Gas turbine auxiliary system for NH3 conditioning

Abstract

A system for generating electricity using a gas turbine is disclosed. The system includes an ammonia cracker for converting at least a portion of an NH3 stream into H2 and N2 to achieve an NH3 / H2 / N2 gas mixture that enables the gas turbine to operate in all conditions. In one aspect, the NH3 stream is split into a first NH3 stream that is cracked to H2 and N2 through cracking and a second NH3 stream that is directed to the gas turbine through a bypass line to obtain H2 and N2 streams.

Description

[Technical Field]

[0001] The present disclosure relates to a system for generating electricity using a gas turbine, the system including an ammonia cracker. The embodiments disclosed herein specifically relate to a gas turbine auxiliary system for NH conditioning, where a fuel skid processes an ammonia input stream to achieve an NH / H / N gas mixture that allows the gas turbine to operate at all conditions. Also disclosed herein is a system for optimizing gas turbine operation and reducing NO from the gas turbine at all gas turbine conditions. x A method for controlling emissions is disclosed. [Background technology]

[0002] Gas turbines are commonly used to generate electricity in power plants by burning fuel. The basic operation of a gas turbine is the Brayton cycle, which uses air as the working fluid. Air flows through a compressor, which raises the pressure. Energy is then added by injecting and igniting fuel into the air in a combustion chamber, resulting in the generation of a hot stream through combustion. This hot, pressurized gas enters the turbine, generating shaft work in the process and is used to drive the compressor. Unused energy exits the exhaust gases, which can be reused for external work, such as directly generating thrust in a turbojet engine or to spin 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 its design so that the most desirable division of energy between thrust and shaft work is achieved. The fourth step of the Brayton cycle (cooling the working fluid) is omitted because gas turbines are open systems that do not reuse the same air.

[0003] Commonly used fuels include natural gas, propane, diesel, biogas, and biodiesel. One of the major problems associated with burning fuels such as these in gas turbines is the resulting production of carbon dioxide (CO2) gas. Increasing CO2 levels in the atmosphere are harmful to the environment and a known cause of global warming. Therefore, there is a need to provide fuels for use in gas turbines that either do not produce CO2 upon combustion or that must have the CO2 removed prior to 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 a fuel in gas turbines is that during the combustion process, ammonia oxidizes to produce nitrogen oxides, NO x , a pollutant that contributes to acid rain and global warming. Additionally, due to the low heat capacity and low reactivity of ammonia with respect to oxygen, ammonia combustion in gas turbines presents stability problems (blowouts) over the entire range of gas turbine operating conditions. On the other hand, the combustion of hydrogen produces NO x Stability issues (blowouts) are eliminated, even if pollutants are still produced. Nevertheless, there are many problems associated with the use of hydrogen as a fuel, including storage issues and the fact that hydrogen is a highly flammable gas. The availability of N2 as an inert in the combustion process can vary depending on the type of flame realized in the gas turbine combustor, as can the use of NO2. x This could help reduce emissions.

[0005] Chinese Patent No. 107288780(A) discloses a system for generating electricity using a gas turbine, in which ammonia is used as fuel. Upstream of the combustion chamber, ammonia is partially decomposed in an ammonia cracker to generate hydrogen, providing a fuel mixture containing hydrogen and ammonia. Because the combustion point of hydrogen is lower than that of ammonia, hydrogen is first burned in the combustion chamber to release heat and ignite the ammonia in the combustion chamber. As a result, hydrogen can accelerate the combustion process, thus improving the combustion performance of ammonia fuel. Consequently, the amount of hydrogen supplied is a function of the ignition of NH3. However, the system disclosed in Chinese Patent No. 107288780 does not completely overcome environmental issues due to the formation of nitrogen oxides resulting from the oxidation of ammonia during the combustion process.

[0006] U.S. Patent No. 1,108,4719 (B2) discloses a process for generating electricity using a gas turbine, the process including: (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 hydrogen and nitrogen mixture; (iii) converting the preheated ammonia gas into a hydrogen and nitrogen mixture in the unit; (iv) cooling the hydrogen and nitrogen mixture to obtain a cooled hydrogen and nitrogen mixture; (v) introducing the cooled hydrogen and nitrogen mixture into a gas turbine; and (vi) combusting the cooled hydrogen and nitrogen mixture in the gas turbine to generate electricity. U.S. Patent No. 1,108,4719 (B2) also discloses an embodiment in which the composition of the hydrogen and nitrogen mixture exiting the ammonia cracking unit can be adjusted using purification techniques. However, the composition of the output mixture from the cracking process may be far from optimal for the GT operating requirements.

[0007] U.S. Pat. No. 11,156,168 (B2) discloses a gas turbine plant including a gas turbine, a heating device, a cracked gas line, and a cracked gas compressor. The heating device heats ammonia and thermally decomposes it, converting it into cracked gas containing 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 greater than the supply pressure, allowing the cracked gas to be supplied to the gas turbine. U.S. Pat. No. 11,156,168 (B2) also discloses a control device that adjusts the ratio of the cracked gas flow rate to the total fuel gas flow rate (including natural gas and cracked gas). Controlling this ratio allows for the adjustment of the mixture of cracked gas and natural gas to the combustion chamber. However, burning natural gas still produces high levels of carbon dioxide, which is either released into the atmosphere or requires an additional carbon capture system.

