Integrated power production and storage system

Abstract

The present invention provides a combined cycle power plant integrated into manufacturing or production facilities related to the production, use, and storage of hydrogen and oxygen. [Solution] In an integrated power production system, the power plant outputs power to the power grid system and comprises a hydrogen production system, a gas turbine combined cycle power plant including a gas turbine engine that generates a gas flow used to rotate a turbine shaft by burning hydrogen from the hydrogen production system, and a heat recovery steam generator (HRSG) that generates steam with the gas flow from the gas turbine engine to rotate a steam turbine, and a hydrogen storage system, and operates the hydrogen production system with power from the power grid when the power grid system has surplus energy, and balances the active and reactive loads on the power grid system using at least one of the hydrogen production system and the gas turbine combined cycle power plant.

Description

[Technical Field]

[0001] This specification relates in general, but not limited to, to combined cycle power plants used to generate electricity. More specifically, but not limited to, this application relates to the production, use, and storage of hydrogen and oxygen in combined cycle power plants that can be integrated into manufacturing or production facilities. [Background technology]

[0002] The power grid is a mechanism for balancing the total energy demand of consumers using the total energy supply from power-producing machines, including renewable energy sources and traditional power plants such as those that burn fossil fuels.

[0003] Renewable energy sources can include energy resources that do not involve combustion or CO2 emissions. Typical renewable energy sources include hydropower, solar power, and wind power. Solar and wind power, in particular, are intermittent and unpredictable.

[0004] A power plant can include means for generating electricity to meet demand using fuels such as fossil fuels or hydrogen derived from various resources. Fossil fuels can include coal, natural gas, or fuel oil. A typical power plant includes a gas turbine and generator, and often a steam turbine in a combined cycle configuration. Gas turbines and steam turbines can generate electricity from mechanical energy converted from the combustion of fuel and the associated steam generation process.

[0005] Electricity consumers include any electricity user. Consumers can be residential, commercial, or industrial consumers. Consumers can use energy in various ways, thereby creating diverse demands on the power grid.

[0006] Apparent power, actual power, and reactive power

[0007] An electrical circuit consists of various types of power producers or "generators" and power consumers or "loads." A generator produces the power that flows to the load, and then returns to the generator to complete the circuit. An active load is a purely resistive load that converts power entirely into other forms of energy without generating a magnetic field; examples include heaters and incandescent light bulbs. A reactive load is a load that generates a magnetic field to convert power into other forms of energy, such as rotational mechanical force in an induction motor or sound in a speaker. When a reactive load is present in an electrical circuit, it appears that more power is supplied to the load by the generator ("apparent power") than the power consumed by the load ("actual power"), and due to the need to generate a magnetic field, there exists a difference in the alignment between voltage and current, known as phase alignment. In an AC circuit, apparent power (S) is the product of voltage (V) and current (I), given by equation (S=VI). The amount of phase alignment between voltage and current is expressed as an angle (Φ), ranging from -90 degrees to +90 degrees. A phase angle Φ = zero indicates that the voltage and current are perfectly phase-aligned, and S = VI represents not only apparent power but also real power (P), so S = P = VI. This corresponds to a circuit that includes a full active load but does not include a reactive load. In a circuit with a reactive load, the voltage and current are out of phase due to the need to generate a magnetic field, and it appears that more power is supplied by the generator than is consumed by the load, where Φ represents the amount of alignment or phase angle between the voltage and current, and the real power is given by the equation P = VIcos(Φ). The difference between apparent power and real power is given by the relationship S = (P 2 +Q 2 ) 1 / 2Given by Q = VIsin(Φ), Q is defined as “reactive power”. As a result, reactive power is the difference between apparent power and real power generated in a circuit, and reactive power is given by the relation Q = VIsin(Φ) and is measured in units known as Volt-Amp-Reactive or VAR. Reactive power can be generated in a generator by increasing or decreasing the voltage that generates a magnetic field ("excitation voltage"), or by controlling the amount of reactive load in a circuit, such as turning reactive loads on or off to control the VAR flow of the entire system. Failure to manage the balance of both active and reactive power flows can lead to fluctuations in both voltage and frequency within the power system, potentially damaging electrical equipment.

[0008] An inverter is an electrical device that converts direct current (DC) power into alternating current (AC) power.

[0009] A rectifier is an electrical device that converts alternating current (AC) power into direct current (DC) power.

[0010] As mentioned above, various factors can have a significant impact on the stability of the power grid. Specifically, this includes (1) when large industrial consumers start (or stop) using large amounts of electricity, or (2) when there are large fluctuations in electricity demand by residential and / or commercial consumers during seasonal variations in demand, such as a) off-peak periods like nighttime and midday versus peak periods like morning and evening, and b) relatively low demand for cooling loads in summer, heating loads in winter, and spring and autumn, or (3) when the type of load changes on a system, such as when a large amount of active load is started or stopped, like lighting that rises and falls with daylight and electric heaters that are started or stopped in response to temperature changes during winter, or (4) when the types of available power generation, such as wind, solar, nuclear fuel, or fossil fuels, change due to changes in weather patterns at both local and regional and national scales, either a) for short periods when the weather system changes, or b) on a seasonal basis as spring, summer, autumn, and winter transitions occur, or (5) when the way consumers use electricity can affect the availability of active and reactive power in addition to the system's voltage and frequency. For example, a single consumer using multiple large induction motors may result in a large amount of reactive power being required, which could effectively reduce the availability of real power that should be used by other consumers, or affect the voltage and frequency of the power grid, requiring adjustments to avoid damage to electrical components and devices. Such demands must be balanced against all of the aforementioned changes in apparent power, real power, and reactive power (collectively referred to as “active and reactive power changes” hereafter, along with other similar changes in the power grid).

[0011] In accordance with the aforementioned active and reactive power changes, the power grid must respond to maintain a balance between the supply and demand for active power, reactive power, system voltage, and frequency. The current way the grid responds is by requiring at least some suppliers of power from both power plants and renewable sources to maintain balance by increasing or decreasing their output of actual power in relation to the amount of watts supplied, and by balancing reactive power by supplying or consuming reactive power in relation to the VAR consumed or supplied by changing the nature of their operation. These various supplies and demands for active power, reactive power, system voltage, and frequency generally operate in isolation from one another, with only the grid administrator managing active and reactive power changes. Such external management is complex and may require numerous instances of power producers being started, stopped, and having their output levels changed, which leads to inefficiencies in the overall system. [Prior art documents] [Patent Documents]

[0012] [Patent Document 1] U.S. Patent No. 5,266,024 [Overview of the project] [Means for solving the problem]

[0013] The inventors have recognized that, in particular, the problems to be solved in power plants may include inefficient production, use, and storage of electricity, especially when consumers change their electricity demand and electricity producers attempt to respond to these changes in demand.

[0014] The inventors recognized that, ideally, the power grid should consume as much renewable energy as possible, because such energy is perceived to be supplied at a lower cost and with reduced environmental impact compared to traditional power plants that utilize fossil fuels. However, the availability of such renewable energy is intermittent and unpredictable. The sun is only available for a portion of the day, wind is unpredictable, and the availability of both forms of energy changes seasonally. Therefore, as the supply or demand for renewable energy fluctuates, the output and reactive power balance of power plants are required to fluctuate. In addition, as the demand and reactive power balance fluctuates, in some cases measures can be taken to reduce the supply from renewable resources, such as reducing the blade pitch of wind turbines. However, this is suboptimal because it represents a loss of opportunity to utilize electricity at a lower cost and with reduced environmental impact. In some areas with abundant solar energy supply, power plants may be required to be "off" (not generating electricity) during the day and "on" at night.

[0015] However, power plants represent complex systems with considerable physical and thermal mass. These systems often require a considerable time to start up or shut down in order to avoid damage that may result from sharp temperature gradients associated with rapid transitions in power output. Furthermore, complex systems are generally designed to yield optimal performance at a specific design point, while operation at other points is often suboptimal. For example, gas turbines are often designed to yield optimal efficiency and emissions at a specific base power output, while operation at other power outputs is less efficient and / or results in undesirable increases in emissions. Therefore, it is desirable for gas turbine power plants to (1) operate near their base power design point, and (2) avoid sharp temperature gradients associated with rapid power transitions.

[0016] In response to the demands of obtaining changes in the system's active and reactive power and the maximum consumption of renewable energy, the grid can typically command power plants to increase or decrease their power output to meet reduced demand, often at a rate of change detrimental to the power plants.

[0017] This subject matter can help provide solutions to these and other problems by using novel thermal and electrical integrations of various equipment, short-term and long-term storage systems and strategies, and new operational concepts and controls. The various systems of this disclosure can 1) stabilize the operating profile of a gas turbine, 2) provide consistent active and reactive power across a range of scenarios within the power grid of a power system, 3) provide a rapid response to changes in demand for active and reactive power, 4) provide voltage and frequency support to the grid, 5) maximize the use of available renewable energy, and 6) reduce carbon dioxide emissions from a gas turbine power plant in either a simple cycle configuration or a combined cycle configuration during fluctuations in renewable energy supply and consumer demand.

[0018] For example, under normal conditions, an electrolytic cell takes time to start operating, consuming a large amount of electricity to heat the water within the device. However, through a novel integration of a combustion turbine power plant and an electrolytic cell, the water can be kept at an operating temperature so that, in response to a large industrial consumer ceasing its demand for electricity, the power grid can immediately command the electrolytic cell to begin consuming electricity to convert the water into hydrogen and oxygen gases. For example, the feedwater to the electrolytic cell can be regulated by first passing through or flowing out of a heat recovery steam generator (HRSG) that captures thermal energy from a gas turbine to generate steam to drive a steam turbine. If the electrolytic cell's capacity is greater than the amount of electricity the consumer was using, the start of the water conversion can maintain grid balance without the need to change the gas turbine's operating profile.

[0019] As the electrolytic cell begins converting water (H2O) into H2(H2) and O2(O2), the gas turbine can change its operation to consume H2, thereby reducing its consumption of fossil fuels (i.e., natural gas or fuel oil). In this way, the power grid can maintain a balance while maximizing its use of renewable energy, avoiding harsh transitions in gas turbine loading, and reducing consumption and corresponding purchasing and environmental costs associated with the combustion of fossil fuels. H2 may be mixed with other fuels or may be the sole fuel consumed by the gas turbine. In either case, since the sole combustion product of H2 is water vapor, the consumption of H2 represents an improvement in gas turbine emissions.

[0020] Furthermore, the control system can utilize intelligence to modify the operation of the gas turbine. For example, if the control system has grounds to anticipate that consumer demand will not increase for some time, it can choose to shut down the gas turbine at a transition rate that avoids the progression of damage to the temperature gradient, and in the most efficient manner that reduces environmental emissions. As the gas turbine output transitions, the electrolytic cell consumption can also transition, thereby resulting in an essentially balanced transition.

[0021] In addition, through the use of inverters and rectifiers, electrolytic cells can be used to balance reactive power on the power grid.

[0022] Furthermore, the electrolyzer can be coupled with H2 storage, which can further enhance the flexibility provided by the system. Using sufficient H2 storage, during peak supply periods (such as when supply dramatically exceeds demand and the power grid requires, in some cases, the shutdown of gas turbines or the reduction of renewable resource production), the system can enable the gas turbine to operate at its optimal design point and avoid such reductions. In such situations, surplus power (i.e., the difference between supply and demand) can be used to power the electrolyzer to produce and store H2 gas.

[0023] Ideally, during such periods, the power generation capacity of the electrolyzer's H2 output exceeds that of the gas turbine, whereby the gas turbine is operated at its design point for 100% H2 gas and hydrogen can be stored for future use. In such a scenario, the gas turbine would be operating at its most efficient point while discharging only steam.

[0024] The system can utilize different amounts of H2 storage as needed. As explained above, balancing benefits and emissions reduction while the power grid avoids severe temperature gradients can be achieved with minimum storage. However, with additional storage, these benefits can be enhanced by enabling the maximum use of renewable energy while continuing the operation of the gas turbine at its optimal design point (or with a sufficiently long transition point to minimize damage to the temperature gradient).

[0025] For those cases where optimizing storage is desirable, transport pipelines can offer considerable storage. For example, a gas turbine operating at a power output of 500 megawatts is known to consume approximately 27 tons of H2 per hour of operation when operating at 100% H2 content. Typical fuel pressure for gas turbine operation is approximately less than 800 pounds per square inch (psi). A 24-inch diameter pipe with a minimum wall thickness of 0.834 inches is strong enough to withstand 3000 psig of H2 gas. Each (1) mile length of such pipe can contain 4.6 tons of H2 gas when circulating between 3000 psig and 800 psig. That is, each 6-mile pipe can store 27.6 tons of H2, which can provide approximately one hour of operation for a gas turbine at 500 MW.

[0026] If the gas turbine is located at a sufficient distance from the H2 source, the transport pipeline can provide sufficient storage on its own. In addition, if the gas turbine and H2 source are installed together, one or more pipelines, each capped at one end or connected together to form a closed system, can extend from the site to a certain distance away, forming an artificial underground storage container. However, if additional on-site storage is needed or desired, the pipe arrangement described herein can provide an improved storage arrangement. The pipe arrangement described herein may include pipes arranged alternately in an inverted pyramid shape, located underground and with construction fill between them. In practice, the construction fill is arranged to result in an inverted pyramid shape, and the pipes are overlapped alternately. Due to the strength of the hoops and the inverted pyramid shape, no internal framework or structure is required.

[0027] For example, a power plant may include a hydrogen production system configured to output power to the power grid and produce hydrogen; a gas turbine combined cycle power plant including a gas turbine engine configured to burn hydrogen from the hydrogen production system to generate a gasflow that can be used to rotate a turbine shaft, and a heat recovery steam generator (HRSG) configured to generate steam with the gasflow from the gas turbine engine to rotate a steam turbine; a storage system configured to store the hydrogen produced by the hydrogen production system; and a controller configured to operate the hydrogen production system with power from the power grid when the power grid has surplus energy, and to balance the active and reactive loads on the power grid using at least one of the hydrogen production system and the gas turbine combined cycle power plant.

[0028] In another example, the power plant may include an electrolytic cell configured to output power to a power grid system and produce hydrogen and oxygen; a gas turbine engine configured to generate a gas flow that can be used to burn hydrogen from the hydrogen production system to rotate a turbine shaft; and a heat recovery steam generator (HRSG) configured to generate steam from the gas flow of the gas turbine engine to rotate a steam turbine; a storage system configured to store the hydrogen produced by the hydrogen production system; and nozzles configured to guide oxygen from the electrolytic cell into the HRSG of the gas turbine combined cycle power plant.

[0029] In an additional example, a method for burning fuel using a hot nozzle comprises the steps of (A) supplying an oxidizer having an oxygen concentration of at least 30 volume percent into an oxidizer supply duct communicating with a combustion zone at an initial velocity of less than 300 fps, and (B) supplying fuel separately into the oxidizer supply duct at a speed of 200 feet per second or more and faster than the initial velocity of the oxidizer, thereby mixing the oxidizer with the high-speed fuel, and burning up to about 20% of the oxygen in the oxidizer supplied into the oxidizer supply duct together with the fuel to generate heat and combustion reactions. The process may include the steps of (c) producing a reaction product and further mixing the combustion reaction product and oxidizer into the combustion reaction, (d) mixing the combustion reaction product with the remaining oxygen of the oxidizer in the oxidizer supply duct to raise the temperature of the remaining oxidizer in the oxidizer supply duct, and (D) discharging the heated oxidizer from the oxidizer supply duct into the combustion zone at an outlet velocity exceeding an initial velocity of at least 300 feet per second, wherein the heated oxidizer is discharged out of the oxidizer supply duct through a plurality of orifices positioned in different directions.

