NH3 Adjustment Gas Turbine Auxiliary System

Abstract

A system for generating electricity using a gas turbine is disclosed. The system includes an ammonia cracking device for converting at least a portion of the NH3 flow into H2 and N2 to create an NH3 / H2 / N2 gas mixture that enables the gas turbine to operate under all conditions. In one embodiment, the NH3 flow is split into a first NH3 flow that is cracked into H2 and N2 through cracking to obtain an H2 and N2 flow, and a second NH3 flow that is guided to the gas turbine through a bypass line, and the power generation system also includes a cracking reactor gas mixture splitting flow line (310) connecting the ammonia cracking reactor (300) to other services (400).

Description

[Technical Field]

[0001] This disclosure relates to a system for generating electricity using a gas turbine, the system comprising an ammonia cracking device. The embodiments disclosed herein specifically relate to an NH3 regulating gas turbine auxiliary system, the fuel skid processing the ammonia feedflow to achieve an NH3 / H2 / N2 gas mixture that enables the gas turbine to operate under all conditions. Furthermore, this disclosure optimizes the operation of the gas turbine and reduces NO from the gas turbine under all gas turbine conditions. x Methods for controlling emissions are disclosed. [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 flow 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 embodiments in which the composition of the mixture of hydrogen and nitrogen 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 device, a cracked gas line, and a cracked gas compressor. The heating device heats ammonia and thermally decomposes ammonia to convert ammonia into cracked gas comprising hydrogen gas and nitrogen gas. The cracked gas line delivers the cracked gas from the heating device to the gas turbine. The cracked gas compressor increases the pressure of the cracked gas to a pressure equal to or higher than a supply pressure at which the cracked gas can be supplied to the gas turbine. U.S. Patent No. 11156168 (B2) also discloses a control device that adjusts the ratio of the flow rate of cracked gas to the total flow rate of fuel gas (including natural gas and cracked gas). Control of such a ratio enables obtaining and adjusting the mixture of cracked gas and natural gas to the combustion chamber. However, combustion of natural gas still produces high levels of carbon dioxide, which is either released to 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 with an engine such as an engine that can be used in aerospace or other vehicle applications. The propulsion system further comprises a fuel cell module, and the ammonia cracking module is thermally balanced with both the engine module and the fuel cell module. In addition to this system being only suitable for vehicle or aircraft applications, the integration between the ammonia cracking module and the fuel cell is performed to thermally balance the system by coupling a heat exchanger downstream of the combustion chamber to exchange heat and power a low-pressure turbine. Furthermore, the decomposed ammonia is supplied in a continuous flow first to the combustion chamber and the turbine, then to the heat exchanger, and finally only to the fuel cell.

[0009] In conclusion, solutions in the prior art either negatively affect the operating cost of the system or adversely affect the environment. Therefore, to address the problem of real-time adjustment of NH₃ to achieve an NH₃ / H₂ / N₂ gas mixture that enables operation of a gas turbine under all conditions, an improved system for power generation using a gas turbine and ammonia as fuel would be beneficial and welcome in the art. NH₃ adjustment needs to be performed flexibly along the path towards the turbine and adjusted at different levels, and therefore, an NH₃ recovery system can also not only improve performance, but also NO x there is a recognized need for a system capable of adjusting and supplying fuel to a gas turbine in different stages to also reduce emissions. More generally, it is desirable to provide a method and system adapted to more efficiently address the problems arising from providing an auxiliary NH₃ adjustment system, to achieve an NH₃ / H₂ / N₂ gas mixture that enables operation of a gas turbine under all conditions. Summary of the Invention

[0010] In one embodiment, the subject matter disclosed herein relates to an improved system for generating electricity using a gas turbine and ammonia as fuel, the system comprising an ammonia cracking device, and the fuel skid processes the ammonia feed stream to realize a first NH3 / H2 / N2 gas mixture that enables the gas turbine to operate under all conditions, and a second gas mixture of nitrogen, hydrogen and residual ammonia, or a second gas mixture of residual ammonia and at least one of nitrogen or hydrogen, or a second gas mixture of nitrogen and hydrogen, such as a first NH3 / H2 / N2 gas mixture that enables the gas turbine to operate under all conditions, and other services, such as a first NH3 / H2 / N2 gas mixture that enables the gas turbine to operate under all conditions, and a second gas mixture of nitrogen, hydrogen and residual ammonia, or a second gas mixture of nitrogen and hydrogen, and a second gas mixture of nitrogen, hydrogen storage solution, hydrogen distribution via pipeline, hydrogen for refueling stations, etc.

[0011] In another embodiment, the subject matter disclosed herein takes into consideration that the amount of H2 produced is greater than the amount required by the gas turbine. In yet another further embodiment, the amount of H2 produced may depend on the availability of exhaust gases. In particular, exhaust gases may be directed to a cracking reactor and used to produce a fuel mixture containing hydrogen and nitrogen, or hydrogen, nitrogen, and ammonia.

[0012] In another embodiment, the subject disclosed herein considers that a gas turbine is supplied with a flow of a gas mixture of nitrogen and hydrogen, the amount of hydrogen being about three times the amount of nitrogen (by volume), the remainder coming from the cracker due to excess heat is sent downstream of the system for other uses, and unreacted ammonia (if present) is sent back (recirculated) to the cracking reactor.

[0013] In another embodiment, the subject matter disclosed herein is supplied to a gas turbine with a flow of a gas mixture of nitrogen and hydrogen, and some or all of the unreacted ammonia to be burned in the gas turbine, and the gas mixture also contains ammonia, with the amount of hydrogen being about three times the amount of nitrogen (by volume).