[0008] In conclusion, the solutions in the prior art have problems that either negatively impact the operating costs of the system or have adverse effects on the environment. Therefore, an improved system for generating electricity using a gas turbine and ammonia as fuel would be beneficial and welcome in the art to address the problem of adjusting NH3 in real time to achieve an NH3 / H2 / N2 gas mixture that allows the gas turbine to operate in all conditions. NH3 adjustment needs to be performed flexibly and adjusted at different levels along the path to the turbine, thus improving performance as well as reducing NO x A need is felt for a system that is able to tailor fuel delivery to a gas turbine at different stages in order to also mitigate emissions.More generally, it is desirable to provide a method and system adapted to more efficiently address the problems involved with providing an auxiliary system for NH3 tailoring in order to achieve an NH3 / H2 / N2 gas mixture that allows the gas turbine to operate in all conditions. Summary of the Invention

[0009] In one aspect, 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 cracker that converts ammonia into hydrogen and nitrogen that is delivered to the gas turbine, and an ammonia bypass line that directs a portion of the ammonia directly to the gas turbine, the system further comprising a plurality of flow valves controlled by an auxiliary control unit, the flow valves including a gas flow valve disposed downstream of the ammonia cracking reactor and / or an NH3 gas bypass flow valve disposed along an NH3 gas supply line connected downstream of the NH3 bypass flow line.Embodiments disclosed herein specifically relate to a gas turbine auxiliary system for NH3 conditioning, wherein a fuel skid processes an ammonia input stream to achieve an NH3 / H2 / N2 gas mixture that enables the gas turbine to operate in all conditions.

[0010] In another aspect, the subject matter disclosed herein relates to a method for generating electricity using a gas turbine and ammonia as a fuel, wherein the ammonia conditioning auxiliary system operates through a control routine as a function of GT parameters, combustion parameters, and NOx requirements in the GT exhaust. [Brief explanation of the drawings]

[0011] A more complete understanding of the disclosed embodiments of this invention and many of the attendant advantages thereof will be readily obtained as the same become better understood by reference to the following detailed description when considered in connection with the accompanying drawings. [Figure 1] 1 shows a schematic diagram of a power generation system using a gas turbine and including an ammonia cracker according to a first embodiment. [Figure 2] 2 shows a block diagram of the control architecture of the power generation system of FIG. 1. [Figure 3] 1 shows a schematic diagram of a power generation system using a gas turbine and including an ammonia cracker according to a second embodiment. [Figure 4]FIG. 4 shows a block diagram of the control architecture of the power generation system of FIG. [Figure 5] 1 shows a schematic diagram of a power generation system using a gas turbine and including an ammonia cracker according to a third embodiment. [Figure 6] 10 shows a schematic diagram of a power generation system using a gas turbine and including an ammonia cracker according to a fourth embodiment. [Figure 7] 10 shows a schematic diagram of a power generation system using a gas turbine and including an ammonia cracker according to a fifth embodiment. [Figure 8] 10 shows a schematic diagram of a power generation system using a gas turbine and including an ammonia cracker according to a fifth embodiment. DETAILED DESCRIPTION OF THE INVENTION

[0012] According to one aspect, the subject matter relates to a system for generating electricity using a gas turbine, the system including an ammonia cracker for converting at least a portion of an NH3 stream to H2 and N2 to achieve an NH3 / H2 / N2 gas mixture that enables the gas turbine to operate under all conditions.

[0013] In another aspect, the subject matter disclosed herein relates to a gas turbine auxiliary system for NH3 conditioning, in which an NH3 feed stream is split into two separate NH3 streams, the first NH3 stream being cracked into H2 and N2 through a catalytic cracking reactor or a thermal cracking reactor to obtain an H2 and N2 stream delivered to the gas turbine, and the second NH3 stream being directed to the gas turbine through a bypass line. To control the precise amounts of ammonia, hydrogen, and nitrogen delivered to the gas turbine, the system further includes a plurality of flow valves controlled by an auxiliary control unit, including a gas flow valve disposed downstream of the ammonia cracking reactor. Additionally or alternatively, the system may also include an NH3 gas bypass flow valve disposed along the NH3 gas supply line connected downstream of the NH3 bypass flow line. In particular, downstream of the cracking reactor, the H2 and N2 streams are mixed with the second NH3 stream to obtain an NH3 / H2 / N2 gas mixture having a controlled ratio of NH3 on the one hand and H2 and N2 on the other hand. Optionally, downstream of the cracking reactor, N2 can be separated from H2 gas in the H2 and N2 stream to obtain an NH3 / H2 / N2 gas mixture with a controlled ratio of NH3, H2, and N2, and additionally allow N2 to be used as a purge gas.

[0014] Reference will now be made in detail to the embodiments of the present disclosure, one or more examples of which are illustrated in the figures. Each example is provided by way of explanation of the disclosure, not as a limitation of the disclosure. Indeed, it will be apparent to those skilled in the art that various modifications and variations can be made in the present disclosure without departing from the scope or spirit of the disclosure. References throughout this specification to "one embodiment" or "one embodiment" or "some embodiments" mean that a particular feature, structure, or characteristic described in connection with an embodiment is included in at least one embodiment of the disclosed subject matter. Thus, the appearances of the phrases "in one embodiment" or "in one embodiment" or "some embodiments" in various places throughout this specification are not necessarily all referring to the same embodiment. Furthermore, particular features, structures, or characteristics may be combined in any suitable manner in one or more embodiments.

[0015] When presenting elements of various embodiments, the articles "a," "an," "the," and "said" are intended to mean that there are one or more of the elements. The terms "comprising," "including," and "having" are intended to be non-exclusive and mean that there may be additional elements other than the listed elements.

[0016] Referring now to the drawings, Figure 1 shows a schematic diagram of an exemplary power generation system including a gas turbine 100. The gas turbine 100 includes a compressor, a combustion chamber, and an expander. The gas turbine 100 is supplied with an NH3 / H2 / N2 gas mixture stream and an NH3 gas stream. The NH3 / H2 / N2 gas mixture stream is directed to a primary stage of the gas turbine 100 through a gas turbine supply line 1, and the NH3 gas stream is directed to a secondary stage of the gas turbine 100 through an NH3 gas supply stream line 2. Additionally, a gas turbine auxiliary system for NH3 conditioning is disposed upstream of the gas turbine 100, and includes an NH3 heater / vaporizer / compressor 200 for heating and then vaporizing an NH3 liquid stream from an NH3 stream line 4, and a cracking reactor 300 connected to the NH3 heater / vaporizer / compressor through an NH3 heater / vaporizer / compressor gas outlet line 5 and a cracking reactor supply line 6. According to alternative exemplary embodiments, the NH heater / vaporizer / pressurizer is composed of a shell-and-tube heat exchanger or a plate heat exchanger. In some embodiments, the heat transfer fluid of the heater / vaporizer / pressurizer is gas turbine exhaust gas or another intermediate fluid (such as steam or thermal oil). According to exemplary embodiments, the heat exchanger is made in two stages, one for heating and vaporizing the liquid ammonia, and the other for restoring the initial pressure or finally 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.

