Systems and Methods for Monitoring, Quantitatively Evaluating, and Authenticating Low-Carbon Hydrogen and Derivative Products

Abstract

A method for evaluating the molecular or isotopic composition of a fluid includes analyzing the proportions derived from the fluid's source to determine the source of the fluid, quantifying the proportions of the fluid derived from one or more sources, and evaluating the relationships of chemical species within the fluid to verify the source of the fluid. This evaluation can be achieved by direct measurement of the molecular composition of the fluid mixture or the isotopic composition of a particular fluid in the mixture, and / or a combination of statistical, thermodynamic, or kinetic modeling of these chemical reactions. The results of these measurements and models can be used to verify the sources and conditions of various forms of hydrogen or other resources.

Description

【Technical Field】 【0001】 (Cross - Reference to Related Applications) This application claims priority to U.S. Provisional Patent Application No. 63 / 349,888, filed on June 7, 2022, and claims priority to U.S. Provisional Patent Application No. 63 / 349,890, filed on June 7, 2022, the disclosures of each of which are hereby incorporated by reference in their entirety. 【Background Art】 【0002】 Embodiments of the present disclosure generally relate to the fields of hydrogen, energy, production tax credits, carbon tax credits, the chemical industry, chemical raw materials, forensic tracking, energy storage, carbon capture, carbon utilization, or carbon or natural gas storage. Some embodiments disclose methods for verifying and tracking hydrogen or carbon. Hydrogen is an energy source that has the potential to contribute to reducing the use of fossil fuels when combined with other energy sources. Hydrogen fuel is becoming more widespread because it can be produced using sustainable energy sources such as geothermal, solar, wind, and hydroelectric power. 【0003】 Furthermore, determining the source of fluids and materials can be important for utilizing tax credit programs. Specifically, it is to determine and quantify the eligibility of hydrogen for the U.S. Internal Revenue Service's 45V production tax credit program, various low - carbon fuel standards, or other production tax credit or subsidy programs, and to determine and quantify the eligibility of carbon dioxide storage for the U.S. Internal Revenue Service's 45Q tax credit program or other programs. As a result, determining and quantifying the components of a fluid or storage tank can be important for companies in various industrial sectors. 【Summary of the Invention】 【Means for Solving the Problems】 【0004】 Embodiments relate to a method for evaluating the molecular composition of a fluid, as well as a method for using chemical instruments to measure elements, molecules, isotopes, or isotope ratios by visual inspection, quantitative analysis, or computer-assisted machine learning with or without a teacher, enabling the identification and characterization of the source of a fluid in any of various chemical substances, raw materials, or energy sources in a subterranean formation or on the earth's surface. 【0005】 In some embodiments, a method for evaluating the molecular composition of a fluid may include analyzing the proportion of the fluid derived from a source to determine the source of the fluid, quantifying the proportion of the fluid, and evaluating the relationship of chemical species in the fluid to verify the source of the fluid. In some embodiments, the fluid may include a gas or a mixture of gases containing at least one of hydrogen, helium, noble gas, ammonia, carbon dioxide, hydrogen sulfide, nitrogen, or hydrocarbon gas. In some embodiments, analyzing the proportion of the fluid may include measuring elements, molecules, isotopes, or isotope ratios to identify and characterize the source of the fluid. The source can include at least one of subterranean hydrogen, subterranean formation, coal, steam methane reforming, pyrolysis, autothermal reforming, chemical looping of gas, or electrolysis. 【0006】 In some embodiments, the method may further include quantifying or differentiating the source of hydrogen in the fluid and verifying the source of hydrogen in the fluid. The source can include at least one of a natural gas pipeline, a hydrogen pipeline, an oil pipeline, a water pipeline, a railway vehicle, a truck, an industrial and storage facility, a spring, a surface outcrop, an underground storage tank, or a borehole for an oil, natural gas, water, or hydrogen well. In some embodiments, the method may further include monitoring leakage or gas emissions in at least one of the sources. In some embodiments, the method can include verifying and authenticating the proportion of carbon dioxide stored in an underground storage tank, and the form of storage can include porosity or mineralization. 【0007】 In some embodiments, the method may further include determining the residence time of fluids in a subterranean formation. Determining the residence time may include analyzing the concentrations of the isotope compositions of noble gases and water, carbon dioxide or other subterranean fluids, and analyzing the timing of crystallization or recrystallization of minerals to derive the timing of hydrogen generation in the subterranean formation using a rock sample core, cutting, or outcrop, and measuring uranium, thorium, potassium, or the mineralogical properties and crustal noble gas content in the minerals and analyzing a core, cutting, or outcrop to derive the timing of hydrogen generation in the subterranean formation. In some embodiments, the method may further include distinguishing the source of hydrogen generation by the timing of hydrogen generation in the subterranean formation. In some embodiments, the method may further include determining the gas saturation rate and gas-water ratio for hydrogen, methane, natural gas, or carbon dioxide in a fluid where the fluid is taken from the surface or a subterranean formation. 【0008】 A method for analyzing the isotope composition can include analyzing a fluid to determine a source of the fluid, analyzing the fluid to determine a proportion of a hydrogen source material derived from the source of the fluid, quantifying the proportion of the hydrogen source material derived from the source, and verifying the proportion of the hydrogen source material derived from the source. In some embodiments, the fluid can include at least one of hydrogen, helium, ammonia, carbon dioxide, hydrogen sulfide, nitrogen, methane or hydrocarbon gas, water, methanol, synthetic fuel, ammonia, or carbon dioxide. The source can include at least one of subterranean hydrogen, coal, natural gas, biomass, ammonia, steel manufacturing, chemical synthesis, waste incineration, gas treatment, air capture, natural gas pipeline, hydrogen pipeline, oil pipeline, water pipeline, railway vehicle, truck, steam methane reforming, pyrolysis, chemical looping, or electrolysis. In some embodiments, the method can further include verifying and authenticating a proportion of carbon dioxide stored in an underground storage tank including pores or mineralization. In some embodiments, the method can further include determining a carbon source material in a hydrogen carrier and quantifying a proportion of carbon derived from the hydrogen carrier. The hydrogen carrier can include at least one of coal combustion, natural gas combustion, biomass incineration, ammonia synthesis, steel manufacturing, chemical synthesis, waste incineration, and air capture. In some embodiments, analyzing the fluid can include comparing a measured value of an isotope ratio of hydrogen from a sample with data of an isotope ratio of hydrogen for a known hydrogen sample. The method can further include authenticating a source of hydrogen in at least one of a natural gas pipeline, a hydrogen pipeline, an oil pipeline, a water pipeline, a railway vehicle, a truck, or an industrial facility. In some embodiments, the method also includes determining a material composition of hydrogen using an isotope composition of hydrogen to determine, quantify, and verify a proportion of hydrogen, methane or other natural gas, or carbon dioxide derived from the source. 