Reactor-based systems, methods, and devices for energy generation and carbon dioxide (CO2) capture.

Abstract

An integrated energy system comprising a power plant configured to generate steam. The power plant may comprise a nuclear reactor and / or an electricity generation system. A chemical product generation system may comprise a first reaction chamber that receives sodium formate (HCOONa), which decomposes into sodium oxalate ((COO)2Na2) and hydrogen (H2), via the insertion of a first portion of steam at a first temperature, wherein the steam may comprise a first reaction chamber containing superheated steam. A chemical product generation system may comprise a second reaction chamber that receives sodium oxalate ((COO)2Na2), which decomposes into sodium oxide (Na2O), carbon monoxide (CO), and carbon dioxide (CO2), via the insertion of a second portion of steam at a second temperature. A syngas generation system may be operably connected to the chemical product generation system and configured to generate a combination of hydrogen (H2), carbon monoxide (CO), and / or carbon dioxide (CO2), and / or syngas.

Description

Technical Field

[0001] Cross - reference to Related Applications This application claims the benefit of U.S. Patent Application No. 18 / 607,268, filed Mar. 15, 2024; U.S. Provisional Patent Application No. 63 / 453,032, filed Mar. 17, 2023, entitled "SMALL MODULAR NUCLEAR REACTOR INTEGRATED ENERGY SYSTEMS FOR ENERGY PRODUCTION AND CO2 PRODUCTION, AND ASSOCIATED DEVICES AND METHODS"; U.S. Provisional Patent Application No. 63 / 493,049, filed Mar. 30, 2023, entitled "SYSTEMS, METHODS, AND DEVICES FOR CAPTURING CARBON DIOXIDE FROM THE ATMOSPHERE USING SODIUM HYDROXIDE"; and U.S. Provisional Patent Application No. 63 / 625,284, filed Jan. 26, 2024, entitled "DECOMPOSITION OF SODIUM FORMATE AND SODIUM OXALATE USING SUPER - HEATED STEAM FROM NUCLEAR REACTOR SYSTEM FOR DIRECT IN - SITU METHANOL PRODUCTION", all of which are hereby incorporated by reference in their entirety.

Background Art

[0002] Various sources can be used to capture carbon dioxide (CO2) in various ways. Resources such as adsorbents can be used to capture carbon dioxide (CO2) by binding with carbon dioxide (CO2) in the air. Carbon dioxide (CO2) capture can be achieved before, during, or after the combustion of fossil fuels such as coal or natural gas. Carbon dioxide (CO2) capture achieved before the combustion of fossil fuels may include capturing carbon dioxide (CO2) before the fossil fuels are gasified, such as to produce synthesis gas. Carbon dioxide (CO2) capture may also be achieved after the combustion process has been carried out. Carbon dioxide (CO2) capture after the combustion process has been carried out may include capturing carbon dioxide (CO2) from the exhaust gases of power plants and industrial facilities after the combustion process has been carried out.

[0003] Captured carbon dioxide (CO2) can be utilized in a variety of ways. Captured carbon dioxide (CO2) can be used in chemical synthesis processes, such as to provide chemicals, metals, and polymers. Captured carbon dioxide (CO2) in the atmosphere can be used in attempts to reduce atmospheric carbon dioxide (CO2) concentrations globally to offset the consequences of the continuous use of carbon-rich fossil fuels such as coal, oil, and natural gas (methane (CH4)). Atmospheric carbon dioxide (CO2) concentrations are projected to reach 530-980 parts per million (ppm) by 2100, double the current level of 410 ppm and potentially much higher than the pre-industrial level of 280 ppm. Lowering atmospheric carbon dioxide (CO2) concentrations may result in less radiant heat being reflected back to the Earth's surface, reducing the level of carbon dioxide (CO2) reacting with seawater molecules and consequently reducing ocean acidification. Captured carbon dioxide (CO2) can be utilized in industrial processes, such as being used as a shielding gas in welding. Captured carbon dioxide (CO2) can also be utilized in enhanced oil recovery (EOR) processes, such as being injected into reservoirs of depleted wells for oil extraction.

[0004] Detailed explanations are provided with reference to the attached figures. In each figure, the leftmost digit of the reference number identifies the figure in which the reference number first appears. The use of the same reference number in different figures indicates similar or identical items. Furthermore, the figures may be considered to provide an approximate depiction of the relative sizes of individual components within each figure. However, the figures are not to scale, and the relative sizes of individual components, both within individual figures and across different figures, may differ from those depicted. In particular, some figures may depict components as a specific size or shape, while other figures may depict the same components at a larger scale or in a different shape for clarity. [Brief explanation of the drawing]

[0005] [Figure 1] A schematic representation of the integrated energy system 100, which includes a small modular reactor (SMR) system integrated with a chemical generation system, is shown. [Figure 2] This diagram shows a process flow chart for an example related to a carbon dioxide (CO2) capture process that results in the carbon-free production of sodium formate (HCOONa) and sodium acetate (CH3COONa). [Figure 3A] This is a schematic diagram of the production system, where the direct air capture (DAC) system 106 in Figure 1 is integrated with the sodium formate production system 108 in Figure 1 and is configured to produce solid carbon dioxide (CO2) and liquid carbon dioxide (CO2) according to this embodiment of the technology. [Figure 3B] A schematic diagram of the 300B syngas generation system for methanol (CH3OH), which uses hydrogen (H2), carbon monoxide (CO), and carbon dioxide (CO2). [Figure 4] A schematic diagram of a production system that generates syngas using a reactor system is shown. For example, the reactor system may include a small modular reactor (SMR) system. [Figure 5]A schematic example system for capturing carbon dioxide (CO2) from the air using a reactor system and a direct air capture (DAC) process is shown. [Figure 6] A flowchart is shown illustrating an example process for utilizing an integrated small modular reactor (SMR) system to continuously and simultaneously generate hydrogen (H2), carbon monoxide (CO), and carbon dioxide (CO2) for methanol (CH3OH) production. [Figure 7] This diagram shows a process flow chart for an example related to the generation of syngas by processing large quantities of plastic waste using a two-stage pressure gasification system. [Figure 8] This diagram shows an example process flow chart for utilizing a small modular reactor plant system to capture carbon dioxide (CO2) using a direct air capture (DAC) process. [Figure 9] These are partial schematic and partial cross-sectional views of a reactor system configured according to an embodiment of this technology. [Figure 10] These are partial schematic and partial cross-sectional views of a reactor system configured according to an additional embodiment of this technology. [Figure 11] This is a schematic diagram of a nuclear power plant system including multiple reactors according to an embodiment of this technology. [Modes for carrying out the invention]

[0006] overview This disclosure pertains to a self-sufficient and fully integrated carbon dioxide (CO2) capture process that produces carbon-free emissions for syngas generation. The carbon dioxide (CO2) capture process can be implemented using nuclear power plant systems, such as small modular reactor (SMR) power plant systems. For example, nuclear power plant systems can be used to implement integrated carbon dioxide (CO2) capture processes that produce carbon-free emissions. Nuclear power plant systems can also be used to implement carbon dioxide (CO2) capture from large quantities of plastic waste.

[0007] Nuclear power plant systems can be utilized by direct air capture (DAC) systems to capture carbon dioxide (CO2) from the atmosphere. For example, a nuclear power plant system can be configured to utilize fully integrated and interconnected subsystems to capture carbon dioxide (CO2) from the atmosphere while producing carbon-free emissions. A nuclear power plant system can be configured to utilize fully integrated and interconnected subsystems to regenerate and process the captured carbon dioxide (CO2). A nuclear power plant system can be configured to utilize fully integrated and interconnected subsystems to capture carbon dioxide (CO2) from the atmosphere and process the by-products that produce carbon-free emissions. A nuclear power plant system can be configured to utilize fully integrated and interconnected subsystems to recapture and process carbon dioxide (CO2) released during operation.

[0008] In one embodiment, the SMR system may comprise a modular multi-reactor plant energy system (e.g., a reactor system with 12 reactor systems, 6 reactor systems, 4 reactor systems, or any other number of reactors). In one embodiment, the small modular reactor power plant system may comprise one or more modular pressurized water reactors. In one embodiment, the small modular reactor power plant system may comprise an energy integration system that dynamically controls the distribution of steam to the power plant.

[0009] In one embodiment, the energy integration system can dynamically control the distribution of power plant steam to various systems, components, and / or processes in order to adjust energy distribution.

[0010] In one embodiment, the SMR system may include a power conversion system. In one embodiment, the power conversion system may be configured to convert steam into electricity and to distribute the electricity to a power distribution system. In one embodiment, the power distribution system may, if necessary, direct the electricity to one or more systems, components, or processes.

[0011] In one embodiment, the SMR system may include a steam transfer system. In one embodiment, the steam transfer system may regulate the distribution of steam by directing the steam flow or by separating the steam flow into one or more components.

[0012] In one embodiment, the SMR system may include a power grid. In one embodiment, the power grid may be an external power distribution system (e.g., a local government power grid). In one embodiment, the SMR system may generate more power than needed (i.e., excess electricity). In such an embodiment, the excess power may be transferred to the power grid.

[0013] In one embodiment, the SMR system may include a nitrogen generator. In one embodiment, the nitrogen generator may be configured to capture nitrogen (N2) through various processes (e.g., pressure swing adsorption (PSA) processes, membrane systems, cryogenic systems, etc.).

[0014] In one embodiment, the SMR system may include a DAC plant. In one embodiment, the DAC plant may be configured to capture carbon dioxide (CO2). In one embodiment, the DAC plant may be configured for pressure swing adsorption operation.

[0015] In one embodiment, the SMR system may include a hydrogen (H2) and oxygen (O2) production plant. In one embodiment, the hydrogen (H2) and oxygen (O2) production plant may be configured to produce hydrogen (H2) and / or oxygen (O2) through various methods (e.g., high-temperature steam electrolysis, low-temperature steam electrolysis, solid oxide electrolysis, and proton exchange membrane water electrolysis). In one embodiment, the hydrogen fuel cell may be configured to convert hydrogen (H2) into electricity.

[0016] In one embodiment, the SMR may include a water generation plant. In one embodiment, the water generation plant may be configured to generate brine and high-quality water for use in homes, hospitals, and industries. In one embodiment, the water generation plant may include a water treatment plant. In an embodiment, the water treatment plant may be configured to remove or isolate specific minerals or particles from water.

[0017] In one embodiment, the SMR system may include an oil refining plant. In one embodiment, the oil refining plant may be configured to desulfurize natural gas, fuel, petroleum, and other chemicals. In one embodiment, the oil refining may be configured to refine petroleum into gasoline, diesel fuel, naphthenic crude oil, heating oil, fuel oil, kerosene, liquefied petroleum gas, petroleum naphtha, or other useful chemicals.

[0018] In one embodiment, the SMR system may include a chemical production plant. In one embodiment, the chemical production plant may be configured to produce sodium hydroxide (NaOH), hydrochloric acid (HCl), ammonia (NH3), urea (NH2CONH2), sulfuric acid (H2SO4), or other useful chemicals.

[0019] In some embodiments, the integrated energy system may comprise a power plant system having multiple SMRs specifically configured to work together to support one or more industrial processes. An SMR may be, for example, a smaller reactor in terms of size (e.g., dimensions). An SMR may generate a relatively equivalent amount of power to, for example, a large conventional reactor. Furthermore, SMRs may be modular in that some or all of their systems and components can be assembled in a factory and transported as units to the installation site. In some aspects of the art, multiple SMRs in an integrated energy system can flexibly and dynamically provide electricity, steam, or a combination of both to industrial processes due to the modularity and flexibility of the SMRs. That is, the configuration of the SMRs can be switched during operation to provide varying levels of steam and electricity output depending on the operating state and / or requirements of the industrial processes.

[0020] Certain details are described below and in Figures 1-11 to provide a complete understanding of the various embodiments of the Art. In other cases, well-known structures, materials, operations, and / or systems related to nuclear reactors, power plant systems, integrated energy systems, chemical production plants, industrial process plants, electrolytic systems, hydrogen (H2) and oxygen (O2) production plants, ammonia (NH3) production plants, nitric acid (HNO3) production plants, and similar are not described or described in detail below to avoid unnecessarily obscuring the description of the various embodiments of the Art. However, those skilled in the art will recognize that the Art can be implemented without one or more of the details described herein and / or with other structures, methods, components, etc. The terms used below should be interpreted in their broadest and most reasonable form, even though they are used in conjunction with the detailed description of certain examples of embodiments of the Art.

[0021] The accompanying figures illustrate embodiments of the present technology and are not intended to limit its scope unless expressly indicated. The sizes of the various elements depicted are not necessarily drawn to scale, and these elements may be enlarged to improve readability. Details of components may be abstracted in the figures to exclude details such as the arrangement of components and certain precise connections between such components, where such details are not necessary for a complete understanding of how the present technology is manufactured and used. Many of the details, dimensions, angles, and other features shown in the figures are merely illustrative of a particular embodiment of the present disclosure. Other embodiments may have other details, dimensions, angles, and features without departing from the present technology. In addition, those skilled in the art will understand that further embodiments of the present technology may be carried out without some of the details described below.

[0022] In the event of any conflict between any material incorporated herein by reference and this disclosure, this disclosure shall prevail. The headings provided herein are for convenience only and should not be construed as limiting the subject matter disclosed.

[0023] Exemplary Embodiments Figure 1 schematically shows a representation of an integrated energy system 100, which includes a small modular reactor (SMR) system integrated with a chemical production system. The energy system 100 may include a power plant system 102, a water treatment system (or “water treatment plant”) 104, a direct air capture (DAC) system (or “DAC plant”) 106, a sodium formate production system (or “sodium formate production plant”) 108, a syngas production system (or “singas production plant”) 110, a syngas storage 112, and a power grid 114.

[0024] As used herein, the term syngas refers to synthesis gas, including but not limited to hydrogen (H2), carbon monoxide (CO), and carbon dioxide (CO2). Alternatively or additionally, the term syngas may refer to any combination of, for example, hydrogen (H2), carbon monoxide (CO), and / or carbon dioxide (CO2), and / or one or more other trace gases. In one embodiment, the syngas generation system 110 may include a process that results in the production of hydrogen (H2), carbon monoxide (CO), and carbon dioxide (CO2), which includes a process that produces a chemical or compound in addition to syngas. For example, sodium formate (HCOONa) decomposes to produce sodium oxalate ((COO)2Na2) and hydrogen (H2).