[0014] In another embodiment, the subject matter disclosed herein relates to a gas turbine and a method for generating electricity using ammonia as fuel. An ammonia adjustment auxiliary system operates through control routines as a function of GT parameters, combustion parameters, NOx requirements in the GT exhaust, and exhaust gas parameters. [Brief explanation of the drawing]

[0015] Many of the disclosed embodiments of the present invention and their associated advantages will be better understood by referring to the following embodiments for carrying out the invention, and a more complete understanding will be easily obtained, as they will be better understood when considered in relation to the accompanying drawings. [Figure 1] This is a schematic diagram of a power generation system that uses a gas turbine and is equipped with an ammonia cracking device according to the first embodiment. [Figure 2] Figure 1 is a block diagram of the control architecture of the power generation system. [Figure 3a] This is a schematic diagram of a power generation system that uses a gas turbine and is equipped with an ammonia cracking device according to the second embodiment. [Figure 3b] This is a schematic diagram of a power generation system that uses a gas turbine and includes an ammonia cracking device according to the third embodiment. [Figure 3c] This is a schematic diagram of a power generation system that uses a gas turbine and is equipped with an ammonia cracking device according to the fourth embodiment. [Figure 4] This is a schematic diagram of a power generation system that uses a gas turbine and is equipped with an ammonia cracking device according to the fifth embodiment. [Figure 5]This is a schematic diagram of a power generation system that uses a gas turbine and is equipped with an ammonia cracking device according to the sixth embodiment. [Figure 6] Figure 5 is a block diagram of the control architecture of the power generation system. [Figure 7] This is a schematic diagram of a power generation system that uses a gas turbine and is equipped with an ammonia cracking device according to the seventh embodiment. [Figure 8] Figure 7 is a block diagram of the control architecture of the power generation system. [Figure 9] This is a schematic diagram of a power generation system that uses a gas turbine and is equipped with an ammonia cracking device according to the eighth embodiment. [Figure 10] This is a schematic diagram of a power generation system that uses a gas turbine and is equipped with an ammonia cracking device according to the ninth embodiment. [Figure 11] This is a schematic diagram of a power generation system that uses a gas turbine and is equipped with an ammonia cracking device according to the tenth embodiment. [Figure 12] This is a schematic diagram of a power generation system that uses a gas turbine and is equipped with an ammonia cracking device according to the 11th embodiment. [Figure 13] This is a schematic diagram of a power generation system that uses a gas turbine and includes an ammonia cracking device and a fuel cell according to the twelfth embodiment. [Figure 14] This is a schematic diagram of a power generation system using a gas turbine and equipped with an ammonia cracking device and a fuel cell according to the 13th embodiment. [Figure 15] This is a schematic diagram of a power generation system using a gas turbine and equipped with an ammonia cracking device and a fuel cell according to the 14th embodiment. [Figure 16] This is a schematic diagram of a power generation system using a gas turbine and equipped with an ammonia cracking device and a fuel cell according to the 15th embodiment. [Modes for carrying out the invention]

[0016] In one embodiment, 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 to H2 and N2 in order to obtain a first NH3 / H2 / N2 gas mixture that enables the gas turbine to operate under all conditions, and a gas turbine auxiliary system for NH3 adjustment, wherein the NH3 supply stream is split into two separate NH3 streams, the first NH3 stream being split into H2 and N2 through a catalytic cracking reactor or a thermal cracking reactor to obtain H2 and N2 streams, and finally decomposed into residual ammonia, and the second NH3 stream being led to a bypass line. In particular, downstream of the cracking reactor, the H2 and N2 streams, and finally the residual ammonia stream, are mixed with the second NH3 stream to obtain an NH3 / H2 / N2 gas mixture having a controlled ratio of NH3 on the one hand and H2 and N2 on the other. 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 with controlled ratios of NH3, H2, and N2, and in addition, N2 can be used as a purge gas.

[0017] 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 the phrase “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.

[0018] 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.

[0019] 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 a first NH3 / H2 / N2 gas mixture flow and an NH3 gas flow. The first 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. According to alternative exemplary embodiments, the NH3 heater / vaporizer / pressurizer consists of a shell-and-tube heat exchanger or a plate heat exchanger. In some embodiments, the heat conduction fluid of the heater / vaporizer / pressurizer is gas turbine exhaust gas or another intermediate fluid (such as steam or heat transfer oil). According to exemplary embodiments, 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.

[0020] According to the exemplary embodiment shown in Figure 1, the NH3 cracking reactor 300 is a catalytic or 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.

[0021]

number

[0022] The mixture of hydrogen and nitrogen produced from the cracking reaction, along with any unreacted or residual ammonia present, 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.

[0023] The NH3 bypass flow is separated from the NH3 gas flow from the heater / vaporizer / pressurizer through the NH3 gas bypass 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.

[0024] 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.

[0025] 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 through the exhaust gas heat recovery line 12 and sent 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. In particular, if the amount of exhaust gas exceeds a predetermined threshold of exhaust gas required to operate the gas turbine 100, such an additional amount of exhaust gas is used to generate excess H2 supplied to other services.

[0026] 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.

[0027] 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 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 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 rise to the end of the gas turbine sequence or 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 final unreacted or residual ammonia. Once the appropriate mixture is produced, the flow of the NH3 / H2 / N2 gas mixture inside 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.

[0028] 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 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, pneumatically operated, or hydraulically operated valves.

[0029] With continued reference to FIG. 1, in accordance with the block diagram of the control architecture of the power generation system shown in FIG. 2, the flow valves 21 and 22, and the heat recovery flow 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 NO x requirements 33. In particular, the gas turbine parameters 31 depend on the gas turbine technology. In some embodiments, the gas turbine parameters 31 include gas turbine generated power, gas turbine speed, and 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 heat load along the combustor, and NO at the outlet of the combustor x and NH3 slip. NO x requirements 33 include NO in the exhaust stream downstream of the gas turbine x exhaust gas emissions. The total amount of gas (indicated by m1 and m2, respectively) supplied to the gas turbine through the gas turbine supply line 1 and the NH3 gas supply line 2 is a function of the aforementioned gas turbine parameters. m1+m2=f(GT parameters)

[0030] Volume composition of the NH3 / H2 / N2 gas mixture stream in the gas turbine supply line 1 (indicated by reference numeral 34 in FIG. 2); the ratio 35 of the NH3 gas mass flow rate (m2) through the NH3 gas supply 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 stream (m2) to the gas turbine through the NH3 gas supply line 2 is a function of the aforementioned combustion parameters and NO x requirements. x 1i =f(combustion parameters; NO x requirements) m2 / (m1+m2)=f(combustion parameters; NO xRequirements)

[0031] These parameters are inputs to an auxiliary control unit 37, such as a computer or programmable logic control device (PLC), 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)

[0032] 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))

[0033] Finally, the operation of the heat recovery flow valve 26 is a function of the gas volume composition.