【0009】 In some embodiments, a system for determining information including one or more characteristics of water, hydrogen, methane or other natural gas, carbon dioxide, or a noble gas may include a chemical analyzer configured to determine information including one or more of: the molecular composition of a fluid including one or more of hydrogen, methane or other natural gas, or carbon dioxide; the gas saturation and gas-water ratio for hydrogen, methane or other natural gas, or carbon dioxide; the residence time of hydrogen or carbon dioxide in the fluid; the mass of water; the concentration of helium and other noble gases, and the concentration of isotopes of helium or other noble gases; and information including at least one of a source of hydrogen, carbon dioxide, or natural gas. The system may also include a computing device operably connected to the chemical analyzer. In some embodiments, the computing device may be configured to electronically communicate the information to a remote computing device. In some embodiments, the remote computing device is operably coupled to the computing device. In some embodiments, the chemical analyzer includes at least one of an isotope ratio mass spectrometer, a cavity ring-down spectrometer, a residual gas analyzer, a quadrupole mass spectrometer, a radon detector, a scintillation counter, a gas chromatograph, a gas chromatograph equipped with a flame ionization detector, and a thermal conductivity detector. 【0010】 Any of the features of the disclosed embodiments can be used in combination with each other without limitation. Additionally, other features and advantages of the present disclosure will become apparent to those of ordinary skill in the art upon consideration of the following detailed description and the accompanying drawings. 【Brief Description of the Drawings】 【0011】 The drawings illustrate several embodiments of the present disclosure, and the same reference numerals refer to the same or similar elements or features in different figures or embodiments shown in the drawings. 【0012】 【Figure 1】Figure 1 shows a list of analytical chemistry instruments, the types of samples that can be analyzed by each device, and the elements and compounds that can be measured, related to determining a hydrogen and carbon dioxide source, residence time, gas saturation rate, and hydrogen formation temperature according to an embodiment. 【Figure 2】 Figure 2 is a block diagram of a system including an analytical chemistry instrument, a computing device, and a remote computing device according to an embodiment. 【Figure 3】 Figure 3 is a flowchart of a method for determining properties of a fluid according to an embodiment. 【Figure 4】 Figure 4 is a graph of the fractionation factor of the hydrogen isotope composition of liquid water and molecular hydrogen as a function of temperature in a pair of liquid water and molecular hydrogen systems that occur during the serpentinization process. 【Figure 5】 Figure 5 is a graph of the relationship between the isotope composition of hydrogen molecules and the hydrogen formation temperature during the serpentinization process. 【Figure 6】 Figure 6 is a flowchart of a method for evaluating the molecular composition of a fluid according to an embodiment. 【Figure 7】 Figure 7 is a flowchart of a method for analyzing isotope composition according to an embodiment. **DETAILED DESCRIPTION OF THE INVENTION** 【0013】 Embodiments of the present disclosure relate to methods and systems for using chemical instruments to measure elements, molecules, isotopes, or isotope ratios by visual inspection, quantitative analysis, or supervised or unsupervised computer-assisted machine learning, and the methods and systems enable the identification and characterization of sources of hydrogen or carbon dioxide in subsurface or various chemical substances, chemical feedstocks, products obtained using hydrogen as a feedstock (e.g., ammonia, methanol, synthetic fuels, renewable or low-carbon diesel, e-fuels, plastics, synthetic methane, various other e-fuels, or processes utilizing other carbon-free or low-carbon hydrogen sources), or other energy sources on the earth's surface. The analysis of chemical species combinations forms the basis of the systems and methods used to determine the source of hydrogen. For example, the methods and systems herein can track and verify the source of natural hydrogen and other forms of hydrogen or carbon dioxide when sold as carbon-free or low-carbon hydrogen, and track and verify chemical species (e.g., in the processes of "green" ammonia, methanol, synthetic fuels, renewable or low-carbon diesel, e-fuels, plastics, synthetic methane, various other e-fuels, or processes utilizing other carbon-free or low-carbon hydrogen sources) in which hydrogen is used as a feedstock or incorporated into another chemical product. 【0014】 Hydrogen as a chemical feedstock and fuel source used to replace hydrocarbons and other fossil fuels is an unmet goal. Once formed, hydrogen provides a clean energy source that can eliminate greenhouse gases associated with the direct use of fossil fuels as an energy source and the carbon load resulting from using hydrocarbons as a feedstock for hydrogen generation. As a result, various mechanisms for producing low-carbon or "blue" (e.g., steam methane reforming combined with carbon capture utilization and storage), "green" (e.g., electrolysis or methane pyrolysis in a carbon dioxide-free manner), and "gold" (e.g., hydrogen recovered from or produced in the subsurface) hydrogen can be included in various industrial sectors. Hydrogen is a very useful and important chemical substance that can be used in various industries. The present disclosure provides systems, methods, and devices that address, and provide solutions for, the quantification, verification, and authentication of low-carbon or carbon-free hydrogen. 【0015】 Subsurface hydrogen, native hydrogen, and natural hydrogen can be considered as energy sources that have the potential to transition to low-carbon fuels. Methods and systems for the quantitative evaluation and monitoring of sources of hydrogen and hydrogen-derived products that are raw materials can be directly or indirectly sampled from natural samples, chemical feedstocks, other industrial chemicals, or chemical substances and products using hydrogen and carbon feedstocks, molecular species (e.g., H2, N2, NH3, CO, CO2) or elemental gases (e.g., noble gases: He, Ne, Ar, Kr, Xe, Rn), and gas isotopes (e.g., δ 2 H-H2, δ 2 H-CH4, δ 13 C-CH4, δ 13 C-CO2, δ 15 N-N2, 3 He, 4 He, 20 Ne, 21 Ne, 22 Ne, 36 Ar, 38 Ar, 40 Ar, and their derived isotope ratios), water (δ 2 H-H2O, δ 18O-H2O), or the measurement of the dissolved forms of carbon dioxide or carbon and their isotope compositions (e.g., δ 13 C-DIC) may be included. Further, low-carbon hydrogen sources include hydrogen produced by electrolysis (e.g., decomposing water molecules into hydrogen and oxygen using wind, solar, hydro, or other forms of electricity); plasma reforming with methane pyrolysis or partial oxidation (catalytic steam reforming from heavy hydrocarbons); chemical looping of gases from various sources (e.g., biomass, renewable natural gas, pressure swing adsorption emissions, refinery emissions, wastewater treatment emissions), hydrogen produced from biological sources (e.g., archaea, bacteria), synthesis gas (H2+CO) formation from coal, oil, or petroleum coke; steam methane reforming, or the like, each of which has different carbon intensities. Further gases, isotopes, or materials may be measured and analyzed according to the techniques disclosed herein. 