[0025] In the exemplary embodiments, the power plant system 102 may be configured for use in one or more industrial processes / operations, and more specifically, for use in resource generation / recovery operations. The power plant system 102 may be located at or near the syngas generation system 110. For example, the power plant system 102 may be a permanent or temporary installation built at or near the syngas generation system 110 (e.g., approximately 1 km away), or it may be a mobile or partially mobile system that is moved to or near the syngas generation system 110 (e.g., within a threshold distance) and assembled therefrom. For example, the power plant system 102 may be moved to or near any other part of the integrated energy system 100 and assembled thereto.

[0026] In one embodiment, the power plant system 102 may include an SMR system (e.g., a multimodule power plant design). However, in various cases, the power plant system 102 may represent any type of power plant system that includes any of various other types of reactors and / or reactor systems.

[0027] The power plant system 102 can be operably connected to a water treatment system 104, a DAC system 106, a sodium formate production system 108, a syngas production system 110, a syngas storage component 112, and a power grid 114, and / or additional components for performing resource generation operations. The power plant system 102 may be referred to as a primary subsystem for performing resource generation operations. The water treatment system 104, the brine treatment system 105, the DAC system 106, the sodium formate production system 108, the syngas production system 110, the syngas storage component 112, and the power grid 114 may be referred to as secondary subsystems for performing secondary processes.

[0028] In one embodiment, the power plant system 102 can be electrically connected to a water treatment system 104, a brine treatment system 105, a DAC system 106, a sodium formate production system 108, a syngas production system 110, a syngas storage component 112, and a power grid 114 to selectively supply them with electricity (e.g., power). Similarly, individual components of the steam output paths of the power plant system 102 can be fluidly connected to the syngas production system 106 to selectively supply it with steam. In another embodiment, the power plant system 102 can be operably connected to additional or fewer outputs, and / or various outputs can receive electricity and / or steam from other sources (e.g., conventional steam suppliers, conventional electricity sources, etc.).

[0029] It should be noted that the water treatment system 104 may perform one or more of the various types of water treatment-related operations, such as seawater desalination (e.g., reverse osmosis distillation, flash boiling desalination, etc.), water purification, mineral filtration, chemical injection, particulate removal, and / or other processes necessary to produce water to desired specifications. In embodiments, the water treatment system 104 may perform water treatment-related operations based on power received from the power plant system 102. The water treatment system 104 may receive power (e.g., electricity) from the power plant system 102 via one or more electrical output paths from the power transmission system of the power plant system 102. In embodiments, the water treatment system 104 may perform water treatment operations based on steam received from the power plant system 102 via steam supply devices (e.g., heat exchangers, steam generators, steam connections, etc.) from the steam transmission system of the power plant 102.

[0030] The water treatment system 104 may be a water treatment plant, a desalination plant (e.g., reverse osmosis, flash type, etc.), and / or similar. The water treatment plant 104 may be configured to produce high-quality water that can be supplied to the power plant system 102 for use in power generation / cooling. For example, the water treatment plant 104 may operate to desalinate a water source and / or remove contaminants and / or unwanted materials from the water source. The water treatment plant 104 may route the produced high-quality water to the power plant system 102, which may use the water to produce power and / or high-quality steam byproducts. For example, the produced water may be used as a secondary coolant in one or more steam generators of the reactor. In some embodiments, the water treatment plant 104 may be omitted, and the power plant system 102 may utilize water from other sources to generate steam.

[0031] The brine treatment system 105 may be configured to receive brine and clean water from the water treatment system 104 and to treat the brine to generate chlorine (Cl2), hydrogen (H2), and sodium hydroxide (NaOH). In some embodiments, the brine treatment system 105 is configured to treat the brine using an electrolytic process, such as a chlor-alkali membrane process, to produce sodium hydroxide (NaOH) from a solution of sodium chloride (NaCl). In some embodiments, the brine treatment system 105 may be configured to remove impurities from the brine received from the water treatment system 104. For example, the brine may undergo precipitation and filtration to remove impurities.

[0032] The DAC plant 106 receives electricity and steam from the power plant system 102, air from the atmosphere, and carbon dioxide (CO2) from the water treatment system 104, and can use sodium hydroxide, electricity, and / or steam in a direct air capture (DAC) process to generate (e.g., sequester, separate, capture) carbon dioxide (CO2) from the air into a solution. The integrated energy system 100 may include one or more post-treatment plants (e.g., a sodium formate production system 108) arranged to receive the captured carbon dioxide (CO2) in solution from the DAC plant 106, generate (e.g., release) carbon dioxide (CO2) (e.g., in liquid, solid, and / or gaseous forms) from the captured carbon dioxide (CO2) in solution, and / or produce other useful chemicals. In some embodiments, during seawater pretreatment, dissolved carbon dioxide (CO2) in the seawater may be released by the water treatment plant 104 and transported to the DAC system 106. Any carbon dioxide (CO2) generated by the post-treatment plant (e.g., sodium formate production system 108) can be used to produce chemicals, bricks, plastics, bottles, etc., and / or stored (e.g., geologically). In some embodiments, the post-treatment plant may utilize steam and / or electricity from the power plant system 102. The DAC plant 106 can perform several different DAC processes and therefore can have different configurations.

[0033] In one embodiment, the DAC plant 106 can perform a liquid DAC process in which carbon dioxide (CO2) is removed by passing air containing carbon dioxide (CO2) through a liquid adsorbent chemical solution. In another embodiment, a solid DAC process can be performed in which carbon dioxide (CO2) is removed by passing air containing carbon dioxide (CO2) through a solid adsorbent chemical filter. Both the liquid and solid DAC processes depend on two steps: firstly, capturing air using an air contactor; and secondly, regenerating a liquid solvent (e.g., an alkaline aqueous solution) or a solid adsorbent (e.g., solid alkali carbonate, amine-functionalized material, metal-organic framework (MOF), zeolite, and / or similar) while generating the captured carbon dioxide (CO2) for subsequent sequestration or reuse to produce useful chemicals and / or materials. Specifically, in some embodiments, the DAC plant 106 uses sodium hydroxide as the liquid adsorbent for DAC. Thus, the captured carbon dioxide (CO2) in solution can include carbon dioxide (CO2) in solution with sodium hydroxide. In some embodiments, the DAC plant 106 and the post-treatment plant can be integrated into a single plant. Therefore, the DAC plant 106 and the post-processing plant may together be referred to as the “DAC plant,” the “DAC and post-processing plant,” and / or similar.

[0034] The sodium formate generation system 108 can generate sodium formate (HCOONa) by receiving a sodium carbonate (Na2CO3) solution from the DAC system 106 and electricity from the power plant system 102. The generation of sodium formate (HCOONa) from sodium carbonate (Na2CO3), including its chemical formula and description, is discussed in more detail below with respect to Figure 2.

[0035] In some embodiments, the power plant system 102 may supply steam, electricity, and water to the syngas generation system 110. The syngas generation system 110 may use a combination of steam and electricity to generate a specific resource (e.g., syngas). In such cases, the amounts of steam and electricity supplied to the syngas generation system 110 may be such that a specified generation level for the resource is achieved. For example, the amounts of electricity, steam, and water directed to the syngas generation system 110 may be the amounts necessary to generate a predetermined amount of resource such as syngas, which is then stored in the syngas storage 112. In some cases, the steam supplied by the power plant system 102 is condensed into liquid water during the resource generation process (e.g., a process such as the syngas generation process carried out by the syngas generation system 110) and then returned to the power plant system 102 (in some cases, via the water treatment plant 104).

[0036] In one embodiment, the syngas storage 112 may include one or more storage solutions (e.g., one or more containers). The storage solutions of the syngas storage 112 may be used to isolate syngas as needed (e.g., a large holding tank, a small portable tank, a mobile tank, etc.).

[0037] It should be noted that the power grid 114 may be equipped with a public or private power distribution system. For example, if the power plant system 102 generates excess electrical energy, the excess electricity may be distributed to the power grid 114 which is electrically connected to the power plant system 102.

[0038] For clarity, a certain number of components are shown in Figure 1. However, it is understood that embodiments of the present disclosure may include two or more of each component. In addition, some embodiments of the present disclosure may include fewer or more components than all of the components shown in Figure 1. Furthermore, the components in Figure 1 may communicate over any suitable communication medium (including the Internet) using any suitable communication protocol.

[0039] Figure 2 shows a flowchart of an example process related to a carbon dioxide (CO2) capture process 200 (hereinafter referred to as "carbon capture process 200") that results in the carbon-free production of sodium formate (HCOONa) and sodium acetate (CH3COONa). The order in which the operations or steps are described is not intended to be construed as limiting, and any number of the described operations or steps may be combined in any order and / or in parallel to perform the carbon capture process 200. In one embodiment, the carbon capture process 200 may include a small modular reactor (SMR) system 202 (hereinafter referred to as "SMR system 202"), a seawater desalination system 204, a chlor-alkali membrane process 206, a DAC process 208, a formic acid treatment process 210, an acetic acid (CH3COOH) treatment process, and a carbon dioxide (CO2) recapture and reuse process 214. In one embodiment, the SMR system 202 may comprise a modular multi-fuel plant energy system (e.g., a furnace system with 12 furnace systems, 6 furnace systems, 4 furnace systems, or any other number of furnaces). In one embodiment, the SMR system 202 depicted in Figure 2 may be the same as or similar to the power plant system 102 depicted in Figure 1. For example, in one embodiment, the SMR system 202 depicted in Figure 2 may be used to supply power and steam to a water treatment system 104, a brine treatment system 105, and a syngas generation system 106, as depicted in Figure 1. Similarly, in one embodiment, the power plant system 102 depicted in Figure 1 may be used to supply steam and electricity to a seawater desalination system 204, to electricity to a chlor-alkali process 206, and to power a DAC process 208, as depicted in Figure 2.

[0040] The carbon capture process 200 may include generating energy using the SMR system 202. In one embodiment, the SMR system 202 may include one or more modular pressurized water reactors (e.g., a multimodule power plant design). In one embodiment, the SMR system 202 may be dynamically controlled in real time to provide a stable and consistent energy source to the process and components as needed during the carbon capture process 200.

[0041] The carbon capture process 200 may include a seawater desalination system 204. In one embodiment, the seawater desalination system 204 may include treating seawater to produce potable drinking water and brine (e.g., a concentrated sodium chloride (NaCl) solution). In one embodiment, the seawater must be pretreated before desalination, which may result in the release of carbon dioxide (CO2). In these embodiments, the released carbon dioxide (CO2) may be routed to other steps of the carbon capture process 200 (e.g., to a DAC process 208, etc.). In embodiments, the seawater desalination system 204 may produce high-quality water for use in hospitals, homes, and industry.

[0042] The carbon capture process 200 may include a chlor-alkali membrane process 206. In one embodiment, the chlor-alkali membrane process 206 may include processing brine to generate sodium hydroxide (NaOH). In one embodiment, processing sodium chloride (NaCl) to produce sodium hydroxide (NaOH) may also produce hydrogen gas and nitrogen gas. In one embodiment, hydrogen gas and nitrogen gas may be used individually or combined for further industrial processing (e.g., production of ammonia (NH3), production of hydrochloric acid (HCl), desulfurization for production of sulfuric acid (H2SO4), production of urea (NH2CONH2), etc.). In embodiments, sodium hydroxide (NaOH) may be used as the capture solution in the carbon capture process 200.

[0043] The carbon capture process 200 may include a DAC process 208. In one embodiment, the DAC process 208 may include routing air (e.g., atmospheric air drawn in from a large fan, compressed air, carbon dioxide (CO2) released during seawater desalination pretreatment) to a contactor. In an embodiment, carbon dioxide (CO2) present in the air may interact with a capture solution (e.g., sodium hydroxide (NaOH)) to produce sodium carbonate (Na2CO3). In one embodiment, sodium carbonate (Na2CO3) is soluble and may remain with the capture solution, as represented by Formula 1 shown below. 2NaOH + CO2 → Na2CO3 + H2O (1) In the formula, 2NaOH represents 2 moles of sodium hydroxide (carbon dioxide capture solution), CO2 represents carbon dioxide in the air, Na2CO3 represents sodium carbonate produced when carbon dioxide molecules in the air combine with the sodium hydroxide capture solution, and H2O is produced along with sodium carbonate (Na2CO3) when carbon dioxide molecules in the air combine with the sodium hydroxide capture solution.

[0044] The carbon capture process 200 may include a formic acid treatment process 210. In one embodiment, the formic acid treatment process 210 may include adding formic acid (HCOOH) to the capture solution to produce sodium formate (HCOONa) and releasing the captured carbon dioxide (CO2) for future use, as represented by formulas (e.g., reaction formulas) 2 and 3 shown below. HCOOH + NaOH → HCOONa + H2O (2) 2HCOOH+Na2CO3→2HCOONa+H2O+CO2(3) In Equation 2, HCOOH is formic acid added to the carbon dioxide scavenging solution, NaOH is sodium hydroxide (carbon dioxide scavenging solution), HCOONa is sodium formate produced when formic acid (HCOOH) reacts with the sodium hydroxide carbon dioxide scavenging solution, and H2O is water produced together with sodium formate (HCOONa) when formic acid (HCOOH) reacts with the sodium hydroxide carbon dioxide scavenging solution. In Equation 3, HCOOH is formic acid added to the sodium carbonate solution produced directly through air scavenging, Na2CO3 is sodium carbonate produced directly through air scavenging, HCOONa is sodium formate produced when formic acid reacts with sodium carbonate (Na2CO3), H2O is water produced together with sodium formate (HCOONa) when formic acid reacts with sodium carbonate (Na2CO3), and CO2 is carbon dioxide produced together with sodium formate (HCOONa) and water when formic acid reacts with sodium carbonate (Na2CO3).

[0045] In one embodiment, HCOONa may be supplied to a first pyrolysis chamber, maintaining a constant temperature of 350°C in the first pyrolysis chamber using superheated steam from NuScale VOYGR SMR to maintain a constant and continuous decomposition of HCOONa. In such an embodiment, HCOONa may be continuously decomposed to sodium oxalate ((COO)2Na2), as shown in Formula 4 below, generating more hydrogen (H2). 2HCOONa → (COO)2Na2 + H2(4) In the formula, 2HCOONa is 2 moles of sodium formate added to the first pyrolysis chamber, (COO)2Na2 is sodium oxalate produced when sodium formate (HCOONa) is heated in the first pyrolysis chamber, and hydrogen (H2) is hydrogen gas produced together with sodium oxalate ((COO)2Na2) when sodium formate (HCOONa) is heated in the first pyrolysis chamber.