[0017] According to the exemplary embodiment shown in FIG. 1, the NH3 cracking reactor 300 is a catalytic or thermal reactor configured to process ammonia and dissociate it into at least its basic components, namely, hydrogen and nitrogen, in the presence of a catalyst or under temperature control, according to the following reactions:

[0018]

number

[0019] The mixture of hydrogen and nitrogen resulting from the cracking reaction and any unreacted ammonia finally present is then conducted to the gas turbine 100 through an NH3 / H2 / N2 gas mixture outlet line 7 connected downstream of the gas turbine supply line 1.

[0020] The NH3 bypass flow is split from the NH3 gas flow from the heater / vaporizer / compressor through an NH3 gas bypass flow line 11, which is connected upstream to the heater / vaporizer / compressor gas outlet line 5 and downstream to the NH3 gas supply flow line 2 of the gas turbine 100, particularly to the secondary stage of the gas turbine 100.

[0021] The system allows the gas turbine control loop to control the proportion of NH3 combusted with H2 and N2 from the cracking reactor according to the operational needs of the gas turbine.

[0022] Exhaust gas from the gas turbine 100 is routed to an exhaust gas flow line 15, from which a portion of the exhaust gas flow is split through an exhaust gas heat recovery line 12 and routed to the cracking reactor 300 and / or the NH3 heater / vaporizer / compressor 200. Referring to Figure 1, the exhaust gas heat recovery line 12 is divided into a first heat recovery sub-line 13 leading to the cracking reactor 300 and a second heat recovery sub-line 14 leading to the NH3 heater / vaporizer / compressor 200.

[0023] An emergency system (not shown) is located along the gas turbine supply line 1 and includes vents and emergency valves to prevent overpressure.

[0024] The gas turbine auxiliary system for NH3 conditioning in Figure 1 operates as follows. The system starts by heating / vaporizing / pressurizing liquid ammonia inside the NH3 heater / vaporizer / compressor 200 and supplying it in a gaseous state to the NH3 cracking reactor 300. A portion of the gaseous ammonia from the NH3 heater / vaporizer / compressor 200 leaks into the NH3 gas bypass flow line 11 and is sent to the gas turbine 100 through the NH3 gas supply flow line 2. A portion of the heat generated by the gas turbine 100 is sent to the NH3 heater / vaporizer / compressor 200 and the NH3 cracking reactor 300. Furthermore, the liquid ammonia is heated, vaporized, and pressurized in the vaporizer / compressor 200, and the NH3 cracking reactor 300 starts operating to supply a gaseous mixture into the NH3 / H2 / N2 gas mixture outlet line 7. A storage drum (not shown) may optionally be disposed 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 value, the gas turbine start-up sequence can begin. Ignition of the gas turbine is achieved by using the stream supplied through the gas turbine supply line 1 or the NH3 gas supply line 2 as fuel and receiving the NH3 gas stream from the NH3 gas bypass flow line 11. If energy is not available to start the NH3 heater / vaporizer / compressor 200 and the NH3 cracking reactor 300, a start-up fuel such as natural gas can be connected to the gas turbine supply line 1 or the NH3 gas supply line 2 and used for gas turbine ignition and ramp-up to the end of the gas turbine sequence or to a full-speed no-load condition. Once the gas turbine is ignited, the exhaust gas heat begins to provide energy to both the NH3 heater / vaporizer / compressor 200, which heats, vaporizes, and pressurizes the liquid ammonia into gaseous ammonia, and the NH3 cracking reactor 300, which cracks the gaseous ammonia into a mixture of hydrogen, nitrogen, and eventually unreacted ammonia. Once the appropriate mixture is created, the flow of the NH3 / H2 / N2 gas mixture stream within the gas turbine supply line 1 is controlled according to the gas turbine control schedule.During the entire sequence of the gas turbine (start-up, load operation, 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 ratio between the gas turbine supply line 1 and the NH3 gas feed line 2. The NH3 cracking reactor parameters managed by the gas turbine auxiliary control unit 37 strictly depend on the NH3 cracking reactor technology. In some embodiments, the NH3 cracking reactor parameters 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 recycle ratio. An emergency shutdown of the gas turbine 100 allows immediate isolation of the gas turbine auxiliary systems for NH3 conditioning from the gas turbine 100 and power down of the NH3 heater / vaporizer / compressor 200 and the NH3 cracking reactor 300 according to their specific safety requirements.

[0025] 1 is controlled through a plurality of control valves that operate according to a control method described herein below. A gas flow valve 21 is disposed along the gas turbine supply line 1 downstream of the NH3 cracking reactor 300 to control the flow of the NH3 / H2 / N2 gas mixture stream within the gas turbine supply line 1. A NH3 gas bypass flow valve 22 is disposed along the NH3 gas supply line 2 downstream of the NH3 gas bypass flow line 11 to control the flow of the NH3 gas bypass flow that is directed to the gas turbine 100 and, conversely, the flow of the NH3 gas stream that is directed to the cracking reactor 300 through the cracking reactor supply line 6. Finally, a heat recovery flow valve 26 is disposed on the first heat recovery subline 13 to control the portion of the exhaust gas from the gas turbine 100 that is directed to the NH3 cracking reactor 300 and, conversely, the portion of the exhaust gas that is directed to the NH3 heater / vaporizer / compressor 200. The gas flow valve 21, the NH3 gas bypass flow valve 22, and the heat recovery flow valve 26 can be electrically operated, pneumatically operated, or hydraulically operated valves.