【0016】 The use of chemical instruments to measure elements, molecules, isotopes, or isotope ratios by visual inspection, quantitative analysis, or computer-assisted machine learning with or without a teacher enables the identification and characterization of products obtained using hydrogen, hydrogen carriers, and hydrogen feedstocks. Figure 1 shows, according to an embodiment, a list of analytical chemical instruments related to determining the sources of products obtained using hydrogen, hydrogen carriers, and hydrogen feedstocks, the types of samples that can be analyzed by each device, and the elements and compounds that can be measured. In some examples, the chemical analyzer includes at least one of an isotope ratio mass spectrometer, cavity ring-down spectrometer, residual gas analyzer or quadrupole mass spectrometer, radon detector, scintillation counter, gas chromatograph, gas chromatograph with a flame ionization detector, and a thermal conductivity detector. It should be noted that additional chemical species and chemical instruments for detecting them may be included in the chemical species listed in Figure 1 and the chemical instruments for detecting those chemical species. 【0017】 The chemical analysis device can be used in a system for determining information including one or more characteristics of water, hydrogen, methane or other natural gas, carbon dioxide, or a noble gas. In some embodiments, the system comprises a chemical analysis device configured to determine information including the molecular composition of at least one fluid containing one or more of hydrogen, methane or other natural gas or carbon dioxide, the gas saturation rate and gas-water ratio with respect to hydrogen, methane or other natural gas or carbon dioxide, the residence time of hydrogen or carbon dioxide in the fluid, the mass of water, the concentrations of helium and other noble gases and the concentrations of isotopes of helium or other noble gases, and at least one of the sources of hydrogen, carbon dioxide or natural gas. 【0018】 FIG. 2 is a system 200 including an analytical chemistry instrument, a computing device 204, and a remote computing device 208 according to one embodiment. System 200 is used to determine information including one or more characteristics of water, hydrogen, methane or other natural gas, carbon dioxide, or noble gas. System 200 can be implemented using a computer for local and remote analysis, quantification, and evaluation. For example, the chemical analysis device 202 can be locally operated in a subterranean formation. The device 202 can communicate with a computing device 204 operably connected to the chemical analysis device. The computing device 204 may electronically communicate with the chemical test or measurement device 202 and receive measurements and data. In some embodiments, the computing device 204 may include a communication interface 206 configured to send notifications, reports, or data to other electronic devices. The computing device 204 can be operably coupled to a remote computing device 208. For example, the computing device 204 can be configured to send notifications and / or data to a remote electronic device or remote computer 208 at a selected radio frequency, via BLUETOOTH, or via WI-FI. In some embodiments, the computing device 204 can wirelessly transmit a signal to a remote electronic device or computer 208 and provide a direct display to the electronic device 208. In some embodiments, the measurements can be transferred via a memory storage device (such as a flash drive, disk, or the like). The computing device 204 can obtain data for comparison with sample measurement data from one or more data libraries. 【0019】 FIG. 3 is a flowchart of a method 300 for determining the characteristics of a fluid according to one embodiment. The method 300 includes, according to one embodiment, the collection of a hydrogen-containing fluid, the chemical analysis of the collected fluid, the acquisition of chemical data, the interpretation of the chemical data, and the classification of the source of hydrogen in the fluid sample, which can be used to determine the carbon credit value of the fluid. Some or all of the blocks shown in FIG. 3 may be utilized in one or more embodiments. For example, methods and systems for evaluating the molecular composition of a fluid can be implemented. In particular, identifying and characterizing hydrogen and its derived products, whether it is a gas or compressed in a fluid, can be an important analysis for determining the feasibility and productivity in energy production. In some examples, the fluid can include a gas or a mixture of gases, such as those containing at least one of hydrogen, helium, noble gases, ammonia, carbon dioxide, hydrogen sulfide, nitrogen, or hydrocarbon gases. 【0020】 The methods and systems disclosed herein apply to, at least, hydrogen from the supply and discharge of natural gas in pipelines; the supply and discharge of natural gas transported by other means (e.g., trucks, railroad cars, pipelines); biologically or organically derived hydrogen or hydrogen-containing molecules; hydrogen formed by electrolysis; plasma reforming with methane pyrolysis or partial oxidation; chemical looping of gases; hydrogen produced from biological sources (e.g., archaea, bacteria); synthesis of hydrogen-containing syngas / electric fuels; investigation of synthetic plastics, potential leaks or emissions or fugitive natural gas; storage in underground storage tanks, formations, cavities, or other facilities; or use in other industrial facilities (e.g., refineries, ammonia plants, synthesis / electric fuel generators, synthetic plastic manufacturing, direct reduced iron manufacturing, or high-temperature heating facilities). 【0021】 The methods and systems of this specification provide for analyzing the proportion of fluid derived from a source to determine the source of the fluid or components within the fluid. In some embodiments, analyzing the proportion of fluid includes measuring elements, molecules, isotopes, or isotope ratios to identify and characterize the source of the fluid. The methods disclosed herein can further include the quantitative assessment and monitoring of the source of hydrogen and hydrogen-derived products, which can be carried out using the measurement of one or more chemical species, elemental gases, gas isotopes, water isotopes, or dissolved forms of carbon dioxide or carbon and their isotope compositions directly or indirectly sampled from natural samples, chemical feedstocks, or other industrial chemicals. 【0022】 In some embodiments, the sources and proportions of various hydrogen supplies are determined, and the status of low-carbon hydrogen can be verified. For example, the source can include at least one of subterranean hydrogen, underground formations, coal, steam methane reforming, pyrolysis, autothermal reforming, chemical looping of gases, or electrolysis. Other sources can include carbon reduction through electrolysis, pyrolysis, geological, biological, or chemical looping. 