[0046] It should be noted that, as used herein and throughout this disclosure, "continuous" is intended to be interpreted as continuing without interruption for any desired length of time (e.g., one month, one year, ten years, one hundred years, etc.). According to some embodiments, methanol (CH3OH) production may be initiated and carried out continuously without interruption of the availability of any of the essential elements required to maintain methanol (CH3OH) production, or with interruptions to methanol (CH3OH) production (e.g., via selections received via user input to a control system used to control any apparatus related to methanol (CH3OH) production).

[0047] In one embodiment, sodium oxalate ((COO)2Na2) can be supplied directly from a first pyrolysis chamber to a second pyrolysis chamber. In such an embodiment, the second pyrolysis chamber can maintain a temperature of 800°C+ within the second pyrolysis chamber by utilizing superheated steam or compression heating from NuScale VOYGR SMR. In such an embodiment, sodium oxalate ((COO)2Na2) can be successively decomposed into sodium carbonate (Na2CO3) and carbon monoxide (CO), as shown in Formula 5 below. (COO)2Na2→Na2CO3+CO (5) In the formula, (COO)2Na2 is sodium oxalate added to the second pyrolysis chamber, Na2CO3 is sodium carbonate produced when sodium oxalate is heated in the second pyrolysis chamber, and CO is carbon monoxide produced together with sodium carbonate (Na2CO3) when sodium oxalate is heated in the second pyrolysis chamber.

[0048] In one embodiment, sodium carbonate (Na2CO3) can be hydrothermally (for example, continuously) decomposed into sodium oxide (Na2O) and carbon dioxide (CO2), as shown in Formula 6 below. Na2CO3 → Na2O + CO2(6) In the formula, Na2CO3 is sodium carbonate, which is injected into the second pyrolysis chamber; Na2O is sodium oxide, which is produced when sodium carbonate (Na2CO3) is hydrothermally decomposed in the second pyrolysis chamber; and CO2 is carbon dioxide, which is produced together with sodium oxide (Na2O) when sodium carbonate (Na2CO3) is hydrothermally decomposed in the second pyrolysis chamber.

[0049] In one embodiment, the formic acid treatment process 210 may include the continuous production of sodium formate (HCOONa) and the continuous decomposition of sodium formate (HCOONa), providing the continuous production of hydrogen (H2), carbon monoxide (CO), and carbon dioxide (CO2). In one embodiment, the continuous supply of hydrogen (H2), carbon monoxide (CO), and carbon dioxide (CO2) may be collected, directed to a synthesis chamber, and used to continuously produce methanol (CH3OH).

[0050] In one embodiment, the formic acid treatment process 210 may be used to release (regenerate) captured carbon dioxide (CO2) without requiring the high energy demands associated with the DAC process. In one embodiment, the released (regenerated) carbon dioxide (CO2) may be compressed, sequestrated, or reused to generate a useful material that can retain carbon molecules for many years.

[0051] In one embodiment, sodium formate (HCOONa) can be heated to below 290°C to produce hydrogen (H2) and sodium oxalate ((COO)2Na2). In another embodiment, the produced sodium oxalate ((COO)2Na2) can be heated to a temperature above 290°C to produce carbon monoxide (CO) gas and sodium carbonate (Na2CO3). In another embodiment, increasing the temperature of the produced sodium oxalate ((COO)2Na2) to above 750°C (for example, by using superheated steam for hydrothermal decomposition) may yield additional hydrogen (H2) and sodium carbonate (Na2CO3).

[0052] The carbon capture process 200 may include an acetic acid (CH3COOH) treatment process 212. In one embodiment, the acetic acid (CH3COOH) treatment process 212 may include adding acetic acid (CH3COOH) to the capture solution to produce sodium acetate (CH3COONa) and releasing the captured carbon dioxide (CO2) for future use, as represented by formulas (e.g., reaction formulas) 7 and 8 shown below. CH3COOH+NaOH→CH3COONa+H2O (7) 2CH3COOH+Na2CO3→2CH3COONa+H2O+CO2(8) In Equation 7, CH3COOH is acetic acid added to sodium carbonate (Na2CO3) for the acetic acid (CH3COOH) treatment process, NaOH is sodium hydroxide (carbon dioxide scavenging solution), CH3COONa is sodium acetate produced when acetic acid (CH3COOH) reacts with sodium hydroxide carbon dioxide scavenging solution, and H2O is water produced together with sodium acetate (CH3COONa) when acetic acid (CH3COOH) reacts with sodium hydroxide carbon dioxide scavenging solution. In Equation 8, CH3COOH is for the acetic acid (CH3COOH) treatment process The first is acetic acid added to sodium carbonate (Na2CO3), where Na2CO3 is sodium carbonate generated directly through air capture, CH3COONa is sodium acetate generated when acetic acid (CH3COOH) reacts with sodium carbonate (Na2CO3), H2O is water generated together with sodium acetate (CH3COONa) when acetic acid (CH3COOH) reacts with sodium carbonate (Na2CO3), and CO2 is carbon dioxide generated together with sodium acetate (CH3COONa) and water when acetic acid (CH3COOH) reacts with sodium carbonate (Na2CO3).

[0053] In Equation 8, carbon dioxide (CO2) may include captured carbon dioxide (CO2) that is released. In one embodiment, the acetic acid (CH3COOH) treatment process 212 may be used to release (regenerate) captured carbon dioxide (CO2) without requiring the high energy demands required for the DAC process. In one embodiment, the released (regenerated) carbon dioxide (CO2) may be compressed, sequestrated, or reused to generate a useful material that can retain carbon molecules for many years.

[0054] In one embodiment, sodium acetate (CH3COONa) can be heated to 330°C to 500°C to generate sodium formate (HCOONa), hydrogen (H2), carbon dioxide (CO2), and methane gas (CH4). In one embodiment, the generated methane (CH4) can be compressed and separated. In another embodiment, a steam-methane reforming process can be used to treat the generated methane (CH4) to produce carbon dioxide (CO2) and regenerate more hydrogen (H2).

[0055] In one embodiment, carbon dioxide (CO2) produced when sodium acetate (CH3COONa) is heated to 330°C to 500°C, and / or carbon dioxide (CO2) produced during the steam-methane reforming process, can be recaptured (e.g., routed to the DAC process 208).

[0056] The carbon capture process 200 may include a carbon dioxide (CO2) recapture and reuse process 214. In one embodiment, the carbon dioxide (CO2) recapture and reuse process 214 may include routing carbon dioxide (CO2) back through the carbon capture process 200 (e.g., routing carbon dioxide (CO2) to the DAC process 208). Note that the carbon dioxide (CO2) recapture and reuse process 214 is necessary to achieve carbon-free emissions.

[0057] Figure 3A is a schematic diagram of the production system 300A, in which the direct air capture (DAC) system 106 of Figure 1 is integrated with the sodium formate production system 108 of Figure 1 and configured to produce solid carbon dioxide (CO2) and liquid carbon dioxide (CO2) according to embodiments of the present technology. The DAC system 106 may include several features that are at least generally similar to, or identical in structure and function to, the corresponding features of the DAC plant 506 (described in detail below with reference to Figure 5) and / or as described in example process 800 (described in detail below with reference to Figure 8).

[0058] This application relates to U.S. Nonprovisional Patent Application No. 18 / 395,441, filed on 22 December 2023, titled "SMALL MODULAR NUCLEAR REACTOR INTEGRATED ENERGY SYSTEMS FOR CAPTURING ATMOSPHERIC CARBON DIOXIDE USING SODIUM HYDROXIDE," which is incorporated herein by reference.

[0059] In the illustrated embodiment, the generation system 300A further comprises a sodium carbonate reaction chamber 304 operably positioned between the air contactor 302 and the compressor 306. Each of the air contactor 302, the sodium carbonate reaction chamber 304, and the compressor 306 can be operated using electricity and / or steam generated by the power plant system 102 (Figure 1) and selectively routed to the DAC system 106, and / or via electric and / or steam inputs from other energy sources.

[0060] As described in detail above, the air contactor 302 can receive sodium hydroxide (NaOH) from the brine treatment system 105, use sodium hydroxide as a liquid adsorbent to capture carbon dioxide (CO2) from the air, and output an aqueous solution of sodium carbonate (Na2CO3) and sodium hydroxide (NaOH) according to formula (1) above. In the illustrated embodiment, the sodium carbonate reaction chamber 304 is arranged to receive formic acid (HCOOH) and aqueous solutions of sodium carbonate (Na2CO3) and sodium hydroxide (NaOH), and is configured to react the formic acid with the solution to produce (e.g., release, generate, regenerate) gaseous carbon dioxide (CO2) and sodium formate (HCOONa) according to the following formulas (9) and (10). HCOOH + NaOH → HCOONa + H2O (9) 2HCOOH+Na2CO3→2HCOONa+H2O+CO2(10) In formula 9, HCOOH is formic acid added to the carbon dioxide scavenging solution, NaOH is sodium hydroxide (carbon dioxide scavenging solution), HCOONa is sodium formate produced when formic acid reacts with sodium hydroxide carbon dioxide scavenging solution, and H2O is water produced together with sodium formate (HCOONa) when formic acid reacts with sodium hydroxide carbon dioxide scavenging solution. In formula 10, HCOOH is formic acid added to a sodium carbonate solution produced directly through air scavenging, Na2CO3 is sodium carbonate produced directly through air scavenging, HCOONa is sodium formate produced when formic acid reacts with sodium carbonate (Na2CO3), H2O is water produced together with sodium formate (HCOONa) when formic acid reacts with sodium carbonate (Na2CO3), and CO2 is carbon dioxide produced together with sodium formate (HCOONa) and water when formic acid reacts with sodium carbonate (Na2CO3).

[0061] The carbon dioxide (CO2) in the capture solution generated in the air contactor 302 can be released in gaseous form (e.g., regenerated) from the compressor 306 and routed to the compressor 306, which is configured to compress the carbon dioxide (CO2) into liquid, solid, and / or gaseous forms for storage (e.g., sequestration) and / or use in one or more industrial processes. The resulting sodium formate (HCOONa) can be routed to the syngas generation system 300B for use in producing hydrogen (H2), for example, in relation to methanol (CH3OH) production. In some aspects of this technology, carbon dioxide (CO2) can be released from the capture solution without the use of large amounts of energy typically required by conventional DAC processes.

[0062] Figure 3B schematically shows a typical syngas production system 300B for the production of methanol (CH3OH) using hydrogen (H2), carbon monoxide (CO), and carbon dioxide (CO2). The syngas production system 300B ("System 300B") may be used to receive sodium formate (HCOONa) 308. System 300B may comprise a first thermal reaction chamber 310 used to output hydrogen (H2) 312 and / or sodium oxalate ((COO)2Na2) 314. System 300B may comprise a second thermal reaction chamber 316 used to output sodium oxide (Na2O) 318 and / or a combination of carbon monoxide (CO) and carbon dioxide (CO2) 320. System 300B may comprise a synthesis chamber 322 configured as a methanol (CH3OH) production system. Although the synthesis chamber 322 is described as being configured to generate methanol (CH3OH) using syngas, it should be noted that the synthesis chamber 322 may be configured to generate any chemical substance used to generate syngas.

[0063] In one embodiment, sodium formate (HCOONa) 308 can be supplied to the first thermal reaction chamber 310 using an auger. Note that sodium formate (HCOONa) 308 can be supplied to the first thermal reaction chamber 310 using various methods, as depicted in Figure 3B as an auger and a rotating spiral, and described herein.

[0064] In various cases, a rotating spiral (e.g., a rotating spiral chamber within the first thermal reaction chamber 310) can be used to convert sodium formate (HCOONa) 308 between particles of different sizes. For example, a rotating spiral can be used to convert sodium formate (HCOONa) 308 from relatively coarser (e.g., larger) particles to relatively finer (e.g., smaller) particles. Rotation and spirals can be used to assist in the conversion between sodium formate (HCOONa) 308 and sodium oxalate ((COO)2Na2) 314. A rotating spiral can be used to maintain the temperature within the first reaction chamber 310. A rotating spiral (for example, a metallic rotating spiral that can be partially and / or completely located within the first thermal reaction chamber 310) can be operated by a control system that controls any part of the syngas generation system 300B and / or any part of the integrated energy system 100, and is used to rotate (e.g., spin) at one or more predetermined and / or dynamically (e.g., in real time) determined speeds during any operation of the syngas generation system 300B.

[0065] In various cases, a rotating spiral (e.g., another rotating spiral) can be used to convert sodium oxalate ((COO)2Na2)314 between particles of different sizes in a manner similar to that for sodium formate (HCOONa)308. For example, a rotating spiral can be used to convert sodium oxalate ((COO)2Na2)314 from relatively coarser particles to relatively finer particles. In some cases, a rotating spiral can be used to convert sodium oxalate ((COO)2Na2)314 to sodium oxide (Na2O)318. The rotating spiral can be used to maintain the temperature in the second reaction chamber 316. A rotating spiral (for example, another metallic rotating spiral which may be partially and / or completely located within the second thermal reaction chamber 316) can be operated by a control system which controls any part of the syngas generation system 300B and / or any part of the integrated energy system 100 and is used to rotate (e.g., spin) at one or more predetermined and / or dynamically (e.g., in real time) determined speeds during any operation of the syngas generation system 300B.

[0066] In various cases, a chemical can be transferred from the first reaction chamber 310 to the second reaction chamber 316 using a cylinder, pipe, conduit, and / or any other suitable structure (e.g., any chamber). The chamber can form an airtight seal between the second reaction chamber 316 and the first reaction chamber 310. A cylinder can separate the first reaction chamber 310 from the second reaction chamber 316. Sodium oxalate ((COO)2Na2)314 can be transported from the first reaction chamber 310 to the second reaction chamber 316 using a cylinder. In some cases, a cylinder can be used to transport sodium oxalate ((COO)2Na2)314 by preventing its exposure to air. A cylinder can provide an airtight seal between the first reaction chamber 310 and the second reaction chamber 316. The cylinder can be used to provide temperature control for the first reaction chamber 310 and the second reaction chamber 316, as well as physical separation between the first reaction chamber 310 and the second reaction chamber 316.