[0030] For example, a power plant configured to output electricity to a power grid system may include an electrolytic cell configured to produce hydrogen and oxygen, a power converter that electrically connects the electrolytic cell to the power grid system, a gas turbine combined cycle power plant including a gas turbine engine configured to burn hydrogen from a hydrogen production system to generate a gas flow that can be used to rotate a turbine shaft, and a heat recovery steam generator (HRSG) configured to generate steam from the gas flow of the gas turbine engine to rotate a steam turbine, a storage system configured to store the hydrogen produced by the hydrogen production system, and a controller configured to balance active and reactive loads on the power grid system using at least one of the power converter, the hydrogen production system, and the gas turbine combined cycle power plant.

[0031] For example, a method for operating an integrated power plant connected to a power grid system may include the steps of: operating a gas turbine engine to drive a first generator to supply power to the power grid system, wherein the gas turbine engine is capable of operating on at least one of hydrogen and natural gas; operating an electrolytic cell to produce hydrogen and oxygen with electricity from the power grid system; storing the hydrogen produced by the electrolytic cell in a storage system; and coordinating the operation of the gas turbine engine and the electrolytic cell to supply power to the demands of the power grid system.

[0032] This abstract is intended to provide a summary of the subject matter of this patent application. It is not intended to provide an exclusive or comprehensive description of the invention. Modes for carrying out the invention are included to provide further information about this patent application. [Brief explanation of the drawing]

[0033] [Figure 1A] This is a schematic diagram showing an integrated power production system including a combined cycle gas turbine power plant (GTCC), a hydrogen production system, a hydrogen storage system, and a controller. [Figure 1B] This is a schematic diagram showing an integrated power production system including a combined cycle gas turbine power plant (GTCC), a hydrogen production system, a hydrogen storage system, and a controller. [Figure 2] This schematic diagram shows an exemplary main control system for subsystems shown in Figures 3 to 10, suitable for use within the integrated power production system shown in Figures 1A and 1B. [Figure 3] This is a schematic diagram showing an exemplary combined-cycle power plant having an electrolytic cell connected to a hydrogen receiving tank and power conversion equipment. [Figure 4] This is a schematic diagram showing a heat recovery steam generator connected to an electrolytic cell, as well as to a battery and a renewable energy source. [Figure 5] This is a schematic diagram showing the cooling loop for the electrolytic cell bank. [Figure 6] This is a schematic diagram showing a heat recovery steam generator connected to an electrolytic cell and a hydrogen surge system. [Figure 7] This is a schematic diagram showing a hydrogen storage system. [Figure 8] This is a schematic diagram illustrating a polygeneration facility, including a combined cycle power plant, renewable energy producer, hydrogen and oxygen storage systems, and electrolytic cells, connected to an industrial power consumer or plant. [Figure 9] This is a schematic diagram showing a nozzle for generating high-temperature oxygen for injection into a heat recovery steam generator. [Figure 10] This is a schematic diagram showing a hybrid power converter that connects the power grid to electrolytic cell banks, battery banks, and renewable energy sources. [Figure 11] This is a schematic diagram showing a vertically arranged piping system suitable for use as a hydrogen storage system. [Figure 12] This is a schematic diagram showing multiple vertically arranged piping systems. [Figure 13A] This is a schematic diagram showing a perspective view of a system of vertically arranged piping, including pipes with changing directions. [Figure 13B] This is a schematic diagram showing an end view of a system of vertically arranged piping, including pipes with changing directions. [Figure 14A] This is a schematic diagram showing a side view of a multiple vertically arranged piping system, including pipes arranged in a radial pattern. [Figure 14B] This is a schematic diagram showing a top view of a system of vertically arranged piping, including pipes arranged in a radial pattern. [Figure 15] This is a schematic diagram showing a side view of multiple horizontally arranged piping systems arranged at multiple levels. [Figure 16A] This is a schematic diagram showing various arrangements of the layering of the piping system of this disclosure. [Figure 16B] This is a schematic diagram showing various arrangements of the layering of the piping system of this disclosure. [Figure 16C] This is a schematic diagram showing various arrangements of the layering of the piping system of this disclosure. [Figure 16D] This is a schematic diagram showing various arrangements of the layering of the piping system of this disclosure. [Figure 16E] This is a schematic diagram showing various arrangements of the layering of the piping system of this disclosure. [Figure 16F] This is a schematic diagram showing various arrangements of the layering of the piping system of this disclosure. [Figure 17] This is a schematic diagram showing a top view of the overhead support structure for fabricating and incorporating the piping system. [Figure 17A] This is a schematic diagram showing a side view of the overhead support structure for fabricating and incorporating the piping system. [Figure 17B] This is a schematic diagram showing a side view of the overhead support structure for fabricating and incorporating the piping system. [Figure 18] This is a schematic diagram showing a top view of an overhead welding gantry system for fabricating and installing a piping system. [Figure 18A] This is a schematic diagram showing a side view of an overhead welding gantry system for fabricating and installing a piping system. [Figure 18B] This is a schematic diagram showing a side view of an overhead welding gantry system for fabricating and installing a piping system. [Figure 19] Figures 18-18B are schematic diagrams showing a top view of the overhead welding gantry system with further sections of assembled pipes. [Figure 19A] Figures 18-18B are schematic diagrams showing a side view of the overhead welding gantry system with further sections of assembled pipes. [Figure 19B] Figures 18-18B are schematic diagrams showing a side view of the overhead welding gantry system with further sections of assembled pipes. [Figure 20]This is a schematic diagram showing how the assembled pipe container is lowered into the trench. [Figure 20A] This is a schematic diagram showing how the assembled pipe container is lowered into the trench. [Figure 20B] This is a schematic diagram showing how the assembled pipe container is lowered into the trench. [Figure 21] This is a schematic diagram showing how the second pipe container is assembled. [Figure 21A] This is a schematic diagram showing how the second pipe container is assembled. [Figure 21B] This is a schematic diagram showing how the second pipe container is assembled. [Figure 22] This is a schematic diagram showing how the second pipe container is lowered into the groove and the third pipe container is assembled. [Figure 22A] This is a schematic diagram showing how the second pipe container is lowered into the groove and the third pipe container is assembled. [Figure 22B] This is a schematic diagram showing how the second pipe container is lowered into the groove and the third pipe container is assembled. [Figure 23A] This is a schematic diagram showing multiple elongated horizontal piping systems incorporated into multiple layers that do not have access passages. [Figure 23B] This is a schematic diagram showing multiple elongated horizontal piping systems incorporated within multiple layers. [Figure 23C] This is a schematic diagram showing multiple elongated horizontal piping systems incorporated within multiple layers that have access passages. [Figure 24] This is a schematic diagram showing multiple vertically arranged piping systems connected to the power grid, including those for consumers. [Figure 25] This is a schematic diagram showing multiple vertically arranged piping systems connected to the power grid, including consumers, and underground storage cavities. [Figure 26] This is a schematic diagram showing multiple vertically arranged piping system banks and underground storage cavities connected to the power grid, including consumers. [Figure 27]This is a schematic diagram showing a power grid including multiple vertically arranged piping system banks and underground storage cavities connected to each other, as well as consumers. [Figure 28] This is a schematic diagram showing an underground storage cavity connected to a power grid without a piping system. [Figure 29] Figures 1A and 1B are schematic diagrams showing the components of the controller for operating the integrated power production system. [Modes for carrying out the invention]

[0034] In drawings that are not necessarily drawn to scale, similar numbers may describe similar components in different drawings. Similar numbers with different subscripts may represent different instances of similar components. Drawings generally illustrate various embodiments described herein as examples, not limitations.

[0035] Figures 1A and 1B are schematic diagrams showing an integrated power production system 100 that offers many advantages over a reference system and a conventional system. System 100 may include a combined cycle gas turbine power plant (GTCC) 104, a hydrogen production system 106, and a controller 108.

[0036] Control signals between various components and systems are indicated by dashed / dotted lines, electrical connections through which electricity can flow are indicated by dashed lines, and process lines through which gas or fluid can flow are indicated by solid lines.

[0037] In the example, the hydrogen production system 106 may include an electrolytic cell that also produces oxygen. The power production system 100 may also include one or both of the hydrogen storage system 110 and the oxygen storage system 112.

[0038] The GTCC104 may include a gas turbine 114, a heat recovery steam generator 116, and a steam turbine 118.

[0039] Controller 108 may be connected to the hydrogen production system 106 via controllers 120 and 122. Controller 108 may be connected to the GTCC 104 via controllers 124 and 126.

[0040] The power grid 128 provides electrical connections between various power sources, such as renewable wind power sources 130, renewable photovoltaic solar power sources 132, or combined cycle gas turbine power plants 104, and power consumers 152. Exemplary consumers 152 include residences, commercial buildings, and industrial facilities. Various consumers 152 can utilize varying levels of active and reactive power.

[0041] Although only one consumer 152, one renewable wind power source 130, one renewable photovoltaic solar power source 132, one GTCC 104, one hydrogen production system 106, one hydrogen storage system 110, and one oxygen storage system 112 are shown in Figures 1A and 1B, the power production system 100 can include multiple instances of each, either in the same geographical location or distributed across a wider geographical area.

[0042] The main controller 108 provides command signals to various power sources, including the wind power source 130, the solar power source 132, and the gas turbine 114, in order to ensure that the total supply and demand for power remain balanced. The main controller 108 can work in conjunction with the electrolytic cell production setpoint controller 122 and the electrolytic cell VAR setpoint controller 120, respectively, and the GTCC output setpoint controller 124 and the GTCC VAR setpoint controller 126, respectively, to ensure a balance between the supply and demand for active power, reactive power, system voltage, and frequency. The main controller 108 can also regulate when hydrogen is produced or consumed, and when power is supplied by using stored hydrogen or producing H2 for storage. As illustrated with reference to Figures 4 and 10, for example, the power production system 100 may additionally include various battery storage systems for short-term power storage and reactive load adjustment, as described herein. As will be explained with reference to Figure 8, for example, the integrated power production system 100 may be further integrated with an industrial plant that can consume power from the power grid 128 and receive various inputs from the system 100.

[0043] The decisions of the main controller 108 may be based on market conditions, the availability of renewable power, grid electricity costs, and other factors. In this way, the main controller 108 can manage power production from renewable wind power sources 130, renewable photovoltaic solar power sources 132, and combined cycle gas turbine power plants 104 based on demand on the grid 128, weather conditions, and other factors, while also managing hydrogen production in the hydrogen production system 106 using, for example, the consumption of hydrogen and oxygen in the GTCC 104 and industrial facilities 350 (Figure 8), and managing long-term and short-term energy storage in the form of hydrogen and oxygen storage in the hydrogen storage system 110 and oxygen storage system 112, respectively, and power in various batteries.

[0044] Power from the power grid 128 may first be supplied to a transformer 133 to convert the voltage of the power grid 128 to a selected voltage optimized for the operation of a power converter 134 for converting AC power to DC power. In this example, the converter 134 may be a rectifier that can receive alternating current (AC) from the power grid 128 and produce direct current (DC) that may be optimal for the operation of the electrolytic cells of the hydrogen production system 106. In addition, the converter 134 may be a hybrid converter as described herein. The GTCC 104, steam turbine 118, wind power source 130, and solar power source 132 may each be provided with transformers 135A to 135D to convert the voltage of the power they generate to a voltage suitable for the power grid 128.

[0045] The hydrogen production system 106 may be connected to a hydrogen purification system 136 that can use a hydrogen compressor 138 to supply hydrogen to the hydrogen storage system 110, and an oxygen purification system 140 that can supply oxygen to the oxygen storage system 112. The hydrogen purification system 136 may include a palladium membrane hydrogen purifier, a high-density thin-film metal membrane purifier, a pressure swing adsorption purifier, a catalytic recombination or deoxygenation purifier, or an electrochemical purifier, and others. The oxygen purification system 140 may utilize a low-temperature distillation process or a vacuum swing adsorption process. Valve 142 may be used to control the flow of stored hydrogen to the gas turbine 114. Valve 143 may be used to control the flow of stored oxygen to the HRSG 116. Valve 144 may be used to control the flow of natural gas to the gas turbine 114. Natural gas may be supplied via a natural gas source 146. The controller 108 can control the flow of hydrogen, oxygen, and natural gas to the GTCC 104 based on factors described herein (e.g., availability of renewable energy) in order to optimize the total output of the system 100 (e.g., power and hydrogen).

[0046] The combined cycle gas turbine power plant 104 includes a gas turbine 114, a heat recovery steam generator (HRSG) 116, and a steam turbine 118. The functions and operations of the combined cycle gas turbine power plant 104 are understood by those skilled in the art, and many of their details are omitted herein for brevity. The gas turbine 114 includes a compressor 148, a combustor 150, and a turbine 152. The compressor 148, the turbine 152, and the generator 154 are physically connected via one or more shafts and can rotate together. Air is introduced into the compressor 148, which compresses the air, and fuel is introduced into the compressed air in the combustor 150. The fuel is ignited, and the combustion products have a very increased temperature and pressure (and energy) relative to the compressed air. The high-energy combustion products expand in the turbine 152, which drives the compressor 148 and the generator 154.

[0047] After the high-energy combustion products exit the gas turbine 114, they are called exhaust gases and are led through the HRSG 116. The HRSG 116 may include one or more heat exchange assemblies that transfer heat from the exhaust gases to water. The water may be in the form of liquid water or steam. The HRSG 116 may have various stages to produce steam at specific temperature and pressure characteristics. Furthermore, as will be explained with reference to Figure 3, the heat from the steam may be used, for example, to heat the electrolytic cells of the hydrogen production system 106 using heat exchanger 158 or heat exchanger 162. The steam is then led to the steam turbine 118, which may be physically connected to the generator 156 via a clutch 160. In this example, the clutch 160 may be omitted. From the steam turbine 118, the steam may flow into a heat exchanger 162, such as a condenser, where the steam can be cooled. The heat from the steam and the water from the HRSG 116 may additionally be fed into another system, for example, as shown in Figure 8. In some examples, the generator 156 may be the same generator connected to the gas turbine 114, or in other examples, it may be a separate generator (as shown in Figures 1A and 1B). The steam can expand within the steam turbine 118, transmitting torque to the generator 156 to generate electricity. The steam can then condense into liquid water, which is returned to the HRSG 116 and reheated to achieve specific properties. It will be understood that, as usual, the water can circulate between the HRSG 116 and the steam turbine 118 in a loop.

[0048] In this example, controller 108 is a main controller that signals to at least one of the following: electrolytic cell VAR (volt-ampere reactive power) setpoint controller 120, electrolytic cell production setpoint controller 122, GTCC plant output controller 124, and GTCC plant VAR setpoint controller 126, each of which can respond to command signals provided by the main controller 108, as will be described in more detail below.

[0049] The hydrogen production system 106 can produce hydrogen using many different processes. Thermochemical processes use heat and chemical reactions to release hydrogen from fossil fuels and organic materials such as biomass, or from materials such as water. Water (H2O) can also be separated into hydrogen (H2) and oxygen (O2) using electrolysis or solar energy. Microorganisms such as bacteria and algae can produce hydrogen through biological processes.

[0050] In the example, the hydrogen production system 106 includes an electrolytic cell. The electrolytic cell may be an electrical device that can operate by consuming electricity to convert water into its constituent elements, hydrogen and oxygen. Generally, the electrolytic cell consumes DC power and utilizes a converter 134 to convert AC current to DC current. The hydrogen can be stored in a hydrogen storage system 110, which may include tanks, pipelines, salt cavities, or other geological repositories, as described with reference to Figures 11 to 16F. As will be understood by those skilled in the art, the electrolytic cell of the hydrogen production system 106 generally takes water and electricity as inputs to produce hydrogen gas and oxygen gas.

