the combustor, and the NO x and NH3 slip. NO x requirements 33 include the NO in the exhaust stream downstream of the gas turbine x exhaust gas emissions. The total amount of gas (denoted as m1 and m2 respectively) supplied to the gas turbine through the gas turbine supply line 1 and the NH3 gas supply flow line 2 is a function of the above gas turbine parameters m1 + m2 = f(GT parameters)

[0028] The volume composition of the NH3 / H2 / N2 gas mixture stream in the gas turbine supply line 1 (denoted by reference numeral 34 in FIG. 2); the ratio 35 of the mass flow rate of NH3 gas (m2) through the NH3 gas supply flow line 2 to the total mass flow rate (m1 + m2) of the NH3 / H2 / N2 gas mixture stream (m1) through the gas turbine supply line 1 and the NH3 gas supply flow to the gas turbine through the NH3 gas supply flow line 2 is a function of the above combustion parameters and NO x requirements x 1i = f(combustion parameters; NO x requirements) m2 / (m1 + m2) = f(combustion parameters; NO x requirements)

[0029] These parameters are input to an auxiliary control unit 37, such as a computer or programmable logic control device (PLC), and are configured to control the operation of flow valves 21 and 22 and heat recovery flow valve 26 according to the following relationship: Operation Y of gas flow valve 21, which controls the amount of NH3 / H2 / N2 gas mixture flowing inside the gas turbine supply line 1. 21 This is a function of the total amount of gas flow m1 supplied to the gas turbine through gas turbine supply line 1 and NH3 gas supply flow m2 supplied to the gas turbine through NH3 gas supply line 2. Y 21 = f(m1+m2)

[0030] Operation Y of NH3 gas bypass flow valve 22 22 This is a function of the ratio 35 between the NH3 gas mass flow rate m2 through NH3 gas supply line 2 and the total mass flow rate of the NH3 / H2 / N2 gas mixture flow m1 through gas turbine supply line 1 and the NH3 gas supply flow m2 to the gas turbine through NH3 gas supply line 2. Y 22 = f(m2 / (m1+m2))

[0031] Finally, the operation of the heat recovery flow valve 26 is a function of the gas volume composition. Y 26 =f(x 1i )

[0032] The control method described above allows for changing the fuel composition to the gas turbine and injecting ammonia in any ratio according to any final combustor and gas turbine requirements (these requirements are not part of this disclosure).

[0033] Referring to Figures 1 and 2, Figure 3 shows a schematic diagram of an exemplary power generation system according to a second embodiment. The gas turbine 100 includes a compressor, a combustion chamber, and a turbine. The gas turbine 100 is supplied with an NH3 / H2 / N2 gas mixture flow, an NH3 gas flow, and an N2 gas flow. The NH3 / H2 / N2 gas mixture flow is guided to the primary stage of the gas turbine 100 through gas turbine supply line 1, the NH3 gas flow is guided to the secondary stage of the gas turbine 100 through NH3 gas supply flow line 2, and the N2 gas flow is guided to the secondary stage of the gas turbine 100 through N2 gas supply flow line 3. Furthermore, an NH3 adjustment gas turbine auxiliary system is located upstream of the gas turbine 100, and the gas turbine auxiliary system includes an NH3 heater / vaporizer / pressurizer 200 for heating and then vaporizing the NH3 liquid flow from the NH3 flow line 4, and a cracking reactor 300 connected to the NH3 heater / vaporizer / pressurizer via an NH3 heater / vaporizer / pressurizer gas outlet line 5 and a cracking reactor supply line 6.

[0034] According to this embodiment, the mixture of hydrogen, nitrogen, and unreacted ammonia resulting from the cracking reaction is treated to separate the NH3 / H2 / N2 gas mixture stream and the N2 gas stream. The NH3 / H2 / N2 gas mixture stream from the cracking reactor 300 is guided to the gas turbine 100 through the NH3 / H2 / N2 gas mixture outlet line 7, which is connected downstream of the gas turbine supply line 1.

[0035] Nitrogen separation can be achieved by different techniques. According to one embodiment, the NH3 cracking reactor 300 is a membrane reactor that operates as follows: The membrane separates the reactor into two separate sections. The first section is directly connected to the cracking reactor supply line 6. Ammonia supplied to the membrane reactor reacts inside the first section. A fraction of nitrogen resulting from the cracking reaction permeates through the membrane and moves to the second section of the membrane reactor, where it separates from hydrogen, unreacted ammonia, and the remaining fraction of nitrogen, which remain inside the first section of the membrane reactor.

[0036] The N2 gas flow from the cracking reactor 300 is directed to the gas turbine 100 through the N2 gas outlet line 8, which is connected downstream of the N2 gas supply flow line 3. One fraction of the N2 gas flow from the cracking reactor 300 is split and returned to the NH3 / H2 / N2 gas mixture outlet line 7 through the N2 gas bypass line 9, allowing control of the composition of the NH3 / H2 / N2 mixture flow directed to the gas turbine 100 through the gas turbine supply line 1.