[0067] In one embodiment, the first reaction chamber utilizes process steam from a small modular reactor (SMR) system to maintain the temperature within the first thermal reaction chamber 310 in the range of 300°C to 350°C. In one embodiment, maintaining the temperature of the first thermal reaction chamber 310 in the range of 300°C to 350°C may result only in the production of hydrogen gas 312 and sodium oxalate ((COO)2Na2)314, as shown below by Equation 11. 2HCOONa→(COO)2Na2+H2, (11) In the formula, 2HCOONa is 2 moles of sodium formate introduced into the first reaction chamber, (COO)2Na2 is sodium oxalate produced by increasing the temperature of sodium formate (HCOONa), and H2 is hydrogen gas produced by increasing the temperature of sodium formate (HCOONa) together with sodium oxalate ((COO)2Na2).

[0068] In one embodiment, the first thermal reaction chamber 310 requires a continuous supply of thermal energy from an SMR system to maintain the temperature of the first thermal reaction chamber 310 in the range of 300°C to 350°C in order to maintain the decomposition of sodium formate (HCOONa) 308 into hydrogen gas (H2) 312 and sodium oxalate ((COO)2Na2) 314. In one embodiment, the thermal energy to sodium formate (HCOONa) 308 as a result of the temperature in the first thermal reaction chamber 310 allows the sodium formate (HCOONa) 308 powder to rapidly decompose into hydrogen gas 312 and sodium oxalate ((COO)2Na2) 314. In this embodiment, hydrogen (H2) 312 is produced instantaneously after the decomposition of sodium formate (HCOONa) 308. In this embodiment, the resulting sodium oxalate ((COO)2Na2) 314 settles at the bottom of the first thermal reaction chamber 310 while it is still thermally hot.

[0069] In one embodiment, sodium oxalate ((COO)2Na2)314 may be transferred to a second reaction chamber 316. In one embodiment, sodium oxalate ((COO)2Na2)314 may be supplied directly to the second reaction chamber 316 using an auger. Note that sodium oxalate ((COO)2Na2)314 may be supplied to the second reaction chamber 316 using a variety of methods, as depicted in Figure 3B as an auger and a rotating spiral and described herein.

[0070] In one embodiment, the second reaction chamber 316 is maintained at a temperature of at least 800°C by utilizing superheated steam and / or compression heating from the SMR system. In one embodiment, maintaining the temperature of the second reaction chamber 316 at at least 800°C sustains the hydrothermal decomposition process to sodium oxalate ((COO)2Na2)314, resulting in the rapid decomposition of sodium oxalate ((COO)2Na2)314 to sodium oxide (Na2O)318. In one embodiment, a combination of carbon monoxide (CO) and carbon dioxide (CO2) 320 may immediately follow the rapid decomposition of sodium oxalate ((COO)2Na2)314 to sodium oxide (Na2O)318.

[0071] While the use of two reaction chambers (e.g., the first thermal reaction chamber 310 and the second reaction chamber 316) is described in this example, it should be noted that a single reaction chamber could be used instead. In such a case, hydrogen (H2) would be produced alongside carbon dioxide (CO2) and carbon monoxide (CO). However, the hydrogen (H2) in this example could not be easily separated from the other gases. Therefore, in a system utilizing a single reaction chamber, it may be difficult to control the composition of the resulting syngas. Thus, the use of two reaction chambers is necessary to produce hydrogen (H2) separated from the other gases, allowing control over the amount of hydrogen (H2) introduced into the synthesis chamber 322, and thus providing greater control over which syngas are produced.

[0072] In one embodiment, hydrogen (H2) 312 and a combination of carbon monoxide (CO) and carbon dioxide (CO2) 320 can be directly introduced into a synthesis chamber 322 used to generate methanol (CH3OH). In one embodiment, system 300B can be run continuously and carried out entirely in the location of the SMR system.

[0073] It should be noted that an SMR system, including all support systems operably connected to the SMR system (e.g., an electrogenerating system, a steam transfer system, an energy integration system, a water treatment system, a chemical generation system, a DAC system, a gasification system, a syngas generation system, etc.), can be physically located in a single location with a threshold boundary. In one embodiment, each system and / or support system may be located less than the threshold distance of the SMR system (e.g., approximately 1 km). Each support system may be a permanently mobile or partially mobile system assembled in or near the SMR (e.g., within approximately 1 km). In one embodiment, each system and support system may be assembled and / or constructed within the threshold radius of the center of the SMR system's location.

[0074] In some examples, aspects of this technology may generally be directed towards IESs (Environmental Energy Uses) and related devices and methods, such as for use in green industrial processes that produce little to no carbon emissions. Industrial processes may include, for example, carbon dioxide (CO2) generation.

[0075] This technology addresses a far cleaner and more efficient approach to producing hydrogen (H2) and carbon dioxide (CO2) that can be used in industrial chemical production using conventional technologies. The methodology of this disclosure includes a multimodule power plant for generating electricity and steam, which is then connected to a high-temperature steam electrolysis (HTSE) cell for hydrogen (H2) production and simultaneously provides the energy necessary to generate carbon dioxide gas. In typical embodiments, there are two methods that can be used for generating carbon dioxide (CO2): 1) via a direct air capture (DAC) system, or 2) via a dual gasifier in a two-stage pressure gasification process using the recycling of large amounts of plastic waste.

[0076] It should be noted that, as used herein and throughout this disclosure, the term "large quantities of plastic waste" is intended to be interpreted as any type of plastic available for processing (e.g., polyethylene terephthalate, high-density polyethylene, polyvinyl chloride, low-density polyethylene, polypropylene, etc.).

[0077] Currently, the primary method for producing hydrogen (H2) and carbon dioxide (CO2) for chemical products is the steam-methane reforming process, which uses natural gas containing methane (CH4) both as a raw material and as a combustion fuel for process heating. Unfortunately, this process results in significant carbon dioxide (CO2) generation and emissions.

[0078] In contrast to existing systems that require the long-distance transport of resources (e.g., steam), the DAC process using this technology can be extremely useful because processing facilities can be safely located adjacent to or near industrial parks, fossil fuel plants, and oil or chemical operations. A large amount of energy is required to capture one ton of carbon dioxide (CO2) from the air. A very large amount of electricity is required (for example, 8.81 GJ = 2.45 MWh is often required to capture one ton of carbon dioxide (CO2). According to conventional technology, the amount of energy required to capture one ton of carbon dioxide (CO2) may be 8.81 GJ of natural gas, or a combination of 5.25 GJ of natural gas and 366 kWh of electricity).

[0079] In contrast to conventional technologies, System 300B can be used to capture carbon dioxide (CO2) without any natural gas input. For example, System 300B can utilize a DAC process to capture carbon dioxide (CO2) by drawing in atmospheric air, and then, through a series of chemical reactions, extract the carbon dioxide (CO2) using vapor from an SMR system, while the remaining air can be returned to the atmosphere. The DAC process can be initiated in a large-scale air contactor structure modeled after an industrial cooling tower. A large fan can draw air into this structure, where the air passes over a thin structural surface through which a sodium hydroxide (NaOH) solution flows. The sodium hydroxide (NaOH) solution chemically binds with carbon dioxide (CO2) molecules, thereby removing the carbon dioxide (CO2) molecules from the air and trapping them in the liquid solution as carbonates.

[0080] In some examples, an air contactor can initiate the DAC process by drawing air from the atmosphere into the air contactor, where the air may pass over a structural surface over which a sodium hydroxide (NaOH) solution and a carbon dioxide capture solution flow. Carbon dioxide (CO2) molecules chemically react with sodium hydroxide (NaOH) to produce sodium carbonate (Na2CO3) and water, as represented by Equation 1, as discussed above with reference to Figure 2, and reproduced below. 2NaOH + CO2 → Na2CO3 + H2O, (1) In the formula, 2NaOH represents 2 moles of sodium hydroxide (carbon dioxide capture solution), CO2 represents carbon dioxide in the air, Na2CO3 represents sodium carbonate produced when carbon dioxide molecules in the air react with the sodium hydroxide capture solution, and H2O is produced along with sodium carbonate (Na2CO3) when carbon dioxide molecules in the air react with the sodium hydroxide capture solution.

[0081] Next, the carbon dioxide (CO2) contained in this carbonate solution (e.g., Na2CO3) can be increased in concentration through a series of chemical processes, purified, and compressed, so that it can be delivered in a gaseous form ready for use in the production of "green" ammonia (NH3) or methanol (CH3OH) via hydrogenation. As used herein, a "green" chemical is a chemical produced in an industrial process that produces little to no carbon emissions when the chemical is produced.

[0082] Two-stage pressure gasification systems can be used to recycle plastic and biomass waste into syngas, primarily hydrogen (H2) and carbon dioxide (CO2). This process can be carried out in a two-stage gasification system including a low-temperature gasifier and a high-temperature gasifier, both operating under pressure. As used herein, the gasifier is a large cylindrical pressure vessel configured to receive solid carbonaceous material (e.g., plastic waste, biomass, coal, etc.) at the top and a mixture of steam and oxygen (O2) at the bottom. The mixture of oxygen (O2) and steam may vary depending on the material added, as well as the pressure and temperature requirements. The mixture of steam and oxygen (O2) increases the temperature and pressure within the gasifier, causing the material to chemically react to produce non-combustible solid waste and a mixed gas. The resulting mixed gas can be collected or redirected to another system for additional processing, including the removal of unwanted contaminants and / or trace contaminants, or it can be collected or redirected to a second gasifier for the second stage of the two-stage process. In existing systems, oxygen (O2) and steam can be used for the thermal decomposition and partial oxidation of waste plastics that do not require segregation or separation. In existing systems, inorganic materials and metals within plastic waste may be recovered as granular slag for use as raw materials in cement and other building materials, while recovered metal scrap that can be reused in existing systems may be produced.

[0083] Plastic waste, crushers, molding machines, molded plastics, dual gasification processing systems (e.g., systems utilizing two gasification units), scrubbers, and syngas by-products can be used for syngas production. Plastic waste can be processed in a crusher to physically break it down into more uniform fragments. The uniform fragments of the waste plastic leave the crusher and enter a molding machine where they can be molded into molded plastics. The molded plastics may have more specific shapes that may be required for further processing and can be fed into a dual gasification processing system.

[0084] A dual gasification treatment system may comprise a low-temperature gasifier and a high-temperature gasifier. The two gasifiers may have operating temperatures ranging from 600°C to 800°C and may require a significant energy supply. The dual gasification treatment system may produce a mixed gas and wastewater. The mixed gas can be treated through a scrubber to separate undesirable particles from it. The scrubber may produce useful syngas (e.g., hydrogen (H2), carbon monoxide (CO), carbon dioxide (CO2), etc.).

[0085] The dual gasification process may include a small modular furnace plant system, waste plastics, a cryogenic gasifier, a high-temperature gasifier, granular slag, the resulting gas, clean water, and the product gas. Waste plastics may be fed into the cryogenic gasifier. Although described as a cryogenic gasifier, it is understood that the operating temperature may be 600°C to 800°C.

[0086] It should be noted that syngas production methods utilizing methane (CH4) and carbon dioxide (CO2) require a consistent temperature of >700°C, which necessitates a large amount of energy. In contrast to systems for syngas production that require large amounts of energy to provide appropriate temperature and pressure, syngas production techniques according to the methods discussed herein, when connected to an SMR system as described herein, are not hindered by energy limitations and can utilize the continuous amounts of steam and electricity necessary for continuous syngas production.

[0087] In one embodiment, the SMR system may comprise a multi-module system. Each module may operate independently to generate electricity or steam. In such an embodiment, multiple modules may be dedicated to generating steam when high-temperature steam is required, and the high-temperature steam may be continuously supplied for use. The systems and / or modules within system 300B may each be located less than a threshold distance (e.g., approximately 1 km) from one another.

[0088] It should be noted that existing syngas production methods require multiple physically separate systems to produce the various gases necessary for chemical production, including ammonia (NH3) and methanol (CH3OH). Existing systems often require resources (e.g., oxygen (O2)) to be transported over long distances for syngas production. In contrast to existing systems, System 300B, with a two-stage gasifier operated by the technique discussed, can utilize the vapor output from a site-mounted SMR system to produce oxygen (O2), which can then be used in the dual gasifier to produce syngas. System 300B can be used for the continuous production of hydrogen (H2), carbon monoxide (CO), and carbon dioxide (CO2) in the same system, which also enables the continuous production of methanol (CH3OH).

[0089] Figure 4 schematically shows a generation system 400 that generates syngas using a reactor system. For example, the reactor system may include a small modular reactor (SMR) system.

[0090] The generation system 400 may utilize the syngas generation system 300B and may comprise a multimodule power plant 402, a water treatment plant 404, a steam supply unit 406, a high-temperature electrolytic cell 408, syngas 410, and a pressure swing adsorption (PSA) system 312. In some examples, the multimodule power plant 402 may be used to run the power plant system 102, as discussed above with reference to Figure 1.

[0091] The multimodule power plant 402, water treatment plant 404, steam supply unit 406, high-temperature electrolytic cell 408, syngas 410, and / or PSA system 412 may be operably coupled to any number of others. Alternatively or additionally, the multimodule power plant 402, water treatment plant 404, steam supply unit 406, high-temperature electrolytic cell 408, syngas 410, and / or pressure swing adsorption (PSA) system 412 may be operably coupled to a syngas generating system such as syngas generating system 300B, as discussed above with reference to Figure 3B. Syngas may be produced using generating system 400 with syngas generating system 300B, but generating system 400 may utilize an alternative syngas generating system in addition to or instead of syngas generating system 300B.

[0092] In one embodiment, the multimodule power plant 402 may supply electricity to the water treatment plant 404, the steam supply device 406, the high-temperature electrolytic cell 408, the syngas generation system 300B, and the PSA system 412. In one embodiment, the water treatment plant 404 may supply water to the steam supply device 406. In one embodiment, the steam generator may supply steam to the high-temperature electrolytic cell 408 and the syngas generation system 300B.

[0093] In one embodiment, a high-temperature electrolytic cell (or "electrolytic cell") 408 can use electricity to convert vapor into hydrogen and oxygen gases. For example, the electrolytic cell 408 may comprise a polymer electrolyte membrane (PEM) electrolytic cell and / or one or more other types of electrolytic cells. The electrolytic cell 408 can receive vapor at any temperature that allows for the conversion of vapor into hydrogen and oxygen gases. The electrolytic cell 408 can represent any type of cell configured to use electricity to separate any form of water (e.g., vapor) into hydrogen and oxygen gases. In various cases, the electrolytic cell 408 may comprise an anode and a cathode separated by an electrolyte.