[0026] Continuing to refer to FIG. 1 , according to the block diagram of the power generation system control architecture shown in FIG. 2 , the flow valves 21 and 22 and the heat recovery flow valve 26 operate as follows. A gas turbine control unit 30, such as a computer or programmable logic controller (PLC), receives the following input parameters: gas turbine parameters 31, combustion parameters 32, and NOx requirements 33. In particular, the gas turbine parameters 31 depend on the gas turbine technology. In some embodiments, the gas turbine parameters 31 include the gas turbine power generation power, the gas turbine speed, and the gas turbine exhaust gas temperature. The combustion parameters 32 depend on the combustion technology employed by the gas turbine. In some embodiments, the combustion parameters 32 include the fuel-to-air ratio in a particular zone of the combustor, the distribution of the heat load along the combustor, and the NOx requirement at the exit of the combustor. x and NH3 slip. The NOx requirement 33 requires NOx in the exhaust stream downstream of the gas turbine. x The total amount of gas (denoted m1 and m2, respectively) supplied to the gas turbine through gas turbine supply line 1 and NH3 gas feed line 2 is a function of the gas turbine parameters listed above. m1+m2=f(GT parameter)

[0027] The volumetric composition of the NH3 / H2 / N2 gas mixture flow in the gas turbine supply line 1 (shown in FIG. 2 as reference numeral 34); 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 flow (m1) through the gas turbine supply line 1 and the NH3 gas supply flow (m2) to the gas turbine through the NH3 gas supply line 2 is a function of the combustion parameters and NOx requirements mentioned above. x 1i = f (combustion parameters; NOx requirements) m2 / (m1+m2)=f(combustion parameters; NOx requirements)

[0028] These parameters are input to an auxiliary control unit 37, such as a computer or programmable logic controller (PLC), which is configured to control the operation of the flow valves 21 and 22 and the heat recovery flow valve 26 according to the following relationships: Y = NH3 / H2 / N2 gas mixture flow rate through the gas turbine supply line 1; 21 is a function of the total amount of gas flow m1 supplied to the gas turbine through the gas turbine supply line 1 and NH3 gas supply flow m2 supplied to the gas turbine through the NH3 gas supply line 2. Y 21 =f(m1+m2)

[0029] Operation of NH3 gas bypass flow valve 22 Y 22 is a function of the ratio 35 of the NH3 gas mass flow rate m2 through the NH3 gas supply flow line 2 to the total mass flow rate of the NH3 / H2 / N2 gas mixture flow m1 through the gas turbine supply line 1 and the NH3 gas supply flow m2 to the gas turbine through the NH3 gas supply flow line 2. Y 22 =f(m2 / (m1+m2))

[0030] Finally, the operation of the heat recovery flow valve 26 is a function of the volumetric composition of the gas. Y 26 =f(x 1i )

[0031] The control method described above allows for varying the composition of the fuel to the gas turbine and injecting ammonia in any ratio according to any final combustor and gas turbine requirements (which are not part of this disclosure).

[0032] Continuing with reference to Figures 1 and 2, Figure 3 shows a schematic diagram of an exemplary power generation system according to a second embodiment. A 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 directed to a first stage of the gas turbine of the gas turbine 100 through a gas turbine supply line 1, the NH3 gas flow is directed to a second stage of the gas turbine of the gas turbine 100 through an NH3 gas supply line 2, and the N2 gas flow is directed to a second stage of the gas turbine of the gas turbine 100 through an N2 gas supply line 3. Further, a gas turbine auxiliary system for NH3 conditioning is disposed upstream of the gas turbine 100, and includes an NH3 heater / vaporizer / compressor 200 for heating and then vaporizing the NH3 liquid stream from the NH3 stream line 4, and a cracking reactor 300 connected to the NH3 heater / vaporizer / compressor through an NH3 heater / vaporizer / compressor gas outlet line 5 and a cracking reactor feed line 6.

[0033] According to this embodiment, the mixture of hydrogen, nitrogen, and unreacted ammonia resulting from the cracking reaction is processed to separate an NH3 / H2 / N2 gas mixture stream and an N2 gas stream. The NH3 / H2 / N2 gas mixture stream from the cracking reactor 300 is directed to the gas turbine 100 through an NH3 / H2 / N2 gas mixture outlet line 7 connected downstream of the gas turbine supply line 1.

[0034] Nitrogen separation can be achieved by different techniques. According to an exemplary embodiment, the NH3 cracking reactor 300 is a membrane reactor that operates as follows: A membrane separates the reactor into two distinct sections. The first section is directly connected to the cracking reactor feed line 6. Ammonia fed to the membrane reactor reacts inside the first section. A fraction of nitrogen resulting from the cracking reaction permeates the membrane and moves to the second section of the membrane reactor, where it is separated from the remaining fractions of hydrogen, unreacted ammonia, and nitrogen, which remain inside the first section of the membrane reactor.

[0035] The N2 gas stream from the cracking reactor 300 is directed to the gas turbine 100 through an N2 gas outlet line 8 connected downstream of the N2 gas supply line 3. A fraction of the N2 gas stream from the cracking reactor 300 can be split and returned to the NH3 / H2 / N2 gas mixture outlet line 7 through an N2 gas bypass line 9 to control the composition of the NH3 / H2 / N2 mixture stream directed to the gas turbine 100 through the gas turbine supply line 1.

[0036] The NH3 bypass flow is split (separated) from the NH3 gas flow from the heater / vaporizer / compressor through an NH3 gas bypass flow line 11, which is connected upstream to the heater / vaporizer / compressor gas outlet line 5 and downstream to the NH3 gas supply flow line 2 of the gas turbine 100, particularly to the secondary stage of the gas turbine of the gas turbine 100.

[0037] The composition of the NH3 / H2 / N2 mixture stream introduced into the gas turbine 100 through the gas turbine supply line 1 is also controlled by mixing the NH3 / H2 / N2 gas mixture stream with ammonia. For this purpose, an NH3 gas bypass split stream is extracted from the NH3 gas bypass stream through an NH3 gas bypass split stream line 10 connected upstream of the NH3 gas bypass stream line 11 and downstream of the NH3 / H2 / N2 gas mixture outlet line 7.