[0037] The NH3 bypass flow is separated from the NH3 gas flow from the heater / vaporizer / pressurizer through the NH3 gas bypass flow line 11, which is connected upstream to the heater / vaporizer / pressurizer gas outlet line 5 and downstream to the NH3 gas supply flow line 2 of the gas turbine 100, specifically to the secondary stage of the gas turbine 100.

[0038] The composition of the NH3 / H2 / N2 mixture flow induced to the gas turbine 100 through the gas turbine supply line 1 is also controlled by mixing the NH3 / H2 / N2 gas mixture flow with ammonia. For this purpose, the NH3 gas bypass split flow is extracted from the NH3 gas bypass flow through the NH3 gas bypass split flow line 10, which is connected upstream of the NH3 gas bypass flow line 11 and downstream of the NH3 / H2 / N2 gas mixture outlet line 7.

[0039] This system allows the gas turbine control loop to control the ratio of NH3 burned along with H2 and N2 from the cracking reactor, according to the operational needs of the gas turbine.

[0040] The exhaust gas from the gas turbine 100 is sent to the exhaust gas flow line 15, from where a portion of the exhaust gas flow is separated and sent through the exhaust gas heat recovery line 12 to the cracking reactor 300 and / or the NH3 heater / vaporizer / pressurizer 200. Referring to Figure 3, the exhaust gas heat recovery line 12 is divided into a first heat recovery subline 13 that leads to the cracking reactor 300 and a second heat recovery subline 14 that leads to the NH3 heater / vaporizer / pressurizer 200.

[0041] An emergency system (not shown) is located along the gas turbine supply line 1 and includes a vent and an emergency valve to prevent overpressure.

[0042] The NH3 adjustment gas turbine auxiliary system shown in Figure 3 operates as follows: The system is started by heating / vaporizing / pressurizing liquid ammonia inside the NH3 heater / vaporizer / pressurizer 200 and supplying it in gaseous form to the NH3 cracking reactor 300. A portion of the gaseous ammonia from the NH3 heater / vaporizer / pressurizer 200 leaks into the NH3 gas bypass flow line 11 and is sent to the gas turbine 100 through the NH3 gas supply flow line 2. A portion of the heat generated by the gas turbine 100 is sent to the NH3 heater / vaporizer / pressurizer 200 and the NH3 cracking reactor 300. Furthermore, the liquid ammonia is heated, vaporized, and pressurized within the vaporizer / pressurizer 200, and the NH3 cracking reactor 300 begins to supply the gaseous mixture into the NH3 / H2 / N2 gas mixture outlet line 7. A storage drum (not shown) may optionally be placed along the NH3 / H2 / N2 gas mixture outlet line 7. When the pressure in the NH3 / H2 / N2 gas mixture outlet line 7 reaches a threshold, the gas turbine starting sequence may begin. Gas turbine ignition is achieved by using the flow supplied through gas turbine supply line 1 or NH3 gas supply flow line 2 as fuel and receiving NH3 gas flow from NH3 gas bypass flow line 11. If energy is not available to start the NH3 heater / vaporizer / pressurizer 200 and NH3 cracking reactor 300, a starting fuel such as natural gas may be connected to gas turbine supply line 1 or NH3 gas supply flow line 2 and used for gas turbine ignition and for the end of the gas turbine sequence or rise to full speed no-load state. Once the gas turbine is ignited, exhaust gas heat begins to provide energy to both the NH3 heater / vaporizer / pressurizer 200, which heats, vaporizes, and pressurizes liquid ammonia into gaseous ammonia, and the NH3 cracking reactor 300, which cracks the gaseous ammonia into a mixture of hydrogen, nitrogen, and unreacted ammonia. Once the appropriate mixture is created, the flow of the NH3 / H2 / N2 gas mixture inside the gas turbine supply line 1 is controlled according to the gas turbine control schedule.Throughout the entire sequence of the gas turbine (startup, load operation, and normal shutdown), the gas turbine control system manages the composition requirements of the mixture of hydrogen, nitrogen, and residual ammonia in the gas turbine supply line 1, acts on the parameters of the NH3 cracking reactor 300, and manages the flow rate ratio between the gas turbine supply line 1 and the NH3 gas supply flow line 2. Emergency shutdown of the gas turbine allows for the immediate isolation of the NH3 regulating gas turbine auxiliary system from the gas turbine, as well as the power cutoff of the NH3 heater / vaporizer / pressurizer 200 and the NH3 cracking reactor 300 in accordance with their specific safety requirements. The NH3 cracking reactor 300 also separates nitrogen from the gas mixture of hydrogen, nitrogen, and unreacted ammonia, and thus provides a flow of N2 into the N2 gas outlet line 8, which can be used for different purposes such as N2 storage or purging service for the gas turbine.