[0034] Y 26 =f(x 1i )

[0035] The control method described above allows for the modification of the fuel composition to the gas turbine and the injection of ammonia in any ratio according to any final combustor and gas turbine requirements (these requirements are not part of this disclosure).

[0036] Further embodiments of the power generation system are shown in Figures 3a, 3b, 3c, 4, and 5, continuing with reference to Figures 1 and 2. The same reference numerals represent the same or corresponding parts, elements, or components already illustrated in Figure 1 and described above, and are not described again here. Specifically, according to the embodiments shown with reference to Figures 3a, 3b, 3c, 4, and 5, the amount of H2 produced by the NH3 cracking reactor 300 is greater than the amount required by the gas turbine 100 and can be used for other services. These other services include, but are not limited to, hydrogen storage solutions, hydrogen distribution via pipelines, hydrogen for refueling stations, hydrogen compression for tube trailer refueling stations, and hydrogen for industrial decarburization (e.g., smelters, steel). In particular, the power generation system shown in Figure 2 includes a cracking reactor gas mixture splitting flow line 310 that connects the ammonia cracking reactor 300 to other services 400. In contrast, in the exemplary embodiment shown in Figure 3a, the cracking reactor gas mixture splitting flow line 310, which connects the ammonia cracking reactor to other services 400, is withdrawn from the cracking reactor gas mixture outlet line 7. The cracking reactor gas mixture splitting flow line 310 is a flow line that exits directly from the cracking reactor and connects the cracking reactor to other services, or is withdrawn from the cracking reactor gas mixture outlet line 7. As shown in Figure 3b, a separator 700 may be located downstream of the cracking reactor gas mixture splitting flow line 310, and the separator is configured to separate a flow containing a second gas mixture of nitrogen and hydrogen and residual ammonia, or a second gas mixture of residual ammonia and at least one of nitrogen or hydrogen, or a second gas mixture of nitrogen and hydrogen, or a second gas mixture of nitrogen or hydrogen or ammonia.The mixture and / or purified components enable the operation of other services, for example, but are not limited to, hydrogen storage solution, hydrogen distribution via pipeline, hydrogen for refueling stations, hydrogen compression for tube trailer refueling stations, hydrogen for industrial decarburization (e.g., smelters or steel), nitrogen storage solution, nitrogen distribution via pipeline, nitrogen for refueling stations, ammonia storage solution, ammonia distribution via pipeline, and ammonia for refueling stations. In particular, as shown in Figure 3c, the separator 700 can be configured to separate the NH3 flow that is recirculated to the cracking reactor supply line 6 through the NH3 flow recirculation line 320. Furthermore, in the power generation system shown in Figure 4, the flow valve 27 is located along the cracking reactor gas mixture splitting flow line 310, and the flow valve 27 may be an electrically operated valve, a pneumatically operated valve, or a hydraulically operated valve, among other types of valves.

[0037] Continuing to refer to Figures 1-5, Figure 6 shows a block diagram of the control architecture of the power generation system shown in Figure 5. In particular, the flow valves 21, 22, 27 and the heat recovery flow valve 26 operate as follows. For example, a gas turbine control unit 30, such as a computer or programmable logic control device (PLC), receives the following input parameters, namely, gas turbine parameters 31, combustion parameters 32, NOx requirements 33, and exhaust gas availability 41. In particular, the gas turbine parameters 31 depend on the gas turbine technology. In some embodiments, the gas turbine parameters 31 include gas turbine power generation, gas turbine speed, and 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 particular zone of the combustor, the distribution of heat load along the combustor, and NOx at the combustor outlet. x and NH3 slip. NO x Requirement 33 is NO in the exhaust stream downstream of the gas turbine. xThis includes exhaust gas emissions. The total amount of gas supplied to the gas turbine through gas turbine supply line 1 and NH3 gas supply flow line 2 (denoted by m1 and m2, respectively) is the gas turbine parameter function described above. m1 + m2 = f (GT parameters)

[0038] Volume composition x of the NH3 / H2 / N2 gas mixture flow in gas turbine supply line 1 1i (Shown as reference number 34 in Figure 6) is a function of the above combustion parameters and NOx requirements. x 1i =f(combustion parameters; NO x Requirements)

[0039] The volume composition of H2 (Y) in the gas cracking reactor gas mixture splitting line 310 (shown as reference number 38 in Figure 6) h1 The ratio (m310 / (m310+m1)) of the total mass flow rate of H2 passing through the H2 cracking reactor gas mixture split flow line 310 and the total mass flow rate of H2 passing through the gas turbine supply line 1 and the H2 cracking reactor gas mixture split flow line 310 is given by the combustion parameter 32, NO x It is a function of requirement 33 and exhaust gas availability parameter 41. Yh1=f(combustion parameter; NO) x Requirements; Exhaust gas availability parameter 41) m2 / (m1+m2)=f(combustion parameter; NO) x Requirements) m310 / (m310+m1)=f(combustion parameter; NO) x Requirements; Exhaust gas availability parameter 41)

[0040] These parameters are inputs to an auxiliary control unit 37, such as a computer or programmable logic control device (PLC), configured to control the operation of flow valves 21, 22, and 27 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. 21This 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)

[0041] 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))

[0042] Controlling the amount of H2 directed to other services, the operation of the H2 flow valve 27 Y 27 m1 is a function of the mass flow rate of the gas cracking reactor gas mixture split stream m310 directed to other services through the gas mixture split stream line 310, and the mass flow rate of the NH3 / H2 / N2 gas mixture stream m1 through the gas turbine supply line 1. Y 27 = f(m310+m1))

[0043] Finally, the operation of the heat recovery flow valve 26 is a function of the gas volume composition. Y 26 =f(x 1i )

[0044] The control method described above allows for altering 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). At the same time, the control method described above allows for utilizing any amount exceeding H2 to divert to other services.

[0045] Figure 7 shows a schematic diagram of an exemplary power generation system according to the seventh 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.