[0038] The system allows the gas turbine control loop to control the proportion of NH3 combusted with H2 and N2 from the cracking reactor according to the operational needs of the gas turbine.

[0039] Exhaust gas from the gas turbine 100 is routed to an exhaust gas flow line 15 from which a portion of the exhaust gas flow is split through an exhaust gas heat recovery line 12 and routed to a cracking reactor 300 and / or an NH3 heater / vaporizer / compressor 200. Referring to Figure 3, the exhaust gas heat recovery line 12 is divided into a first heat recovery sub-line 13 leading to the cracking reactor 300 and a second heat recovery sub-line 14 leading to the NH3 heater / vaporizer / compressor 200.

[0040] An emergency system (not shown) is located along the gas turbine supply line 1 and includes vents and emergency valves to prevent overpressure.

[0041] The gas turbine auxiliary system for NH3 conditioning in Figure 3 operates as follows. The system starts by heating / vaporizing / pressurizing liquid ammonia inside the NH3 heater / vaporizer / compressor 200 and supplying it in a gaseous state to the NH3 cracking reactor 300. A portion of the gaseous ammonia from the NH3 heater / vaporizer / compressor 200 leaks into the NH3 gas bypass flow line 11 and is sent to the gas turbine 100 through the NH3 gas supply flow line 2. A portion of the heat generated by the gas turbine 100 is sent to the NH3 heater / vaporizer / compressor 200 and the NH3 cracking reactor 300. Furthermore, the liquid ammonia is heated, vaporized, and pressurized in the vaporizer / compressor 200, and the NH3 cracking reactor 300 starts operating to supply a gaseous mixture into the NH3 / H2 / N2 gas mixture outlet line 7. A storage drum (not shown) may optionally be disposed 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 value, the gas turbine start-up sequence can begin. Ignition of the gas turbine is achieved by using the stream supplied through the gas turbine supply line 1 or the NH3 gas supply stream line 2 as fuel and receiving the NH3 gas stream from the NH3 gas bypass stream line 11. If energy is not available to start the NH3 heater / vaporizer / compressor 200 and the NH3 cracking reactor 300, a start-up fuel such as natural gas can be connected to the gas turbine supply line 1 or the NH3 gas supply stream line 2 and used for gas turbine ignition and ramp-up to the end of the gas turbine sequence or to a full-speed no-load condition. Once the gas turbine is ignited, the exhaust gas heat begins to provide energy to both the NH3 heater / vaporizer / compressor 200, which heats, vaporizes, and pressurizes liquid ammonia into gaseous ammonia, and the NH3 cracking reactor 300, which cracks the gaseous ammonia into a mixture of hydrogen, nitrogen, and unreacted ammonia. Once the appropriate mixture is created, the flow of the NH3 / H2 / N2 gas mixture stream within the gas turbine supply line 1 is controlled according to the gas turbine control schedule.During the entire sequence of the gas turbine (start-up, load operation, 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 ratio between the gas turbine supply line 1 and the NH3 gas feed stream line 2. An emergency shutdown of the gas turbine allows the immediate isolation of the gas turbine auxiliary systems for NH3 conditioning from the gas turbine and the de-energization of the NH3 heater / vaporizer / compressor 200 and the NH3 cracking reactor 300 according to their specific safety requirements. The NH3 cracking reactor 300 also separates nitrogen from the gas mixture of hydrogen, nitrogen and unreacted ammonia, thus providing a flow of N2 in the N2 gas outlet line 8, which can be used for different applications such as N2 storage or purge service for the gas turbine.

[0042] 3 is controlled through a plurality of control valves that operate according to a control method described herein below. A gas flow valve 21, i.e., valve 21, is disposed along the gas turbine supply line 1 to control the flow of the NH3 / H2 / N2 gas mixture stream within the gas turbine supply line 1. An NH3 gas bypass flow valve 22 is disposed along the NH3 gas bypass flow line 11 to control the flow of the NH3 gas bypass flow directed to the gas turbine through the NH3 gas supply flow line 2, and conversely, the flow of the NH3 gas stream directed to the cracking reactor 300 through the cracking reactor supply line 6. An NH3 gas bypass split flow valve 23 is disposed along the NH3 gas bypass split flow line 10 to control 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 stream directed to the gas turbine 100 through the gas turbine supply line 1. An N2 gas bypass flow valve 24 is disposed along the N2 gas bypass line 9 to control 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 stream that is directed through the gas turbine supply line 1 to the gas turbine 100. In addition, a gas turbine N2 feed flow valve 25 is disposed along the N2 gas feed line 3 to control the flow of nitrogen in the N2 gas outlet line 8 from the NH3 cracking reactor 300 to the gas turbine 100. Finally, a heat recovery flow valve 26 is disposed on the first heat recovery sub-line 13 to control the portion of the heat recovery stream of exhaust gas from the gas turbine 100 that is directed to the NH3 cracking reactor 300, and conversely, the portion of the heat recovery stream that is directed to the NH3 heater / vaporizer / compressor 200. The gas flow valve 21, the NH3 gas bypass flow flow valve 22, the NH3 gas bypass divided 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.

[0043] Continuing to refer to Figure 3, and in accordance with the power generation system control architecture block diagram shown in Figure 4, flow valves 21-25 and heat recovery flow valve 26 operate as follows: The input parameters to gas turbine control unit 30 are gas turbine parameters 31, combustion parameters 32, and NOx requirements 33. The total amount of gas supplied to the gas turbine as the sum of the NH3 / H2 / N2 gas mixture flow (m1) through gas turbine supply line 1, the 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)

[0044] The volumetric composition of the NH3 / H2 / N2 gas mixture flow in the gas turbine supply line 1 (shown in FIG. 2 by reference numeral 34); the ratio 35 of the NH3 gas mass flow rate m2 through the NH3 gas supply line 2 to the total mass flow rate of the NH3 / H2 / N2 gas mixture flow m1 through the gas turbine supply line 1 and the NH3 gas supply flow m2 to the gas turbine through the NH3 gas supply line 2, and the ratio 36 of the N2 gas mass flow rate through the N2 gas supply line 3 to 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 line 2 are functions of the combustion parameters and NOx requirements. x 1i = f (combustion parameters; NOx requirements) m2 / (m1+m2)=f(combustion parameters; NOx requirements) m3 / (m1+m2)=f(combustion parameters);NOx requirement)