[0043] The operation of the NH3 regulating gas turbine auxiliary system in Figure 3 is controlled through a number of control valves that operate according to the control methods described below herein. A gas flow valve 21, i.e., valve 21, is located along the gas turbine supply line 1 and controls the flow of the NH3 / H2 / N2 gas mixture flow within the gas turbine supply line 1. An NH3 gas bypass flow flow valve 22 is located along the NH3 gas bypass flow line 11 and controls the flow of the NH3 gas bypass flow that is directed to the gas turbine through the NH3 gas supply flow line 2, and conversely, the flow of the NH3 gas flow that is directed to the cracking reactor 300 through the cracking reactor supply line 6. An NH3 gas bypass split flow flow valve 23 is located along the NH3 gas bypass split flow line 10 and controls the amount of NH3 gas bypass flow sent to the NH3 / H2 / N2 gas mixture outlet line 7 to control the composition of the NH3 / H2 / N2 mixture flow that is directed to the gas turbine 100 through the gas turbine supply line 1. The N2 gas bypass flow valve 24 is located along the N2 gas bypass line 9 and controls the flow of nitrogen in the N2 gas outlet line 8 from the NH3 cracking reactor 300, which is used to mix with the NH3 / H2 / N2 gas mixture flow that is guided to the gas turbine 100 through the gas turbine supply line 1. In addition, the gas turbine N2 supply flow flow valve 25 is located along the N2 gas supply flow line 3 and controls the flow of nitrogen in the N2 gas outlet line 8 that is guided from the NH3 cracking reactor 300 to the gas turbine 100. Finally, the heat recovery flow valve 26 is located on the first heat recovery subline 13 and controls a portion of the heat recovery flow of exhaust gas from the gas turbine 100 that is guided to the NH3 cracking reactor 300, and conversely, a portion of the heat recovery flow that is guided to the NH3 heater / vaporizer / pressurizer 200. The gas flow valve 21, the NH3 gas bypass flow flow valve 22, the NH3 gas bypass split flow flow valve 23, the N2 gas bypass flow flow valve 24, the gas turbine N2 supply flow flow valve 25, and the heat recovery flow valve 26 may be electrically operated valves, pneumatically operated valves, or hydraulically operated valves.

[0044] Continuing with Figure 3, according to the block diagram of the control architecture of the power generation system shown in Figure 4, the flow valves 21-25 and the heat recovery flow valve 26 operate as follows. The input parameters to the gas turbine control unit 30 are the gas turbine parameters 31, the combustion parameters 32, and the NOx requirement 33. The total amount of gas supplied to the gas turbine as the sum of the NH3 / H2 / N2 gas mixture flow (m1) through gas turbine supply line 1, the N2 gas supply flow (m3) through NH3 gas supply flow line 2, and the N2 gas supply flow line 3 is a function of the gas turbine parameters. m1 + m2 + m3 = f (GT parameters)

[0045] The volumetric composition of the NH3 / H2 / N2 gas mixture flow in gas turbine supply line 1 (indicated by reference numeral 34 in Figure 2); the ratio 35 of the NH3 gas mass flow rate m2 through NH3 gas supply line 2 to the total mass flow rate of the NH3 / H2 / N2 gas mixture flow m1 through gas turbine supply line 1 and the NH3 gas supply flow m2 to the gas turbine through NH3 gas supply line 2; and the ratio 36 of the N2 gas mass flow rate through N2 gas supply line 3 to the total mass flow rate of the NH3 / H2 / N2 gas mixture flow through gas turbine supply line 1 and the NH3 gas supply flow to the gas turbine through NH3 gas supply line 2 are functions of combustion parameters and NOx requirements. x 1i =f(combustion parameters; NOx requirements) m2 / (m1+m2)=f(combustion parameter; NOx requirement) m3 / (m1+m2)=f(combustion parameters); NOx requirements)

[0046] These parameters are inputs to the auxiliary control unit 37 and control the operation of the flow valves 21-25 and the heat recovery flow valve 26 according to the following relationship: Operation Y of the gas flow valve 21 which controls the amount of NH3 / H2 / N2 gas mixture flowing inside the gas turbine supply line 1. 21 m1, m2, and m3 are functions of the total amount of gas supplied to the gas turbine through gas turbine supply line 1, NH3 gas supply flow line 2, and N2 gas supply flow line 3. Y 21 = f(m1+m2+m3)

[0047] Operation Y of NH3 gas bypass flow valve 22 22 This is a function of the ratio 35 between the mass flow rate of NH3 gas through NH3 gas supply line 2 and the total mass flow rate of the NH3 / H2 / N2 gas mixture flow through gas turbine supply line 1 and the NH3 gas supply flow to the gas turbine through NH3 gas supply line 2. Y 22 = f(m2 / (m1+m2))

[0048] Operation Y of NH3 gas bypass split flow valve 23 23 This is a function of the volume composition of the NH3 / H2 / N2 gas mixture flow in the gas turbine supply line 1. Y 23 =f(x 1i )