[0094] In various cases, the vapor may react at the anode to form oxygen (O2) (e.g., oxygen gas) and positively charged hydrogen ions (e.g., protons). Electrons may flow through the external circuit, and hydrogen ions may selectively move across the electrolytic cell 408 to the cathode. At the cathode, hydrogen ions may combine with electrons from the external circuit to form hydrogen gas (e.g., via the anodic reaction: 2H2O → O2 + 4H2O). + +4e - In the formula, 2H2O is two molecules of water, O2 is oxygen gas, and 4H + It consists of four hydrogen ions, and 4e - It has 4 electrons; and cathode reaction: 4H + +4e - →2H2, in the formula, 4H + It consists of four hydrogen ions, and 4e - (where is 4 electrons, and 2H2 is 2 moles of hydrogen gas). The hydrogen gas can be utilized, supplied, and / or output by the generation system 400.

[0095] In one embodiment, the multimodule power plant 402 can be used to produce various products (e.g., syngas, methanol (CH3OH), sodium hydroxide (NaOH), sodium formate (HCOONa), etc.) by utilizing various methods (e.g., a two-stage gasification system for syngas production utilizing continuous sodium formate decomposition and / or for decomposing large amounts of plastic waste).

[0096] For example, syngas production utilizing continuous sodium formate (HCOONa) decomposition can be used when the multimodule power plant 402 is operably connected to the PSA system 412, enabling electricity to be supplied by the multimodule power plant 402 and to the PSA system 412. A syngas production system 300B operably connected to the PSA system 412 can enable syngas 410 to be supplied by the syngas production system 300B and to the PSA system 412. For example, syngas 410 may include one or more combinations of carbon monoxide (CO), carbon dioxide (CO2), and hydrogen (H2).

[0097] For example, syngas generation utilizing a two-stage gasification process for a large-scale plastic waste system may be utilized with a multimodule power plant 402 operably connected to a PSA system 412, allowing electricity to be supplied by the multimodule power plant 402 and to the PSA system 412. Additionally, the multimodule power plant 402 may provide the steam required for each stage of gasification, while the high-temperature electrolytic cell 408 may provide the necessary oxygen (O2) required to be combined with the steam for gasification in each gasifier. The two-stage gasification process for a large-scale plastic waste system operably connected to the PSA system 412 may allow syngas 410 to be supplied by the two-stage gasification process for a large-scale plastic waste system and to the PSA system 412. For example, syngas 410 may include a combination of one or more of carbon monoxide (CO), carbon dioxide (CO2), and hydrogen (H2).

[0098] It should be noted that the multimodule power plant 402 can simultaneously generate syngas using one or more modules, utilizing both the syngas generation system 300B and the two-stage gasification system. For example, in a multimodule power plant configuration with six modules, one module may be offline for refueling, while three modules may be dedicated to providing the appropriate electricity and steam demand requirements to operate the two-stage gasification process, while the remaining two modules provide the electricity and steam demand requirements to operate the syngas generation system 300B.

[0099] The multimodule power plant 402 can generate syngas using one or more systems, and it should be noted that one or more modules of the multimodule power plant 402 can generate sodium formate (HCOONa) used by the syngas generation system 300B by utilizing a seawater desalination system, a chlor-alkali membrane process, a DAC system, and a formic acid treatment process. For example, one or more modules can supply steam and electricity to the seawater desalination system 204 to generate sodium chloride (NaCl), and then use the chlor-alkali membrane process 206 to generate sodium hydroxide (NaOH). Then, sodium hydroxide (NaOH) can be used in the DAC process to generate sodium carbonate (Na2CO3), which can be treated with formic acid to generate sodium formate (HCOONa) 308, which is used to generate syngas via the syngas generation system 300B.

[0100] In various examples, the PSA system 412 can be used to separate syngas into one or more gases (e.g., one or more designated and / or predetermined gases) and / or one or more other gases (e.g., one or more unwanted off-gases). The designated gases obtained by the PSA system 412 may include, for example, hydrogen (H2), carbon monoxide (CO), and carbon dioxide (CO2). The unwanted off-gases generated by the PSA system 412 may be recycled and reinputted back into the PSA system 412. The unwanted off-gases may include, for example, one or more of various types of gases other than hydrogen (H2), carbon monoxide (CO), and carbon dioxide (CO2). For example, by recycling the gases, the generating system 400 can operate as a closed-loop system with zero emissions. Using the generating system 400, which is a non-emission system, methanol (CH3OH) can be produced and / or output without any natural gas input. In contrast to providers of existing systems that must purchase and / or acquire natural gas for methanol (CH3OH) generation, providers of the generation system 400 can utilize the generation system 400 to generate methanol (CH3OH) without any expenditure / cost associated with the supply of natural gas. Various parts of the multimodule power plant 402 can be used to supply steam to various parts of the generation system 300, such as the steam supply unit 406. Individual modules of the multimodule power plant 402 (e.g., individual SMRs) can be controlled separately. For example, the control of the multimodule power plant 402 may include the control of individual SMRs to output steam, electricity, or a combination thereof. Individual SMRs can be controlled to output steam at a desired steam generation rate. For example, an SMR may utilize a turbine bypass so that steam bypasses the SMR's turbine and is sent directly to the steam supply unit 406. By utilizing the turbine bypass, the SMR can be used to supply steam to the steam supply unit 406, which can then supply steam to the high-temperature electrolytic cell 408 and / or the syngas generation system 300B.For example, by utilizing the turbine bypass, the SMR can supply steam to the syngas generation system 300B via the steam supply device 406 at a temperature that enables continuous syngas generation by the syngas generation system 300B.

[0101] In this hypothetical example, the multimodule power plant 402 may include one or more power modules dedicated to steam generation and / or one or more modules dedicated to electricity generation. Each module originally dedicated to steam generation may be configured to generate electricity when steam demand decreases and electricity demand increases. It is expected that the change in the form of energy generation for each power module can be rapidly modified in real time to dynamically respond to energy demand depending on system conditions or requirements.

[0102] For example, the multimodule power plant 402 may supply electricity and steam to the water treatment plant 404 to produce water that can be used by the generation system 400. The water treatment plant 404 may be a desalination plant or other water treatment facility. The water treatment plant 404 may then supply water to the steam supply unit 406 to produce process steam. The steam supply unit 406 may supply steam to one or more syngas generation systems. One or more syngas generation systems may operate simultaneously, and the syngas generation systems do not have to be of the same type. For example, one or more gasification systems may operate while one or more generation systems 300B are operating.

[0103] In one embodiment utilizing a two-stage gasification system, a steam supply unit 406 may supply steam to a high-temperature electrolytic cell 408, while a multi-module power plant 402 may supply electricity to the high-temperature electrolytic cell 408, which may produce hydrogen gas and oxygen gas. The oxygen gas, along with process steam, may be supplied directly to the first gasifier in the two-stage gasification process. The gas produced in the first gasifier may be supplied to a second gasifier to initiate the second stage of the gasification process. The second gasifier may receive oxygen (O2) from the high-temperature electrolytic cell 408 and additional process steam. Note that the process steam entering the second gasifier is at a higher temperature than the steam used in the first gasifier. The second gasifier may produce syngas 410, which can be recovered and redirected to a pressure swing adsorption system 412. The pressure swing adsorption system 412 may be used to separate gas species from a mixture of gases based on their characteristics and affinity for various absorbent materials.

[0104] In this hypothetical example, a multimodule power plant 402 may utilize a chemical production system to produce sodium formate (HCOONa) 308. It should be noted that the production of sodium formate (HCOONa) 308 may be continuous as desired. Sodium formate (HCOONa) 308 may be supplied to a rotating auger capable of supplying a controlled amount to the top of a first reaction chamber. The first reaction chamber may receive superheated process steam from the multimodule power plant 402 to maintain the temperature in the first thermal reaction chamber 310 in the range of 300°C to 350°C. The temperature of the first thermal reaction chamber 310 may cause a thermal shock to the sodium formate (HCOONa) 308, which may cause its instantaneous decomposition to sodium oxalate ((COO)2Na2) 318. The decomposition may also generate hydrogen gas 312.

[0105] The newly formed sodium oxalate ((COO)2Na2) can settle into a second auger at the bottom of the first thermal reaction chamber 310 and be directly supplied to the top of the second reaction chamber 320. The second auger can provide a consistent supply of sodium oxalate ((COO)2Na2) to the second reaction chamber, which receives superheated process steam (i.e., hydrothermal decomposition) from the multimodule power plant 402 to maintain a temperature of >800°C. Maintaining the temperature of the second reaction chamber 320 at a temperature of at least 800°C causes a thermal shock to the sodium oxalate ((COO)2Na2) 318, resulting in its rapid decomposition into sodium oxide (Na2O) 322. The decomposition of sodium oxalate 314 also produces a combination of carbon monoxide (CO) and carbon dioxide (CO2) 320. It should be noted that the ability to generate superheated steam over extended periods is essential for the production of carbon monoxide (CO) and carbon dioxide (CO2) combination 320.

[0106] The hydrogen (H2) 316 produced in the first thermal reaction chamber 310 can be collected and combined with a combination of carbon monoxide (CO) and carbon dioxide (CO2) 324 produced in the second reaction chamber 320 inside the synthesis chamber 322 for producing methanol (CH3OH) via the hydrogenation of carbon dioxide (CO2). The synthesis chamber 322 can also receive vapor to maintain a temperature range including 200°C to 300°C. For example, 1 mole of carbon dioxide (CO2) can react with 3 moles of hydrogen (H2) to produce 1 mole of methanol (CH3OH) and 1 mole of water.

[0107] However, the hydrogenation of carbon dioxide (CO2) to produce methanol (CH3OH) requires a catalyst to induce catalytic activity for methanol (CH3OH) production, such as a copper and / or zinc oxide-based catalyst. While these catalysts are necessary to initiate the required reaction, the formation of water molecules can deactivate the catalyst, which stops methanol (CH3OH) production and necessitates restarting the process.

[0108] Since water molecules are produced when carbon dioxide molecules react with hydrogen (H2) (for example, 1 mole of carbon dioxide (CO2) can react with 3 moles of hydrogen (H2) to produce 1 mole of methanol (CH3OH) and 1 mole of water), water molecules are formed without additional intervention, and the catalyst is deactivated very quickly. Carbon monoxide (CO) is essential because water molecules can be produced. Carbon monoxide (CO) reacts with water to produce carbon dioxide (CO2) and hydrogen gas (for example, the water-gas shift reaction in which 1 mole of carbon monoxide (CO) reacts with 1 mole of water to produce 1 mole of carbon dioxide (CO2) and 1 mole of hydrogen (H2)). Once the water molecules are converted to hydrogen (H2) and carbon dioxide (CO2), the production of methanol (CH3OH) continues. Although methanol (CH3OH) can be produced through the interaction of carbon dioxide (CO2) and hydrogen (H2), carbon monoxide (CO) is essential for its reaction with water molecules to prevent the deactivation of the catalyst. After the water-gas shift reaction, 1 mole of carbon dioxide (CO2) can react with 2 moles of hydrogen (H2) to produce 1 mole of methanol (CH3OH).

[0109] Carbon monoxide (CO) is essential for the production of methanol (CH3OH), and since methanol (CH3OH) is a valuable chemical, carbon monoxide (CO) is expensive, which can make methanol (CH3OH) production prohibitively costly. Since the multimodule power plant 402 can continuously produce hydrogen (H2), carbon dioxide (CO2), and carbon monoxide (CO) on-site, the methods utilizing the technologies discussed herein do not suffer from the same constraints. It should be noted that the cost of the chemicals produced includes more than just the purchase price. For example, purchasing chemicals requires the delivery of the chemicals, which reduces the possibility of mobile or partially mobile production sites. Additionally, transport vehicles delivering the chemicals may burn fuel, which also generates unwanted emissions.

[0110] Figure 5 schematically shows an example system 500 for capturing carbon dioxide (CO2) from the air using a reactor system and a direct air capture (DAC) process.

[0111] System 500, for example, a DAC system, may comprise a multimodule power plant 502, a water treatment plant 504, and a DAC plant 506 configured to produce carbon dioxide (CO2) 508. In one embodiment, the multimodule power plant 502 may provide electrical and thermal energy to the water treatment plant 504 and the DAC plant 506. In one embodiment, the water treatment plant 504 may supply high-quality water to the DAC plant 506. In one embodiment, the DAC plant 506 may produce carbon dioxide (CO2) 508 using energy from the multimodule power plant 502 and high-quality water from the water treatment plant 504. In various examples, the multimodule power plant 502, the water treatment plant 504, and the DAC plant 506 may be used to run a power plant system 102, a water treatment system 104, and a DAC system 106, as discussed above with reference to Figure 1.

[0112] In contrast to conventional systems, DAC systems (including systems powered by natural gas and / or fossil fuel consumption, systems that generate harmful emissions, and / or systems that obtain necessary elements through processes that generate harmful emissions) can provide a more efficient and environmentally responsible direct air capture system when integrated into a power plant system (e.g., power plant system 102) utilizing a multimodule power plant (e.g., multimodule power plant 502) by the techniques discussed herein. For example, system 500 may capture carbon dioxide (CO2) from the air using DAC 506. Conventional technologies capture and / or generate carbon dioxide (CO2) by utilizing components configured to process various chemicals (e.g., sodium carbonate (Na2CO3), sodium hydroxide (NaOH), calcium hydroxide (Ca(OH)2), calcium carbonate (CaCO3), and calcium oxide (CaO)) that cannot efficiently, cost-effectively, safely, and cleanly produce carbon dioxide (CO2). However, a DAC plant 506 located at or near the multimodule power plant 502 can be used to generate carbon dioxide (CO2) 508 without requiring a natural gas input or an output of environmentally harmful emissions.

[0113] Atmospheric carbon dioxide (CO2) concentrations are rising globally as a result of the continued use of carbon-rich fossil fuels such as coal, oil, and natural gas (methane (CH4)). Carbon dioxide (CO2) is a greenhouse gas that absorbs and radiates heat. The more carbon dioxide (CO2) there is in the atmosphere, the more heat can be radiated back from the Earth to the Earth's surface, which contributes to the rise in global temperature. High concentrations of carbon dioxide (CO2) in the atmosphere also contribute to ocean acidification; carbon dioxide (CO2) reacts with seawater molecules to produce carbonic acid. Increased carbonic acid production lowers the pH of the ocean, increasing its acidity. Known carbon dioxide capture processes may help mitigate the increase in carbon dioxide (CO2) concentrations, but the significant energy demand required to power these processes results in the production of more carbon dioxide (CO2) than is captured. Therefore, new carbon dioxide capture processes are needed; processes that produce little to no carbon dioxide (CO2) emissions.