[0051] Electricity may be supplied via the power transmission and distribution network 128. The power transmission network 128 may obtain electricity from one or more of various power sources, such as the renewable wind power source 130 and the renewable photovoltaic solar power source 132. The power transmission network 128 may also obtain electricity from other sources, such as hydroelectric power plants, nuclear power plants, one or both of the generators 154 of the gas turbine 114 and the generators 156 of the steam turbine 118 of the combined cycle gas turbine plant 104, or from other gas turbine generators connected to the power transmission network 128.

[0052] The operation of the electrolytic cell in the hydrogen production system 106 can respond to the production setpoint controller 122. The production setpoint controller 122 can control the amount of DC current supplied to the electrolytic cell. The supply of DC current and water to the electrolytic cell is directly related to the production of hydrogen gas and oxygen gas.

[0053] The operation of the electrolytic cell of the hydrogen production system 106 can also respond to the electrolytic cell VAR setpoint controller 120. The VAR setpoint controller 120 can control the amount of alternating current that is converted into direct current to be supplied to the electrolytic cell.

[0054] A power inverter converts DC power to AC power. A power inverter is a grid connection device that enables the power to be fed into the power grid 128. Typical uses of power inverters are unidirectional and may include, for example, those in a photovoltaic solar power source 132 or a fuel cell.

[0055] In the example, converter 134 may include thyristor rectifier technology using transistor electronics that can convert single-phase, two-phase, or three-phase AC power to DC power. Such DC power output is generally unidirectional and not smooth, and is typically used for electroplating, DC processes, and electrolytic cell stacks.

[0056] In the example, converter 134 may include chopper rectifier technology using a combination of silicon-controlled rectifiers (SCRs) and insulated-gate bipolar transistors (IGBTs) to convert single-phase, two-phase, or three-phase AC power to DC power. Such DC power outputs are generally unidirectional and not smooth, and are typically used for electroplating, DC processes, and electrolytic cell stacks.

[0057] In this example, converter 134 may be a power conversion system (PCS) that uses IGBTs and PWM (pulse wave modulation) to convert single-phase, two-phase, and three-phase AC power to DC, and also obtains DC power from a source such as an electrochemical battery, wind turbine, or solar power generator and converts the DC power to AC power. Such a PCS is bidirectional, and both AC and DC are "clean," close to a pure waveform without harmonics or "ripple," and is a typical technique used to supply active and reactive power services to the power grid 128.

[0058] In the example, converter 134 may be a “hybrid power conversion” system. The hybrid power conversion system can use a PCS topology on the AC (transmission grid 128) side and a chopper / thyristor topology on the DC side connected to the electrolytic cell of the hydrogen production system 106. This provides “clean” AC power that can be phase-angled to supply reactive power services to the transmission grid 128, while producing “unclean” DC suitable for use by the electrolytic cell to perform electrolysis at low cost. It will be understood that this hybrid power conversion can generally provide beneficial transmission grid services, such as reactive power services provided by a full PCS topology, at a lower overall cost. Since the “hybrid power conversion” system can connect to the transmission grid 128 and provide reactive services, it is desirable that it be certified to UL standard UL1741 or its equivalent. An example of a hybrid power conversion system for converter 134 will be further described with reference to Figure 10.

[0059] It will be understood that the electrolytic cells of the hydrogen production system 106 can receive water and DC power from the converter 134 to produce hydrogen gas and oxygen gas. Some examples of electrolytic cells may also require the input of an electrolyte such as potassium hydroxide. The hydrogen gas can proceed to the hydrogen purification system 136, the hydrogen compressor 138, and enter the hydrogen storage system 110. Similarly, the oxygen gas can proceed to the oxygen purification system 140 and enter the oxygen storage system 112. A similar oxygen compressor (e.g., compressor 356 in Figure 8) may be used as appropriate. Although examples as hydroxide electrolytic cells have been described herein, it will be understood that the scope of this disclosure is not limited in that way and is intended to include other electrolytic cell configurations, such as polymer electrolyte membrane (PEM) electrolysis units.

[0060] The hydrogen storage system 110 may include a rock salt cavity for storing hydrogen gas. In some examples, the hydrogen storage system 110 may include one or more pipes or pressure vessels of one or more lengths, such as a highly compressible “bullet” shape or spherical shape, for storing hydrogen. Examples of the hydrogen storage system 110 will be described in more detail with reference to Figures 11 to 16F.

[0061] The hydrogen gas in the hydrogen storage system 110 can be used as fuel and supplied to the combustor 150 of the gas turbine 114. Flow valves 142 and 144 can respond to the GTCC plant output controller 124 to supply the flow of hydrogen and natural gas fuel to the gas turbine 114. Under certain conditions, the controller 124 can instruct valves 142 and 144 to supply, for example, only one fuel (either natural gas or hydrogen) to the gas turbine 114. Under other conditions, the controller 124 can instruct valves 142 and 144 to supply, for example, a mixture of both natural gas and hydrogen to the gas turbine 114.

[0062] Compared to natural gas, hydrogen combustion occurs at a higher temperature. Higher temperature combustion can be expected to result in increased nitrogen oxide (NOx) production. In this example, oxygen from the oxygen storage system 112 may be supplied as "high-temperature oxygen" to the inlet duct 164 of the HRSG 116 to reduce NOx production, for example by using the nozzle 300 in Figure 9.

[0063] While the examples in this disclosure describe the use of hydrogen as an energy storage medium, it should be understood that the scope of this disclosure is not limited in this way, and other energy storage mediums may be produced using surplus renewable energy for later use as fuels (or energy carriers that, when decomposed, can yield fuel containing hydrogen, for example), such as ammonia.

[0064] As described below with reference to Table 1, the integrated power production system 100 may be operated to produce energy for direct consumption or storage, through the production of storable hydrogen or storable electricity, utilizing available sources. In addition, the use of renewable energy and hydrogen fuel may be increased, for example, by using renewable energy sources when available, or by using stored hydrogen produced during periods of low demand to reduce emissions from the GTCC 104. Thus, for example, the overall operation of the GTCC 104 may be smoothed to eliminate or reduce periods of constant rate ramp up and constant rate ramp down, which are inefficient and require high machine efficiency.

[0065] Figure 2 shows another diagram of the control method for system 100 shown in Figures 1A and 1B. The main controller 108 can communicate with more specific setpoint controllers 120-126 (Figures 1A and 1B) via various plant controllers 154 for one or more instances of the GTCC 104 and electrolytic cell of the hydrogen production system 106 within system 100. Figure 2 shows different instances of power producers, such as the GTCC 104 and renewable wind power source 130, and the hydrogen production system 106 can be combined to provide an integrated power production system 100.

[0066] As will be explained with reference to Figure 3, the GTCC 104 can be combined with a hydrogen production system 106 to allow the HRSG 116 to heat the electrolytic cell 201, which in turn supplies hydrogen to the gas turbine 114.

[0067] As will be explained with reference to Figure 4, the GTCC 104 can be combined with the hydrogen production system 106 and the renewable wind power source 130 for use during intermittent downtime of the renewable wind power source 130 and to supply power to the battery 222 for frequency support, and oxygen can be expanded to allow cooling of the electrolytic cell 201. In this example, the battery 222 can be replaced with another electrolytic cell 201.

[0068] As will be explained with reference to Figure 5, multiple electrolytic cells 201 are connected to multiple converters 134, and the loop 230 can be heated or cooled to selectively heat or cool one or more of the electrolytic cells 201 and converters 134.

[0069] As will be explained with reference to Figure 6, the HRSG116 may be combined with an electrolytic cell 201 for heating, a steam turbine 118 for synchronous condensation, and hydrogen compressors 138 and 254 for providing hydrogen storage and surge capacity to coordinate the combustion of hydrogen and natural gas in the gas turbine 114.

[0070] As will be explained with reference to Figure 7, any or all of the hydrogen production systems 106 in Figures 1 to 6 may be connected to a hydrogen storage system 110, which can take the form of various underground storage facilities as will be explained with reference to Figures 11 to 16F.

[0071] The various subsystems, as described with reference to Figures 3 to 7, can be combined into a configuration of an integrated power production system 100, which operates in conjunction with a main controller 108 to smooth out periods of high and low demand on the grid 128. This system operates by simultaneously reducing emissions through the efficient use of available renewable energy sources and the production of hydrogen for combustion in gas turbine engines, while producing electricity for short-term storage in batteries and hydrogen for long-term storage in storage containers during periods of low grid demand for use later during periods of high grid demand.

[0072] Figure 3 is a schematic diagram showing a system 200 including a combined cycle power plant 104 (Figure 1B) having a gas turbine 114 (Figure 1B), an HRSG 116, and a hydrogen production system 106. The hydrogen production system 106 may include an electrolytic cell 201. The hydrogen production system 106 may be connected to power conversion equipment including a hydrogen receiving tank 110 and a converter 134. Figure 3 shows another diagram of some components suitable for use in the integrated power production system 100 of Figures 1A and 1B. Figure 3 shows a system for utilizing the heat from the exhaust gas of the turbine 114 to be captured by the HRSG 116 using the integrated power production system 100. The system 200 may be connected to a main controller 108 (Figure 1).

[0073] Power lines 203 may be used to deliver power from the power grid 128 (Figures 1A and 1B) to the hydrogen production system 106 to control the production of hydrogen using the electrolytic cell 201 based on other parameters of system 100, for example. The hydrogen produced by the hydrogen production system 106 may be supplied to the hydrogen receiving tank 110 via hydrogen lines 204. A hydrogen compressor 138 may be used to increase the pressure of hydrogen and move it to another location. The hydrogen compressor 138 can be supplied to the gas turbine 114 via line 206A and to other processes such as industrial or fuel applications via line 206B. In addition, compressed hydrogen may be returned to the hydrogen receiving tank 110 via line 208 and valve 210. Furthermore, hydrogen may be supplied to the HRSG 116 via line 212 to provide, for example, an auxiliary combustion function.

[0074] The gas turbine 114 may be configured to supply exhaust gas to the HRSG 116, as described with reference to Figures 1A and 1B. However, a gas turbine configured to receive hydrogen from the hydrogen production system 106 may be installed anywhere on the power grid 128, away from the hydrogen production system 106. The gas turbine 114 may include a multi-shaft gas turbine engine and may be connected to a generator 154 via a clutch 214, so that the generator 154 can be configured to operate as a synchronous condenser. For example, the clutch 214 may be operated by a controller 108 to disconnect the generator 154 from the gas turbine 114, and the generator 154 may be supplied with AC power from the power grid 128 to change or adjust the phase angle (Φ) of the power grid 128. The gas turbine 114 may be configured to operate as a simple-cycle power producer or in conjunction with a combined-cycle facility. The gas turbine 114 may be installed away from the electrolytic cell 201. The gas turbine 114 may be configured to use hydrogen from the hydrogen production system 106, hydrogen storage 110, as well as from other hydrogen sources or storage systems as shown in Figures 11 to 16F.

[0075] Advantageously, the heat from HRSG116 can be used by other industrial processes installed together with or near system 100, such as for chemical product production or for equipment ambient temperature control, as shown in Figure 8.

[0076] In the illustrated example, the electrolytic cell 201 of the hydrogen production system 106 may be heated by steam or water from the HRSG 116 using a fluid line 202. Thus, the electrolytic cell 201 is maintained in a heated state or standby mode, thereby enabling it to reach operational function more quickly compared to starting from ambient temperature, and thereby providing rapidly reacting hydrogen production. Fluid can be circulated between the HRSG 116 and the hydrogen production system 106 using the fluid line 202 to provide heating or cooling as needed. In the example, heat may be supplied to the hydrogen production system 106 from an industrial process or other heat source. In an additional example, cooling may be supplied to the hydrogen production system 106 by a cooling fluid source other than the HRSG 116, such as expanded oxygen.

[0077] Figure 4 is a schematic diagram showing system 200, which includes a heat recovery steam generator 116 connected to the hydrogen production system 106, and the hydrogen production system 106 is also connected to a battery 222 and a wind power source 130. The hydrogen production system 106 may be connected to a cooling system 224 which may include an expansion turbine 226, a generator 228 and a heat exchanger 229. The hydrogen production system 106 may be connected to a hydrogen receiving tank 110 and power conversion equipment including a transformer 133 and a converter 134. The battery 222 may be connected to the wind power source 130 via power conversion equipment including transformers 133 and 134. Figure 4 shows another diagram of some components suitable for use in the integrated power production system 100 of Figures 1A and 1B. Figure 4 shows a system for storing power in battery 222 to provide, for example, power load and frequency support functions, and for using compressed O2 (or H2) from electrolytic cell 201 to generate power and cool one or both of the converter 134 and the electrolytic cell 201. System 220 may be connected to a main controller 108 (Figure 1) to control, for example, the fluid flow to electrolytic cell 201 and the operation of battery 222 based on other parameters of system 100. Power lines 203 may be used to deliver power from the power grid 128 (Figures 1A and 1B) to the hydrogen production system 106 and battery 222.

[0078] There are various ways in which oxygen from the hydrogen production system 106 can be advantageously integrated with other components within the integrated power production system 100. For example, oxygen from the oxygen storage system 112 (Figures 1A and 1B) or directly from the hydrogen production system 106 can be expanded, for example, via an orifice, expansion valve, or expansion turbine 226. It will be understood that the expansion of compressed oxygen results in a decrease in temperature. This reduced-temperature oxygen can be used as a fluid to cool a converter 134 connected to the hydrogen production system 106 via a heat exchanger 229. Similarly, reduced-temperature oxygen may be used to cool an electrolytic cell 201, which may benefit from facilitating a cooldown so that maintenance and other procedures can be carried out. The fluid lines to the heat exchanger 229 may include various valves that can be operated by a controller 108 to control the flow of reduced-temperature oxygen based on the state of the power grid. In this example, the expansion turbine 226 may be connected to a generator 228 to supply additional power to the power grid 128. In this example, the expansion turbine 226 may be connected to the hydrogen compressor 138 (Figure 3) to supply rotational power to the hydrogen compressor 138, thereby also recovering the energy expanded by the system 220 in cooling the electrolytic cell 201. In such a configuration, the expansion turbine 226 can increase the total output or decrease the auxiliary load to improve system efficiency.

[0079] As described herein, the electrolytic cell 201 may be heated using heat from HRSG116, industrial process heat, local heat sources, commercial building heat, etc.

[0080] Battery 222 may be used to store electricity generated by the wind power source 130. Additionally, battery 222 can support both power load and frequency support functions, for example, when power from the wind power source 130 may decrease. Controller 108 can provide up-and-down adjustments, frequency up-and-down adjustments, or reactive power management. The oxygen cooling described above may also be used for temperature control of battery 222. In this example, battery 222 may be located in the hydrogen production system 106.

[0081] Figure 5 is a schematic diagram showing a fluid loop 230 to an electrolytic cell bank 232 which may be connected to a rectifier bank 234. The fluid loop 230 may include a heat exchanger 229, fluid lines 236 and electrolytic cell lines 238. The electrolytic cell 201 may be connected to a power converter 134 via power lines 240. The fluid loop 230 can supply a temperature input (e.g., heat) or cooling to the electrolytic cell 201, and the power converter 134 can supply an electrical input to the electrolytic cell 201 so that the electrolytic cell 201 can produce hydrogen and oxygen outputs (not shown in Figure 5). Figure 5 represents another diagram of components suitable for use with the integrated power production system 100 of Figures 1A and 1B. Figure 5 shows how the electrolytic cell 201 may be kept ready using heat from the loop 230 or may be rapidly cooled down after using the loop 230. Loop 230 may be connected to a main controller 108 (Figure 1) to control the fluid flow through loop 230 based on other parameters of system 100, for example. Power lines 203 may be used to deliver power to the electrolytic cell 201 separately from the power grid 128 (Figures 1A and 1B) via converters 134.