[0049] Also, the operation Y of the N2 gas bypass flow valve 24 24 This is a function of the volume composition of the NH3 / H2 / N2 gas mixture flow in the gas turbine supply line 1. Y 24 =f(x 1i )

[0050] Operation Y of the N2 supply flow valve 25 of the gas turbine 25 This is a function of the ratio 36 between the mass flow rate m3 of N2 gas through N2 gas supply line 3 and the total mass flow rate of the NH3 / H2 / N2 gas mixture flow through gas turbine supply line 1 and the NH3 gas supply flow to the gas turbine through NH3 gas supply line 2. Y 25 =f(m3 / (m1+m2))

[0051] Finally, the operation of the heat recovery flow valve 26 is a function of the volume composition of the NH3 / H2 / N2 gas mixture flow in the gas turbine supply line 1. Y 26 =f(x 1i )

[0052] The control method described above allows for altering the fuel composition to the gas turbine and injecting ammonia and nitrogen in any ratio according to any final combustor and gas turbine requirements (these requirements are not part of this disclosure).

[0053] For example, if the combustor requires a hydrogen-rich fuel but a consistent inert fluid (N2) to reduce flame temperature and increase gas turbine output, Case 1 in Table 1 below is applicable. If the combustor requires a hydrogen-rich fuel but a consistent, separate ammonia injection to optimize NOx emissions, Case 3 in Table 1 is applicable. If the combustor does not require large amounts of hydrogen, large amounts of separated ammonia, and large amounts of separated nitrogen, Case 2 in Table 1 is applicable.

[0054] [Table 1]

[0055] Continuing with reference to Figures 1, 2, 3, and 4, Figure 5 illustrates a third example of a power generation system using a gas turbine and equipped with an ammonia cracking device. The same reference numerals specify the same or corresponding parts, elements, or components already illustrated in Figures 1, 2, 3, and 4 and described above, and are not described again here.

[0056] The embodiment shown in Figure 5 differs from the embodiment in Figure 3 in that at least a portion of the N2 gas flow from the cracking reactor 300 is not directed to the gas turbine 100 but is collected and used for a different purpose. According to this embodiment, the N2 gas outlet line 8 is connected downstream to the N2 gas extraction line 3'. A flow valve 25' is positioned along the N2 gas extraction line 3' to control the flow of nitrogen from the NH3 cracking reactor 300 to the N2 gas outlet line 8, which is directed for external use. The control method in this embodiment is the operation Y of the flow valve 25'. 25This differs from those described with reference to Figures 3 and 4 in that it is a function of requirements that do not constitute the objective of the present invention. Y 25′ =f(other requirements)

[0057] Continuing with reference to Figures 1, 2, 3, 4, and 5, Figure 6 illustrates a fourth embodiment of a power generation system using a gas turbine and equipped with an ammonia cracking device. The same reference numerals already illustrate in Figures 1, 2, 3, 4, and 5, and specify the same or corresponding parts, elements, or components described above, which are not described again here.

[0058] The embodiment shown in Figure 6 differs from the embodiments in Figures 3 and 5 in that the injection points of the gas turbine supply line 1 and the NH3 gas supply flow line 2 are swapped. Swapping the injection points may be necessary to consider different combustion techniques that can be applied to gas turbines, which involve different flame evolution along the flow paths inside the combustor. In particular, according to this embodiment, the gas turbine supply line 1 is directed to the secondary stage of the gas turbine 100, and the NH3 gas supply flow line 2 is directed to the primary stage of the gas turbine 100. The control method of this embodiment is the same as that described with reference to Figures 3 and 4.

[0059] Furthermore, referring to Figures 1 to 6, Figure 7 illustrates a fifth embodiment of a power generation system using a gas turbine and equipped with an ammonia cracking device. The same reference numerals specify the same or corresponding parts, elements, or components already illustrated in Figures 1 to 6 and described above, and are not described again here.

[0060] The embodiment shown in Figure 7 differs from the embodiments in Figures 3 to 6 in that at least a portion of the N2 gas flow from the cracking reactor 300 is not directed to the gas turbine 100 but is collected and used for a different purpose, and the injection points of the gas turbine supply line 1 and the NH3 gas supply flow line 2 are swapped. In particular, according to this embodiment, the gas turbine supply line 1 is directed to the secondary stage of the gas turbine 100, and the NH3 gas supply flow line 2 is directed to the primary stage of the gas turbine 100. Furthermore, the N2 gas outlet line 8 is connected downstream to the N2 gas extraction line 3'. The control method of this embodiment is the same as that described with reference to Figure 5.

[0061] Continuing with Figures 1-7, Figure 8 illustrates a sixth embodiment of a power generation system using a gas turbine and equipped with an ammonia cracking device. The same reference numerals specify the same or corresponding parts, elements, or components already illustrated in Figures 1-7 and described above, and are not described again here.