[0114] In a hypothetical example, using conventional technology for long-term direct air capture requires a large amount of energy and therefore cost. In contrast to conventional systems, which are expensive and not environmentally safe, the system according to the present invention can be used to provide carbon dioxide (CO2) through direct air capture with lower costs and higher levels of efficiency. In contrast to conventional technology, which requires a large amount of energy to power the large fans used to draw air into the carbon dioxide (CO2) absorber, the system according to the present invention utilizes SMR modules to generate the energy necessary to maintain long-term direct air capture. It should be noted that the concentration of carbon dioxide (CO2) in the atmosphere is not high, which means that a large amount of energy is required because the system must operate for a long time to capture a large amount of carbon dioxide (CO2) from the atmosphere. The more energy used to capture carbon dioxide (CO2) from the air (e.g., 1 ton or any other amount of carbon dioxide (CO2)), the higher the cost and the greater the environmental impact. However, when the DAC system is connected to a multimodule power plant (e.g., multimodule power plant 502 depicted in Figure 5), the DAC system (e.g., DAC plant 506) can run continuously without being constrained by energy limitations. Since the multimodule power plant 502 can provide continuous steam and / or electrical energy as needed while producing zero or negative carbon emissions, the DAC plant 506 can be operated continuously.

[0115] Figure 6 shows a flowchart illustrating an example process 600 for utilizing an integrated small modular reactor (SMR) system to continuously and simultaneously generate hydrogen (H2), carbon monoxide (CO), and carbon dioxide (CO2) for methanol (CH3OH) production. The order in which the operations or steps are described is not intended to be construed as limiting, and any number of the described operations can be combined in any order and / or in parallel to operate the integrated SMR system (e.g., the production system 300 discussed above with reference to Figure 3).

[0116] In step 602, process 600 may include, if necessary, the use of a small modular reactor power plant system to generate processing steam and electricity for the integrated SMR system. For example, the seawater desalination system 204, the chlor-alkali membrane process 206, and the DAC process 206 utilize the electricity generated by the SMR system to produce sodium carbonate (Na2CO3), which is then processed to produce sodium formate (HCOONa) 308, which is used in the syngas production system 300B.

[0117] In step 604, process 600 may include receiving process steam and electricity in a syngas generation system operably connected to a small modular reactor power plant system. For example, syngas generation system 300B receives both electrical energy and process steam and converts sodium formate (HCOONa) into syngas for methanol (CH3OH) generation utilizing a methanol (CH3OH) generation system. Syngas generation system 300B uses electricity to supply energy to electrical components and process steam to generate the high temperatures required for chemical decomposition.

[0118] In step 606, process 600 may include receiving sodium formate (HCOONa) in a first reaction chamber of a chemical polymer generation system and using process vapor and electricity to decompose the sodium formate (HCOONa) into sodium oxalate ((COO)2Na2) and hydrogen (H2) (one of the three elements required for methanol (CH3OH) production). For example, syngas generation system 300B uses electricity to supply energy to an auger that feeds sodium formate (HCOONa) 308 into a first thermal reaction chamber 310. The first thermal reaction chamber 310 receives process vapor from the SMR system to heat the sodium formate (HCOONa) 308, causing its decomposition into sodium oxalate ((COO)2Na2) 314 and hydrogen (H2) 312. The hydrogen (H2) 312 can then be used for methanol (CH3OH) production.

[0119] In step 608, process 600 receives sodium oxalate ((COO)2Na2) in a second reaction chamber of the chemical polymer generation system and uses superheated steam to hydrothermally decompose the sodium oxalate ((COO)2Na2) into sodium oxide (Na2O) and a combination of carbon monoxide (CO) and carbon dioxide (CO2), two of the three elements necessary for methanol (CH3OH) production. For example, syngas generation system 300B uses electricity to supply energy to an auger that delivers sodium oxalate ((COO)2Na2) 314 to a second reaction chamber 316. The second reaction chamber 316 receives superheated steam from the SMR system and hydrothermally decomposes the sodium oxalate ((COO)2Na2) 314, causing its decomposition into sodium oxide (Na2O) 212 and a combination of carbon monoxide (CO) and carbon dioxide (CO2) 324. Next, the combination of carbon monoxide (CO) and carbon dioxide (CO2) 324 can be used to produce methanol (CH3OH).

[0120] Figure 7 shows a flowchart of process 700, an example related to the production of syngas by processing a large volume of plastic waste using a two-stage pressure gasification system. The order in which the operations or steps are described is not intended to be construed as limiting, and any number of the described operations may be combined in any order and / or in parallel to operate the two-stage pressure gasification system. It should be noted that, as used herein and throughout this disclosure, the term "large volume of plastic waste" is intended to be interpreted as any type of plastic available for processing (e.g., polyethylene terephthalate, high-density polyethylene, polyvinyl chloride, low-density polyethylene, polypropylene, etc.). It should also be noted that a large volume of plastic waste may be one or more types of plastic waste that do not need to be sorted or separated for processing. The large volume of plastic waste may be processed before being fed into the first of two gasification units (e.g., an embodiment of production system 400 that produces syngas using a two-stage pressure gasification system, as discussed above with reference to Figure 4). For example, the large volume of plastic waste may be crushed and molded into uniform fragments of molded plastic.

[0121] In step 702, process 700 may include a multimodule power plant, a reverse osmosis (RO) water treatment plant, a steam generator, a high-temperature electrolytic cell, a two-stage pressure gasification system, and a pressure swing adsorption (PSA) system. In one embodiment, the multimodule power plant, reverse osmosis (RO) water treatment plant, steam generator, high-temperature electrolytic cell, two-stage pressure gasification system, and pressure swing adsorption (PSA) system may be the same as or similar to the multimodule power plant 402, reverse osmosis (RO) water treatment plant 404, steam supply unit 406, high-temperature electrolytic cell 408, two-stage pressure gasification system, and pressure swing adsorption (PSA) system 412 as depicted in Figure 4. A small modular reactor (SMR) system may provide suitable electricity and steam for use in the two-stage pressure gasification system. For example, a dual gasification system may utilize electricity to supply energy to the components necessary to carry out the operation of the dual gasification system, including a low-temperature gasifier, a high-temperature gasifier, and a gas purification unit. The low-temperature and high-temperature gasifiers utilize process steam provided by the SMR system to maintain the required temperature in each gasifier.

[0122] In step 704, process 700 may include a multimodule power plant, a steam generator, a cryogenic gasifier, a high-temperature electrolytic cell, and oxygen gas. In one embodiment, the multimodule power plant, steam generator, and high-temperature electrolytic cell may be the same as or similar to the multimodule power plant 402, steam supply unit 406, and high-temperature electrolytic cell 408 depicted in Figure 4. The oxygen (O2) and steam may interact with waste plastics in the cryogenic gasifier to produce a mixed gas. For example, a large amount of waste plastics may be deposited in the cryogenic gasifier, and may be of any type of plastic that does not need to be separated. The mixture of process steam and oxygen (O2) is then injected into the cryogenic gasifier. The oxygen (O2) may be oxygen (O2) produced using the syngas generation system 300B, another syngas generation system connected to the SMR system, or oxygen (O2) that has been recaptured as a byproduct from a chemical generation system that may be connected to the SMR system. The injection of process steam and oxygen (O2) heats large quantities of plastic waste so that it produces a mixed gas and forms a non-combustible solid substance. The solid substance can be removed through the bottom of a low-temperature gasifier, and the gas can be supplied to a high-temperature gasifier.

[0123] In step 706, process 700 may include a mixed gas produced in a multimodule power plant, a steam generator, a high-temperature gasifier, a high-temperature electrolytic cell, and a low-temperature gasifier. In one embodiment, the multimodule power plant, steam generator, and high-temperature electrolytic cell may be the same as or similar to the multimodule power plant 402, steam supply unit 406, and high-temperature electrolytic cell 408 depicted in Figure 4. The mixed gas may be supplied to the high-temperature gasifier. In one embodiment, the high-temperature gasifier may have an operating temperature range including 1300°C to 1500°C. For example, the mixed gas generated in the low-temperature gasifier may be supplied directly to the high-temperature gasifier. The high-temperature gasifier may also receive process steam and oxygen (O2) to maintain a specific temperature and pressure range within the high-temperature gasifier. The injection of process steam and oxygen (O2) causes the formation of granular slag and a useful mixed gas, which are non-combustible materials that can be used in other industries.

[0124] In step 708, process 700 may include a high-temperature gasifier, a high-temperature electrolytic cell, and oxygen gas. In one embodiment, the high-temperature electrolytic cell may be the same as or similar to the high-temperature electrolytic cell 408 depicted in Figure 4. The mixed gas may contain particles that cannot be further processed. For particles that cannot be further processed, the dual gasification process 700 proceeds to step 710. For gases that can be further processed, the dual gasification process 700 proceeds to step 712. For example, processing the mixed gas in the high-temperature gasifier may produce granular slag and a useful mixed gas. The granular slag cannot be further processed in the two-stage pressure gasification system 700. If desired, the useful mixed gas can be further processed.

[0125] In step 710, process 700 may include a high-temperature gasification unit and a granular slag collection system. Particles in the mixed gas that cannot be further processed are converted into granular slag and recovered for use as a raw material in cement and other building materials. For example, the granular slag can be removed from the high-temperature gasification unit and, due to its rock-like properties, can be used in the production of cement or other building materials.

[0126] In step 712, process 700 may include a high-temperature gasifier and a mixed gas. The high-temperature gasifier may further process the mixed gas using boiler water, quenching water, oxygen (O2), and steam to obtain a gas. For example, the mixed gas may undergo various reactions through interaction with oxygen (O2) and temperature reactions caused by process steam, boiler water, and quenching water. These interactions may convert the mixed gas into a useful mixed gas that can be processed and separated.

[0127] In step 714, process 700 may include a mixed gas and a gas purifier. The resulting useful mixed gas may be supplied through the gas purifier. The gas purifier may use purified water to remove unwanted particles from the resulting gas in order to produce a product gas. For example, the useful mixed gas may still contain contaminants and undesirable compounds. The gas purifier may be used as needed to separate particles, remove tar, and remove any remaining trace contaminants. It should be noted that the specific type of gas purifier depends on the specific gas to be produced and the desired specifications for the gas to be produced.

[0128] In step 716, process 700 may include a product gas, a gas purifier, a PSA system, and a syngas. In one embodiment, the PSA system and syngas may be the same as or similar to the PSA system 412 and syngas 410 depicted in Figure 4. The generated gas may include a syngas (e.g., hydrogen (H2), carbon monoxide (CO), and carbon dioxide (CO2)). For example, a gas purifier may remove contaminants and undesirable compounds to ensure the generation of hydrogen (H2), carbon monoxide (CO), and carbon dioxide (CO2). Additionally, a gas purifier may ensure that the generated hydrogen (H2), carbon monoxide (CO), and carbon dioxide (CO2) are of suitable quality for producing useful chemicals (e.g., methanol (CH3OH), ammonia (NH3)).

[0129] Figure 8 shows a flowchart of an example process 800 for utilizing a small modular reactor plant system to capture carbon dioxide (CO2) using a direct air capture (DAC) process. The order in which the operations or steps are described is not intended to be construed as limiting, and any number of the described operations may be combined in any order and / or in parallel to perform method 800.

[0130] In step 802, process 800 may include dynamically supplying electrical and thermal energy using a modular multi-reactor plant energy system (e.g., a 12-module system, a 6-module system, a 4-module system, etc.). Note that by using a modular multi-reactor plant energy system, it can be dynamically and flexibly controlled to provide the appropriate energy as needed.

[0131] In step 804, process 800 may include treating seawater with water and concentrated sodium chloride (NaCl) solution using a desalination plant. Note that seawater desalination may require seawater pretreatment. Also note that dissolved carbon dioxide (CO2) in the seawater may be released during seawater pretreatment. The released carbon dioxide (CO2) may be routed into the DAC process.

[0132] In step 806, process 800 may include producing sodium hydroxide (NaOH) (carbon-scavenging solution) using a chlor-alkali process. Note that treating sodium chloride (NaCl) to produce sodium hydroxide (NaOH) also produces hydrogen (H2) gas and chlorine (Cl2) gas. In one embodiment, hydrogen (H2) gas and chlorine (Cl2) gas may be combined in an industrial process to produce hydrochloric acid (HCl).

[0133] In step 808, process 800 may include using a DAC process to interact with atmospheric air, specifically carbon dioxide (CO2) present in the atmospheric air, with a sodium hydroxide (NaOH) scavenging solution to generate an aqueous sodium bicarbonate (NaCO3) solution.

[0134] If it is desired to regenerate the captured carbon dioxide (CO2) into sodium formate (HCOONa), process 800 may proceed to step 810. If it is desired to regenerate the captured carbon dioxide (CO2) into sodium acetate (CH3COONa), method 900 may proceed to step 812.

[0135] In step 810, process 800 may include combining formic acid with sodium hydroxide (NaOH) to produce sodium formate (HCOONa), as expressed in formulas 2 and 3, as discussed above with reference to Figure 2, and as reproduced below. HCOOH + NaOH → HCOONa + H2O (2) 2HCOOH+Na2CO3→2HCOONa+H2O+CO2(3) In Equation 2, HCOOH is formic acid added to the carbon dioxide scavenging solution, NaOH is sodium hydroxide (carbon dioxide scavenging solution), HCOONa is sodium formate produced when formic acid reacts with sodium hydroxide carbon dioxide scavenging solution, and H2O is water produced together with sodium formate (HCOONa) when formic acid reacts with sodium hydroxide carbon dioxide scavenging solution. In Equation 3, HCOOH is formic acid added to a sodium carbonate solution produced directly through air scavenging, Na2CO3 is sodium carbonate produced directly through air scavenging, HCOONa is sodium formate produced when formic acid reacts with sodium carbonate (Na2CO3), H2O is water produced together with sodium formate (HCOONa) when formic acid reacts with sodium carbonate (Na2CO3), and CO2 is carbon dioxide produced together with sodium formate (HCOONa) and water when formic acid reacts with sodium carbonate (Na2CO3).