【0023】 The analysis can be carried out for at least the U.S. Internal Revenue Service Section 45V production tax credit, various low-carbon fuel standards, or other incentive, subsidy, or tax credit programs, enabling the low-carbon or "green" certification of hydrogen and the tracking of "green" hydrogen and derived chemicals where hydrogen is a feedstock. Hydrocarbon gases can be naturally formed by inorganic or biological processes that result in characteristic molecular and stable isotope signatures of methane (e.g., δ 2 H-CH4, δ 13 C-CH4) and hydrocarbon species of higher molecular weight hydrocarbons (e.g., δ 2 H-C2, δ 13 C-C2). Thermogenic hydrocarbons (e.g., petroleum, shale gas) can be formed by thermal catagenesis of organic matter, and δ 2 H-CH4 is generally greater than about -250‰, and δ 13C-CH4 is generally between about -55‰ and -25‰. As the thermal maturity of the organic matter increases, the stable isotope signatures of carbon and hydrogen in the produced hydrocarbons can become more positive in a predictable manner. In contrast, microbial methane (e.g., coalbed methane) may be formed in the shallow subsurface where methanogenic archaea utilize the reduction of CO2 or the fermentation of acetate, resulting in a normal δ 13 C-CH4 value of less than about -55‰ and a δ 2 H-CH4 value that is usually greater than about -250‰ and less than about -100‰. Abiotic methane may be the result of the Sabatier reaction between H2 and CO2 at high temperatures (about 150 °C or higher) and may be observed in geothermal systems, resulting in isotopically heavy δ 13 C-CH4 (about -20‰ or higher) and δ 2 H-CH4 (about -400‰ or higher). 【0024】 Hydrogen can be formed by either inorganic or biological processes. The isotopic composition of hydrogen produced by either mechanism exhibits molecular or isotopic characteristics that can be used to determine the source of the hydrogen. For example, similar to microbial methane, hydrogen produced by biological species is associated with very high concentrations of dissolved inorganic carbon and isotopically enriched dissolved inorganic carbon (e.g., δ 13 C-DIC is generally in the range of -30‰ to -10‰) compared to that produced from the dissolution of CO2 or the oxidation of organic matter (e.g., δ 13 C-DIC greater than about -10‰). Hydrogen produced by microorganisms also exhibits a hydrogen isotopic composition that is significantly depleted in deuterium compared to protium (e.g., δ 2 H-H2 less than about -750‰). 【0025】 The most dominant geological process for producing natural hydrogen is the serpentinization of iron-rich minerals such as serpentine and pyroxene, which are the most commonly identified minerals in mantle-derived mafic and ultramafic igneous rocks (e.g., basalt, porphyry, and serpentinite). Serpentine and pyroxene minerals also trap 3Since it contains He, the hydrogen-rich fluid produced from serpentinization can be enriched in He compared to other crust-derived or microbially-derived hydrogen-rich fluids. 3 He can be concentrated. This is most frequently observed in geothermal environments, but has also been confirmed in continental interior environments where mafic and ultramafic igneous rocks penetrate and natural hydrogen is rising. Furthermore, while carbon dioxide has many sources in the crust (e.g., microbial respiration, dissolution of calcium carbonate, post-mature kerogen), mantle-derived fluids have characteristic δ 13 C-CO2 (from about -2‰ to -8‰) and [CO2] / 3 He] ratios (from about 1×10 9 to 10×10 9 ). Mantle-derived helium has a 3 He] / 4 He] of up to about 6 - 8R A (R A is the 3 He] / 4 He] in the atmosphere or 1.384×10 -6 ), and is even higher in mantle plume environments, while the atmospheric helium isotope ratio is about 1R A , and the crustal gas helium isotope ratio is about 0.02R A . In summary, these geochemical signatures can be used as evidence to identify the sources of natural hydrogen underground. In most crustal systems, the relative contributions of each component can be resolved by using combinations of the isotopes of helium, neon, or argon, or various ratios of helium or other noble gases to other atmospheric noble gases (e.g., He / Ne, He / Ar, He / Kr, He / Xe, or ratios to a specific isotope of one of these elements). 【0026】 Hydrogen produced by various inorganic processes shows a predictable relationship between temperature and the source of the water from which the hydrogen is obtained, as shown in Figures 4 and 5. Figure 4 shows the hydrogen isotope composition of liquid water (δ 2 H-H2O) as a function of temperature and the hydrogen isotope composition of molecular hydrogen (δ2 It is a graph of the resolution (e.g., alpha or separation factor) between (H-H2). Similar graphs for other hydrogen-forming reactions such as pyrite mineralization quantify the resolution between a given reactant and hydrogen products (e.g., hydrogen sulfide and hydrogen), and are envisioned as part of the embodiments. Since hydrogen can be formed by the reduction of water by various mechanisms (e.g., serpentinization), the H2O-H2 system has a strong temperature and fractionation relationship. For example, thermochemical calculations show that under very reducing conditions (e.g., low oxygen fugacity), the fractionation factor between oxygen and hydrogen in the interaction of chlorite with water or pyroxene with water, such as serpentinization, is well calibrated in the temperature range from about 20°C to 700°C. As a result, the δ 2 H-H2O and δ 2 H-H2 values can be measured, or when the δ 2 H-H2 value of a hydrogen-containing fluid can be measured while the isotopic composition of the original water can be reasonably assumed, the gas formation temperature can be calculated based on measuring δ 2 H-H2 and calculating the temperature-dependent resolution for the molecule carrying the original hydrogen. For example, when the δ 2 H-H2O value is known, it is based on either the local pore water isotope value, the seawater isotope value, or the known isotopic composition of the water source used in electrolysis or other reactions. By comparing these calculated temperatures with the local geothermal gradient, the source of natural hydrogen gas can be determined, and by comparison with various parameters (e.g., the concentration of other gases, the concentration of dissolved inorganic carbon, mineralogical properties), the mechanisms involved in hydrogen formation such as serpentinization or pyrite mineralization can be determined. 【0027】 Figure 5 shows hydrogen molecules (δ 2It is a graph of the relationship between the isotopic composition of H-H2) and the hydrogen formation temperature. Similar graphs for other hydrogen formation reactions (e.g., pyritization) that quantify the fractionation between a given reactant and the hydrogen product (e.g., hydrogen sulfide and hydrogen) are also envisioned as part of the embodiments. A small re-equilibration between ambient H2O and H2 is expected to exceed 100 °C in a hotter environment, suggesting that these calculated temperatures may represent minimum values. Whether plotted manually, using a computer, or by other forms of graphing or statistical tools, δ 2 The graph of H-H2 can be plotted against a calibration line of predicted temperature based on the thermodynamics of the equilibrium between the isotopic data of water (δ 2 H-H2O) or water and newly formed hydrogen gas, which assumes a fractionation factor between two species that depends on mineralogical properties, pore water chemistry, and temperature. 