[0062] The embodiment shown in Figure 8 differs from the embodiments in Figures 3 to 7 in that at least a portion of the N2 gas flow from the cracking reactor 300 is not directed to the gas turbine 100 but is sent to the NH3 gas supply flow line 2. In particular, according to this embodiment, at least a portion of the N2 gas flow from the cracking reactor 300 is used to purge the NH3 gas supply flow line 2 when necessary.

[0063] Continuing with reference to Figures 1 to 8, Figures 9 to 12 illustrate several embodiments of a system comprising a gas turbine 100, an NH3 regulating gas turbine auxiliary system, and a fuel cell 500. These embodiments differ from the illustrative non-claimed embodiments in Figures 1 to 8 in that they further comprise a fuel cell 500. Furthermore, while the embodiments illustrated in Figures 1 to 8 were described as comprising an NH3 bypass line connected to the gas turbine 100 via an NH3 gas supply flow line that guides the NH3 flow to the bypass line, the power generation systems illustrated in Figures 9 to 12 do not necessarily require an NH3 bypass line, and therefore, it will be apparent to those skilled in the art that the power generation systems shown in Figures 9 to 12 may or may not have an NH3 bypass line. Figure 9, in particular, illustrates a first embodiment of a power generation system that does not include an NH3 bypass line. The same reference numerals specify the same or corresponding parts, elements, or components already illustrated in Figures 1 to 8 and described above.

[0064] Although not shown in Figures 9 to 12, it will be apparent to those skilled in the art that the power generation systems described below in this specification may comprise a plurality of gas turbines 100 and / or a plurality of fuel cells 500. Each of the one or more gas turbines 100 can operate in power generation mode or as a mechanical drive unit. The plurality of fuel cells 500 may be of the same type or different types.

[0065] In Figure 9, the fuel cell 500 is located downstream of the gas turbine 100 and supplied using separate flows of ammonia and / or hydrogen to generate electricity and / or heat to power / heat auxiliary equipment or serve other purposes. In this embodiment, the system allows for the decomposition of ammonia at high temperatures, such as 100°C or higher, preferably above 200°C, and enables the fuel cell 500 to operate at high temperatures.

[0066] The system generates power, such as mechanical power, by the gas turbine 100, and / or electricity by at least one of the gas turbine 100 and the fuel cell 500. In this way, when the gas turbine 100 operates in power generation mode or as a mechanical drive for oil and gas applications or industrial applications, the combined use of the gas turbine 100 and the fuel cell 500 allows for the utilization of the capabilities of both technologies and provides a versatile approach that can be adapted to different scenarios. For example, in liquefied natural gas (LNG) and natural gas (NG) plants, the gas turbine 100 can be used for mixed refrigerant (MR) or propane refrigerant (PR), and the fuel cell 500 can be used to supply power to plant auxiliary equipment equipped with storage devices.

[0067] The NH3 adjustment gas turbine auxiliary system is located upstream of the gas turbine 100 and is configured to process the ammonia feed stream to obtain a decomposition gas containing at least hydrogen and nitrogen, preferably an NH3 / H2 / N2 gas mixture.

[0068] The gas turbine 100 is coupled to a separator and supplied with a gas mixture, preferably a mixture containing hydrogen and / or nitrogen. The turbine then generates electricity and heat. The latter is transported to a heat recovery steam generator (HRSG) 110 having a post-combustion module, which can provide enough heat to decompose ammonia at high temperatures and / or heat the reactant flow, such as the N2 / NH3 / H2 flow, preferably the H2 or NH3 flow, used in the system.

[0069] As described with reference to Figures 1 to 8, in Figure 9, the gas turbine auxiliary system includes an ammonia cracking reactor 300 configured to decompose ammonia into a gas mixture of hydrogen, nitrogen, and unreacted or residual ammonia, which is then sent to a heat exchanger 710 and subsequently to a separation module 720. The ammonia cracking reactor 300 may be, for example, a catalyst, a heat reactor, or a membrane reactor.

[0070] The system further comprises a separator configured to separate a gas mixture of hydrogen, nitrogen, and unreacted or residual ammonia into separate streams of hydrogen, nitrogen, and ammonia.

[0071] The separator may be located downstream of the cracking reactor 300 and comprises at least one of a heat exchanger 710, a separation module 720, and a membrane which may be part of or outside the membrane reactor itself.

[0072] The heat exchanger 710 may be supplied by the gas mixture outlet line of the cracking reactor 300, and then the cooled gas mixture may be supplied to the separation module 720 through the connection line 75.

[0073] The separation module 720 may be a pressure swing adsorption (PSA) separator that separates gas species from a gas mixture using pressure according to the molecular properties of the species and their affinity for the adsorbent material provided therein. The separation module 720 allows for the recovery of unreacted or residual ammonia, thus maximizing the overall system efficiency. The separation module 720 can be connected downstream of the heat exchanger 710.