[0046] 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.

[0047] According to an alternative embodiment, the ammonia input flow can be separated into a first NH3 / H2 / N2 gas mixture that allows the gas turbine to operate under all conditions, a second gas mixture of nitrogen, hydrogen and residual ammonia, or residual ammonia and at least one of nitrogen or hydrogen, or a second gas mixture of nitrogen and hydrogen. The second gas mixture is the mixture of gases coming out of a separator, which may be located inside or outside the cracking reactor. In particular, the gas turbine can be supplied with a flow consisting of H2 and N2 (with hydrogen being approximately three times the volume of nitrogen), the remainder coming out of the cracking reactor due to excess heat can be sent downstream of the system for other uses, and unreacted or residual ammonia (if present) can be sent back to the cracking reactor (recirculated). According to an alternative embodiment, the gas turbine can be supplied with a flow consisting of H2 and N2 (with hydrogen being approximately three times the volume of nitrogen), and some or all of the unreacted ammonia to be burned within the gas turbine.

[0048] According to other alternative embodiments, the ammonia cracking reactor 300 may be equipped with an H2 stream separator for separating the H2 stream that is directed to other services by a cracking reactor gas mixture splitting stream line 310.

[0049] Nitrogen separation can be achieved by various techniques, including membranes, condensers, and pressure swing adsorber units (PSAs). According to an exemplary 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 small amount of nitrogen resulting from the cracking reaction permeates through the membrane and moves to the second section of the membrane reactor, where it is separated from hydrogen, unreacted or residual ammonia, and the remaining small amount of nitrogen, which remain inside the first section of the membrane reactor.

[0050] 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. A small amount of 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.

[0051] The NH3 bypass flow is separated from the NH3 gas flow from the heater / vaporizer / pressurizer through the NH3 gas bypass line 11. The NH3 gas bypass flow line 11 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.

[0052] 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 line 11 and downstream of the NH3 / H2 / N2 gas mixture outlet line 7.

[0053] 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.

[0054] 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 through the exhaust gas heat recovery line 12 and sent to the cracking reactor 300 and / or the NH3 heater / vaporizer / pressurizer 200. Referring to Figure 7, 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. Also, if the amount of exhaust gas exceeds a predetermined threshold of exhaust gas required to operate the gas turbine (100), such an additional amount of exhaust gas is used to generate excess H2 that is delivered to other services. Other services in this case include, but are not limited to, hydrogen storage solutions, hydrogen distribution via pipelines, hydrogen for refueling stations, hydrogen compression for tube trailer refueling stations, and hydrogen for industrial decarburization (e.g., smelters, steel industry).

[0055] 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.

[0056] The NH3 adjustment gas turbine auxiliary system shown in Figure 7 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 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 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 rise to the end of the gas turbine sequence or 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 produced, the flow of the NH3 / H2 / N2 gas mixture inside 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 cut-off 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.

[0057] The operation of the NH3 regulating gas turbine auxiliary system in Figure 7 is controlled by 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 and controls the flow of the NH3 / H2 / N2 gas mixture flow inside the gas turbine supply line 1. An NH3 gas bypass flow valve 22 is located along the NH3 gas bypass 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, among other types of valves.

[0058] Continuing to refer to Figure 7, according to the block diagram of the control architecture of the power generation system shown in Figure 8, 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 parameter 31, the combustion parameter 32, and NO x Requirement 33 states that 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 NH3 gas supply flow line 2, and the N2 gas supply flow (m3) through N2 gas supply flow line 3, is a function of the gas turbine parameters. m1 + m2 + m3 = f (GT parameters)

[0059] Volume composition x of the NH3 / H2 / N2 gas mixture flow in gas turbine supply line 1 1i (Shown as reference number 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 related to the combustion parameters and NO x It is a function of the requirements. x 1i =f(combustion parameters; NO x Requirements) m2 / (m1+m2)=f(combustion parameter; NO) x Requirements) m3 / (m1+m2)=f(combustion parameter);NO x Requirements)

[0060] 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. 21m1, 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)

[0061] The operation Y22 of the NH3 gas bypass flow valve 22 is a function of the ratio 35 between the NH3 gas mass flow rate through the NH3 gas supply flow line 2 and the total mass flow rate of the NH3 / H2 / N2 gas mixture flow 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. Y 22 = f(m2 / (m1+m2))

[0062] 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 )

[0063] 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 )

[0064] Operation of the N2 supply flow valve 25 of the gas turbine Y 25 This is a function of the ratio 36 between the N2 gas mass flow rate m3 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))

[0065] 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 )

[0066] The control method described above allows for the modification of the fuel composition to the gas turbine and the injection of ammonia and nitrogen in any ratio according to any final combustor and gas turbine requirements (these requirements are not part of this disclosure).

[0067] For example, if a combustor requires a consistent inert fluid (N2) but uses a hydrogen-rich fuel to reduce flame temperature and increase gas turbine output, Case 1 in Table 1 below is applicable. x Case 3 in Table 1 is applicable when a hydrogen-rich fuel is required to optimize emissions, but consistent, separate ammonia injection is necessary. Case 2 in Table 1 is applicable when the combustor does not require large amounts of hydrogen, large amounts of separated ammonia, and large amounts of separated nitrogen.

[0068] [Table 1]

[0069] Continuing with Figures 1 to 8, Figure 9 illustrates a eighth embodiment of a power generation system using a gas turbine and equipped with an ammonia cracking device. The same reference numerals are already illustrated in Figures 1 to 8 and specify the same or corresponding parts, elements, or components that have been previously described and are not described again here.

[0070] The embodiment shown in Figure 9 differs from the embodiment in Figure 7 in that at least a portion of the gas N2 flow from the cracking reactor 300 is not directed to the gas turbine 100 but is collected and used for a different purpose or other service, such as, but not limited to, nitrogen storage solution, nitrogen distribution via pipeline, or nitrogen for refueling stations. 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 in the N2 gas outlet line 8 from the NH3 cracking reactor 300 that is directed for external use. The control method in this embodiment is the operation Y of the flow valve 25'. 25 This differs from those described with reference to Figures 7 and 8 in that it is a function of requirements that do not constitute the object of the present invention. Y 25′ =f(other requirements)

[0071] Furthermore, referring to Figures 1 to 9, Figure 10 illustrates a ninth embodiment of a power generation system using a gas turbine and equipped with an ammonia cracking device. The same reference numerals are already illustrated in Figures 1 to 9 and specify the same or corresponding parts, elements, or components that have been previously described and are not described again here.