【0028】 Natural hydrogen can also be produced by biologically mediated (e.g., bacterial production) processes or other inorganic processes including magmatic oxidation, basalt alteration, magmatic degassing, fracturing, pyritization ("metal sulfide precipitation"), lava crystallization, radiolysis, graphitization, and the interaction between lava and seawater. In reactions involving these interactions with water (e.g., magmatic oxidation, basalt alteration, low-temperature weathering, magmatic crystallization, interaction between lava and seawater), there is also a similarly predictable temperature-dependent relationship between the original water source and the resulting hydrogen. In this case, the same processes described for serpentinization can be applied and used to determine the source of hydrogen. For other mechanisms, similar thermodynamic relationships exist between the original hydrogen-containing molecules, such as hydrogen sulfide in pyritization ("metal sulfide precipitation"), methane or other heavy hydrocarbons in graphitization, water in radiolysis or fracturing, or hydroxyl groups in radiolysis or fracturing, and the generated hydrogen. For example, thermochemical calculations show that the fractionation factor between hydrogen sulfide and hydrogen formed during the cancrinite sulfide hydrogen sulfide reaction or the pyroxene sulfide hydrogen sulfide reaction (e.g., pyritization ("metal sulfide precipitation")) is well calibrated in the temperature range from about 20°C to 700°C. As a result, when the δ 2 H-H2S and δ 2 H-H2 values can be measured, or when the δ 2 H-H2 value of a hydrogen-containing fluid can be measured while the isotope composition of the original hydrogen sulfide can be reasonably assumed, the gas formation temperature is δ 2It can be calculated based on measuring H-H₂ and calculating the temperature-dependent fractionation factor for the molecules carrying the original hydrogen. Using these calculated temperatures and various parameters, especially when compared with other geochemical parameters (e.g., concentrations of other gases, dissolved inorganic carbon concentration, mineralogical properties), and when compared with the source rock of hydrogen gas based on the comparison with the local geothermal gradient, the mechanisms (e.g., generation sources) involved in hydrogen formation (e.g., pyritization compared with serpentinization) can be determined. Whether plotted manually, plotted using a computer, or plotted by other forms of graphing or statistical tools, δ 2 The graph of δ 2 H-H₂ can be plotted against a calibration line of the predicted temperature based on the isotope composition of the molecules carrying hydrogen (e.g., δ 【0029】 Other gases and chemical species (e.g., H₂, N₂, NH₃, CO, CO₂, noble gases: He, Ne, Ar, Kr, Xe, Rn, and the isotopes of these gases (e.g., δ 2 H-CH₄, δ 13 C-CH₄, δ 13 C-CO₂, δ 15 N-N₂, 3 He, 4 He, 20 Ne, 21 Ne, 22 Ne, 36 Ar, 38 Ar, 40The concentration of Ar, etc. can also be used to distinguish hydrogen formed by various synthesis processes, electrolysis (e.g., decomposing water molecules into hydrogen and oxygen using wind, solar, hydro, or other forms of electricity); plasma reforming involving methane pyrolysis or partial oxidation (catalytic steam reforming from heavy hydrocarbons); chemical looping of gases from various sources (e.g., biomass, renewable natural gas, pressure swing adsorption emissions, refinery emissions, wastewater treatment emissions), hydrogen produced from biological sources (e.g., archaea, bacteria), synthesis gas (H2 + CO) formation from coal, oil, or petroleum coke; steam methane reforming, or the like, each of which has a different carbon intensity. This technique uses the measurable abundances of common tracers (e.g., CH4, N2, 4 He, Ne, Ar, Kr, Xe) and their isotope values (e.g., δ 2 H-CH4, δ 13 C-CH4, δ 13 C-CO2, δ 15 N-N2, 3 He, 4 He, 20 Ne, 21 Ne, 22 Ne, 36 Ar, 38 Ar, 40Based on comparing the predicted values of, for example, Ar, etc., the hydrogen source can be distinguished. In each process, temperature, pressure, and salinity-dependent variables can determine the predictable fractionation in the gas tracer through the hydrogen synthesis process and subsequent gas separation or purification processes. For example, during membrane separation, pressure swing adsorption, or cryogenic separation, these and other chemical species are predictably separated. Physicochemical parameters (e.g., temperature, pressure, and salinity) can be used to determine the initial composition, distinguish the amount of hydrogen supplied from various natural and synthetic formation mechanisms, or authenticate the hydrogen source. For example, hydrogen formed by steam reforming of methane, which is later processed for carbon capture and storage, shows predictable fractionation of chemical species used to determine the source, distinguish the amount of hydrogen supplied from various natural and synthetic formation mechanisms, or authenticate the hydrogen source. Whether plotted manually, using a computer, or by other forms of graphing or statistical tools, δ 2 The graph of δ 2 H-H2 can be plotted against a calibration line of the predicted temperature based on the thermodynamics of the equilibrium between the isotopic data of water (δ 【0030】 Hydrogen can also be produced by various synthesis processes, including electrolysis (e.g., decomposing water molecules into hydrogen and oxygen using wind power, solar power, hydropower, or other forms of electricity); plasma reforming with methane pyrolysis or partial oxidation (catalytic steam reforming from heavy hydrocarbons); chemical looping of gases from various sources (e.g., biomass, renewable natural gas, pressure swing adsorption emissions, refinery emissions, wastewater treatment emissions), hydrogen produced from biological sources (e.g., archaea, bacteria), synthesis gas (H2+CO) formation from coal, oil, or petroleum coke; steam methane reforming, or the like, each of which has different carbon intensities. In these reactions, there is also a similarly predictable temperature-dependent relationship between the original source of the molecule carrying hydrogen (e.g., water, methane) and the obtained hydrogen. Similar to the natural processes described above, in other synthesis processes (e.g., electrolysis, pyrolysis), the temperature calculated from chemical measurements (e.g., chemical abundance or their isotope composition) can be compared with the reaction temperature for determining the source of water, methane or other forms of natural gas, hydrogen sulfide, or other known sources of hydrogen carriers, as well as the source of synthetic hydrogen produced by various reactions or other reactions using these hydrogen-carrying molecules. Therefore, by comparing the measured, known or assumed composition of the feed water, the source of methane or other forms of natural gas, or the source of hydrogen sulfide and the temperature range of the related reactions, the source of hydrogen can be identified, classified or authenticated as green (e.g., formed by electrolysis), blue (e.g., formed by steam methane reforming with carbon capture and storage, methane pyrolysis), gold (e.g., natural hydrogen formed by various mechanisms), or other forms of hydrogen synthesis. In addition to isotope measurements, various parameters (e.g., the concentration of other gases (e.g., H2, N2, NH3, CO, CO2; noble gases: He, Ne, Ar, Kr, Xe, Rn; and the isotopes of these gases (e.g., δ 2 H-CH4, δ 13 C-CH4, δ 13 C-CO2, δ 15 N-N2, 3 He, 4 He, 20 Ne,21 Ne, 22 Ne, 36 Ar, 38 Ar, 40 Ar, etc.) can be used to determine the source of hydrogen formed by various processes. Whether plotted manually, using a computer, or by other forms of graphing or statistical tools, δ 2 The graph of δH-H2 can be plotted against the calibration line of the predicted temperature based on the thermodynamics of the equilibrium between water and newly generated hydrogen gas, assuming the fractionation factor between two species that depends on temperature, pressure, and salinity concentration, or the isotope data of water (δ 2 H-H2O) or other hydrogen-bearing molecules (e.g., methane: δ 13 C-CH4; δ 2 H-CH4 or other forms of natural gas (e.g., δ 13 C-C2H6; δ 2 H-C2H6), or hydrogen sulfide (e.g., δ 2 H-H2S)). A computer-executable software program including a mixing algorithm can be utilized to model the mixing of species (e.g., fractionation factor) in a sample based on the chemical data obtained by the analysis disclosed herein. 