[0074] The heat exchanger 710 is configured to preheat the ammonia flow and / or hydrogen flow entering the fuel cell 500 to a set temperature sufficient to operate the fuel cell 500. In this way, the heat exchanger provides sufficient heat to operate the fuel cell 500 at a high temperature, for example, at least 600°C, preferably 600°C to 700°C, when the ammonia and / or hydrogen preheated by the heat exchanger 710 are supplied to the fuel cell 500. However, as will be apparent to those skilled in the art, any gas leaks in the power generation system, such as H2, N2, NH3, and / or gas mixtures, may be delivered to the fuel cell 500 after being heated if required by the requirements of the fuel cell 500.

[0075] For example, in Figure 9, the separation module 720 provides separated flows of hydrogen and ammonia to the heat exchanger 710, which then heats the corresponding flows to enable high-temperature operation of the fuel cell 500. In Figure 9, the ammonia flow is supplied from the separation module 720 to the heat exchanger 710 through the connection line 74.

[0076] The separator includes one or more outlet lines for transporting separate flows of hydrogen, nitrogen, and ammonia to the respective modules of a power generation system, such as a gas turbine 100, an HRSG 110, a fuel cell 500, and / or a cracking reactor 300. For example, the separator includes a first separator outlet line 71 and a second separator outlet line 72.

[0077] A first separator outlet line 71, which connects the heat exchanger 710 to the fuel cell 500, delivers the ammonia flow to the fuel cell 500. The ammonia flow provided by the heat exchanger 710 can be cooled to the required temperature. For example, if a temperature of 200°C is required to operate the fuel cell 500, and the heat exchanger 710 outputs an ammonia flow at a temperature of at least 600°C, then, in order to operate the fuel cell 500 according to the specific fuel cell requirements / technology, the ammonia flow can be cooled to the required temperature by a further heat exchanger (not shown in Figure 9) before it enters the fuel cell 500. The further heat exchanger may be provided in the first separator outlet line 71. The first separator outlet line 71 can also be connected to the cracking reactor 300 and / or post-combustion module through a connecting line 71a to deliver the ammonia flow thereto, as shown in Figure 9.

[0078] The second separator outlet line 72 supplies a hydrogen flow to the fuel cell 500. In this embodiment, the second separator outlet line 72 comprises a first outlet section 72a for transporting a hydrogen flow from the separation module 720 to the heat exchanger 710, and a second outlet section 72b for transporting a preheated hydrogen flow from the heat exchanger 710 to the fuel cell 500 at a temperature required to enable the fuel cell 500 to operate according to specific fuel cell requirements / technology. The second separator outlet line 72 may also be connected to the respective components of the gas turbine 100 and / or after-combustion module to transport at least a portion of the hydrogen flow to these modules, as shown in Figure 9.

[0079] The separator may also include a third separator outlet line 73, as shown in Figure 9, which is open to the atmosphere or, optionally, connected to the gas turbine 100 to transport the nitrogen flow to the gas turbine 100.

[0080] The gas turbine 100 may be equipped with an HRSG 110 for recovering at least a portion of the heat from the exhaust gas flow 15 from the gas turbine 100 and directing at least a portion of the heat to an ammonia cracking reactor 300 to provide it with thermal output.

[0081] In some embodiments, NO from the gas turbine 100 x To further reduce emissions, the HRSG 110 is designed for dry low NO combustion systems, particularly for gas turbines. x (dry low NO x When not DLN or dry low emission (DNE), ammonia or urea is used as a reducing agent for NO x A selective catalytic reduction (SCR) system can be provided to offer selective catalytic reduction. Therefore, the proposed system configuration shown in Figure 9 makes it possible to further reduce the environmental impact of the entire system.

[0082] The HRSG110 may include a post-combustion module, which receives and processes at least a portion of the hydrogen flow from the separator outlet line 72 and / or the ammonia flow from the connection line 71a together with the exhaust gas flow 15, generating additional heat, and transporting at least a portion of the additional heat to the ammonia cracking reactor 300, thereby enabling the decomposition of ammonia at high temperatures while increasing the overall efficiency of the system.

[0083] The power generation system may also include a heat exchanger, such as a second heat exchanger (not shown in Figure 9), configured to preheat the ammonia feed stream entering the ammonia cracking reactor 300 and / or fuel cell 500 by using the heat generated by the gas turbine auxiliary system and / or gas turbine 100. Alternatively, the ammonia feed stream entering the ammonia cracking reactor 300 may be supplied to the ammonia cracking reactor 300 at the required temperature by an external heating system.

[0084] Alternatively, or in addition, the power generation system may include a third heat exchanger 800 for preheating the air entering the fuel cell 500. The third heat exchanger 800 may use at least a portion of the electricity generated by the fuel cell 500 to heat the clean air downstream of the filter house of the gas turbine 100.