[0072] The embodiment shown in Figure 10 differs from the embodiments in Figures 7 and 9 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 accommodate 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 7 and 8.

[0073] Furthermore, referring to Figures 1 to 10, Figure 11 illustrates a tenth embodiment of a power generation system using a gas turbine and equipped with an ammonia cracking device. The same reference numerals are already illustrated in Figures 1 to 10 and specify the same or corresponding parts, elements, or components that have been previously described and are not described again here.

[0074] The embodiment shown in Figure 11 differs from the embodiments in Figures 7-10 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 or other service, such as, but not limited to, nitrogen storage solution, nitrogen distribution via pipeline, or nitrogen for refueling stations, 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 9.

[0075] Finally, continuing to refer to Figures 1 to 11, Figure 12 illustrates an eleventh embodiment of a power generation system using a gas turbine and equipped with an ammonia cracking device. The same reference numerals are already illustrated in Figures 1 to 11 and specify the same or corresponding parts, elements, or components that have been previously described and are not described again here.

[0076] The embodiment shown in Figure 12 differs from the embodiments in Figures 7 to 11 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 if necessary.

[0077] Continuing with reference to Figures 1 to 12, Figures 13 to 16 show several embodiments of a system comprising a gas turbine 100, a gas turbine auxiliary system for NH3 adjustment, and a fuel cell 500. These embodiments differ from the embodiments in Figures 1 to 12 in that they further include a fuel cell 500. Furthermore, while some embodiments shown in Figures 1 to 12 have been described as having 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 shown in Figures 13 to 16 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 13 to 16 may or may not have an NH3 bypass line. Figure 13, in particular, shows a twelfth 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 12 and described previously.

[0078] Although not shown in Figures 13 to 16, 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.

[0079] In Figure 13, 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, enabling the fuel cell 500 to operate at high temperatures.

[0080] 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 with storage devices.

[0081] 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.

[0082] 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.

[0083] As described with reference to Figures 1 to 12, Figure 13 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.

[0084] The system further includes a separator configured to separate a gas mixture of hydrogen, nitrogen, and unreacted or residual ammonia into separate streams of hydrogen, nitrogen, and ammonia.

[0085] 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.

[0086] The heat exchanger 710 may be supplied by a second gas mixture outlet line of the cracking reactor 300, which then provides the cooled gas mixture to the separation module 720 through a connection line 75.

[0087] 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.

[0088] The heat exchanger 710 is configured to preheat the ammonia flow and / or hydrogen flow entering the fuel cell 500 to a preset temperature, in accordance with the technology / requirements of the fuel cell 500. In this way, the heat exchanger provides enough 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 fuel cell 500 is supplied with ammonia and / or hydrogen preheated by the heat exchanger 710. 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.

[0089] For example, in Figure 13, the separation module 720 provides separated flows of hydrogen and ammonia to the heat exchanger 710, and the heat exchanger 132 heats the corresponding flows to enable high-temperature operation of the fuel cell 500. In Figure 13, the ammonia flow is supplied from the separation module 720 to the heat exchanger 710 through the connection line 74.

[0090] The separator has one or more outlet lines for transporting separate flows of hydrogen, nitrogen, and ammonia to their respective modules in 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 has a first separator outlet line 71 and a second separator outlet line 72.

[0091] 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 first separator outlet line 71 may also be connected through a connection line 71a to a cracking reactor 300 and / or a post-combustion module to deliver the ammonia flow there, as shown in Figure 13.

[0092] The second separator outlet line 72 supplies the hydrogen flow to the fuel cell 500. In this embodiment, the second separator outlet line 72 comprises 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. The second separator outlet line 72 can 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 13.

[0093] The separator may also include a third separator outlet line 73 connected to the gas turbine 100 to transport the nitrogen flow to the gas turbine 100, as shown in Figure 13.

[0094] 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 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.

[0095] In some embodiments, NO from the gas turbine 100 x To further reduce emissions, the HRSG 110 is designed for dry low NOx combustion systems, particularly for gas turbines. x When not DLN or 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 13 makes it possible to further reduce the environmental impact.

[0096] The HRSG 110 may include a post-combustion module, which is configured to receive and process at least a portion of the hydrogen flow from the separator outlet line 72 and / or the ammonia flow from the connection line 71a along with the exhaust gas flow, generating additional heat, and to transport 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.

[0097] The power generation system may also include a heat exchanger, such as a second heat exchanger (not shown in Figure 13), configured to preheat the ammonia input flow 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 input flow entering the ammonia cracking reactor 300 may be supplied to the ammonia cracking reactor 300 at the required temperature by an external heating system.

[0098] Alternatively, or additionally, 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 can 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.

[0099] 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.

[0100] 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 produced by a gas turbine auxiliary system, a flow of hydrogen, a flow of nitrogen, or a flow of ammonia.

[0101] The power generation system may include one or more storage units (not shown in Figure 13) 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.

[0102] Continuing to refer to Figures 1 to 13, Figure 14 shows a thirteenth 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 Figure 13 and described above, and are not described again here.

[0103] The embodiment shown in Figure 14 differs from the embodiment in Figure 13 in that the system does not include an HRSG with a post-combustion module. The gas turbine exhaust flow provides sufficient heat to the ammonia cracking reactor 300 to enable its operation. Thus, according to the system shown in Figure 14, ammonia can be decomposed at a low temperature while the fuel cell 500 operates at a high temperature.

[0104] Continuing to refer to Figures 1 to 14, Figure 15 shows a fourteenth 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 Figures 13 and 14 and described above, and are not described again here.

[0105] The embodiment shown in Figure 15 differs from the embodiment in Figure 14 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 15 further differs in that the separator outlet line 71 is not connected to the fuel cell 500.