[0082] It is desirable to supply heat to at least one of the electrolytic cells 201 in order to keep such electrolytic cells ready for a rapid and efficient start of hydrogen production during times when one or more of the electrolytic cells 201 are not operating to produce hydrogen and oxygen. There are various ways in which the temperature control of the electrolytic cells 201 can be advantageously integrated with other components in the integrated system 100. In one example, heat is supplied via HRSG 116 (see Figure 3), which can supply steam or water to loop 230 at a temperature sufficient to keep the electrolytic cells 201 in standby mode. In another example, heat may be supplied by a converter 134 of the electrolytic cells 201 that operates to keep the electrolytic cells that are not currently operating ready, thereby additionally cooling the converter 134 associated with the operating electrolytic cells 201. In an additional example, heat may be supplied via a dedicated heating device 242. In another example, the heating device 242 may include a resistance heater, which may be powered from the power grid 128 (Figures 1A and 1B) or another source. In this example, the heating device 242 may include a burner that can be supplied with hydrogen fuel via the electrolytic cell 201 for combustion.

[0083] Heat exchanger 229 or another heat exchanger may additionally be connected to a loop of cooling fluid, such as expanded oxygen from turbine 226 in Figure 4. Expanded oxygen may be used to cool electrolytic cell 201, for example, after it has stopped, to enable rapid maintenance of electrolytic cell 201 after it has stopped. In an additional example, converter 134 may receive cooling via heat exchanger 229 in Figure 4.

[0084] Although not shown in Figure 5, loop 230 may be connected to converter 134 via additional fluid lines to provide cooling for converter 134, for example, to allow converter 134 to operate at an efficient temperature.

[0085] Each of these examples, described with reference to Figure 5, represents the synergistic use of heat exchange to facilitate one or more of the following: cooling of the converter 134 in standby mode and heating of the electrolytic cell 201.

[0086] Figure 6 is a schematic diagram showing a heat recovery steam generator 116 connected to the electrolytic cell 201 and the hydrogen surge system 250. The hydrogen surge system 250 may include a hydrogen storage system 110, a hydrogen compressor 138, a hydrogen surge tank 252, a hydrogen surge compressor 254, a hydrogen purifier 136, and a mixing tank 258. Figure 6 represents another diagram of components suitable for use with the integrated power production system 100 of Figures 1A and 1B. Figure 6 shows how the hydrogen produced using the electrolytic cell 201 can be incorporated into the power generation of the integrated power production system 100. The system 250 may be connected to a main controller 108 (Figure 1) to control the flow of hydrogen and natural gas to the gas turbine 114, for example. Power lines 203 may be used to deliver power from the power grid 128 (Figures 1A and 1B) to the electrolytic cell 201.

[0087] HRSG116 may include low-temperature, medium-temperature, and high-temperature steam circuits within a steam circuit 260 configured to heat water and supply steam to the steam turbine 118. The electrolytic cell 201 may output hydrogen on line 262 to supply hydrogen to the purifier 136. Hydrogen from the purifier 136 may be supplied to the hydrogen storage system 110 via line 264. The hydrogen storage system 110 may include tanks, etc., as described with reference to Figures 7 and 11-16F. The hydrogen compressor 138 may supply compressed hydrogen to the surge tank 252 via lines 266A and 266B. Hydrogen in the surge tank 252 may be connected to the surge compressor 254 via line 268 and to the mixing tank 258 via line 270. The mixing tank 258 may be connected to a natural gas source via line 272 and to the combustor of the gas turbine 114 via line 274. The hydrogen surge system 250 may additionally include valves 276A, 276B, and 276C that can be operated by the controller 108 to control the flow of fuel through the system 250.

[0088] There are various methods by which the temperature control of a component can be advantageously integrated with other components in the integrated system 100. For example, feedwater in the HRSG 116 in circuit 260 can be used to heat the electrolytic cell 201. In addition, the electrolyte in the electrolytic cell 201 can be heated by the exhaust of the gas turbine 114 via the economizer coil in the HRSG 116. Alternatively, the electrolytic cell 201 can be cooled via the feedwater of the HRSG 116, depending on where the feedwater is taken from the HRSG 116. In an additional example, a cooling circuit for the gas turbine 114 can be used to heat the electrolytic cell 201.

[0089] The steam turbine 118 may be connected to a generator 156 via a clutch 160, allowing the generator 156 to rotate freely from the steam turbine 118 and function as a synchronous condenser for reactive power and / or voltage support. For example, the clutch 160 may be operated by a controller 108 to disconnect the generator 156 from the steam turbine 118, and AC power may be supplied from the power grid 128 to change or adjust the phase angle (Φ) of the power grid 128.

[0090] The hydrogen compressor 138 can be driven by various power sources or combinations of power sources. For example, the hydrogen compressor 138 can be driven by an electric motor. In another example, the hydrogen compressor 138 can be driven by steam supplied by another heat source such as the HRSG 116 or the converter 134. Another example may include a mechanical drive from the gas turbine 114 or steam turbine 118 to the hydrogen compressor 138.

[0091] Figure 7 is a schematic diagram showing a hydrogen storage system 110. The hydrogen storage system 110 may include a storage tank 280 and a pipeline 282. Figure 7 shows another diagram of components suitable for use with the integrated power production system 100 of Figures 1A and 1B. Figure 7 shows that hydrogen can be stored in various containers, including a tank 280 located far away from the hydrogen production system 106 via pipeline 282. Various configurations exist for providing hydrogen storage 110, such as the configurations shown in Figures 11 to 16F. In the example of Figure 7, the hydrogen storage 110 may include pipelines of varying lengths, which are compressed above a typical operating pressure to accommodate hydrogen storage. The system 110 may be connected to a main controller 108 (Figure 1) to control, for example, the flow of hydrogen to and from the tank 280.

[0092] Figure 8 is a schematic diagram showing the integrated power production system 100 of Figures 1A and 1B, which can operate in conjunction with the industrial facility 350. It will be understood that the industrial facility 350 can produce one or more of various fuels, chemicals, or material products (such as steel and aluminum) as output products 376. The industrial facility 350 may include a controller 352 and a transformer 354. As shown in Figures 1A and 1B, the integrated power production system 100 may include an oxygen storage system 112 and an oxygen purification system 140. The oxygen purification system 140 may be configured to supply purified oxygen to the oxygen storage system 112 via a compressor 356. The industrial facility 350 may have multiple inputs, including an oxygen input line 360 ​​or 362, a hydrogen input line 366, a saturated steam line 368, and a compressed steam line 370.

[0093] An oxygen input line 360 ​​can be connected to system 100 at the output of electrolytic cell 201. Oxygen compressed by compressor 356 can be purified by purifier 140 and then flow into oxygen storage system 112. Oxygen from oxygen storage system 112 can proceed to industrial facility 350 via line 362. The oxygen can further return to system 100 from oxygen storage system 112 in HRSG 116 via extension of line 364. A hydrogen input line 366 can be connected to system 100 at the output of hydrogen purification system 136. A saturated steam line 368 can be connected to system 100 between HRSG 116 and heat exchanger 158. A compressed steam line 370 can be connected to system 100 at the inlet of steam turbine 118 or at any drum of HRSG 116, as will be understood by those skilled in the art.

[0094] The industrial facility 350 can receive power from the power grid 128 (Figures 1A and 1B) via power line 372, the voltage of which can be changed by transformer 354. Controller 352 can communicate with main controller 108 (Figures 1A and 1B) via control line 374. The industrial facility 350 can be operated using inputs 360-366 and other inputs to output product 376. Controller 352 can work in conjunction with controller 108 to produce output product 376 using sources from integrated power production system 100, based on the availability of hydrogen, oxygen, and steam due to the state of the power grid 128. Therefore, lines 360-370 may include valves that can be operated by controllers 108 and 352.

[0095] Figure 9 is a schematic diagram of a thermal nozzle 300 that may be used to produce high-temperature oxygen. The thermal nozzle 300 may include a housing 302, an injector 304, an inlet port 306, and an outlet orifice 308. The housing 302 may include a chamber 310, to which an opening 312 may be connected, and the injector 304 may be inserted into the opening 312 through a port 314. The port 314 may be configured to axially align the injector 304 with the outlet orifice 308. The injector 304 may include a tube having a lumen 316 and a discharge orifice 318. The thermal nozzle 300 can receive oxygen and fuel. In this example, the thermal nozzle 300 may be configured similarly to the thermal nozzle described in Anderson's Patent Document 1, which is incorporated herein by reference in whole. However, the thermal nozzle 300 additionally includes an opening 312. As described in Patent Document 1, a combination of fuels in an oxygen-rich environment can produce a high-temperature oxygen jet 320 that produces an axial mixture 322. By adding an opening 312, a further high-temperature oxygen jet 324 that produces a radial mixture 326 can be provided.

[0096] Oxygen jets 320 and 324 can be discharged from the hot nozzle 300 with the following characteristics: high speed generally exceeding 750 m / s and high radical concentration supporting reaction kinetics, for generating recirculation and mixing 322 and 326. This drives the lower-temperature "oxidation" reaction compared to the higher-temperature "combustion" reaction. The exhibited reactivity and kinetics are due to the injection of highly reactive gases. In the example, preheated oxygen destroys CO and NOx precursors (NH3 and HCN) with little to no NOx production.

[0097] Referring back to Figures 1A and 1B, the heat nozzle 300 may be located directly within the inlet duct 164 of the HRSG 116. In this example, the oxygen supplied to the heat nozzle 300 may be supplied directly from the oxygen storage system 112. In this example, the oxygen supplied by the oxygen storage system 112 can be thermally connected to one or more of the following: (i) heated water in the HRSG 116, (ii) heated steam in the HRSG 116, or (iii) exhaust gas flowing through the HRSG 116. Any suitable heat exchanger may be used to transfer heat between the oxygen and the aforementioned flows.

[0098] The exemplary nozzle of Patent Document 1 can provide a high-speed output that may be sufficiently suitable for injection into generally laminar flows, such as in a pipe, intended to result in rapid mixing of high-temperature oxygen in a laminar flow. The opening 312 can function as an output orifice positioned at multiple locations around the housing 302 of the nozzle 300. The opening 312 is intended to result in enhanced mixing of high-temperature oxygen in a large turbulent region, such as within the inlet duct 164 of the HRSG 116.

[0099] As shown in Figure 1B, in this example, the oxygen supplied by the oxygen storage system 112 can be supplied directly to the inlet of the gas turbine 114. Directly introducing oxygen to the inlet of the gas turbine 114 can reduce the percentage composition of nitrogen in the mass flow of the gas turbine, thereby reducing NOx generation and emissions. The oxygen from the oxygen storage system 112 can be supplied directly to the inlet of the gas turbine 114 in the form of high-temperature oxygen produced by the heat nozzle 300 described above. In this example, the oxygen from the oxygen storage system 112 can be supplied directly to the inlet duct 164 in the state of the oxygen storage system 112 (i.e., without using the heat nozzle 300). Other examples may include other equipment to change the state of the oxygen before it is introduced into the inlet duct 164. Examples of such equipment may include a pump for increasing the pressure (and / or temperature) of oxygen from the oxygen storage system 112, an expansion nozzle or valve for decreasing the pressure (and / or temperature) of oxygen from the oxygen storage system 112, and heat exchangers that may be installed at various stages of the heat recovery steam generator 116 to heat or cool the oxygen supplied from the oxygen storage system 112. Other examples may include thermal communication between oxygen from the storage system 112 and other electronic or process components that can benefit from heat exchange, such as controllers 108, 120-126, power converters 133, 134, hydrogen production system 106, or gas turbine 114.

[0100] [Table 1]

[0101] As summarized in Table 1, there are various potential operating states that can be provided through coordination between the main controller 108 and the other controllers 120, 122, 124, and 126, as well as various other controllers of the various subsystems shown with reference to Figures 3-7 and 10. Examples of such controllers will be described with reference to Figure 29.

[0102] Case 1: The GTCC plant 104 is shut down when electricity demand from consumers 152 is relatively low, such as during weekends. The surplus electricity supplied by renewable power sources 130, 132 (in excess of the amount requested by consumers 152) is supplied via the grid 128 to the transformer 133, converter 134, and electrolytic cell of the hydrogen production system 106 to produce hydrogen to be stored in the hydrogen storage system 110. Since the GTCC plant 104 is shut down, it is in a relatively "cold" thermal state. In such a "cold" thermal state, it is desirable to gradually increase the power output of the GTCC plant 104 at a constant rate to minimize temperature gradients and thermal stress. However, as can sometimes happen, the grid 128 may be called upon to prepare for a large electricity demand, perhaps from a large industrial consumer starting up their factory. Typically, the GTCC plant 104 may be required to undergo a "rapid start," which can impose high temperature gradients and thermal stress within the gas turbine 114. The integration of the components of system 100 provides an alternative solution that allows the gas turbine 114 to immediately supply power to meet high demand while performing a desirable slow start. In this case, the electrolytic cells of the hydrogen production system 106 are shut down immediately or as quickly as possible, and the energy previously consumed by the electrolytic cells is then immediately or as quickly as possible made available to the power grid 128 and can be distributed from renewable sources 130, 132 to consumers 152. At the same time, while the power previously consumed by the electrolytic cells is made available to consumers 152, the GTCC plant 104 can begin warming up the process at a desirable constant rate rise. In other words, the almost immediate shutdown of the electrolytic cells simulates a "rapid start" by the GTCC 104 without imposing a high temperature gradient and thermal stress on the gas turbine 114 of the GTCC 104.

[0103] Case 2: GTCC104 is operating at minimum load (approximately 30%) and is "parked" running on natural gas. Since the demand for electricity on the power grid 128 is low, electricity is inexpensive, and the electrolytic cells of the hydrogen production system 106 can operate at full load, and the electricity from the power grid 128 and / or GTCC104 is consumed to produce hydrogen gas to be stored in the hydrogen storage system 110. As in Case 1, an emergency increase in electricity may be requested by a consumer 152. Again, the electrolytic cells can be quickly shut down to provide the power grid 128 with an apparent almost immediate supply of electricity. Since GTCC104 is operating at minimum load, its capacity to produce electricity can be increased at a constant rate faster than in Case 1. Again, a rapid demand for electricity can be met not by a rapid constant rate increase of GTCC104, but by reducing the consumption of the electrolytic cells. It should be understood that if GTCC104 is parked and running on hydrogen instead of running on natural gas, the emissions could simply be water vapor without carbon dioxide.

[0104] Case 3: High but rapidly decreasing demand for electricity. Consider a scenario where a large industrial consumer 152 suddenly disappears (trips off), causing a sudden decrease in electricity demand from the power grid 128. Because demand is high, the GTCC 104 is operating at base load, and the electrolytic cells of the hydrogen production system 106 cannot produce large amounts of hydrogen (consume large amounts of energy from the power grid 128). If the electrolytic cells are kept warm (for example, via heat from the HRSG 116 as described herein with reference to Figures 3-6), the electrolytic cells can immediately increase hydrogen production to 100% and immediately begin consuming the electricity previously consumed by the large industrial consumer 152. In other words, by rapidly starting up the electrolytic cells, the decrease in demand from the industrial consumer 152 can be quickly replaced. Therefore, the GTCC 104 can begin a slow, constant rate decline (balancing with the electrolytic cells of the hydrogen production system 106) to reduce the temperature gradient of the GTCC 104. The surplus electricity consumed by the electrolytic cell can be stored in the form of hydrogen in the hydrogen storage system 110 for later conversion into electricity by the GTCC 104.