【0031】 The same thermodynamic calculations and measurements can be applied and used to determine the source of hydrogen and depict the process used to synthesize hydrogen formation. These same chemical parameters can be used to determine the mechanism (e.g., source) involved in hydrogen formation (e.g., steam methane reforming purified by chemical looping, electrolysis, and thermal decomposition compared to various forms of natural hydrogen), especially when combined with other geochemical parameters (e.g., concentrations of other gases). Whether plotted manually, using a computer, or by other forms of graphing or statistical tools, δ 2 The graph of δH-H2 can show the isotope composition of hydrogen-bearing molecules (e.g., δ 2 H-H2O, δ 13C-CH4, δ 2 H-CH4, δ 2 H-H2S), or can be plotted against a calibration line of predicted temperature based on the thermodynamics of the equilibrium between a hydrogen-bearing molecule and the newly generated hydrogen gas, assuming a fractionation factor between two species that depends on temperature, pressure, and salinity concentration. These techniques can be used to determine, distinguish, or authenticate natural hydrogen ("gold hydrogen") or other synthetic forms of hydrogen. 【0032】 In some embodiments, properties such as the comparison of methane concentration to hydrogen concentration (e.g., [CH4] / [H2]) can help provide important information regarding the origin of natural hydrogen. Generally, as temperature increases, in the presence of ambient gaseous or dissolved carbon dioxide, the kinetic rate of the Sabatier reaction converts more hydrogen to methane. During this process, the newly formed methane (e.g., abiotic methane) can have its own isotope composition (e.g., δ 13 C-CH4 greater than -20‰). As a result, the general positive correlation between [CH4] / [H2] and δ 2 H-H2 or δ 13 C-CH4 can be considered an indicator of an increase in gas formation temperature (and vice versa). Whether plotted manually, plotted using a computer, or plotted by other forms of graphing or statistical tools, graphs of these data can be used to determine temperature and resolve the mixture of multiple sources or gas generation. In some embodiments, systems and methods for determining the source of hydrogen can deduce or infer the source based on determining the hydrogen formation temperature. By determining the thermal conditions ("source of generation") of hydrogen, hydrogen production can be monitored, the fate of fugitive hydrogen can be traced, or the "fingerprint" of natural hydrogen that can be used to track its utilization in various commercial processes can be identified. For example, determining the thermal conditions under which hydrogen is formed from an industrial facility can enable determination of which natural hydrogen storage tank the facility is supplied from. 【0033】 In some embodiments, accurately determining the source can be important in assessing the likelihood that hydrogen formed at a particular depth migrates to a particular storage tank or is located under a particular seal and / or in estimating the volume of gas accumulating in a given three-dimensional trap. The source fingerprint can be important in various efforts to distinguish the source of the gas, identify chemicals obtained using hydrogen in this form or other forms as a feedstock, or track the fate of its downstream utilization or environment. In some embodiments, the source fingerprint can also be used to identify, classify, or verify or authenticate eligibility for the U.S. Internal Revenue Service Section 45V production tax credit, various low-carbon fuel standards, and various other hydrogen subsidies, incentives, or credit programs. 【0034】 In some embodiments, for the classification of hydrogen, one or more of a series of geochemical analyses can be performed on fluid samples or samples taken from various other sources of hydrogen formation. Fluid samples can be taken from wells at one or more depths or from the surface. Suitable sample containers for gas samples can include copper cooling tubes sealed with brass, steel, or other forms of cooling clamps, seamless stainless steel cylinders, Isotubes™, airtight septum vials, or the like. The fluid may be extracted from the sample container on a vacuum line and, if necessary, sonicated (e.g., for about 30 minutes) to ensure complete transfer of dissolved gas from the extraction container to the sample introduction line. 【0035】 The major gas / dissolved gas components in the sample (e.g., H2, N2, NH3, CO, CO2, C1-C6+) can be measured by a residual gas analyzer (RGA), a quadrupole mass spectrometer, a gas source mass spectrometer, a gas chromatograph (GC) equipped with a flame ionization detector (FID) and a thermal conductivity detector (TCD), or other suitable analytical apparatuses and techniques. Noble gases and their stable isotopes can be measured by a gas source mass spectrometer, for example, by the cavity ring-down method or other suitable techniques after purification of a portion of the sample. The stable isotope composition of gas molecules (e.g., δ 2 H-H2, δ 2 H-CH4, δ 13 C-CH4, δ 13 C-CO2, δ 15 N-N2) can be measured by an isotope ratio mass spectrometer (IRMS), cavity ring-down spectroscopy, or other suitable methods. The IRMS can also be used to measure the stable isotopes of hydrogen and oxygen in water (e.g., δ 2 H-H2O, δ 18 O-H2O). Any other techniques disclosed herein can be utilized to measure isotopes in fluid samples. 【0036】 Determining the properties of hydrogen, carbon, or any other material in a subsurface geological formation can involve collecting fluid samples from a borehole or a mine shaft. The borehole or mine shaft can be drilled for property evaluation. Samples can be collected at the surface, such as from a source of surface water or other fluids. For example, determining the properties of other materials in hydrogen, carbon, or other forms of gas can involve recovering fluid samples from various feeds and discharges for producing synthetic hydrogen (e.g., electrolysis, pyrolysis, chemical looping), being taken from various mechanisms of hydrogen transport (e.g., pipelines, trucks, cryogenic trucks, tanks, or other forms), storage (e.g., tanks, tube trailers, salt caverns, underground gas storage tanks, or being taken from chemicals where various forms of hydrogen are used as a feedstock (e.g., ammonia, methanol, synthetic fuels, renewable or low-carbon diesel, e-fuels, plastics, synthetic methane, various other e-fuels, or carbon-free or low-carbon hydrogen sources, synthetic plastics, or processes that utilize other energy sources at the surface)). Samples can be analyzed or tested as described above to obtain chemical data. The chemical data (e.g., measurements) can be compared to measurements from known samples or standards using any of the analytical techniques disclosed herein. The comparison can be performed on a computing device using electronic instructions to perform any of the analytical techniques disclosed herein. For example, software may be utilized to automatically perform any of the analytical techniques disclosed herein. Such comparisons may be performed in real time. 【0037】 Figure 6 is a flowchart of a method 600 for evaluating the molecular composition of a fluid according to one embodiment. In some examples, method 600 may include an act 602 of analyzing the proportion of fluid derived from a source to determine the source of the fluid. For example, the fluid may include a gas or a mixture of gases containing at least one of hydrogen, helium, noble gas, ammonia, carbon dioxide, hydrogen sulfide, nitrogen, or hydrocarbon gas. Hydrogen produced by various inorganic processes exhibits a predictable relationship between temperature and the source of the water from which the hydrogen is obtained. Other fluids may include similar unique signatures. Analyzing a portion of the fluid derived from a source to determine the source of the fluid may include analyzing the fluid to determine one or more properties of the fluid or components therein, such as isotope content. Any analytical technique disclosed herein may be utilized to analyze the proportion of the fluid. 