[0106] In contrast to Figure 13, in Figure 15, the ammonia and / or hydrogen flows 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 200°C, preferably between 80°C and 200°C. For example, the hydrogen flow is supplied to the fuel cell 500 using a 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. The configuration shown in Figure 15 allows the fuel cell 500 to operate at low temperatures while the ammonia cracking reactor 300 operates at high temperatures.

[0107] Continuing to refer to Figures 1 to 15, Figure 16 shows a fifteenth 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 are already illustrated in Figures 13 to 15 and specify the same or corresponding parts, elements, or components that have been previously described and are not described again here.

[0108] The embodiment shown in Figure 16 differs from the embodiment in Figure 13 in that it does not include an HRSG with a post-combustion module. In Figure 16, the gas turbine exhaust flow provides sufficient heat to the ammonia cracking reactor 300 for cryogenic decomposition of ammonia.

[0109] Figure 16 differs further from the embodiment in Figure 13 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.

[0110] In contrast to Figure 13, in Figure 16, the ammonia and / or hydrogen flows 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 200°C, preferably between 80°C and 200°C. In particular, the hydrogen flow is supplied to the fuel cell 500 using a second separator outlet line 72, while the ammonia flow is supplied using another outlet line 74, in this case, which directly connects the separation module 720 to the fuel cell 500. The configuration shown in Figure 16 allows the fuel cell 500 to operate at low temperatures while the ammonia cracking reactor 300 operates at high temperatures.

[0111] 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 step may be changed or rearranged according to alternative embodiments.

Claims

1. Gas turbine (100) and NH ３ A power generation system comprising a regulating gas turbine auxiliary system, Said NH ３ The regulating gas turbine auxiliary system processes the ammonia feed stream and produces 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), The ammonia input flow is connected to the cracking reactor supply line (6) and NH ３ It is divided into a bypass line (11) and The ammonia cracking reactor (300) is configured to decompose ammonia into a first gas mixture of hydrogen and nitrogen, or a first gas mixture of hydrogen, nitrogen and residual ammonia. A cracking reactor gas mixture outlet line (7) is connected to said gas turbine (100), and said NH ３ The bypass line (11) is connected to NH ３ It is connected to said gas turbine (100) via a gas supply flow line (2), The power generation system further comprises a cracking reactor gas mixture splitting flow line (310) connecting the ammonia cracking reactor (300) to other services (400).

2. The power generation system according to claim 1, wherein the cracking reactor gas mixture splitting flow line (310) connecting the ammonia cracking reactor to other services is withdrawn from the cracking reactor gas mixture outlet line (7).

3. The power generation system according to claim 1, wherein the amount of hydrogen in the first gas mixture of hydrogen and nitrogen, or hydrogen, nitrogen and residual ammonia, is about three times the amount of nitrogen.

4. The power generation system according to any one of claims 1 to 3, wherein the other service includes a separator (700) configured to separate a flow containing a second gas mixture of nitrogen, hydrogen, and residual ammonia, or a second gas mixture of residual ammonia, and at least one of nitrogen or hydrogen, or a second gas mixture of nitrogen and hydrogen.

5. The power generation system according to claim 4, wherein the amount of hydrogen in the second gas mixture of hydrogen and nitrogen, or the second gas mixture of hydrogen, nitrogen and residual ammonia, is about three times the amount of nitrogen.

6. The separator (700) ３ The power generation system according to claim 4 or 5, wherein the device is a flow separator.

7. Said NH ３ The power generation system according to claim 6, wherein the flow separator is a membrane.

8. Said NH ３ The power generation system according to claim 6, wherein the flow separator is a condenser.

9. Said NH ３ The power generation system according to claim 6, wherein the flow separator is a pressure swing adsorption (PSA).

10. Said NH ３ The flow separator is NH ３ NH is recirculated to the cracking reactor supply line (6) by the flow line. ３ A power generation system according to any one of claims 6 to 9, which separates the flow.

11. The separator (700) is H ２ The power generation system according to claim 4, wherein the device is a flow separator.

12. The aforementioned H ２ The power generation system according to claim 11, wherein the flow separator is a membrane.

13. The aforementioned H ２ The power generation system according to claim 11, wherein the flow separator is a PSA.

14. The aforementioned H ２ The flow separator guides the hydrogen flow line to other services. ２ A power generation system according to any one of claims 6 to 11, which separates the flow.

15. The nitrogen separated from the first gas mixture of hydrogen and nitrogen, or the gas mixture of hydrogen, nitrogen and residual ammonia, is withdrawn from the ammonia cracking reactor (300) through the nitrogen flow line (8), and the nitrogen flow line (8) is supplied to the gas turbine supply line (1) via the nitrogen gas supply line (9) upstream of the gas turbine (100), and / or to the gas turbine (100) via the nitrogen gas supply line (3), and / or to N ２ The power generation system according to claim 4, which is connected to a gas extraction line 3'.

16. The power generation system according to any one of claims 1 to 15, wherein the cracking reactor gas mixture splitting flow line (310) is a nitrogen flow line.

17. NH ３ The system further includes a gas bypass splitting flow line (10), the NH3 gas bypass splitting flow line (10) upstream of the gas turbine (100) ３ The power generation system according to any one of claims 1 to 16, wherein a bypass line (11) is connected to the cracking reactor gas mixture outlet line (7) to form a gas turbine supply line (1).

18. Said NH ３ Bypass flow, ３ The power generation system according to any one of claims 1 to 17, wherein gas is injected through a gas supply line (2) into the primary stage or alternatively the secondary stage of the gas turbine (100).

19. NH configured to heat / vaporize / pressurize an ammonia input stream that is at least partially liquid. ３ The power generation system according to any one of claims 1 to 18, further comprising a heater / vaporizer / pressurizer (200).

20. NH configured to pressurize the ammonia gas inlet flow ３ The power generation system according to any one of claims 1 to 19, further comprising a pressurizer.

21. A power generation system according to any one of claims 1 to 20, wherein a plurality of flow valves (21, 22, 23, 24, 25, 26, 27) are controlled by an auxiliary control unit.