[0105] Case 4: GTCC 104 is off, and the electrolytic cell of the hydrogen production system 106 is operating at partial load. As the availability of renewable electricity from sources 130 and 132 decreases, the electrolytic cell can reduce hydrogen production to maintain balance in the power grid 128.

[0106] Case 5: GTCC104 is operating at maximum speed with no load (depending on temperature and speed, but without producing electricity) and is running on hydrogen from hydrogen storage system 110. The power grid 128 recognizes and responds to the increase in electricity demand, and hydrogen production by the electrolytic cell of hydrogen production system 106 can be reduced while GTCC104 begins a constant rate increase in response to the load. If there is insufficient hydrogen available to supply power to gas turbine 114, GTCC104 can begin opening the flow of natural gas through valve 144.

[0107] Case 6: The generator 154 of the gas turbine 114 is operating as a synchronous condenser, and the electrolytic cell of the hydrogen production system 106 produces hydrogen gas while maintaining the balance of the power grid 128, while consuming electricity from the power grid 128. When the power grid 128 begins to sense an increasing demand for electricity, the main controller 108 can instruct the other controllers 120-126 and other controllers of the subsystems in Figures 3-7 and 10 to lower the electrolytic cell at a constant rate, and then raise the GTCC 104 at a constant rate, first with natural gas fuel via valve 144, and then with hydrogen gas via the storage system 110 and valve 142.

[0108] While six specific cases have been described above, it should be understood that the scope of this disclosure is not limited in this way and includes any intermediate operating states between those specific states described, and various combinations of each or all of the above cases, such as operating on all natural gas, all hydrogen, or any combination of natural gas and hydrogen.

[0109] Figure 10 is a schematic diagram of a hydrogen production system 400, which includes an electrolysis pack 402, a battery pack 404, and a renewable energy producer 405 connected to a power grid 128 via a bidirectional inverter 406 and DC-DC inverters 408A and 408B. The system 400 may further include a first circuit breaker 410A, a second circuit breaker 410B, a third circuit breaker 410C, a fourth circuit breaker 410D, a fifth circuit breaker 410E, and a sixth circuit breaker 410F. Power from the power grid 128 may be transmitted to the system 400 through transformers 412A and 412B. The bidirectional inverter 406 may include an AC converter 414 and a DC converter 416. The DC-DC inverter 408A may include a first converter 418A and a second converter 420A. The DC-DC inverter 408B may include a first converter 418B and a second converter 420B. The electrolysis unit 428 is connected to the GTCC 422 (via its hydrogen output), and the GTCC 422 may be connected to the generator 424. The electrolysis unit 428 may also be connected to the oxygen consumer 426.

[0110] Transformer 412A can transmit power from the power grid 128 to the hydrogen production system 400. Similarly, transformer 412B can transmit power from transformer 412A to converter 406. Bidirectional inverter 406 can convert alternating current from transformer 412A to direct current via AC converter 414. Electrolysis pack 402 may include multiple electrolysis units 428 that can be electrically connected together in series or parallel, etc., to receive current from inverter 406. Each electrolysis unit 428 may be configured to use electricity, such as via DC, to convert a water (H2O) input into hydrogen (H2) gas and oxygen (O2) gas.

[0111] The inverter 408A can convert the DC from the inverter 406 from one voltage to another voltage suitable for use with the battery pack 404. The battery pack 404 may include multiple battery units 430 that can be electrically connected together in series or parallel, etc., to receive or supply current to the inverter 408A.

[0112] The renewable energy producer 405 may include multiple instances 432 of one or both solar panels and / or wind turbines, which may be connected together in series or parallel to supply electrical input to the inverter 408B. The inverter 408B can convert DC from one voltage to another, such as converting DC from the renewable energy producer 405 to a voltage suitable for use with the inverter 406.

[0113] [Table 2]

[0114] In the first state, circuit breakers 410A to 410D may be closed. In such a state, the electrolysis unit 428 can actively convert electricity and water into hydrogen and oxygen, and the battery unit 430 can be charged simultaneously. The first state can be used when hydrogen and oxygen products are stored in the hydrogen storage system 110 and oxygen storage system 112 (Figure 1) for long-term storage, and when energy is stored in the battery unit 430 for short-term storage. The first state can occur when there is surplus energy available in the power grid 128, such as when renewable energy sources, such as the wind power source 130 and the solar power source 132 (Figure 1), are operating at high capacity.

[0115] In the first state, circuit breakers 410E and 410F may be open or closed. With circuit breaker 410E open, the renewable energy source 405 may be in a non-productive state. With circuit breaker 410E closed, the renewable energy source 405 may produce and supply power, for example, to produce hydrogen using the electrolysis unit 428 and store the power in the battery unit 430. With circuit breaker 410F open, the GTCC 422 may be shut down. With circuit breaker 410F closed, the GTCC 422 may operate for standby service, such as at minimum load.

[0116] In the second state, circuit breakers 410A, 410B, and 410D are closed, and circuit breaker 410C may be open. In such a state, surplus power from the power grid 128 can be stored in the battery unit 430. Thus, surplus power from the power grid 128 during periods when it is desired not to operate the electrolysis pack 402 can be stored for later use in the electrolysis pack 402.

[0117] In the second state, circuit breakers 410E and 410F may be open or closed. With circuit breaker 410E open, the renewable energy source 405 may be in a non-productive state. With circuit breaker 410E closed, the renewable energy source 405 may be producing power, for example, to store power in the battery unit 430. With circuit breaker 410F open, the GTCC 422 may be shut down. With circuit breaker 410F closed, the GTCC 422 may be operating for standby service, such as at minimum load.

[0118] In the third state, circuit breakers 410A, 410B, and 410D are closed, and circuit breaker 410C may be open. In such a state, the battery unit 430 may be discharging into the power grid 128 or connected to the power grid 128 in standby mode. Thus, the battery unit 430 may be used for energy storage services. The benefits of operation in the third state include peak power (e.g., supplying additional power to the power grid 128 from the battery unit 430), frequency regulation (e.g., using the battery unit 430 to regulate the frequency of the power grid 128), voltage, and reactive power, including traditional battery energy storage system (BESS) services.

[0119] In the third state, circuit breaker 410E may be open, with the renewable energy source 405 not supplying power. With circuit breaker 410F open, the GTCC 422 may be shut down, and the battery unit 430 may provide traditional service or act as a spinning reserve. With circuit breaker 410F closed, the GTCC 422 and battery unit 430 may be adding power to the power grid 128.

[0120] In the fourth state, circuit breaker 410A may be closed, and circuit breakers 410B, 410C, and 410D may be open. In such a state, the bidirectional inverter 406 may be connected to the power grid 128 to provide power conversion system services and reactive power services.

[0121] In the fourth state, circuit breaker 410E may be open, with the renewable energy source 405 not supplying power. The opening of circuit breaker 410F may shut down the GTCC 422. The closing of circuit breaker 410F may allow the GTCC 422 to continue providing power, reactive service, and inertia.

[0122] In the fifth state, circuit breakers 410A and 410D may be closed, and circuit breakers 410B and 410C may be open. The fifth state may be useful for providing power conversion system services to the power grid 128, for providing reactive power services, and for connecting the renewable energy source 405 to the battery unit 430.

[0123] In the fifth state, circuit breaker 410E is closed, thereby allowing the renewable energy source 405 to charge the battery unit 430. By opening circuit breaker 410F, the GTCC 422 may be shut down. By closing circuit breaker 410F, the GTCC 422 may be providing power, reactive service, and inertia.

[0124] In the sixth state, circuit breakers 410A, 410B, and 410C may be closed, and circuit breaker 410D may be open. In such a state, system 400 may be connected to an electrolytic power grid. The sixth state may be useful for the production of hydrogen and oxygen for long-term storage (for example, through the storage of hydrogen in system 110 and oxygen in system 112).

[0125] In the sixth state, circuit breakers 410E and 410F may be open or closed. With circuit breaker 410E open, the renewable energy source 405 may be non-producing. With circuit breaker 410E closed, the renewable energy source 405 may be producing, for example, to supply power to the electrolysis unit 428 to produce hydrogen. With circuit breaker 410F open, the GTCC 422 may be shut down. With circuit breaker 410F closed, the GTCC 422 may be operating for standby service, such as at minimum load.

[0126] In the seventh state, circuit breakers 410C and 410D may be closed, and circuit breakers 410A and 410B may be open. In such a state, the electrolysis pack 402 may be connected to the battery pack 404. The seventh state may be useful for recovering surplus power stored in the battery unit 430 for use with the electrolysis unit 428 to produce hydrogen and oxygen, thereby shifting short-term storage to long-term storage (for example, via the storage of hydrogen to system 110 and oxygen to system 112).

[0127] In the seventh state, circuit breakers 410E and 410F may be open or closed. With circuit breaker 410E open, the renewable energy source 405 may be in a non-productive state. With circuit breaker 410E closed, the renewable energy source 405 may be producing, for example, to supply power to the electrolysis unit 428 to produce hydrogen. With circuit breaker 410F open, the GTCC 422 may be shut down. With circuit breaker 410F closed, the GTCC 422 may be operating for standby service, such as at minimum load.

[0128] Figure 10 shows a system in which an electrolysis unit 428 may be integrated into system 100. System 400 may have a DC subsystem within a circuit breaker 410A that is not connected to the power grid 128, so that system 400 can operate independently of the power grid 128. Thus, energy from the renewable energy producer 405 may be stored in a battery or used directly by the electrolysis unit 428. The inclusion of a battery unit 430 may additionally be used to reduce the number of electrolysis units 428 or damage to the electrolysis units 428. For example, the battery unit 430 may be used to keep the electrolysis unit 428 operating or warmed up when power from the renewable energy producer 405 or the power grid 128 is unavailable, thereby reducing the circulation of the electrolysis unit 428. In this example, the components of system 400 may include the components shown in Figures 1A to 9, having different reference numbers and similar names. For example, the electrolysis unit 428 may include an electrolytic cell 201, and the battery unit 430 may include a battery 222.

[0129] Storage system

[0130] This application further discloses a plurality of storage systems that may be used for hydrogen storage, means and methods for incorporating storage systems, and methods for connecting such storage systems to an integrated power production facility.

[0131] Hydrogen and other gases are known to be stored in various storage containers. Common storage container arrangements include forged tubes that can be certified to ASME and / or DOT standards, particularly incorporating transport safety requirements for containers that may be transportable. These storage containers may incorporate specific design features, such as flanges and / or hemispherical ends, to meet such standards. Containers with such safety and certification margins are expensive to produce.

[0132] This disclosure provides several configurations for stationary pipelines that are safe, easy to install, and inexpensive. Stationary pipelines can be used as storage vessels for hydrogen after being pressurized beyond standard pressure. In addition, if pipelines are not readily available or in use, standard pipes can be located both above and / or underground as storage vessels.

[0133] Figure 11 shows a vertically positioned piping system 500 that may be used as a gas storage system, for example, for storing hydrogen. The piping system 500 may include various subsystems for providing and maintaining an acceptable amount and pressure of hydrogen, including a compressor 505, one or more vent subsystems 510, vents 512, valves 514A-514G, appropriate sensors 515 such as pressure transducers, storage pipes 520, and connecting wires 522A-522F. In the example, the storage pipes 520 may be buried below ground 525. In the example, the system 500 may be connected to an adjacent storage system 530, which may be similar to system 500 or other systems described herein, in order to increase the storage capacity of system 500.

[0134] Figure 12 shows a storage system 550 including multiple storage pipes 520 interconnected in a cluster 554. The system 550 may be connected to one or more producers 552 that generate or produce hydrogen, such as an electrolysis unit. The cluster 554 may include packs of pipes 520 connected to a common header pipe 556 that connects to the above-ground portion of the system 550, such as line 522A. In the illustrated example, each of the clusters 554 includes six pipes 520. It will be understood that the system 550 is intended to include pipes 520 that can be buried to a depth of 2 miles underground at ground level 525 using current drilling techniques. For comparison, the pipes 520 may be stacked to an end-to-end length equivalent to nine Empire State Buildings for comparable reference. In the example of system 500 in Figure 11 or system 550 in Figure 12, the depth utilized is expected to be directly related to the amount of hydrogen that needs to be stored. In other words, longer pipes can be extended deeper underground to store larger quantities (e.g., by volume) of hydrogen.

[0135] In the example, pipe 520 may be a steel pipe inserted into an open borehole. In the example, pipe 520 may be made of other materials such as fiber-reinforced composites and other metals and alloys. In the example, pipe 520 may include a standard well casing or multiple well casings joined together to adequately contain hydrogen. In the example, other storage arrangements may be used, such as to treat the well to make it suitable for hydrogen containment, or to make the geology surrounding the well hydrogen impermeable.

[0136] A vertical cylindrical tank or container with pipe 520 is under high pressure P high The gas is stored in a lower pressure P when needed. low The volume of hydrogen reduced to P can be supplied. Therefore, the hydrogen storage capacity in any such pipe is P high From the amount of hydrogen that can be stored in the volume of pipe 520, P lowIt may be the amount obtained by subtracting the amount of hydrogen that can be stored within the volume of the pipe 520. Incorporation techniques for installing the pipe 520 below the ground 525 may include drilling or excavation. Additionally, the pipe 520 may be incorporated into existing (such as abandoned) oil and / or gas production wells. Various support subsystems, such as valves, converters, headers, and / or manifolds, may be incorporated either above or below the grade of the ground 525.

[0137] The compressor 505 consumes energy to compress hydrogen to the required storage pressure, such as P high It will be understood that during periods of low demand for hydrogen (and / or electricity), when the peak times of renewable power production and availability may coincide, the compressor 505 can be operated to compress hydrogen to the required storage pressure. Similarly, during periods of high demand for hydrogen (and / or electricity), the compressor 505 may be turned off to save power, and hydrogen can be withdrawn from the pipe 520 to supply energy such as electricity through thermal combustion and / or one or more fuel cells.

[0138] The pressure of hydrogen in the pipe 520 can approach P low (or drop below P low ), so the compressor 505 can be used to draw hydrogen from the pipe 520 and supply hydrogen at any particular desired pressure that can be greater than the pressure within the pipe 520.

[0139] Figure 13A shows a storage system 560. Storage system 560 may be similar to storage system 500 (Figure 1). However, storage system 560 may include a container 562 (such as a pipe) that includes a change of direction. The container 562 may include a vertical section 564 and a horizontal section 566. Inclined drilling techniques used in other industries (oil, gas, and / or water exploration) may be used to increase the storage capacity of system 500 without having to drill to the required depth, or when obstacles prevent or obstruct drilling to the otherwise required depth. As described above, multiple systems 560 may be arranged together in a cluster 568 in fluid communication to provide an increased storage capacity. As shown in Figure 13B, each cluster 568 may include a matrix of one to six containers 562 from system 560. Clusters 568 may be stacked vertically.

[0140] Figures 14A and 14B show a top and side view of the cluster arrangement 570. The cluster arrangement 570 includes a radial shape that can enable efficient use of ground space so that all related subsystems can be located near common connection points to many storage containers. The cluster arrangement 570 may include a container 572 positioned where the first end of the container 572 is located near a central 574 where the ends of the containers are close together, and the container 572 may extend radially away from the central 574 to an outer portion 576 where the end of the container 572 is far away. The container 572 may include pipes as described herein and may be arranged in a linear configuration or in a configuration with curved or angled changes in direction.