[0136] In the embodiment, utilizing step 810 allows for the regeneration of captured carbon dioxide (CO2) for further industrial processing without requiring high energy demands. In the embodiment, captured carbon dioxide (CO2) can be compressed, sequestrated, and / or reused to generate new useful materials.

[0137] In step 812, method 800 may include combining acetic acid (CH3COOH) with sodium hydroxide (NaOH) to produce sodium acetate (CH3COONa), as shown in formulas 7 and 8, as discussed above with reference to Figure 2, and as reproduced below. CH3COOH+NaOH→CH3COONa+H2O (7) 2CH3COOH+Na2CO3→CH3COONa+H2O+CO2(8) In Equation 7, CH3COOH is acetic acid added to sodium carbonate (Na2CO3) for the acetic acid (CH3COOH) treatment process, NaOH is sodium hydroxide (carbon dioxide scavenging solution), CH3COONa is sodium acetate produced when acetic acid (CH3COOH) reacts with sodium hydroxide carbon dioxide scavenging solution, and H2O is water produced together with sodium acetate (CH3COONa) when acetic acid (CH3COOH) reacts with sodium hydroxide carbon dioxide scavenging solution. In Equation 8, CH3COOH is for the acetic acid (CH3COOH) treatment process The first is acetic acid added to sodium carbonate (Na2CO3), where Na2CO3 is sodium carbonate generated directly through air capture, CH3COONa is sodium acetate generated when acetic acid (CH3COOH) reacts with sodium carbonate (Na2CO3), H2O is water generated together with sodium acetate (CH3COONa) when acetic acid (CH3COOH) reacts with sodium carbonate (Na2CO3), and CO2 is carbon dioxide generated together with sodium acetate (CH3COONa) and water when acetic acid (CH3COOH) reacts with sodium carbonate (Na2CO3).

[0138] In the embodiment, utilizing step 814 allows for the regeneration of captured carbon dioxide (CO2) for further industrial processing without requiring high energy demands. In the embodiment, captured carbon dioxide (CO2) can be compressed, sequestrated, and / or reused to generate new useful materials.

[0139] Figures 9 and 10 show typical reactors that may be included in embodiments of the present technology. Figure 9 is a partial schematic, partial cross-sectional view of a reactor system 900 configured according to embodiments of the present technology. The system 900 may comprise a power module 902 having a core 904 in which controlled nuclear reactions take place. Thus, the core 904 may comprise one or more fuel assemblies 901. The fuel assemblies 901 may include fissile and / or other suitable materials. The heat from the reactions generates steam in a steam generator 930, where the steam is directed to a power conversion system 940. The power conversion system 940 generates power and / or provides other useful outputs such as superheated steam. A sensor system 950 is used to monitor the operation of the power module 902 and / or other system components. Data acquired from the sensor system 950 can be used to control the power module 902 in real time and / or to update the design of the power module 902 and / or other system components.

[0140] The power module 902 then comprises a containment vessel 910 (e.g., a radiation shielding vessel or radiation shielding container) that houses / encloses a reactor vessel 920 (e.g., a reactor pressure vessel or reactor pressure container) that houses the reactor core 904. The containment vessel 910 can be housed in a power module bay 956. The power module bay 956 may include a cooling pool 903 filled with water and / or another suitable cooling fluid. The majority of the power module 902 can be located below the surface 905 of the cooling pool 903. Thus, the cooling pool 903 can act as a heat sink, for example, in the event of a system malfunction.

[0141] The volume between the reactor vessel 920 and the containment vessel 910 can be partially or completely evacuated to reduce heat transfer from the reactor vessel 920 to the surrounding environment (e.g., the cooling pool 903). However, in other embodiments, the volume between the reactor vessel 920 and the containment vessel 910 can be at least partially filled with gases and / or liquids that increase heat transfer between the reactor vessel 920 and the containment vessel 910. For example, the volume between the reactor vessel 920 and the containment vessel 910 can be at least partially filled (e.g., filled with primary coolant 907) during emergency operations.

[0142] Within the reactor vessel 920, the primary coolant 907 carries heat from the core 904 to the steam generator 930. For example, as indicated by the arrows located within the reactor vessel 920, the primary coolant 907 is heated in the core 904 toward the bottom of the reactor vessel 920. The heated primary coolant 907 (e.g., water with or without additives) rises from the core 904 to the riser tube 908 through the core shroud 906. The hot, buoyant primary coolant 907 continues to rise through the riser tube 908 and then exits the riser tube 908 and passes downward through the steam generator 930. The steam generator 930 comprises a number of conduits 932 arranged circumferentially around the riser tube 908, for example in a helical pattern, as schematically shown in Figure 9. The descending primary coolant 907 transfers heat to the secondary coolant (e.g., water) in the conduit 932 and descends to the bottom of the reactor vessel 920, where the cycle is restarted. The cycle can be driven by the change in buoyancy of the primary coolant 907, thus reducing or eliminating the need for pumps to move the primary coolant 907.

[0143] The steam generator 930 may include a feedwater header 931 into which incoming secondary coolant enters the steam generator conduit 932. The secondary coolant rises through the conduit 932, is converted into vapor (e.g., steam), and collected in the steam header 933. The steam exits the steam header 933 and is directed to the power conversion system 940.

[0144] The power conversion system 940 may include one or more steam valves 942 that regulate the passage of high-pressure, high-temperature steam from the steam generator 930 to the steam turbine 943. The steam turbine 943 converts the thermal energy of the steam into electricity via a generator 944. The low-pressure steam exiting the turbine 943 is condensed in a condenser 945 and then directed to one or more feedwater valves 241 (e.g., via a pump 946). The feedwater valves 941 control the rate at which the feedwater re-enters the steam generator 930 via a feedwater header 931. In other embodiments, the steam from the steam generator 930 can be routed for direct use in industrial processes such as hydrogen (H2) and oxygen (O2) production plants, chemical production plants, and / or similar, as described in detail below. Thus, the steam exiting the steam generator 930 can bypass the power conversion system 940.

[0145] The power module 902 comprises several control systems and associated sensors. For example, the power module 902 may include a hollow cylindrical reflector 909 that returns neutrons into the core 904 to further accelerate the nuclear reaction occurring therein. Control rods 913 are used to regulate the nuclear reaction and are driven via a fuel rod driver 915. The pressure inside the reactor vessel 920 can be controlled via a pressurizer plate 917 by controlling the pressure in a pressurized volume 919 located above the pressurizer plate 917 (this can also function to direct the primary coolant 907 downward through the steam generator 930).

[0146] The sensor system 950 may include, for example, one or more sensors 951 located at various positions within and / or elsewhere in the power module 902 to identify operating parameter values ​​and / or changes in parameter values. The data collected by the sensor system 950 can then be used to control the operation of system 900 and / or to make design changes for system 900. For sensors located within the containment 910, the sensor link 952 directs data from the sensor to the flange 953 (where the sensor link 952 exits the containment 910) and to the sensor junction box 954. From there, the sensor data can be routed via the data bus 955 to one or more controllers and / or other data systems.

[0147] Figure 10 is a partial schematic, partial cross-sectional view of a reactor system 1000 configured according to additional embodiments of the present technology. In some embodiments, the reactor system 1000 ("System 1000") may include several features that are at least generally similar in structure and function to, or identical in structure and function to, the corresponding features of System 1000 described in detail above with reference to Figure 10, and may operate in a manner generally similar to or identical to System 1000.

[0148] In the exemplary embodiments, the system 1000 comprises a furnace vessel 1020 and a containment vessel 1010 surrounding / enclosing the furnace vessel 1020. In some embodiments, the furnace vessel 1020 and the containment vessel 1010 may be approximately cylindrical or capsule-shaped. The system 1000 further comprises a plurality of heat pipe layers 1011 within the furnace vessel 1020. In the exemplary embodiments, the heat pipe layers 1011 are spaced apart from each other and stacked. In some embodiments, the heat pipe layers 1011 can be mounted / secured to a common frame 1012, a portion of the furnace vessel 1020 (e.g., its walls), and / or other suitable structures within the furnace vessel 1020. In other embodiments, the heat pipe layers 1011 can be stacked directly on top of each other such that each heat pipe layer 1011 supports and / or is supported by one or more of the other layers of heat pipe layers 1011.

[0149] In the exemplary embodiments, the system 1000 further includes a shielding or reflector region 1014 that at least partially surrounds the core region 1016. The heat pipe layer 1011 can be circular, linear, polygonal, and / or have other shapes, and as a result, the core region 1016 has a corresponding three-dimensional shape (e.g., cylindrical, spherical). In some embodiments, the core region 1016 is separated from the reflector region 1014 by a core partition 1015, such as a metal wall. The core region 1016 may include one or more fuel sources, such as fissile material, for heating the heat pipe layer 1011. The reflector region 1014 may include one or more materials configured to contain / reflect products generated by burning fuel within the core region 1016 during the operation of the system 1000. For example, the reflector region 1014 may include a liquid or solid material configured to reflect neutrons and / or other fission products radially inward toward the core region 1016. In some embodiments, the reflector region 1014 may completely surround the core region 1016. In other embodiments, the reflector region 1014 may partially surround the core region 1016. In some embodiments, the core region 1016 may include control material 1017 such as a moderator and / or coolant. The control material 1017 may at least partially surround the heat pipe layer 1011 within the core region 1016, allowing heat to be transferred between them.

[0150] In the exemplary embodiments, the system 1000 further comprises at least one heat exchanger 1030 (e.g., a steam generator) arranged around the heat pipe layer 1011. The heat pipe layer 1011 may extend at least partially from the core region 1016 into the reflector region 1014 and be thermally coupled to the heat exchanger 1030. In some embodiments, the heat exchanger 1030 may be located outside the reflector region 1014 or partially within the reflector region 1014. The heat pipe layer 1011 provides a heat transfer path from the core region 1016 to the heat exchanger 1030. For example, each heat pipe layer 1011 may include an array of heat pipes that provide a heat transfer path from the core region 1016 to the heat exchanger 1030. When system 1000 is operating, the fuel in the core region 1016 can heat and vaporize the fluid in the heat pipes within the heat pipe layer 1011, and the fluid can transfer heat to the heat exchanger 1030. The heat pipes within the heat pipe layer 1011 can then return the fluid towards the core region 1016 by suction, gravity, and / or other means of heating and vaporizing it again.

[0151] In some embodiments, the heat exchanger 1030 may be analogous to the steam generator 930 in Figure 9 and may comprise, for example, one or more helical coil tubes winding around a heat pipe layer 1011. The tubes of the heat exchanger 1030 contain or can contain a working fluid (a coolant such as water or another fluid) that carries heat from the heat pipe layer 1011 out of the furnace vessel 1020 and containment vessel 1010 for use in generating electricity, steam, and / or the like. For example, in the embodiment shown, the heat exchanger 1030 is operably connected to a turbine 1043, a generator 1044, a condenser 1045, and a pump 1046. As the temperature of the working fluid in the heat exchanger 1030 rises, the working fluid may begin to boil and vaporize. The vaporized working fluid (e.g., steam) can be used to drive the turbine 1043 and convert the thermal potential energy of the working fluid into electrical energy via the generator 1044. The condenser 1045 can condense the working fluid after it has passed through the turbine 1043, and the pump 1046 can direct the working fluid back to the heat exchanger 1030, where the working fluid can initiate another thermal cycle. In other embodiments, the steam from the heat exchanger 1030 can be routed for direct use in industrial processes, such as enhanced oil recovery operations, which are described in detail below. Thus, the steam leaving the heat exchanger 1030 can bypass the turbine 1043, generator 1044, condenser 1045, pump 1046, etc.

[0152] Figure 11 is a schematic diagram of a nuclear power plant system 1150 comprising a plurality of reactors 1100 according to an embodiment of the present technology. Each of the reactors 1100 (each individually identified as the 1st to 12th reactors 1100a to l) may be similar to or identical to the reactors 1100 and / or reactors 1100 described in detail above with reference to Figures 9 and 10. The power plant system 1150 ("power plant system 1150") may be "modular" in that each of the reactors 1100 may operate separately to provide output such as electricity or steam. The power plant system 1150 may comprise fewer than 12 reactors 1100 (e.g., 2, 3, 4, 5, 6, 7, 8, 9, 10, or 11 reactors 1100) or more than 12 reactors 1100. The power plant system 1150 can be a permanent installation or it can be mobile (e.g., mounted on a truck, tractor, mobile platform, and / or similar). In the exemplary embodiment, each reactor 1100 is located in a common housing 1151, such as a reactor plant building, and can be controlled and / or monitored via a control room 1152.

[0153] Each reactor 1100 can be connected to a corresponding power conversion system 1140 (each individually identified as the first to twelfth power conversion systems 1140a to l). The power conversion system 1140 may include one or more devices that generate electricity or any other form of usable electricity from the steam generated by the reactor 1100. In some embodiments, multiple reactors 1100 can be connected to the same power conversion system 1140, and / or one or more reactors 1100 can be connected to multiple power conversion systems 1140 such that there is no one-to-one correspondence between the reactors 1100 and the power conversion systems 1140.

[0154] The power conversion system 1140 can be further connected to a power transmission system 1154, for example, via a power bus 1153. The power transmission system 1154 and / or power bus 1153 may include one or more transmission lines, transformers, and / or similar for regulating the current, voltage, and / or other characteristics of the electricity generated by the power conversion system 1140. The power transmission system 454 can route the electricity to one or more end uses, such as different electrical loads of an integrated energy system, via a plurality of electrical output paths 1155 (individually identified as electrical output paths 1155a to n).

[0155] Each of the reactors 1100 can be further connected to a steam transfer system 1156, for example, via a steam bus 1157. The steam bus 1157 can route steam generated from the reactors 1100 to the steam transfer system 1156, which can then route the steam to one or more end uses, such as different steam inputs in an integrated energy system, via a plurality of steam output paths 1158 (individually identified as steam output paths 1158a to n).

[0156] In some embodiments, the reactor 1100 can be individually controlled (e.g., via a control room 1152) to supply steam to a steam transmission system 1156 and / or to a corresponding one of the power conversion systems 1140 to supply electricity to a power transmission system 1154. In some embodiments, the reactor 1100 is configured to supply steam to either a steam bus 1157 or a corresponding one of the power conversion systems 1140, and can switch quickly and efficiently between the steam supplied to either. Thus, in some aspects of the art, the reactor 1100 can be controlled modularly and flexibly so that the power plant system 1150 can supply electricity through a power transmission system 1154 and / or steam through a steam transmission system 1156 at different levels / amounts. For example, if the power plant system 1150 is used to supply electricity and steam to one or more industrial processes, such as various components of an integrated energy system, the reactor 1100 can be controlled to meet the different electrical and steam requirements of the industrial processes.