22. The plurality of flow valves (21, 22, 23, 24, 25) are gas flow valves (21) and NH arranged along the gas turbine supply line (1). ３ NH3 gas supply line (2) is arranged along the bypass flow line (11) which is connected downstream ３ The power generation system according to claim 21, further comprising a gas bypass flow valve (22).

23. The plurality of flow valves (21, 22, 23, 24, 25, 26, 27) are the NH ３ NH arranged along the gas bypass split flow line (10) ３ The power generation system according to claim 22, further comprising a flow valve (23) for gas bypass splitting flow.

24. The plurality of flow valves (21, 22, 23, 24, 25, 26, 27) are the N ２ N arranged along the gas bypass line (9) ２ The gas bypass flow valve (24) is further provided and / or the gas turbine N ２ The flow valve (25) of the supply flow, ２ The power generation system according to claim 23, which is arranged along a gas supply flow line (3).

25. The system further comprises a heat recovery system configured to recover at least a portion of the heat from the exhaust gas flow from the gas turbine (100), wherein the heat recovery system is configured to transport a first portion of the exhaust gas flow to the cracking reactor (300) via a first heat recovery subline (13), and / or a second portion of the exhaust gas flow via the NH ３ The power generation system according to any one of claims 1 to 24, further comprising a second heat recovery subline (14) configured to deliver to a heater / vaporizer / pressurizer (200).

26. The power generation system according to claim 27, further comprising at least one heat recovery flow valve (26).

27. The power generation system according to claim 26, wherein the at least one heat recovery flow valve (26) is located on the first heat recovery subline (13) or the second heat recovery subline (14).

28. It is further equipped with a fuel cell (500), The separator (700) coupled to the gas turbine (100) 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 The power generation system according to claim 4, further comprising at least one of a second separator outlet line (72, 72b) connected to the fuel cell (500) for transporting the hydrogen flow to the fuel cell (500).

29. The power generation system according to claim 28, wherein the separator includes a membrane.

30. 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 28 or 29, comprising at least one of separation modules (720), preferably a pressure swing adsorption (PSA), configured to separate the gas mixture using pressure.

31. The power generation system according to claim 30, wherein the heat exchanger (710) is configured to supply the cooled gas mixture to the separation module (720).

32. The power generation system according to claim 30 or 31, 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.

33. The power generation system according to claim 30 or 31, 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.

34. The system further comprises at least one compression system, the at least one compression system is Adjusting the fluid pressure, It is configured to transport the fluid to the outside of the system for external use, The power generation system according to any one of claims 1 to 33, wherein the fluid includes at least one of the gas mixture, the hydrogen flow, the nitrogen flow, and the ammonia flow.

35. The power generation system according to any one of claims 28 to 34, wherein the first separator outlet line (71) comprises an ammonia storage system arranged along the outlet line (71).

36. The power generation system according to any one of claims 28 to 35, wherein the second separator outlet line (72, 72b) comprises a hydrogen storage system arranged along the outlet line (72, 72b).

37. The power generation system according to any one of claims 28 to 36, 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.

38. The power generation system according to any one of claims 1 to 37, wherein the gas turbine (100) is further 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 at least a portion of the heat to the ammonia cracking reactor (300).

39. The power generation system according to claim 38, wherein the HRSG includes a selective catalytic reduction (SCR) system.

40. The power generation system according to claim 38 or 39, wherein the HRSG (110) comprises a post-combustion module configured to receive and process at least a portion of the hydrogen and / or ammonia flow to generate additional heat and to transport at least a portion of the additional heat to the ammonia cracking reactor (300).

41. The power generation system according to any one of claims 38 to 40, 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.

42. A power generation system according to any one of claims 38 to 41, comprising a third heat exchanger (800) for preheating the air entering the fuel cell (500), wherein at least a portion of the heat 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).

43. A method for controlling the operation of a power generation system according to any one of claims 1 to 27, comprising the following steps, namely: - The NH supplied to the gas turbine through the gas turbine supply line (1) ３ / H ２ / N ２ A gas mixture stream (m1) and the NH ３ The NH passing through the gas supply flow line (2) ３ A step of determining the total amount (m1 + m2) of the gas supply flow (m2) as a function of the gas turbine parameters, - The NH in the gas turbine supply line (1) ３ / H ２ / N ２ Volume composition of gas mixture flow (x １ｉ ), and the NH ３ The NH passing through the gas supply flow line (2) ３ The gas mass flow rate (m²) and the NH passing through the gas turbine supply line (1) ３ / H ２ / N ２ Gas mixture flow (m1) and the NH ３ The NH to the gas turbine through the gas supply flow line (2) ３ The ratio (35) of the gas supply flow (m2) to the total mass flow rate (m1 + m2) is given to the combustion parameters (32) and NO ｘ The process (34) of determining the function of requirement (33), - NH flowing inside the gas turbine supply line (1) ３ / H ２ / N ２ Operation of the gas flow valve (21) that controls the amount of gas mixture flow (Y ２１ ) the gas flow (m1) supplied to the gas turbine through the gas turbine supply line (1) and the NH ３ The NH supplied to the gas turbine through the gas supply line (2) ３ The process involves determining the total amount of gas supply flow (m2) as a function of (m1 + m2), - Said NH ３ Operation of gas bypass flow valve (22) (Y ２２ ) to the aforementioned NH ３ The NH passing through the gas supply flow line (2) ３ The gas mass flow rate (m²) and the NH passing through the gas turbine supply line (1) ３ / H ２ / N ２ Gas mixture flow (m1) and the NH ３ The NH to the gas turbine through the gas supply flow line (2) ３ A method comprising the step of determining the ratio (35) of the gas supply flow (m2) to the total mass flow rate (m1 + m2).