[0141] Figure 15 is a schematic diagram of the storage system 580. The system 580 shows an arrangement having three layers 582, 584, and 586 of containers 588. Layers 582-586 can be connected to line 522A in various ways. Containers 588 in each layer 582, 584, and 586 can be individually piped over the grade using line 590, as shown in layer 582 of layer 1 in the header pipe 592. Individual containers 588 can be connected to the common header 592 via line 594 before being piped over the grade, as shown in the arrangement of layer 584 of layer 2. Individual layers can be independent, as shown in layer 1, or can be in fluid communication with an upper or lower layer, as shown in the configuration where layer 584 of layer 2 and layer 586 of layer 3 are connected using line 596.

[0142] Figures 16A to 16C show various cross-sectional views of layers 582 to 586. Figure 16A shows layers 582 to 586 arranged symmetrically. Figures 16B and 16C show layers 582 to 586 arranged asymmetrically. Layers 582 to 586 may be arranged to minimize the cost of mechanical support between individual containers 588 and to reduce the total space required. In the example, the containers 588 may be fixed in place by soil or artificial supports.

[0143] Figures 16D and 16E show an alternative layer arrangement in which the container 588 is positioned within the groove 590.

[0144] In any configuration, the vessel 588 may be incorporated entirely below ground level, or it may be incorporated with access passages 596 at its ends for maintenance and inspection, or at the locations of various subsystems, as shown in Figure 16F. In this way, valves connected to the ends of the vessel 588 may be accessible.

[0145] Figures 17, 17A, and 17B show diagrams of the gantry system 600. The gantry system 600 can be used for the fabrication and erection of various vessels described herein.

[0146] Figure 17 shows a top view of a gantry system 600 including a support structure 602 having a vertical section 604 and a horizontal section 606. Figure 17A is a side view of the gantry system 600 showing the separated vertical section 604. Figure 17B is a side view of the gantry system 600 showing the vertical section 604 connected by the horizontal section 606.

[0147] The gantry system 600 can be incorporated above the trench 608. The vertical section 604 can be incorporated underground above the grade 525 along both sides of the trench 608. The horizontal section 606 can connect the vertical section 604 on both sides of the trench 608. The vertical section 604 and the horizontal section 606 can form a temporary support structure.

[0148] Figure 18 shows a top view of the welding gantry 620 relative to the support structure 602 of the gantry system 600. Figure 18A is a side view of the welding gantry 620, showing the container 622 and welding unit 621 with the gantry system 600 omitted for clarity. Figure 18B is a side view of the gantry system 600, showing the welding gantry 620 positioned on the wheels 624 within the support structure 602.

[0149] The welding gantry 620 may include a lower frame 626 on which wheels 624 can be mounted. The lower frame 626 may be connected to an upper frame 628 via a support 630. The vessel 622 may be suspended from the upper frame 628 using cables 632 and a hoist 634. The welding gantry 620 may include a welding unit 621 that can weld individual sections 636 together to form a vessel 622 that is longer than the length of the individual sections 636 alone. The welding unit 621 may be fully enclosed to manage pre- and post-weld heat treatment, X-ray photography, environmental control, etc. In the example, the welding unit 621 may also be open to the atmosphere or partially enclosed to provide a lower-cost alternative for applications where the requirements may be less stringent. The welding gantry 620 may be robotically controlled to move along the gantry system 600 and to perform welding operations using the welding unit 621.

[0150] In the example, the first step may be to excavate and remove soil in grade 525 to create a location for a trench 608 for the container 622. Following the excavation of the site, a temporary support structure 602 may be incorporated. The temporary support structure 602 may include a vertical section 604 and a horizontal section 606. After the support structure 602 has been incorporated, a welding gantry 620 having a welding unit 621 may be incorporated so that various sections 636 of pipe can be joined to obtain the desired container length. The welding gantry 620 may include a hoist 634 with a trolley for moving the pipe sections 636 into place on a workbench. The gantry 620 may include hoists 634 on both sides of the temporary support structure 602 so that the pipe sections 636 may be placed on both sides of the structure to optimize the efficiency of construction, such as welding.

[0151] Figure 19 shows a top view of the gantry system 600 showing the location of the welding gantry 620 relative to the groove 608. Figure 19A is a side view of the gantry system 600 showing a temporary support structure 602 supporting a section 636 of the assembled pipe forming the vessel 622, and a welding gantry 620 supporting another section 636 of the pipe. Figure 19B is a side view of the gantry system 600 showing the temporary support structure 602 and the welding gantry 620 holding a section 636 of the pipe at the same horizontal level.

[0152] Figures 20–20B show further configuration details and assembly steps for the use of system 600. The temporary support structure 602 may include a wire rope 640 connected to a synchronous hoist 638 to lower the vessel 622 evenly into the groove 608. The welding gantry 620 may be supported by the structure 602 directly below the section 636 of the pipe and can move from section to section to weld the ends of the sections together to form a vessel 622 of the desired length.

[0153] Figures 21–22B show further assembly steps using system 600. Once each vessel 622 is welded together to the desired length, each vessel 622 can be lowered into the trench 608 via a hoist 638 and positioned as desired. Once one layer of vessel 622 is complete, soil 642 can be backfilled over the first layer of vessel 622 in the trench 608 to support the next layer of vessel 622. If passage access is employed (see Figure 16F), the soil 642 does not cover the ends relative to the passage. As shown in Figures 23A–23C, this continues until the complete arrangement of the layers of vessel 622 is provided and backfilled with soil, or until other supporting structures are suitable. Figure 23A shows that the vessel 622 is completely filled, with only the header pipe 644 extending over the grade 525 of soil 642.

[0154] The gantry system 600, including the temporary support structure 602 and the welding gantry 620, can enable the on-site assembly of pipes to be assembled in long lengths and the lowering of the assembled pipes to the fabricated location. The hoist 638 can move longitudinally from side to side along the support structure 602 to provide access to the entire groove 608. The wire rope 640 can move sections of pipe perpendicular to the groove 608. Thus, sections of pipe can be moved to various three-dimensional positions within the groove 608. The welding gantry 620 can move longitudinally within the support structure 602 above the groove 608. The hoist 634 can move left to right on the gantry 620 to provide access to the entire groove 608. The cable 632 can move sections of pipe perpendicular to the groove 608. Thus, sections of pipe can be moved to various three-dimensional positions within the groove 608. In this way, the welding gantry 620 can be used to load sections of pipe into the support structure 602 and to assemble additional sections of pipe on top of sections of pipe supported by the support structure 602. The welding gantry 620 can move out of the way of the support structure 602 or work together with the support structure 602 to move the assembled length of pipe section into the groove 608.

[0155] Figures 24 to 27 show the storage system 700 through a sequence of steps in which pipe storage systems 702, 704, 706, and 708 are successively added to accommodate the need to increase hydrogen storage capacity. The storage system 700 may include a storage controller 710 for communicating with a main controller 108 for communicating with the power grid 128 (Figures 1A and 1B).

[0156] Figure 24 shows a first system 702 including a hydrogen production unit 712 and a hydrogen consumer 714. The hydrogen production unit 712 and the consumer 714 may be connected by piping 716. In addition, system 702 may include appropriate sensors 718 and actuators and be able to communicate signals and controls with a storage controller 710, which can operate system 700 and related subsystems (described above with reference to other figures herein, in particular Figures 11 to 23C) to store and supply hydrogen in response to appropriate conditions, as may be defined or instructed by a grid controller 108. A compressor 722 may be provided in piping 716 to compress and move hydrogen through system 702. In this example, the first system 702 may be configured similarly to system 550 in Figure 12.

[0157] Figure 25 shows the addition of a second storage system 704, which has a rock salt cavity 730 as the storage system instead of the container described above. System 704 may have a hydrogen production unit 732 and a consumer 734. In addition, system 704 may include appropriate sensors 736 and actuators and be able to communicate signals and controls with a storage controller 710, which can operate system 704 and related subsystems (described above with reference to other figures herein, in particular Figures 11 to 23C) to store and supply hydrogen in response to appropriate conditions, as may be defined or instructed by a grid controller 108. A compressor 738 may be provided in the piping 740 to compress and move hydrogen through system 704. As shown in Figure 25, systems 702 and 704 can each communicate signals and controls with the controller 710, but are separated with respect to their respective capabilities for distributing hydrogen. In other words, the storage in system 702 cannot receive hydrogen from the producer 732 of system 704, nor can it supply hydrogen to the consumer 734 of system 704. Similarly, the hydrogen stored in system 704 cannot be exchanged with the producer 712 or consumer 714 of system 702.

[0158] Figure 26 shows the addition of a third storage system 706. As will be understood, storage system 706 contains the same components as system 702, which was described with reference to Figure 24, and is not described here for the sake of clarity. As shown in Figure 26, systems 702, 704, and 706 can each communicate signals and controls with the storage controller 710. Systems 702 and 706 are connected in terms of their respective capabilities for distributing hydrogen. That is, the storage in system 700 can receive hydrogen from the producer 712 of system 706 and supply hydrogen to the consumer 714 of system 706. Similarly, hydrogen stored in system 706 can be exchanged with the producer 712 or consumer 714 of system 700. However, as shown in Figure 26, systems 700 and 706 are separated from system 704 in terms of their respective capabilities for distributing hydrogen to system 704.

[0159] Figure 27 shows the addition of a fourth storage system 708. As can be understood, storage system 708 contains the same components as system 702, which was described with reference to Figure 24, and for simplicity, these components are not labeled or described here. As shown in Figure 27, systems 702, 704, 706, and 708 can each communicate signals and controls with the storage controller 710. Figure 27 shows that the introduction of system 708 "bridges together" systems 702 and 706 and system 704. Thereafter, systems 702, 704, 706, and 708 are all connected in terms of their respective capabilities to distribute hydrogen among themselves. In other words, each storage in systems 702, 704, 706, and 708 can receive hydrogen from producers 712 and 732 of any of the other systems 702, 704, 706, and 708, and can supply hydrogen to consumers 714 and 734 of any of the other systems 702, 704, 706, and 708. In such a situation, the large amount of hydrogen stored in the salt cavity 704 can be utilized by the other systems. In addition, if any hydrogen producer from any of systems 702, 704, 706, or 708 becomes inoperable or unavailable due to maintenance or repairs, hydrogen produced or stored by any of the other systems may become available for use by consumers associated with the potentially unavailable system.

[0160] The storage system 700 may include an example of the hydrogen storage system 110 shown in Figures 1A and 1B. In additional examples, the hydrogen storage system 110 shown in Figures 1A and 1B may include one of systems 702, 704, 706, and 708.

[0161] Figure 29 is a schematic diagram showing the components of a controller 108 for operating the integrated power production system 100 and controllers 120-126 for operating the hydrogen production system 106 and GTCC 104. Controller 108 may include circuits 80, a power supply 82, memory 84, a processor 86, input devices 88, output devices 90, and a communication interface 92. Controller 108 can communicate with the power grid 128, which can supply power to end users or consumers 152. Controller 108 can also communicate with controllers 120 and 122 for the hydrogen production system 106 and controllers 124 and 126 for the GTCC 104, and the controller can communicate with one or more subsystem controllers, such as a storage controller 24A and a battery and generator controller 24B. Controller 24A can communicate not only with the hydrogen storage system 110 and the oxygen storage system 112, but also with various components thereof, such as valves 142-144, compressor 138, turbine 226 and compressor 254, and purification units 136 and 140. Controller 24B can communicate not only with batteries 222 and 430, but also with various other components, such as circuit breakers 410A-410F and clutches 160 and 214.

[0162] Controllers 120-126 and controllers 24A and 24B may also include various computer system components that facilitate receiving and transmitting electronic instructions, storing instructions, data and information, and communicating with other devices such as display devices, input devices, and output devices. For example, power controllers 120-126 may each include a power supply 50, memory 52, processor 54, and control circuit 56, respectively.

[0163] Circuit 80 may include any suitable computer architecture, such as a microprocessor or chip, that enables the memory 84, processor 86, input device 88, output device 90, and communication interface 92 to work together. Power supplies 82 and 50 may include any suitable method for supplying power to controllers 108 and 120-126, respectively, such as AC or DC power supplies. Memory 84 and 52 may include any suitable memory device, such as random access memory, read-only memory, flash memory, magnetic memory, and optical memory. Input device 88 may include a keyboard, mouse, pointer, touchscreen, and other suitable devices for supplying user input or other input to circuit 80 or memory 84. Output device 90 may include a display monitor, viewing screen, touchscreen, printer, projector, audio speaker, and the like. Communication interface 92 may include a device that enables circuit 80 and controller 108 to receive and transmit information to other computing devices such as modems, routers, I / O interfaces, buses, local area networks, wide area networks, and the internet.

[0164] The controller 108 may be configured to operate the power grid 128 and is therefore sometimes referred to as the "home office" for system 100. The power grid 128 may include a hydrogen production system 106, a GTCC 104, renewable energy sources 130 and 132, high-voltage transmission lines that carry power from remote sources to demand centers, and distribution lines that connect to consumers 152. The power grid 128 may be configured to operate at a control frequency in which all power input into the grid from dissimilar sources is input at the same frequency, in order to facilitate power integration. In one example, the power grid 128 may operate at a control frequency of 60 hertz (Hz).

[0165] The controller 108 can determine the demand on the power grid 128, for example, by monitoring the consumption of consumer 152. The controller 108 can coordinate the generation of electricity from the GTCC 104 and renewable energy sources 130 and 132. The controller 108 can allocate or instruct the GTCC 104 on how much power output it should contribute to the power grid 128, and such allocation can be dynamically adjusted based on the capacity and availability of either the GTCC 104 or the renewable energy sources 130 and 132. The controller 108 can ensure that the total power generated by the GTCC 104 and renewable energy sources 130 and 132 meets the electricity demand of consumer 152. If consumer 152's electricity demand exceeds or falls below the power supplied by the GTCC 104 and renewable energy sources 130 and 132, the controller 108 can instruct the GTCC 104 on a response strategy. In this way, controller 108 can interact with controllers 124 and 126 for GTCC 104.

[0166] Circuit 80 communicates with memory devices such as memory 84, that is, it can read from and write to memory devices. Memory 84 can contain various computer-readable instructions to perform operations on the power grid 128. In this way, memory 84 can contain instructions for monitoring the demand on the power grid 128 and the power supplied to the power grid 128. Circuit 80 can be connected to various sensors to perform such functions. Memory 84 can also contain information that can help controller 108 give instructions to controllers 120-126. For example, memory 84 can contain type, size (capacity), age, maintenance history, location, location within the geography covered by the power grid 128, and proximity of each GTCC 104 to consumers 152. Memory 84 can also contain instructions for determining the proportion of GTCC 104 and other power plants, and their contribution to the total power supply.

[0167] Controllers 120-126 may be configured to operate the GTCC 104 and the hydrogen production system 106. Memory 52 can contain various computer-readable instructions to carry out the operation of the GTCC 104 and the hydrogen production system 106. In this way, memory 52 can contain instructions for monitoring power generation allocation from controller 108, instructions for power generation to each generator 156 and 154, and so on. Memory 52 may additionally contain instructions for operating the electrolytic cell 201 and the electrolysis unit 428.

[0168] In addition, memory 52 may include operational efficiency information, such as production efficiency and economic efficiency information for each of the generator units 156 and 154, including the gas turbine 114. For example, memory 52 may include the power generation efficiency of each of the turbines 114. Memory 52 may also include maintenance and economic history for the gas turbine 114, as well as economic information such as the time since the last service, repair, overhaul, and refurbishment status. Memory 52 may also include information on the operational efficiency of the GTCC 104, including the financial efficiency of each of the gas turbines 114, as well as various contractual obligations to the operators of the various power plants, the manufacturers of the gas turbines 114, and the service providers for the gas turbines 114.