[0045] These parameters are inputs to the auxiliary control unit 37, which controls the operation of the flow valves 21-25 and the heat recovery flow valve 26 according to the following relationships: Y = NH3 / H2 / N2 gas mixture flow rate through the gas turbine supply line 1; 21 is a function of the total amount of gas (m1, m2, and m3, respectively) supplied to the gas turbine through gas turbine supply line 1, NH3 gas supply line 2, and N2 gas supply line 3. Y 21 =f(m1+m2+m3)

[0046] Operation of NH3 gas bypass flow valve 22 Y 22 is a function of the ratio 35 of the NH3 gas mass flow rate through NH3 gas supply line 2 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. Y 22 =f(m2 / (m1+m2))

[0047] Operation of NH3 gas bypass dividing valve 23 Y 23 is a function of the volumetric composition of the NH3 / H2 / N2 gas mixture flow in the gas turbine supply line 1. Y 23 =f(x 1i )

[0048] Also, the operation Y of the N2 gas bypass flow valve 24 24 is a function of the volumetric composition of the NH3 / H2 / N2 gas mixture flow in the gas turbine supply line 1. Y 24 =f(x 1i )

[0049] Operation of the N2 supply flow valve 25 of the gas turbine Y 25 is a function of the ratio 36 of the N2 gas mass flow rate m3 through the N2 gas supply line 3 to 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 to the gas turbine through the NH3 gas supply line 2. Y 25 =f(m3 / (m1+m2))

[0050] Finally, the operation of the heat recovery flow valve 26 is a function of the volumetric composition of the NH3 / H2 / N2 gas mixture flow in the gas turbine supply line 1. Y 26 =f(x 1i )

[0051] The control method described above allows for varying the composition of the fuel to the gas turbine and injecting ammonia and nitrogen in any ratio according to any final combustor and gas turbine requirements (which are not part of this disclosure).

[0052] For example, if the combustor requires a hydrogen-rich fuel but a consistent inert fluid (N2) to reduce flame temperature and increase gas turbine power output, Case 1 in Table 1 below is applicable. If the combustor requires a hydrogen-rich fuel but a consistent separate ammonia injection to optimize NOx emissions, Case 3 in Table 1 is applicable. If the combustor does not require a large amount of hydrogen, a large amount of separated ammonia, and a large amount of separated nitrogen, Case 2 in Table 1 is applicable.

[0053] [Table 1]

[0054] With continued reference to Figures 1, 2, 3, and 4, Figure 5 illustrates a third embodiment of a power generation system using a gas turbine and including an ammonia cracker. Like reference numerals designate the same or corresponding parts, elements, or components already illustrated and described in Figures 1, 2, 3, and 4 and will not be described again here.

[0055] The embodiment shown in Figure 5 differs from that of Figure 3 in that at least a portion of the N2 gas flow from the cracking reactor 300 is not directed to the gas turbine 100 but is collected and used for a different purpose. According to this embodiment, the N2 gas outlet line 8 is connected downstream to the N2 gas bleed line 3'. A flow valve 25' is arranged along the N2 gas bleed line 3' to control the flow of nitrogen in the N2 gas outlet line 8 from the NH3 cracking reactor 300 that is directed to external use. The control method of this embodiment is based on the operation of the flow valve 25'. 253 and 4 in that is a function of requirements which do not form the object of the present invention. Y 25’ =f(other requirements)

[0056] With continued reference to Figures 1, 2, 3, 4, and 5, Figure 6 illustrates a fourth embodiment of a power generation system using a gas turbine and including an ammonia cracker. Like reference numerals designate the same or corresponding parts, elements, or components already illustrated and described in Figures 1, 2, 3, 4, and 5 and will not be described again here.

[0057] The embodiment shown in Figure 6 differs from the embodiments of Figures 3 and 5 in that the injection points of the gas turbine supply line 1 and the NH3 gas supply line 2 are swapped. The swapping of the injection points may be necessary to take into account different combustion technologies that may be applied to gas turbines with different flame evolutions along the flow path inside the combustor. In particular, according to this embodiment, the gas turbine supply line 1 is led to a secondary stage of the gas turbine of the gas turbine 100, and the NH3 gas supply line 2 is led to a primary stage of the gas turbine of the gas turbine 100. The control method of this embodiment is the same as that described with reference to Figures 3 and 4.

[0058] Further, with continued reference to Figures 1-6, Figure 7 illustrates a fifth embodiment of a power generation system using a gas turbine and including an ammonia cracker. Like reference numerals designate the same or corresponding parts, elements, or components already illustrated and described in Figures 1-6 and will not be described again here.

[0059] 7 differs from the embodiments of FIGS. 3 to 6 both in that at least a part of the N2 gas flow from the cracking reactor 300 is not directed to the gas turbine 100 but is collected and used for a different purpose, and the injection points of the gas turbine supply line 1 and the NH3 gas supply line 2 are interchanged. In particular, according to this embodiment, the gas turbine supply line 1 is directed to the secondary stage of the gas turbine of the gas turbine 100, and the NH3 gas supply line 2 is directed to the primary stage of the gas turbine of the gas turbine 100. Furthermore, the N2 gas outlet line 8 is connected downstream to the N2 gas withdrawal line 3'. The control method of this embodiment is the same as that described with reference to FIG. 5.

[0060] Finally, with continued reference to Figures 1-7, Figure 8 illustrates a sixth embodiment of a power generation system using a gas turbine and including an ammonia cracker. Like reference numerals designate the same or corresponding parts, elements, or components already illustrated and described in Figures 1-7 and will not be described again here.

[0061] 8 differs from the embodiments of FIGS. 3-7 in that at least a portion of the N2 gas flow from the cracking reactor 300 is not directed to the gas turbine 100 but is sent to the NH3 gas feed 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 feed line 2, if necessary.