[0085] The remaining heat generated by the fuel cell 500 can be transferred to the ammonia cracking reactor 300 to provide additional heat for the decomposition of ammonia, or it can be transferred outside the system for external use.

[0086] The power generation system may include at least one compression system configured to regulate fluid pressure and / or transport fluid outside the system for external use. The fluid may include any fluid in the system, such as a gas mixture generated by a gas turbine auxiliary system, a flow of hydrogen, a flow of nitrogen, or a flow of ammonia.

[0087] The power generation system may include one or more storage units (not shown in Figure 9) for storing NH3, H2, heat, electricity, and / or N2. For example, the first separator outlet line 71 may include an ammonia storage system located along the outlet line 71, the second separator outlet line 72 may include a hydrogen storage system located along the outlet line 72, and the third separator outlet line 73 may include a nitrogen storage system located along the outlet line 73.

[0088] Continuing with Figure 9, Figure 10 illustrates a second embodiment of a power generation system using a gas turbine 100 and comprising an ammonia cracking unit 300 and a fuel cell 500. The same reference numerals represent the same or corresponding parts, elements, or components already illustrated in Figure 9 and described above, and are not described again here.

[0089] The embodiment shown in Figure 10 differs from the embodiment in Figure 9 in that the system does not include an HRSG with a combustion module. The gas turbine exhaust flow 15 provides sufficient heat to the ammonia cracking reactor 300 to enable its operation. Thus, the system shown in Figure 10 allows the fuel cell 500 to operate at a high temperature while ammonia is decomposed at a low temperature.

[0090] Continuing with reference to Figures 9 and 10, Figure 11 illustrates a third embodiment of a power generation system using a gas turbine 100 and comprising an ammonia cracking device 300 and a fuel cell 500. The same reference numerals represent the same or corresponding parts, elements, or components already illustrated in Figures 9 and 10 and described above, and are not described again here.

[0091] The embodiment shown in Figure 11 differs from the embodiment in Figure 9 in that it does not include at least a first outlet section 72a for transporting a hydrogen flow from the separation module 720 to the heat exchanger 710, and a second outlet section 72b for transporting a preheated hydrogen flow from the heat exchanger 710 to the fuel cell 500. The embodiment in Figure 11 further differs in that the separator outlet line 71 is not connected to the fuel cell 500.

[0092] In contrast to Figure 9, in Figure 11, the ammonia flow from the connection line 74 and / or the hydrogen flow from the second separator outlet line 72 are not preheated and are supplied directly to the fuel cell 500 by the separation module 720. Therefore, the ammonia and / or hydrogen flows are supplied to the fuel cell 500 at low temperatures, such as below 100°C, preferably 60°C to 80°C. For example, the hydrogen flow is supplied to the fuel cell 500 using the second separator outlet line 72, while the ammonia flow is supplied in this case using another outlet line 74 connecting the separation module 720 to the fuel cell 500. Additionally or alternatively, the ammonia flow can be supplied directly to the fuel cell 500 from the ammonia input flow entering the ammonia cracking reactor 300 and / or preheater 710 to provide sufficient ammonia for the fuel cell 500. The configuration shown in Figure 11 allows the fuel cell 500 to operate at a low temperature, such as below 100°C, preferably 60-80°C, while the ammonia cracking reactor 300 can operate at a high temperature, such as above 700°C, preferably 700-800°C.

[0093] Continuing with reference to Figures 9 to 11, Figure 12 illustrates a fourth embodiment of a power generation system that uses a gas turbine 100 and includes an ammonia cracking device 300 and a fuel cell 500. The same reference numerals specify the same or corresponding parts, elements, or components already illustrated in Figures 9 to 11 and described above, and are not described again here.

[0094] The embodiment shown in Figure 12 differs from the embodiment in Figure 9 in that it does not include an HRSG with a combustion module. In Figure 12, the gas turbine exhaust flow 15 provides sufficient heat to the ammonia cracking reactor 300 to perform low-temperature decomposition of ammonia, such as the decomposition of ammonia at a temperature of 350°C to 700°C, preferably 350°C to 550°C.

[0095] Figure 12 differs further from the embodiment in Figure 9 in that it does not include a first outlet section 72a for transporting the hydrogen flow from the separation module 720 to the heat exchanger 710, and a second outlet section 72b for transporting the preheated hydrogen flow from the heat exchanger 710 to the fuel cell 500. Also, the separator outlet line 71 is not connected to the fuel cell 500.

[0096] In contrast to Figure 9, in Figure 12, the ammonia flow from the connection line 74 and / or the hydrogen flow from the second separator outlet line 72 are not preheated and are supplied directly to the fuel cell 500 by the separation module 720. Therefore, the ammonia and / or hydrogen flows are supplied to the fuel cell 500 at low temperatures, such as below 100°C, preferably 60°C to 80°C. In particular, the hydrogen flow is supplied to the fuel cell 500 using the second separator outlet line 72, while the ammonia flow is supplied in this case using another outlet line 74 that directly connects the separation module 720 to the fuel cell 500. Additionally or alternatively, the ammonia flow can be supplied directly to the fuel cell 500 from the ammonia input flow entering the ammonia cracking reactor 300 and / or preheater 710 to provide sufficient ammonia as required by the fuel cell 500. The configuration shown in Figure 12 allows the fuel cell 500 to operate at low temperatures while the ammonia cracking reactor 300 operates at high temperatures.