[0169] Controllers 120-126 can operate or communicate with controllers 24A and 24B to operate the compressor 138, turbine 226, compressor 254, valves 142-144, purification units 136 and 140, circuit breakers 410A-410F, and clutches 160 and 214, as well as other components of system 100.

[0170] Controller 108 can work in conjunction with controllers 120-126 to operate controllers 24A and 24B to maximize or most efficiently operate system 100, for example, by controlling the operation of the hydrogen production system 106 to produce hydrogen when conditions on the power grid 128 permit it. In this way, memories 52 and 84 can contain instructions to operate or execute any of the methods described herein, such as the seven operating states described with reference to Table 1 and Cases 1-6, and with reference to Figure 10.

[0171] Various memos and examples Integrated power generation system

[0172] Example 1 is a power plant configured to output power to a power grid system, the power plant comprising: a hydrogen production system configured to produce hydrogen; a gas turbine combined cycle power plant including a gas turbine engine configured to burn hydrogen from the hydrogen production system to generate a gas flow that can be used to rotate a turbine shaft, and a heat recovery steam generator (HRSG) configured to generate steam with the gas flow from the gas turbine engine to rotate a steam turbine; a storage system configured to store hydrogen produced by the hydrogen production system; and a controller configured to operate the hydrogen production system with power from the power grid system when the power grid system has surplus energy, and to balance active and reactive loads on the power grid system using at least one of the hydrogen production system and the gas turbine combined cycle power plant.

[0173] In Example 2, the subject of Example 1 optionally includes a power conversion device that connects the hydrogen generation system to the power grid system, the power conversion device including a DC converter for converting DC power from the hydrogen generation system to clean AC power for the power grid system, and an AC converter for converting AC power from the power grid system to DC power for the hydrogen generation system.

[0174] In Example 3, any one or more themes from Examples 1-2 may optionally include the fact that the DC converter includes a chopper converter or a thyristor converter, and that the AC converter includes a power conversion system.

[0175] In Example 4, any one or more of the themes from Examples 1 to 3 optionally include the fact that a gas turbine engine is connected to a gas turbine generator via a first clutch, and that a controller is configured to selectively actuate the first clutch, allowing the gas turbine generator to rotate freely and absorb reactive loads.

[0176] In Example 5, any one or more themes from Examples 1 to 4 optionally include the fact that the steam turbine is connected to a steam turbine generator via a second clutch, and that the controller is configured to selectively actuate the second clutch, allowing the steam turbine generator to rotate freely and absorb reactive loads.

[0177] In Example 6, any one or more subjects from Examples 1-5 optionally include batteries connected to the grid power system to provide load and frequency support.

[0178] In Example 7, the subject of Example 6 optionally includes a renewable energy producer connected to the power grid system, and the battery can be charged from the renewable energy producer without the power grid system.

[0179] In Example 8, any one or more subjects from Examples 1-7 optionally include an auxiliary burner configured to burn hydrogen from the hydrogen production system to heat the hydrogen production system.

[0180] In Example 9, any one or more of the themes from Examples 1 to 8 optionally include the fact that the hydrogen production system includes an electrolytic cell.

[0181] In Example 10, the subject of Example 9 optionally includes a heat source for heating the electrolytic cell, and the heat source includes a resistance heater or a power conversion device.

[0182] In Example 11, any one or more subjects from Examples 9-10 optionally include a heat exchange circuit connected to the electrolytic cell for cooling or heating the electrolytic cell.

[0183] In Example 12, the subject of Example 11 optionally includes the connection of the heat exchange circuit to a gas turbine combined cycle power plant to receive steam.

[0184] In Example 13, any one or more subjects from Examples 11-12 optionally include further configuration of the electrolytic cell to produce oxygen, and the power plant further includes an oxygen storage system.

[0185] In Example 14, the subject of Example 13 optionally includes the fact that the heat exchange circuit is supplied with cooled oxygen from an electrolytic cell.

[0186] In Example 15, any one or more subjects from Examples 13-14 optionally include an oxygen turbine driven by oxygen from an electrolytic cell and a generator driven by the oxygen turbine.

[0187] In Example 16, any one or more subjects from Examples 9-15 optionally include conduits connecting the oxygen output of an electrolytic cell to the HRSG of a gas turbine combined cycle power plant.

[0188] In Example 17, the subject of Example 16 optionally includes a nozzle connected to the inlet of the HRSG to inject oxygen from the electrolytic cell at a rate of 750 m / s or more.

[0189] In Example 18, any one or more subjects from Examples 1-17 optionally include burning hydrogen in the HRSG using an auxiliary combustion burner.

[0190] In Example 19, any one or more subjects from Examples 1-18 optionally include a natural gas source connected to a gas turbine engine, and the gas turbine engine is configured to burn natural gas, hydrogen, and combinations thereof.

[0191] In Example 20, any one or more of the themes from Examples 1 to 19 may optionally include the fact that the hydrogen storage system includes an underground storage system.

[0192] In Example 21, the subject of Example 20 optionally includes the fact that the hydrogen storage system includes a rock salt cavity.

[0193] In Example 22, any one or more of the themes from Examples 20-21 optionally include the fact that the hydrogen storage system includes multiple pipes.

[0194] In Example 23, the subject of Example 22 optionally includes a temporary support structure, which includes a hoist configured to install pipes in a groove, and a welding gantry that can operate using the temporary support structure to assemble sections of pipe.

[0195] syringe

[0196] Example 1 is a power plant configured to output power to a power grid system, the power plant comprising an electrolytic cell configured to produce hydrogen and oxygen, a gas turbine combined cycle power plant including a gas turbine engine configured to burn hydrogen from a hydrogen production system to generate a gas flow that can be used to rotate a turbine shaft, and a heat recovery steam generator (HRSG) configured to generate steam from the gas flow of the gas turbine engine to rotate a steam turbine, a storage system configured to store hydrogen produced by the hydrogen production system, and nozzles configured to guide oxygen from the electrolytic cell into the HRSG of the gas turbine combined cycle power plant.

[0197] In Example 2, the subject of Example 1 optionally includes a nozzle comprising an injector configured to receive fuel, and a housing into which the injector extends and oxygen enters, and the housing optionally includes a plurality of mixing ports of the injector arranged radially to allow the fuel and oxygen to be mixed outside the nozzle.

[0198] In Example 3, the subject of Example 2 optionally includes the configuration in which multiple radial mixing ports are configured to generate mixing vortices and reduce NOx generation in the gas flow.

[0199] Example 4 is a method for burning fuel using a hot nozzle, the method comprising: (A) supplying an oxidizer having an oxygen concentration of at least 30 volume percent into an oxidizer supply duct communicating with a combustion zone at an initial velocity of less than 300 fps; and (B) supplying fuel separately into the oxidizer supply duct at a speed of 200 feet per second or more and at a speed greater than the initial velocity of the oxidizer, thereby mixing the oxidizer with the high-speed fuel, and burning up to about 20% of the oxygen in the oxidizer supplied into the oxidizer supply duct together with the fuel to generate heat and combustion reactions. The process includes (C) producing a combustion reaction product and further mixing the combustion reaction product and oxidizer into the combustion reaction, (D) mixing the combustion reaction product with the remaining oxygen in the oxidizer in the oxidizer supply duct to raise the temperature of the remaining oxidizer in the oxidizer supply duct, and (D) discharging the heated oxidizer from the oxidizer supply duct into the combustion zone at an outlet velocity exceeding an initial velocity of at least 300 feet per second, wherein the heated oxidizer is discharged out of the oxidizer supply duct through a plurality of orifices positioned in different directions.

[0200] Hybrid power converter

[0201] In Example 1, the subject of the example, which is not definitive, optionally includes the fact that the power converter is configured to convert AC power from the grid power system to DC power to the electrolytic cell, and DC power from the electrolytic cell to AC power to the grid power system.

[0202] In Example 2, the subject of the example, which is not definitive, optionally includes the fact that the power converter includes a DC converter, which includes a chopper converter or a thyristor converter, and an AC converter, which includes a power conversion system.

[0203] In Example 3, the subject of the example, which is not definitively defined, optionally includes a further step of including a battery configured to absorb active and reactive loads on a power grid system.

[0204] In Example 4, the subject of Example 3 optionally includes a renewable energy producer configured to power a battery without a power grid system.

[0205] Operating status method

[0206] Example 1 is a method for operating an integrated power plant connected to a power grid system, the method comprising: operating a gas turbine engine to drive a first generator to supply power to the power grid system, wherein the gas turbine engine is capable of operating on at least one of hydrogen and natural gas; operating an electrolytic cell to produce hydrogen and oxygen with electricity from the power grid system; storing the hydrogen produced by the electrolytic cell in a storage system; and coordinating the operation of the gas turbine engine and the electrolytic cell to supply power to the demands of the power grid system.

[0207] In Example 2, the subject of Example 1 optionally includes the step of coordinating the operation of a gas turbine engine and an electrolytic cell in response to the power demand of the power grid system, which includes the step of starting the gas turbine engine from a stop until it is operating at maximum output, and the step of stopping the operation of the electrolytic cell, and the requirement that the demand of the power grid system is a requirement for maximum power.

[0208] In Example 3, the subject of Example 2 optionally includes the fact that the gas turbine engine is started from 0% load and that the electrolytic cell is started from 100% load and operates on renewable energy connected to the power grid system.

[0209] In Example 4, any one or more of the themes from Examples 1 to 3 may optionally include the step of coordinating the operation of a gas turbine engine and an electrolytic cell in response to the power demand of a power grid system, the step of increasing the operation of the gas turbine engine from partial load at a constant rate at the maximum ramp rate, and the step of stopping the operation of the electrolytic cell, and the step of the power demand of the power grid system being a demand for maximum power.

[0210] In Example 5, the subject of Example 4 optionally includes the fact that the gas turbine engine starts up at 30% load and operates on natural gas, and that the electrolytic cell starts up at 100% load.

[0211] In Example 6, any one or more themes from Examples 1 to 5 optionally include the step of coordinating the operation of a gas turbine engine and an electrolytic cell in response to the power demand of a power grid system, the step of reducing the operation of the gas turbine engine at a constant rate from a maximum load state, and the step of starting the operation of the electrolytic cell, and the step of changing the demand of the power grid system from maximum power demand to reduced power demand.

[0212] In Example 7, the subject of Example 6 optionally includes the fact that the gas turbine engine starts up from 100% load and operates on natural gas and hydrogen from the electrolytic cell, and that the electrolytic cell starts up from 0% load.

[0213] In Example 8, any one or more themes from Examples 1 to 7 optionally include the step of coordinating the operation of a gas turbine engine and an electrolytic cell in response to the power demand of a power grid system, the step of operating the gas turbine engine in standby mode, the step of stopping the operation of the electrolytic cell, and the condition that the demand of the power grid system is constant.

[0214] In Example 9, the subject of Example 8 optionally includes the fact that the gas turbine engine is starting up from a stop, that the electrolytic cell is one of several electrolytic cells, that 50% of the multiple electrolytic cells start up from 0% load and 50% of the electrolytic cells start up from 100% load, and that the electricity is supplied to the power grid system due to a decrease in renewable energy output.

[0215] In Example 10, any one or more themes from Examples 1 to 9 optionally include the step of coordinating the operation of a gas turbine engine and an electrolytic cell in response to the power demand of a power grid system, the step of increasing the operation of the gas turbine engine at a constant rate up to its maximum speed, the step of reducing the output of the electrolytic cell, and the step of increasing the demand of the power grid system.

[0216] In Example 11, the subject of Example 10 optionally includes the fact that the gas turbine engine is run on natural gas and hydrogen from an electrolytic cell after being revved up to no-load speed, and that the electrolytic cell is started at 100% load and runs on renewable energy connected to the power grid system.

[0217] In Example 12, any one or more themes from Examples 1 to 11 optionally include the step of coordinating the operation of a gas turbine engine and an electrolytic cell in response to the power demand of a power grid system, the step of increasing the operation of the gas turbine engine from a non-operating state at a constant rate, and the step of stopping the operation of the electrolytic cell, and the condition that the demand of the power grid system is increasing.

[0218] In Example 13, the subject of Example 12 optionally includes the fact that the gas turbine engine starts up performing grid condensation operations and then begins operation with natural gas first, followed by hydrogen, and that the electrolytic cell starts up at 100% load.

[0219] In Example 14, any one or more subjects from Examples 1 to 13 optionally include the step of operating a heat recovery steam generator (HRSG) using the exhaust gases of a gas turbine engine to rotate a steam turbine and drive a second generator.

[0220] In Example 15, any one or more subjects from Examples 1 to 14 optionally include the step of heating the electrolytic cell with steam from the HRSG.

[0221] The embodiments for carrying out the invention described above include references to accompanying drawings that form part of the embodiments for carrying out the invention. For example, the drawings illustrate specific embodiments in which the invention may be carried out. These embodiments are also referred to herein as “Examples.” Such examples may include elements that are in addition to the illustrated or described elements. However, the inventors also intend examples in which only the illustrated or described elements are provided. Furthermore, the inventors also intend examples in which, with respect to a particular example (or one or more embodiments thereof) or with respect to other examples (or one or more embodiments thereof) illustrated or described herein, any combination or arrangement of those illustrated or described elements (or one or more embodiments thereof) is used.

[0222] In the event of any conflict between usage in this specification and any document incorporated by reference, the usage in this specification shall prevail.

[0223] In this specification, the terms “a” and “an” are used to include one or more, independently of any other instances or uses of “at least one” or “one or more,” as is common in patent documents. In this specification, the term “or” is used to refer non-exclusively, or unless otherwise indicated, so that “A or B” includes “A but not B,” “B but not A,” and “A and B.” In this specification, the terms “including” and “in which” are used as readily understandable English synonyms for “comprising” and “wherein,” respectively. Similarly, in the following claims, the terms “including” and “comprising” are unrestricted; that is, any system, device, item, configuration, phrase, or process that includes elements in addition to those listed after such terms in the claims is still considered to fall within the scope of those claims. Furthermore, in the following claims, terms such as “first,” “second,” and “third” are used merely as labels and are not intended to impose numerical requirements on those objects.