[0062] While aspects of the present invention have been described in terms of 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. Additionally, unless otherwise specified herein, the order or sequence of any process or method steps may be varied or rearranged according to alternative embodiments.

Claims

1. A gas turbine (100) and a NH ３ a regulating gas turbine auxiliary system, - Said NH ３ A conditioning gas turbine auxiliary system processes the ammonia input stream and produces a cracked gas containing at least hydrogen and nitrogen, preferably NH ３ / H ２ / N ２ configured to obtain a gas mixture; - Said NH ３ a modulating gas turbine auxiliary system comprising an ammonia cracking reactor (300); - the ammonia input stream is fed through the cracking reactor feed line (6) and the NH ３ The bypass line (11) is divided into - said ammonia cracking reactor (300) is configured to decompose ammonia into a gas mixture of hydrogen and nitrogen or a gas mixture of hydrogen, nitrogen and residual ammonia; the gas mixture outlet line (7) of the cracking reactor is connected to said gas turbine (100); - Said NH ３ The bypass flow line (11) is ３ connected to said gas turbine (100) through a gas supply flow line (2); - the system comprises a gas turbine supply line (1) and a number of flow valves (21, 22, 23, 24, 25) controlled by an auxiliary control unit, The plurality of flow valves (21, 22, 23, 24, 25) are arranged along the gas turbine supply line (1) downstream of the ammonia cracking reactor (300), and / or the NH ３ The NH connected downstream of the bypass flow line (11) ３ NH placed along the gas supply line (2) ３ A power generation system comprising a gas bypass flow valve (22).

2. 2. The power generation system of claim 1, wherein the ammonia cracking reactor (300) is configured to separate the nitrogen stream from a gas mixture of hydrogen and residual nitrogen or a gas mixture of hydrogen, residual nitrogen, and residual ammonia.

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

4. NH ３ A gas bypass split flow line (10) is also provided, ３ A gas bypass split flow line (10) is provided upstream of the NH ３ 4. The power generation system according to claim 1, further comprising a bypass flow line (11) connected downstream to the gas mixture outlet line (7) of the cracking reactor and upstream to the gas turbine (100) to form a gas turbine supply line (1).

5. Said NH ３ The bypass flow is ３ The power generation system of any one of claims 1 to 4, wherein the gas is injected through a gas supply line (2) into a primary stage or alternatively a secondary stage of the gas turbine (100).

6. an NH ３ The power generation system of any one of claims 1 to 5, also comprising a heater / vaporizer / compressor (200).

7. an NH ３ The power generation system according to any one of claims 1 to 5, further comprising a pressurizer.

8. The plurality of flow valves (21, 22, 23, 24, 25) ３ NH disposed along the gas bypass split flow line (10) ３ The power generation system of claim 4, also comprising a gas bypass split flow valve (23).

9. The plurality of flow valves (21, 22, 23, 24, 25) ２ N placed along the gas bypass line (9) ２ A flow valve (24) for the gas bypass flow is also provided and / or the N ２ The supply flow valve (25) ２ 3. The power generation system of claim 2, arranged along a gas supply flow line (3).

10. The gas turbine also includes a heat recovery system configured to recover at least a portion of the heat of an exhaust gas stream from the gas turbine, the heat recovery system including a first heat recovery sub-line configured to direct a first portion of the exhaust gas stream to the cracking reactor, and / or a second portion of the exhaust gas stream to the NH ３ The power generation system of any one of claims 1 to 9, comprising a second heat recovery sub-line (14) configured to lead to a heater / vaporizer / compressor (200).

11. The power generation system of claim 10, also comprising at least one heat recovery flow valve (26).

12. The power generation system of claim 11, wherein the at least one heat recovery flow valve (26) is located on the first heat recovery sub-line (13) or the second heat recovery sub-line (14).

13. 13. A method for controlling the operation of a power generation system according to any one of claims 1 to 12, said method comprising the steps of: - the NH supplied to the gas turbine through the gas turbine supply line (1) ３ / H ２ / N ２ a gas mixture flow (m1) and the NH ３ The NH ３ determining a total amount (m1 + m2) of the gas turbine with the gas supply flow (m2) as a function of said gas turbine parameters; - the NH in the gas turbine supply line (1) ３ / H ２ / N ２ The volumetric composition of the gas mixture flow (x １ｉ ), and the NH ３ The NH ３ Gas mass flow rate (m2) and the NH ３ / H ２ / N ２ The gas mixture flow (m1) and the NH ３ The NH to the gas turbine through a gas supply flow line (2). ３ determining (34) the ratio (35) of the gas feed flow (m2) to the total mass flow rate (m1+m2) as a function of the combustion parameters (32) and the NOx requirement (33); - NH flowing inside the gas turbine supply line (1) ３ / H ２ / N ２ The operation of the gas flow valve (21) that controls the amount of gas mixture flow (Y ２１ ) into the gas flow (m1) supplied to the gas turbine through the gas turbine supply line (1) and the NH ３ The NH4 supplied to the gas turbine through a gas supply line (2) ３ determining the gas feed flow (m2) as a function of the total amount (m1 + m2); - Said NH ３ The NH ３ gas mass flow rate (m2)+ and the NH ３ / H ２ / N ２ The gas mixture flow (m1) and the NH ３ The NH to the gas turbine through a gas supply flow line (2). ３ as a function of the ratio (35) of the gas feed flow (m2) to the total mass flow rate (m1 + m2), ３ Operation of the gas bypass flow valve (22) (Y ２２ and determining a power generation system operation time.