【0038】 Method 600 may include an act 604 of quantifying the proportion of the fluid. Act 604 may include quantifying or differentiating the source of hydrogen in natural gas and may include quantifying or differentiating the source of hydrogen. In other words, fluid analysis includes the amount or proportion of the components of the fluid and includes representing the amount or proportion as data. Quantifying the proportion of the fluid may include utilizing a mixing algorithm or the like to determine the possible or estimated ratios of components in the fluid (e.g., types and amounts of isotopes, types and amounts of chemical species). 【0039】 Method 600 may include an act 606 of quantifying or differentiating the source of hydrogen in the fluid. The source may include at least one of a natural gas pipeline, a hydrogen pipeline, an oil pipeline, a water pipeline, a railroad car, a truck, an industrial and storage facility, a spring, a surface outcrop, an underground storage tank, or a borehole for an oil, natural gas, water, or hydrogen well. Quantifying and differentiating may assign a ratio, proportion, or other numerical value to a component of the fluid (e.g., hydrogen or its isotope) such that a source associated therewith can be generated. 【0040】 Method 600 may include an act 608 of authenticating a source of hydrogen in a fluid. Verification and authentication may be determined by tracking "green" hydrogen and derived chemical substances where hydrogen is a raw material. In some embodiments, authenticating the source includes comparing a value determined for the source to one or more known values of a natural hydrogen or new hydrogen source. In some embodiments, authenticating the source is performed by comparing the determined isotope ratio of the hydrogen to one or more known values of natural hydrogen or new hydrogen. 【0041】 Method 600 may also include an act 610 of differentiating a source of hydrogen generation. For example, by determining the residence time of hydrogen (or other gas), the geological age (e.g., timing) of hydrogen generation in a given subterranean formation can be used to differentiate among various potential sources of hydrogen. For example, natural hydrogen may be stored in a subterranean formation (in gas, fluid, or mineral) for thousands to millions of years, while newer hydrogen may be obtained from more modern sources. Hydrogen from various sources is different from each other and has an isotope content indicative of the source of hydrogen generation. Thus, the determined residence time and the associated source of hydrogen generation determined from the residence time can be used to evaluate the eligibility of hydrogen for the U.S. Internal Revenue Service 45V production tax credit, various low-carbon fuel standards, or other incentive, subsidy, or tax credit programs. The residence time can be determined by analyzing the isotope content (e.g., ratio) of hydrogen in the fluid. 【0042】 Method 600 may include an act 612 of verifying and certifying the proportion of carbon dioxide stored in an underground storage tank and the form of storage including porosity or mineralization. For example, carbon dioxide can be certified according to its source as a reaction product or as a stored and / or converted product, at least in part based on the isotope content of the carbon dioxide. In some embodiments, carbon dioxide can be mineralized and sequestered, and the history and / or formation of the carbon dioxide is analyzed and verified for tax credit purposes. Such verification or certification may include documenting the proportion of carbon dioxide stored in the underground storage tank, such as by attaching test results and data analysis to a certificate. 【0043】 Method 600 can include an act 614 of determining the gas saturation rate and gas-water ratio for hydrogen, methane, natural gas, or carbon dioxide in a fluid, where the fluid is sampled from the surface or a subterranean formation. The gas saturation rate can be defined as the ratio or proportion of the adsorbed gas content to the adsorption capacity. This value can be determined by comparing desorption data with the adsorption isotherm derived from the sample for a fluid sample at a given pressure and temperature. The saturation rate data can be an important characteristic parameter for determining at what saturation rate the trapped gas can be remobilized. 【0044】 Method 600 may include an act 616 of determining the residence time of fluids in a subterranean formation. The residence time of a fluid is a determination of the time the fluid has spent within a volume. The residence time may provide insights and data regarding the type of fluid present within the volume. Determining the residence time may include an act 618 of analyzing the concentration of noble gas elements (e.g., helium-4), and the isotopic composition of water, carbon dioxide, or other subterranean fluids. Determining the residence time may include an act 620 of analyzing the abundance of radioactive gases in the fluid obtained or in minerals formed during the interaction of water and rock that generates hydrogen. These measurements may be performed by sampling and separating gases, formation water, or other fluids, or minerals (e.g., magnetite, titanomagnetite) selected from a rock sample core, drill cuttings, or outcrop. For example, the timing of hydrogen generation in a subterranean formation can be derived by analyzing a core, cutting, or outcrop to measure the abundance of uranium (uranium-238, uranium-235), thorium (thorium-232), or potassium (potassium-40) of a parent isotope (e.g., source of radioactivity) in constituent minerals (e.g., magnetite, the source of hydrogen generation), and the abundance of daughter isotopes (e.g., helium-4, neon-21, argon-40), as shown in act 622. Based on these measurements, the age or residence time of the fluid can be calculated using the equation N(t)=N(0)e^-(λ*t), where N(t) is the number of atoms currently measured, N(0) is the initial number of atoms inferred by the abundance of the measured daughter (or radioactive) isotope, λ is the radioactive decay constant for a given parent isotope (or radioactive mineral), and t is the residence time. The residence time can be calculated by rearranging the equation to solve for t. 【0045】 Method 600 may optionally include an act 624 of monitoring for leakage or gas discharge in at least one of the sources. The method and system may be applied to the supply and discharge of natural gas in a pipeline for hydrogen, and hydrogen from the supply and discharge of natural gas transported by other means. For example, investigations of potential leakage or dissipation involving hydrogen, or stray natural gas, can be monitored by either the system described herein or an independent monitoring system. In some embodiments, the leakage and / or gas discharge of hydrogen can be monitored for purposes of gas loss and safety. 【0046】 Method 600 may include an act 626 of evaluating the relationship of chemical species in the fluid to verify the source of the fluid. The ratio of the components of the fluid can be determined to measure and confirm the source of the fluid, especially a fluid containing a mixture of components. Such verification may include a comparison of the statistical data of chemical species, mixtures, or the like for a known source with the determined statistical data of the fluid. For example, the source of the fluid can be verified by matching the statistical data of chemical species, mixtures, or the like for a known source and the fluid. The fluid mixture from the selected source may have a proportion of components with unique statistical data that do not correlate with other mixtures or fluid sources. Thus, a match between the statistical data (e.g., proportion of components, residence time, isotope content, or the like) for a known source can be used to identify the unknown source of the fluid sample. 