[0224] The above description is intended to be illustrative, not restrictive. For example, the examples described above (or one or more of their embodiments) may be used in combination with each other. Other embodiments may be used, for example, by a person skilled in the art reconsidering the above description. The abstract is provided in accordance with Section 1.72(b) of the U.S. Patent Law Enforcement Rules to enable the reader to quickly confirm the nature of the technical disclosure. The abstract is submitted with the understanding that it is not used to describe or limit the scope or meaning of the claims. Similarly, in the embodiments for carrying out the invention described above, various features may be grouped together to simplify the disclosure. This should not be interpreted as intended to mean that unclaimed disclosed features are essential to any claim. Rather, the inventive subject matter may be less than all the features of a particular disclosed embodiment. Accordingly, the following claims are incorporated herein by specification as examples or embodiments in the embodiments for carrying out the invention, and each claim is intended to be based on itself as a separate embodiment, and such embodiments may be combined with each other in various combinations or arrangements. The scope of the present invention should be determined in accordance with the appended claims, along with the entire scope of equivalents to which such claims are entitled. [Explanation of symbols]

[0225] 100 Integrated Power Production Systems 104 Combined Cycle Gas Turbine Power Plant (GTCC) 106 Hydrogen Production System 108 controllers 110 Hydrogen storage system, hydrogen receiving tank 112 Oxygen Storage System 114 Gas Turbine 116 Heat Recovery Steam Generator (HRSG) 118 Steam Turbine 120 Electrolytic Cell VAR Setpoint Controller 122 Electrolytic Cell Production Setting Point Controller 124 GTCC Plant Output Setpoint Controller 126 GTCC Plant VAR Setpoint Controller 128 Power grid 130 Renewable wind power sources 132 Renewable Photovoltaic Solar Power Source 134 converter 135A~D Transformer 136 Hydrogen Purification System 138 Hydrogen Compressor 140 Oxygen Purification System 142, 143, 144 valves 146 Natural gas sources 148 Compressor 150 Combustor 152 Turbine 154,156 generators 158 Heat exchanger 160 Clutch 162 Heat exchanger 164 Inlet duct 200 Systems 201 Electrolytic cell 214 Clutch 220 Systems 222 BT 224 Cooling System 226 Expansion Turbine 228 Generators 229 Heat exchanger 230 Fluid Loop 232 Electrolytic Cell Bank 234 Rectifier Bank 236 Fluid lines 238 Electrolyzer line 240 power lines 242 Heating devices 250 Hydrogen Surge System 252 Hydrogen Surge Tank 254 Hydrogen Surge Compressor 258 Mixing tank 260 Steam Circuit 276A~C valve 280 storage tanks 282 pipelines

Claims

1. A power plant configured to output power to the power grid system, A hydrogen generation system configured to produce hydrogen, A gas turbine engine configured to generate a gas flow usable to rotate a turbine shaft by burning hydrogen from the hydrogen generation system, and A heat recovery steam generator (HRSG) configured to generate steam with the gas flow of the gas turbine engine and rotate a steam turbine, A gas turbine combined cycle power plant including, A storage system configured to store hydrogen produced by the hydrogen generation system, To operate the hydrogen generation system with power from the power grid system when the power grid system has surplus energy, and To balance the active and reactive loads on the power grid system using at least one of the hydrogen generation system and the gas turbine combined cycle power plant. A power plant including a controller configured to perform the following actions.

2. The hydrogen generation system further includes a power conversion device that connects the hydrogen generation system to the power grid system, and the power conversion device is A DC converter for converting DC power from the hydrogen generation system into clean AC power for the power grid system, The power plant according to claim 1, further comprising an AC converter for converting AC power from the power transmission grid system into DC power for the hydrogen generation system.

3. The DC converter includes a chopper converter or a thyristor converter. The power plant according to claim 2, wherein the AC converter includes a power conversion system.

4. The gas turbine engine is connected to a gas turbine generator via a first clutch. The power plant according to claim 1, wherein the controller is configured to selectively activate the first clutch, thereby enabling the gas turbine generator to rotate freely and absorb reactive loads.

5. The steam turbine is connected to a steam turbine generator via a second clutch. The power plant according to claim 1, wherein the controller is configured to selectively activate the second clutch, thereby enabling the steam turbine generator to rotate freely and absorb the reactive load.

6. The power plant according to claim 1, further comprising a battery connected to the power grid system to provide load and frequency support.

7. The power plant according to claim 6, further comprising a renewable energy producer connected to the power grid system, wherein the battery can be charged from the renewable energy producer without the power grid system.

8. The power plant according to claim 1, further comprising an auxiliary burner configured to burn hydrogen from the hydrogen generation system in order to heat the hydrogen generation system.

9. The power plant according to claim 1, wherein the hydrogen generation system includes an electrolytic cell.

10. The power plant according to claim 9, further comprising a heat source for heating the electrolytic cell, wherein the heat source comprises a resistance heater or a power conversion device.

11. The power plant according to claim 9, further comprising a heat exchange circuit connected to the electrolytic cell for cooling or heating the electrolytic cell.

12. The power plant according to claim 11, wherein the heat exchange circuit is connected to the gas turbine combined cycle power plant and supplied with steam.

13. The electrolytic cell is further configured to produce oxygen, The power plant according to claim 11, further comprising an oxygen storage system.

14. The power plant according to claim 13, wherein the heat exchange circuit is supplied with cooled oxygen from the electrolytic cell.

15. An oxygen turbine driven by oxygen from the electrolytic cell, The power plant according to claim 13, further comprising a generator driven by the oxygen turbine.

16. A conduit connecting the oxygen output of the electrolytic cell to the HRSG of the gas turbine combined cycle power plant, A nozzle connected to the inlet of the HRSG for injecting oxygen from the electrolytic cell at a high speed of 750 m / s or more, The power plant according to claim 9, further comprising:

17. The power plant according to claim 1, further comprising burning the hydrogen in the HRSG using an auxiliary combustion burner.

18. The power plant according to claim 1, further comprising a natural gas source connected to the gas turbine engine, wherein the gas turbine engine is configured to burn natural gas, hydrogen, and combinations thereof.

19. The power plant according to claim 1, wherein the hydrogen storage system includes an underground storage system comprising at least one of a rock salt cavity and a plurality of pipes.

20. A temporary support structure including a hoist configured to install a pipe in a groove, The power plant according to claim 19, further comprising a welding gantry that is operable using the temporary support structure for assembling sections of pipe.

21. It is a system, A first gas turbine operably connected to a first generator and generating base load power, wherein the base load power is transmitted to a power grid controlled by a main controller, and the first gas turbine A second gas turbine operably connected to a second generator and generating electricity for transmission to the power grid, A hydrogen generation electrolytic cell configured to be selectively powered by electricity from the aforementioned power grid, the hydrogen generation electrolytic cell being operably connected to supply hydrogen fuel to the second gas turbine, It is a controller, In response to the surplus power from the power grid exceeding a threshold, the power from the power grid to the hydrogen production electrolytic cell is increased to increase the amount of hydrogen fuel produced for the second gas turbine. Depending on whether the surplus power from the power grid exceeds a threshold, the power from the power grid to the hydrogen production electrolytic cell is reduced to reduce the amount of hydrogen fuel produced for the second gas turbine. A controller configured in such a way, A system that includes these features.

22. The system according to claim 21, further comprising a plurality of third gas turbines installed together with the first gas turbine, each of the plurality of third gas turbines being operably connected to a third generator to generate base load power for transmission to the power grid.

23. The system according to claim 22, wherein the second gas turbine is at least one of the plurality of third gas turbines.

24. The system according to claim 21, wherein the hydrogen generation electrolytic cell and the second gas turbine are located at different geographical locations from the first gas turbine.

25. The system according to claim 21, wherein, in response to the controller reducing the power from the power grid to the hydrogen production electrolytic cell, the controller adjusts at least the non-hydrogen fuel flow rate of the second gas turbine in order to maintain the output of the second gas turbine.

26. The system according to claim 21, wherein the controller is located in the power grid.

27. The system according to claim 21, wherein the threshold includes the industrial consumer going offline.

28. The system according to claim 21, further comprising a hydrogen input line for supplying hydrogen from the hydrogen generation electrolytic cell to industrial consumers.

29. The system according to claim 21, further comprising a storage tank for storing hydrogen fuel from the hydrogen generation electrolytic cell.

30. The system according to claim 21, further comprising a heating system that is thermally in communication with the hydrogen generation electrolytic cell and maintains the hydrogen generation electrolytic cell in a standby mode at or near the operating temperature.

31. It is a system, A first gas turbine is operably connected to a first generator and generates electricity for transmission to the power grid, A second gas turbine is operably connected to a second generator and generates electricity for transmission to the power grid, A hydrogen generation electrolytic cell configured to be selectively driven by power from the power grid or power from one or both of the first gas turbine and the second gas turbine, the hydrogen generation electrolytic cell being operably connected to supply hydrogen fuel to one or both of the first gas turbine and the second gas turbine, A controller operably connected to the first gas turbine, the second gas turbine, and the hydrogen generation electrolytic cell, wherein the controller is In response to a signal indicating a power shortage from the power grid, the power outputs of the first generator and the second generator are directed towards the hydrogen generation electrolytic cell. In response to a signal from the controller indicating the power demand from the power grid, the power outputs of the first generator and the second generator are directed towards the power grid. A controller and A system that includes these features.

32. The system according to claim 31, wherein the shortage of electricity demand from the power grid includes a decrease in demand from industrial consumers.

33. The system according to claim 32, wherein the decline in demand from the industrial consumer includes the industrial consumer going offline.

34. The system according to claim 31, further comprising a hydrogen input line for supplying hydrogen from the hydrogen generation electrolytic cell to industrial applications.

35. The system according to claim 31, further comprising a storage tank for storing hydrogen fuel from the hydrogen generation electrolytic cell.

36. The system according to claim 31, wherein the controller is configured to issue a signal to the hydrogen generation electrolytic cell to maintain standby mode when there is a power demand from the power grid.

37. The system according to claim 36, further comprising a heating system that is thermally in communication with the hydrogen generation electrolytic cell and maintains the hydrogen generation electrolytic cell in a standby mode at or near the operating temperature.

38. The system according to claim 31, wherein the first gas turbine and the second gas turbine are distributed across a geographical area.

39. The steps include transmitting base load power generated by a first gas turbine coupled to a first generator to a power grid controlled by a main controller, Steps include: sending the base load power generated by the first gas turbine to a hydrogen generation electrolytic cell in response to the power demand from the main controller exceeding a threshold, wherein the hydrogen generation electrolytic cell is operably coupled to supply hydrogen fuel to the first gas turbine; The steps include transmitting the base load power generated by the first gas turbine to the power grid in response to the power demand from the main controller exceeding the threshold, A method that includes [a certain feature].

40. The method according to claim 39, wherein the operation of the hydrogen generation electrolytic cell is stopped in response to the power demand from the main controller exceeding the threshold.

41. The method according to claim 39, wherein the hydrogen-producing electrolytic cell is operably connected to supply hydrogen fuel to a second gas turbine, and the second gas turbine is operably connected to a second generator to generate electricity.

42. A method for operating an integrated power plant connected to a power grid system, A step of operating a gas turbine engine to drive a generator in order to supply power to the aforementioned power grid system, wherein the gas turbine engine is operable with hydrogen, natural gas, and mixtures thereof, The steps include operating an electrolytic cell that generates hydrogen and oxygen using electricity from the aforementioned power grid system, The steps include storing the hydrogen produced by the electrolytic cell in a storage system, The steps include adjusting the operation of the gas turbine engine and the electrolytic cell based on the power demand of the power transmission grid system, A method that includes [a certain feature].

43. The step of adjusting the operation of the gas turbine engine and the electrolytic cell based on the power demand of the power transmission grid system is: The method according to claim 42, further comprising the step of operating the gas turbine engine with natural gas when renewable energy sources are available.

44. The step of adjusting the operation of the gas turbine engine and the electrolytic cell based on the power demand of the power transmission grid system is: The method according to claim 42, further comprising the step of operating the gas turbine engine with hydrogen when renewable energy sources are unavailable.

45. The step of adjusting the operation of the gas turbine engine and the electrolytic cell based on the power demand of the power transmission grid system is: The method according to claim 44, further comprising the step of obtaining hydrogen for the gas turbine engine from a hydrogen storage system.

46. The step of adjusting the operation of the gas turbine engine and the electrolytic cell based on the power demand of the power transmission grid system is: The method according to claim 42, comprising the step of operating a gas turbine engine with a mixture of hydrogen and natural gas.

47. The method according to claim 46, wherein the step of operating the gas turbine engine with a mixture of hydrogen and natural gas is performed when the power demand of the power grid system is in a transitional state between a first power demand level and a second power demand level.

48. The method according to claim 47, wherein the step of operating the gas turbine engine with a mixture of hydrogen and natural gas is performed when a renewable energy source is partially available to the power grid system.

49. The step of adjusting the operation of the gas turbine engine and the electrolytic cell based on the power demand of the power transmission grid system is: The steps include starting the gas turbine engine from a non-operating state and operating it at a speed that increases the amount of power generated to achieve the maximum rated output, The steps include: operating the electrolytic cell and stopping the consumption of power from the power grid system by the electrolytic cell; The method according to claim 42, wherein the power demand of the power grid system is a maximum power requirement.

50. The step of adjusting the operation of the gas turbine engine and the electrolytic cell based on the power demand of the power transmission grid system is: The steps include increasing the operation of the gas turbine engine from a partial load state to the maximum ramp speed, The steps include: operating the electrolytic cell and stopping the consumption of power from the power grid system; The method according to claim 42, wherein the power demand of the power grid system is a maximum power requirement.

51. The step of adjusting the operation of the gas turbine engine and the electrolytic cell based on the power demand of the power transmission grid system is: The steps include reducing the operation of the gas turbine engine from a maximum load state to a minimum load state to reduce the power output, The steps include starting the operation of the electrolytic cell to consume the reduced electrical output, The method according to claim 42, which includes reducing the power demand of the power grid system.

52. The step of adjusting the operation of the gas turbine engine and the electrolytic cell based on the power demand of the power transmission grid system is: The steps include operating the aforementioned gas turbine engine in standby mode, The steps include stopping the operation of the electrolytic cell, The method according to claim 42, wherein the demand for the power grid system is constant.

53. The step of adjusting the operation of the gas turbine engine and the electrolytic cell based on the power demand of the power transmission grid system is: The steps include increasing the speed of the gas turbine engine to full speed, The steps of reducing the output of the electrolytic cell, The method according to claim 42, which includes an increase in the demand for the power grid system.

54. The step of adjusting the operation of the gas turbine engine and the electrolytic cell based on the power demand of the power transmission grid system is: The steps include increasing the operation of the gas turbine engine from a non-operating state, The steps include stopping the operation of the electrolytic cell, The method according to claim 42, which includes an increase in the demand for the power grid system.

55. An integrated power plant system, A gas turbine engine that can operate on hydrogen, natural gas, and mixtures thereof, Multiple electrolytic cells, Storage system and A controller that communicates with the plurality of electrolytic cells, the gas turbine engine, and the storage system, A memory that is executable by the controller and stores instructions for operating the plurality of electrolytic cells, the gas turbine engine, and the storage system, The instruction is provided, A command for operating the gas turbine engine to drive a generator and supply power to the power grid system, wherein the gas turbine engine is capable of operating on at least one of hydrogen, natural gas, and mixtures thereof. A command to operate one or more electrolytic cells to generate hydrogen and oxygen using electricity from the aforementioned power grid system, A command for storing hydrogen produced by one or more of the aforementioned electrolytic cells in a storage system, Commands for adjusting the operation of the gas turbine engine and the plurality of electrolytic cells to match the power demand of the power grid system, An integrated power plant system, including...

56. Commands for adjusting the operation of the gas turbine engine and the plurality of electrolytic cells based on the power demand of the power transmission grid system, The integrated power plant system according to claim 55, further comprising the step of operating the gas turbine engine with natural gas when renewable energy sources are available.

57. Commands for adjusting the operation of the gas turbine engine and the plurality of electrolytic cells based on the power demand of the power transmission grid system, The integrated power plant system according to claim 55, further comprising the step of operating the gas turbine engine with hydrogen when renewable energy sources are unavailable.

58. Commands for adjusting the operation of the gas turbine engine and the plurality of electrolytic cells based on the power demand of the power transmission grid system, The integrated power plant system according to claim 57, comprising the step of obtaining hydrogen for the gas turbine engine from a hydrogen storage system.

59. Commands for adjusting the operation of the gas turbine engine and the plurality of electrolytic cells based on the power demand of the power transmission grid system, The integrated power plant system according to claim 55, comprising the step of operating the gas turbine engine with a mixture of hydrogen and natural gas.

60. The integrated power plant system according to claim 59, wherein the step of operating the gas turbine engine with a mixture of hydrogen and natural gas is performed when the power demand of the power grid system is in a transitional state between a first power demand level and a second power demand level.

61. The integrated power plant system according to claim 60, wherein the step of operating the gas turbine engine with a mixture of hydrogen and natural gas is performed when renewable energy sources are partially available to the power grid system.

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