[0097] While aspects of the present invention have been described in relation to various specific embodiments, it will be apparent to those skilled in the art that many modifications, changes, and omissions are possible without departing from the spirit and scope of the claims. In addition, unless otherwise specified herein, the order or arrangement of any process or method steps may be changed or rearranged according to alternative embodiments.

Claims

1. Gas turbine (100), fuel cell (500), and NH ３ A power generation system comprising a regulating gas turbine auxiliary system, Said NH ３ A regulating gas turbine auxiliary system processes the ammonia feed stream to produce a decomposition gas containing at least hydrogen and nitrogen, preferably NH ３ / H ２ / N ２ It is configured to obtain a gas mixture, Said NH ３ The regulating gas turbine auxiliary system includes an ammonia cracking reactor (300), which is configured to decompose ammonia into a gas mixture of hydrogen, nitrogen, and residual ammonia. The separator is coupled to the gas turbine (100) and is configured to separate the gas mixture into separate flows of hydrogen, nitrogen, and ammonia, and the separator is A first separator outlet line (71, 74) connected to the fuel cell (500) for transporting the ammonia flow to the fuel cell (500), and A power generation system comprising at least one of two separator outlet lines (72, 72b) connected to the fuel cell (500) for transporting the hydrogen flow to the fuel cell (500).

2. The power generation system according to claim 1, wherein the separator includes a membrane.

3. The separator further comprises a gas mixture outlet line of the cracking reactor (300) connected to the separator, and the separator is Heat exchanger (710), and The power generation system according to claim 1 or 2, comprising at least one of the separation modules (720), preferably a pressure swing adsorption (PSA), configured to separate the gas mixture using pressure.

4. The power generation system according to claim 3, wherein the heat exchanger (710) is configured to supply the cooled gas mixture to the separation module (720).

5. The power generation system according to claim 3 or 4, wherein the heat exchanger (710) is configured to heat at least one of the ammonia flow and the hydrogen flow to at least a temperature sufficient to operate the fuel cell (500) at a high temperature.

6. The power generation system according to claim 3 or 4, wherein the separation module (720) is configured to supply the separated hydrogen and / or ammonia stream to the fuel cell (500) at a temperature sufficient to allow the fuel cell (500) to operate at a low temperature.

7. The system further comprises at least one compression system, and the at least one compression system is Adjusting the fluid pressure, It is configured to transport fluid to the outside of the system for external use, The power generation system according to any one of claims 1 to 6, wherein the fluid comprises at least one of the gas mixture, the hydrogen flow, the nitrogen flow, and the ammonia flow.

8. The power generation system according to any one of claims 1 to 7, wherein the first separator outlet line (71) comprises an ammonia storage system arranged along the outlet line (71).

9. The power generation system according to any one of claims 1 to 8, wherein the second separator outlet line (72, 72b) comprises a hydrogen storage system arranged along the outlet line (72, 72b).

10. The power generation system according to any one of claims 1 to 9, wherein the separator comprises a third separator outlet line (73) connected to the gas turbine (100) for transporting the flow of nitrogen to the gas turbine (100), and preferably the third separator outlet line (73) comprises a nitrogen storage system arranged along the outlet line (73).

11. The power generation system according to any one of claims 1 to 10, wherein the gas turbine (100) is provided with a heat recovery steam generator HRSG (110) for recovering at least a portion of the heat from the exhaust gas flow (15) from the gas turbine (100) and for transporting the at least portion of the heat to the ammonia cracking reactor (300).

12. The power generation system according to claim 11, wherein the HRSG (110) includes a selective catalytic reduction (SCR) system.

13. The power generation system according to claim 11 or 12, further comprising a post-combustion module configured to receive and process at least a portion of the hydrogen and / or ammonia flow, generate additional heat, and transport at least a portion of the additional heat to the ammonia cracking reactor (300).

14. The power generation system according to any one of claims 1 to 13, further comprising a second heat exchanger configured to preheat the ammonia feed stream entering the ammonia cracking reactor (300) and / or the fuel cell (500), wherein the gas turbine auxiliary system is configured to generate heat and transport at least a portion of the heat to the second heat exchanger.

15. A power generation system according to any one of claims 1 to 14, comprising a third heat exchanger (800) for preheating the air entering the fuel cell (500), wherein at least a portion of the electricity generated by the fuel cell (500) is transported to the third heat exchanger (800), and preferably the remaining portion of the heat generated by the fuel cell (500) is transported to the ammonia cracking reactor (300).

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