[0157] As an example, during a first operating state of an integrated energy system using a power plant system 1150, a first subset of reactors 1100 (e.g., reactors 1 to 6 1100a to f) may be configured to supply steam to a steam transmission system 1156 for use in the first operating state of the integrated energy system, while a second subset of reactors 1100 (e.g., reactors 7 to 12 1100g to l) may be configured to supply steam to the corresponding power conversion systems 1140 (e.g., power conversion systems 7 to 12 1140g to l) to generate electricity for the first operating state of the integrated energy system. Subsequently, during a second operating state of the integrated energy system where different (e.g., more or less) amounts of steam and / or electricity are required, some or all of the first subset of the reactor 1100 can be switched to supply steam to the corresponding power conversion systems 1140 (e.g., the 7th to 12th power conversion systems 1140g to l) and / or some or all of the second subset of the reactor 1100 can be switched to supply steam to the steam transmission system 1156, in order to vary the amount of steam and electricity generated to match the requirements / demands of the second operating state. Other variations in steam and electricity generation are possible based on the needs of the integrated energy system. That is, the reactor 1100 can be dynamically / flexibly controlled during other operating states of the integrated energy system to meet the steam and electricity requirements of the operating state.

[0158] In contrast, some conventional nuclear power plant systems can typically generate either steam or electricity for output, and cannot be modularly controlled to provide varying levels of steam and electricity for output. Furthermore, switching between steam and electricity generation is typically difficult (e.g., expensive, time-consuming) in conventional nuclear power plant systems. Specifically, for example, in prototype large-scale nuclear power plant systems, switching between steam and electricity generation is typically extremely time-consuming.

[0159] The reactor 1100 can be individually controlled via one or more operators and / or via a computer system. Therefore, many embodiments of the technology described herein may take the form of computer or machine or controller executable instructions, including routines executed by a programmable computer or controller. Those skilled in the art will understand that this technology can be implemented on computer / controller systems other than those shown and described herein. This technology can be embodied in a special-purpose computer, controller, or data processor that is specifically programmed, configured, or constructed to implement one or more of the computer executable instructions described below. Therefore, the terms “computer” and “controller” as used herein refer to any data processor and may include Internet appliances and handheld devices (including palmtop computers, wearable computers, cellular or mobile phones, multiprocessor systems, processor-based or programmable home electronic devices, network computers, minicomputers, and similar). Information handled by these computers may be presented on any suitable display medium, including liquid crystal displays (LCDs).

[0160] This technology can also be implemented in a distributed environment in which tasks or modules are performed by remote processing devices linked through a communication network. In a distributed computing environment, program modules or subroutines may reside in local and remote memory storage devices. Embodiments of the technology described herein may be stored or distributed on computer-readable media, including magnetically or optically readable or removable computer disks, and may be electronically distributed over a network. Specific data structures and data transfer for embodiments of this technology are also included within the scope of the embodiments of the technology.

[0161] The power plant system 1150 in Figure 11 can be connected to one or more industrial processes and / or systems to form an integrated energy system for producing industrial products such as hydrogen (H2), oxygen (O2), nitrogen (N2), ammonia (NH3), sulfuric acid (H2SO4), methanol (CH3OH), urea (NH2CONH2), and / or similar, while resulting in carbon-free emissions. Such an integrated energy system can drastically reduce, or even eliminate, carbon dioxide (CO2) emissions compared to conventional systems and processes for producing industrial products. In some embodiments, the integrated energy system according to this technology can produce carbon-free hydrogen (H2), nitrogen (N2), oxygen (O2), electricity, and process heating (e.g., steam) as individual commodities or as feedstocks or energy sources for other systems for producing other industrial products. In some embodiments, the power plant system 1150 can flexibly deliver power and steam to one or more of the following: a DAC system for generating carbon dioxide (CO2), a high-temperature and / or low-temperature electrolysis system for generating hydrogen (H2), a desalination system for generating desalination water, a water purification system for generating clean water, a reversible solid oxide fuel cell system for generating electricity using hydrogen (H2), and / or the like.

[0162] In some embodiments, a suitable integrated energy system for powering either of the processes described above may include several features that are at least generally similar in structure and function to, or identical in structure and function to, the corresponding features of the integrated energy system described in detail in U.S. Patent Application No. 18 / 116,819, filed March 2, 2023, entitled “SMALL MODULAR NUCLEAR REACTOR INTEGRATED ENERGY SYSTEMS FOR ENERGY PRODUCTION AND GREEN INDUSTRIAL APPLICATIONS,” which are incorporated herein by reference in their entirety.

[0163] conclusion All numerical values ​​herein are assumed to be modified by the term "about," whether explicitly stated or not. The term "about" generally refers to a range of numbers that a person skilled in the art would consider equivalent to (e.g., having the same function and / or result) the listed value in the context of a numerical value. For example, the term "about" can refer to plus or minus 10 percent of a given value. For example, the use of the term "about 100" can refer to the range of 90 to 110, including both ends. Where the context requires otherwise, and / or where relative terms are used in relation to something that does not contain or is not related to numerical values, the terms shall give their usual meaning to a person skilled in the art.

[0164] The above detailed description of embodiments of the Art is not intended to be exhaustive or to limit the Art to the exact forms disclosed above. Specific embodiments of the Art, and examples thereof, are described above for illustrative purposes, but various equivalent modifications are possible within the scope of the Art, as will be recognized by those skilled in the art. For example, the steps may be presented in a given order, but in other embodiments, the steps may be carried out in a different order. The various embodiments described herein may also be combined to provide further embodiments.

[0165] From the foregoing, it will be understood that while certain embodiments of the present technology are described herein for illustrative purposes, well-known structures and functions are not shown or described in detail in order to avoid unnecessarily obscuring the description of the embodiments of the present technology. Where the context allows, singular or plural terms may also include plural or singular terms, respectively.

[0166] Where used herein, the terms and / or, as in A and / or B, refer to A alone, B alone, and A and B. Additionally, the term including is used throughout to mean including at least the listed features, so as not to exclude any more than a certain number of the same features and / or other features of additional types. It will also be understood that while certain embodiments are described herein for illustrative purposes, various modifications can be made without departing from the Art. Furthermore, while some advantages relating to certain embodiments of the Art are described in the context of those embodiments, other embodiments may also exhibit such advantages, and not all embodiments are necessarily required to exhibit such advantages to fall within the scope of the Art. Therefore, this disclosure and related art may encompass other embodiments not expressly shown or described herein.

[0167] While some embodiments are described in a language specific to structural features and / or methodological actions, it should be understood that the claims are not necessarily limited to the specific features or actions described. Rather, specific features and actions are disclosed as exemplary forms of performing the claimed subject matter.

Claims

1. It is an integrated energy system, A power plant comprising at least one nuclear reactor and a power generation system, wherein the at least one nuclear reactor is configured to generate steam, A syngas generation system operably connected to the aforementioned power plant, A methanol generation system operably connected to the aforementioned syngas generation system and Equipped with, The aforementioned syngas generation system is Through the injection of the first portion of the steam at the first temperature, sodium oxalate ((COO) ２ Na ２ ) and hydrogen (H ２ A first reaction chamber that receives sodium formate (HClOONa) which is broken down into ), Through the injection of the second portion of the steam at the second temperature, sodium oxide (Na ２ (O), the sodium oxalate ((COO)) which is decomposed into carbon monoxide (CO) and carbon dioxide. ２ Na ２ ) and a second reaction chamber that receives Equipped with, The aforementioned steam includes superheated steam, The methanol generation system comprises the hydrogen (H ２ ), using the combination of carbon monoxide (CO) and carbon dioxide, methanol (CH ３ An integrated energy system configured to generate OH.

2. The methanol generation system combines the hydrogen (H ２ ), carbon monoxide (CO), and carbon dioxide to generate methanol (CH ３ OH) in a synthesis chamber configured as such. The integrated energy system according to claim 1.

3. The aforementioned syngas generation system generates hydrogen (H) by processing plastic waste. ２ The integrated energy system according to claim 1, further configured to generate carbon monoxide (CO) and carbon dioxide.

4. The aforementioned syngas generation system utilizes a sodium formate generation system, The integrated energy system according to claim 1, wherein the sodium formate generation system comprises seawater desalination, a chlor-alkali membrane process, a direct air capture process, and a formic acid treatment process.

5. Carbon dioxide (CO2) ２ ) A method for generating, Using a small modular nuclear reactor power plant system, superheated steam is generated, The process involves receiving sodium formate (HClOONa) into a first reaction chamber, wherein the first reaction chamber receives a first portion of the superheated vapor at a first temperature. The aforementioned sodium formate (HClOONa) is replaced with sodium oxalate ((COO) ２ Na ２ ) and hydrogen (H ２ ) and The aforementioned sodium oxalate ((COO) ２ Na ２ The process involves receiving the superheated vapor into a second reaction chamber, wherein the second reaction chamber receives the second portion of the superheated vapor at a second temperature. The aforementioned sodium oxalate ((COO) ２ Na ２ ) to sodium oxide (Na ２ O), carbon monoxide (CO), and carbon dioxide (CO) ２ ) and Methods that include...

6. The hydrogen (H ２ ), the carbon monoxide (CO), and the carbon dioxide (CO) ２ The process involves receiving the superheated steam into a synthesis chamber, wherein the synthesis chamber receives the third portion of the superheated steam at a third temperature. Methanol (CH ３ Receiving a catalyst to induce catalytic action for OH) generation, The hydrogen (H ２ ), the carbon monoxide (CO), and the carbon dioxide (CO) ２ Using the combination of ), methanol (CH ３ To continuously generate OH) and The method according to claim 5, further comprising:

7. The method according to claim 5, further comprising receiving the superheated steam at the first temperature which is in the range of 300°C to 350°C.

8. The method according to claim 5, further comprising receiving the superheated steam at the second temperature which is at least 800°C.

9. Inside the synthesis chamber, the hydrogen (H ２ ), the carbon monoxide (CO), and the carbon dioxide (CO) ２ ) receiving, The synthesis chamber receives a third portion of the superheated steam at a third temperature in the range of 200°C to 300°C, In the synthesis chamber, the hydrogen (H ２ ), the carbon monoxide (CO), and the carbon dioxide (CO) ２ In response to receiving ) and receiving the third portion of the superheated steam into the synthesis chamber, methanol (CH) is released from the synthesis chamber. ３ Outputting OH) The method according to claim 5, further comprising:

10. Catalyst, and the hydrogen (H ２ ), the carbon monoxide (CO), and the carbon dioxide (CO) ２ Using the combination of ), methanol (CH ３ This further includes continuously generating OH, The method according to claim 5, wherein the catalyst comprises a combination of copper and zinc oxide.

11. 1 mole of the aforementioned carbon dioxide (CO2) ２ ) 3 moles of the aforementioned hydrogen (H ２ ) is reacted with 1 mole of first methanol (CH ３ To produce OH) and 1 mole of water, One mole of carbon monoxide (CO) is reacted with one mole of water to produce one mole of carbon dioxide (CO). ２ ) and 1 mole of second hydrogen (H ２ ) to cause, 1 mole of the aforementioned carbon dioxide (CO2) ２ ) with 2 moles of the aforementioned hydrogen (H ２ ) is reacted with 1 mole of second methanol (CH ３ To generate OH) The method according to claim 6, further comprising:

12. The method according to claim 6, further comprising receiving the second portion of the superheated steam at the second temperature by a second reaction chamber located at the same production site as the synthesis chamber.

13. Carbon dioxide (CO2) ２ ) A system for generating, A small modular reactor (SMR) power plant system configured to supply steam, Sodium formate (HClOONa) is received, and a first portion of the steam is received from the SMR power plant system at a first temperature, and sodium oxalate ((COO) ２ Na ２ ) and hydrogen (H ２ A first reaction chamber configured to supply ) The aforementioned sodium oxalate ((COO) ２ Na ２ ) receives, and receives the second portion of the steam at a second temperature from the SMR power plant system, and sodium oxide (Na ２ O), carbon monoxide (CO), and carbon dioxide (CO) ２ A second reaction chamber configured to supply ) A system that includes these features.

14. From the first reaction chamber, hydrogen (H ２ ) receives the carbon monoxide (CO) and carbon dioxide (CO) from the second reaction chamber. ２ ) receives methanol (CH ３ The system according to claim 13, further comprising a synthesis chamber configured to receive a catalyst for inducing catalytic action for the generation of OH.

15. The system according to claim 13, wherein the first portion of the steam includes superheated steam having the first temperature, which is in the range of 300°C to 350°C.

16. The system according to claim 13, wherein the second portion of the steam includes superheated steam having the second temperature of at least 800°C.

17. The SMR power plant system is further configured to supply the third portion of the steam at a third temperature in the range of 200°C to 300°C. The hydrogen (H ２ ), the carbon monoxide (CO), the carbon dioxide (CO) ２ ), and methanol (CH ３ The system according to claim 13, further comprising a synthesis chamber configured to receive a catalyst for inducing catalytic action for the generation of OH.

18. The first reaction chamber includes a first rotating spiral, The second reaction chamber includes a second rotating spiral, The system according to claim 14, wherein the first reaction chamber is separated from the second reaction chamber by an airtight chamber.

19. Furthermore, the synthesis chamber is 1 mole of carbon dioxide and 3 moles of hydrogen (H ２ ) reacts to produce 1 mole of first methanol (CH ３ OH) and, 1 mole of the aforementioned carbon dioxide (CO2) ２ ) and 3 moles of the aforementioned hydrogen (H ２ One mole of water produced by the reaction between and One mole of carbon dioxide (CO) is produced by the reaction between one mole of carbon monoxide (CO) and one mole of water. ２ )and, One mole of second hydrogen (H) is produced by the reaction between one mole of carbon monoxide (CO) and one mole of water. ２ )and, 1 mole of the aforementioned carbon dioxide (CO2) ２ ) and 2 moles of the aforementioned hydrogen (H ２ ) produces 1 mole of second methanol (CH) ３ OH) and The system according to claim 14, configured to generate.

20. The system according to claim 14, wherein the first reaction chamber, the second reaction chamber, and the synthesis chamber are located at the same production site as the small modular reactor power plant.

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