44. The following steps, namely, - As a function of the gas turbine parameters, H is induced to other services by the cracking reactor gas mixture splitting flow line (310) and the gas turbine supply line (1). ２ The process of determining the total amount (m310 + m1) of the flow line (m310), - Available H delivered to the gas turbine by the gas turbine supply line (1) ２ A process for measuring the amount, - Value of such quantity H ２ The value is compared with a predetermined threshold and H ２ If the H in the gas cracking reactor gas mixture splitting flow line (m310) is greater than the aforementioned threshold, it is directed to another service. ２ Volume composition (Y ｈ１ ), and H ２ H passing through the split flow line of the cracking reactor gas mixture (m310) ２ and the gas turbine supply line (1) and H ２ H passing through the split flow line of the cracking reactor gas mixture (m310) ２ The ratio of the total mass flow rate to (m310 / (m310+m1)) is the combustion parameter (32), NO ｘ The process (38) involves determining the requirements (33) and exhaust gas usability (41) parameters as a function of the parameters, - H flowing inside other services ２ The amount of H is controlled as a function of the total amount (m310 + m1). ２ Operation of flow valve (27) (Y ２７ A method for controlling the operation of a power generation system according to claim 43, comprising the step of determining ).

45. The following steps, namely, - Operation of the heat recovery flow valve (26) (Y ２６ ) the volume composition (x) of the gas １ｉ A method for controlling the operation of a power generation system according to claim 43 or 44, further comprising the step of determining as a function of ).

46. The following steps, namely, - the said NH passing through said gas turbine supply line (1) ３ / H ２ / N ２ mixed stream (m1), the said NH ３ the said NH passing through the said NH gas supply flow line (2) ３ gas supply flow (m2), and the total amount (m1+m2+m3) of gas supplied to the said gas turbine (100) by the said N gas supply flow (m3) passing through the said N gas supply flow line (3) ２ the said N passing through the said N gas supply flow line (3) ２ , determining as a function of the said gas turbine parameter (31); - said NH in said gas turbine supply line (1) ３ / H ２ / N ２ the volume composition (x １ｉ ) of the gas mixture stream, the NH ３ the mass flow rate (m2) of NH ３ gas passing through said NH3 gas supply flow line (2), and the NH ３ / H ２ / N ２ gas mixture stream (m1) passing through said gas turbine supply line (1) and said NH ３ gas passing through said NH3 gas supply flow line (2) ３ the ratio (35) of the mass flow rate of said NH3 gas supply stream (m2) to the total mass flow rate (m1+m2), and the N ２ the mass flow rate (m3) of N2 gas passing through said N2 gas supply flow line (3), and the NH ３ / H ２ / N ２ gas mixture stream (m1) passing through said gas turbine supply line (1) and said NH ３ gas passing through said NH3 gas supply flow line (2) ３ the ratio (36) of the mass flow rate of said NH3 gas supply stream (m2) to the total mass flow rate (m1+m2), determined as a function of said combustion parameters and said NO ｘ x requirements; and step (34) - NH flowing inside the gas turbine supply line (1) ３ / H ２ / N ２ Operation of the gas flow valve (21) that controls the amount of gas mixture flow (Y ２１ ) passing through the gas turbine supply line (1) ３ / H ２ / N ２ Gas mixture flow (m1), the NH ３ The NH supplied to the gas turbine through the gas supply line (2) ３ Gas supply flow (m²), and the N ２ The N passing through the gas supply flow line (3) ２ A step of determining the total amount of gas flow (m1 + m2 + m3) supplied to the gas turbine by the gas supply flow (m3), - Said NH ３ Operation of gas bypass flow valve (22) (Y ２２ ) to the aforementioned NH ３ The NH passing through the gas supply flow line (2) ３ The gas mass flow rate (m²) and the NH passing through the gas turbine supply line (1) ３ / H ２ / N ２ The NH3 gas mixture flow (m1) and the NH3 gas supply flow line (2) to the gas turbine ３ The process involves determining the ratio (35) of the gas supply flow (m2) to the total mass flow rate (m1 + m2), - The above N ２ Operation of gas bypass flow valve (24) (Y ２４ ) in the gas turbine supply line (1) ３ / H ２ / N ２ The volume composition x of the gas mixture flow １ｉ The process of determining it as a function of, - The N of the gas turbine ２ Operation of the supply flow valve (25) (Y ２５ ) to the above N ２ The N passing through the gas supply flow line (3) ２ The gas mass flow rate (m³) and the NH passing through the gas turbine supply line (1) ３ / H ２ / N ２ Gas mixture flow (m1) and the NH ３ The NH to the gas turbine through the gas supply flow line (2) ３ A method for controlling the operation of a power generation system according to claim 15 or any one of claims 17 to 27, comprising the step of determining the gas supply flow (m2) as a function of the ratio (36) of the total mass flow rate (m1 + m2).

47. The following steps, namely, - H is directed to other services by the cracking reactor gas mixture splitting flow line (310) and the gas turbine supply line (1). ２ A step of determining the total amount (m310 + m1) of the flow line (m310) as a function of the gas turbine parameters, - Available H delivered to the gas turbine by the gas turbine supply line (1) ２ A process for measuring the amount, - Value of such quantity H ２ The value is compared with a predetermined threshold and H ２ If the H in the gas cracking reactor gas mixture splitting flow line (m310) is greater than the aforementioned threshold, the H is diverted to another service. ２ The volume composition (Yh1), and H ２ H passing through the split flow line of the cracking reactor gas mixture (m310) ２ And H2 cracking reactor gas mixture splitting flow line (m310) passing through the gas turbine supply line (1) and the H2 cracking reactor gas mixture splitting flow line (m310) ２ The ratio of the total mass flow rate to (m310 / (m310+m1)) is the combustion parameter (32), and the NO ｘ A step (38) to determine the requirements (33) and the exhaust gas usability (41) parameters as a function of the requirements (33), - The H that flows inside the other service ２ The amount of H ２ The operation of the flow valve (27) (Y ２７ A method for controlling the operation of a power generation system according to claim 46, further comprising the step of determining as a function of the total amount (m310 + m1).

48. The following steps, namely, - Operation of the heat recovery flow valve (26) (Y ２６ A method for controlling the operation of a power generation system according to claim 46 or 47, further comprising the step of determining as a function of the volume composition of the gas.

49. The following steps, namely, - Said NH ３ Operation of the gas bypass split flow valve (23) (Y ２３ ) in the gas turbine supply line (1) ３ / H ２ / N ２ The volume composition x of the gas mixture flow １ｉ A method for controlling the operation of a power generation system according to any one of claims 46 to 48, further comprising the step of determining as a function of .

Images