14. The method comprises the steps of: - the volumetric composition of the gas (x １ｉ ) as a function of the operation (Y ２６ 14. The method for controlling operation of a power generation system of claim 13, further comprising determining:

15. 13. A method for controlling the operation of a power generation system according to any one of claims 1 to 12, said method comprising the steps of: - the NH passing through the gas turbine supply line (1) ３ / H ２ / N ２ Mixed stream (m1), the NH ３ The NH ３ gas feed flow (m2), and the N ２ The N passing through the gas supply flow line (3) ２ determining a total amount of gas (m1+m2+m3) supplied to the gas turbine (100) by the gas feed flow (m3) as a function of the gas turbine parameters; - the NH in the gas turbine supply line (1) ３ / H ２ / N ２ The volumetric composition (x １ｉ ), the NH ３ The NH ３ Gas mass flow rate (m2) and the NH ３ / H ２ / N ２ The gas mixture flow (m1) and the NH ３ The NH ３ the ratio (35) of the gas supply flow (m2) to the total mass flow rate (m1 + m2), and ２ The N passing through the gas supply flow line (3) ２ Gas mass flow rate (m3) and the NH ３ / H ２ / N ２ The gas mixture flow (m1) and the NH ３ The NH ３ determining (34) the total mass flow rate (m1 + m2) and ratio (36) of the gas feed streams (m2) as a function of the combustion parameters and the NOx requirement; - NH flowing inside the gas turbine supply line (1) ３ / H ２ / N ２ The operation of the gas flow valve (21) that controls the amount of gas mixture flow (Y ２１ ) through the gas turbine supply line (1) ３ / H ２ / N ２ Gas mixture flow (m1), the NH ３ The NH4 supplied to the gas turbine through a gas supply line (2) ３ gas feed flow (m2), and the N ２ The N passing through the gas supply flow line (3) ２ determining the total amount of gas flow (m1+m2+m3) supplied to the gas turbine by the gas feed flow (m3) as a function of - Said NH ３ The NH ３ Gas mass flow rate (m2) and the NH ３ / H ２ / N ２ The gas mixture flow (m1) and the NH ３ The NH to the gas turbine through a gas supply flow line (2). ３ as a function of the ratio (35) of the gas feed flow (m2) to the total mass flow rate (m1 + m2). ３ Operation of the gas bypass flow valve (22) (Y ２２ ) determining - the NH in the gas turbine supply line (1) ３ / H ２ / N ２ The volumetric composition x of the gas mixture flow １ｉ As a function of ２ Operation of the gas bypass flow valve (24) (Y ２４ ) determining - the N ２ The N passing through the gas supply flow line (3) ２ Gas mass flow rate (m3) and the NH ３ / H ２ / N ２ The gas mixture flow (m1) and the NH ３ The NH to the gas turbine through a gas supply flow line (2). ３ N of the gas turbine as a function of the ratio (36) of the gas feed flow (m2) to the total mass flow (m1 + m2). ２ Operation of the supply flow valve (25) (Y ２５ 20. A method for controlling operation of a power generation system, comprising: determining a power generation capacity;

16. The method comprises the steps of: - the operation of the heat recovery flow valve (26) (Y ２６ 16. The method for controlling operation of a power generation system of claim 15, further comprising determining

17. 13. A method for controlling the operation of a power generation system according to any one of claims 1 to 12, said method comprising the steps of: - the NH passing through the gas turbine supply line (1) ３ / H ２ / N ２ Mixed stream (m1), the NH ３ The NH ３ gas feed flow (m2), and the N ２ The N passing through the gas supply flow line (3) ２ determining a total amount of gas (m1+m2+m3) supplied to the gas turbine (100) by the gas feed flow (m3) as a function of the gas turbine parameters; - the NH in the gas turbine supply line (1) ３ / H ２ / N ２ The volumetric composition (34) of the gas mixture stream, the NH ３ The NH ３ Gas mass flow rate (m2) and the NH ３ / H ２ / N ２ The gas mixture flow (m1) and the NH ３ The NH ３ the ratio (35) of the gas supply flow (m2) to the total mass flow rate (m1 + m2), and ２ The N passing through the gas supply flow line (3) ２ Gas mass flow rate (m3) and the NH ３ / H ２ / N ２ The gas mixture flow (m1) and the NH ３ The NH ３ determining a ratio (36) of the total mass flow rate (m1+m2) of the gas feed streams (m2) as a function of the combustion parameters and the NOx requirement; - NH flowing inside the gas turbine supply line (1) ３ / H ２ / N ２ The operation of the gas flow valve (21) that controls the amount of gas mixture flow (Y ２１ ) through the gas turbine supply line (1) ３ / H ２ / N ２ Gas mixture flow (m1), the NH ３ The NH4 supplied to the gas turbine through a gas supply line (2) ３ gas feed flow (m2), and the N ２ The N passing through the gas supply flow line (3) ２ determining the total amount of gas flow (m1+m2+m3) supplied to the gas turbine by the gas feed flow (m3) as a function of - Said NH ３ The NH ３ Gas mass flow rate (m2) and the NH ３ / H ２ / N ２ The gas mixture flow (m1) and the NH ３ The NH to the gas turbine through a gas supply flow line (2). ３ as a function of the ratio (35) of the gas feed flow (m2) to the total mass flow rate (m1 + m2). ３ Operation of the gas bypass flow valve (22) (Y ２２ ) determining - the NH in the gas turbine supply line (1) ３ / H ２ / N ２ The volumetric composition x of the gas mixture flow １ｉ As a function of ３ Operation of the gas bypass split flow valve (23) (Y ２３ ) determining - the NH in the gas turbine supply line (1) ３ / H ２ / N ２ The volumetric composition x of the gas mixture flow １ｉ As a function of ２ Operation of the gas bypass flow valve (24) (Y ２４ ) determining - the N ２ The N passing through the gas supply flow line (3) ２ Gas mass flow rate (m3) and the NH ３ / H ２ / N ２ The gas mixture flow (m1) and the NH ３ The NH to the gas turbine through a gas supply flow line (2). ３ N of the gas turbine as a function of the ratio (36) of the gas feed flow (m2) to the total mass flow (m1 + m2). ２ Operation of the supply flow valve (25) (Y ２５ 20. A method for controlling operation of a power generation system, comprising: determining a power generation capacity;

18. The method comprises the steps of: - the operation of the heat recovery flow valve (26) (Y ２６ 20. The method for controlling operation of a power generation system of claim 17, further comprising determining:

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