【0047】 One or more parts of method 600 may be implemented using any of the techniques disclosed herein. For example, method 600 may be implemented using the techniques disclosed with respect to method 300 or method 700. Similarly, the parts of method 700 below may be implemented using any part of the methods and techniques disclosed herein. 【0048】 Figure 7 is a flowchart of a method 700 for analyzing isotope composition. Analyzing the isotope composition can be used to determine the characteristics of hydrogen incorporated into newer chemical species of fuels, ammonia, petroleum, polymers, or the like. In some embodiments, method 700 may include an act 702 of analyzing the isotope composition of a fluid to determine the source of the fluid. The isotope composition may include isotope values of hydrogen (e.g., δ 2 H-H2) or other molecules such as helium, methane, ethane. The analysis may include using any of the analytical techniques and systems described herein. The fluid may include at least one of hydrogen, helium, ammonia, carbon dioxide, hydrogen sulfide, nitrogen, methane or hydrocarbon gas, water, methanol, synthetic fuel, ammonia, or carbon dioxide. In some embodiments, the source may include at least one of subterranean hydrogen, coal, natural gas, biomass, ammonia, steel manufacturing, chemical synthesis, waste incineration, gas treatment, air capture, natural gas pipeline, hydrogen pipeline, petroleum pipeline, water pipeline, railway vehicle, truck, steam methane reforming, pyrolysis, chemical looping, or electrolysis. 【0049】 Method 700 may include an act 704 of analyzing the fluid to determine the proportion of hydrogen feedstock derived from the source of the fluid. For example, derivative products where hydrogen is the feedstock can include synthetic / electrolytic fuels derived from hydrogen such as ammonia, methanol, renewable or low-carbon kerosene, diesel, jet fuel, plastics, synthetic methane, or other hydrogen carriers or products; other hydrogen carriers; or synthetic plastics, among others. Hydrogen derived from these sources can have characteristic properties not associated with other sources such as natural hydrogen stored in subterranean rock formations. In some embodiments, the sources and proportions of various hydrogen supplies are determined and the status of low-carbon hydrogen can be verified. In some embodiments, analyzing the fluid includes measuring the isotope ratio of hydrogen from the sample and comparing it to data on the isotope ratio of hydrogen for known hydrogen samples (e.g., natural hydrogen, or electrolytic hydrogen, hydrogen from pyrolysis or other new forms of hydrogen). 【0050】 Method 700 may include an act 706 of quantifying the proportion of hydrogen feedstock derived from a source. Quantifying the proportion of hydrogen feedstock derived from a source may include quantifying the proportion of the hydrogen incorporated into newly formed chemical species (e.g., ammonia, synthetic fuel, petroleum) that is derived from the source. Such quantification may include determining the proportion from the isotope composition of hydrogen (or other atoms) in the newer chemical substance and comparing them with known isotope composition data for newer chemical substances made from natural hydrogen or new forms of hydrogen. 【0051】 Method 700 may include an act 708 of authenticating the proportion of hydrogen feedstock derived from a source. For example, authenticating the source of hydrogen may include authenticating the source in at least one of a natural gas pipeline, a hydrogen pipeline, an oil pipeline, a water pipeline, a railroad car, a truck, or an industrial facility. Authenticating the source may include documenting (e.g., correlating or storing) the analysis (and its results) used to determine the source and proportion of hydrogen in the fluid. 【0052】 In some embodiments, method 700 may include verifying and authenticating the proportion of carbon dioxide stored in a subsurface reservoir containing pores or mineralization. For example, carbon dioxide can be authenticated as a reaction product or as a stored and / or converted product according to its source. In some embodiments, carbon dioxide can be mineralized and sequestered, and the history and / or formation of carbon dioxide is analyzed and verified for tax credit purposes. Such verification and authentication may include documenting the results of the analysis corresponding to the fluid and its source, such as providing a statement or authentication form to a record-keeping agency, a government agency, a hydrogen user, or a hydrogen supplier. 【0053】 In some embodiments, method 700 may include act 712 of determining a carbon source in a hydrogen carrier and quantifying the proportion of carbon derived from the hydrogen carrier. In some embodiments, the hydrogen carrier may include at least one of coal combustion, natural gas combustion, biomass incineration, ammonia synthesis, steel manufacturing, chemical synthesis, waste incineration, and air capture. 【0054】 In some embodiments, method 700 may include act 714 of determining the material composition of hydrogen by using the isotopic composition of hydrogen to determine, quantify, and verify the proportion of hydrogen, methane or other natural gas, or carbon dioxide derived from a source. Thus, method 700 can be implemented by using chemical instruments to measure elements, molecules, isotopes, or isotope ratios by visual inspection, quantitative analysis, or computer-assisted machine learning with or without a teacher, thereby enabling the identification and characterization of the source of hydrogen or carbon dioxide in underground or various chemical substances, chemical raw materials, products obtained using hydrogen as a raw material, or other energy sources in surface and underground strata. 【0055】 In some embodiments, a method for analyzing a molecular composition may include analyzing a mixture of hydrogen molecules, hydrocarbon gases, noble gases, carbon dioxide, nitrogen, and natural gases with different compositions to determine the source of hydrogen, carbon dioxide, or natural gas. In some embodiments, a method for analyzing the molecular composition of a hydrogen and other gas mixture may include evaluating the proportion of hydrogen derived from a source including a source of in-situ hydrogen, coal, steam methane reforming, pyrolysis, chemical looping, or electrolysis, quantifying the proportion of hydrogen derived from the source, and verifying and authenticating the proportion of hydrogen derived from a carbon-free, low-carbon, and / or high-carbon source including a source of in-situ hydrogen, coal, steam methane reforming, pyrolysis, chemical looping, or electrolysis. 【0056】 In some embodiments, a method for analyzing an isotope composition may include analyzing at least one of a hydrogen molecule, a hydrocarbon gas, a noble gas, carbon dioxide, nitrogen, or a mixture of natural gases with different compositions to determine a source of hydrogen, carbon dioxide, or natural gas; analyzing water to determine a raw material for hydrogen formation by electrolysis of water; and analyzing methane or other hydrocarbon gases to determine a raw material for hydrogen formation by thermal decomposition of methane or other hydrocarbon gas raw materials, steam methane reforming, or steam methane reforming combined with carbon capture utilization and storage. 【0057】 In some embodiments, a method for analyzing an isotope composition may include evaluating the proportion of hydrogen, carbon dioxide, or natural gas derived from a source including one or more of subterranean hydrogen, coal, steam methane reforming, pyrolysis, chemical looping, or electrolysis; quantifying the proportion of hydrogen or carbon dioxide derived from the source; and verifying and certifying the proportion of hydrogen derived from a carbon-free, low-carbon, and / or high-carbon source including subterranean hydrogen, coal, steam methane reforming, pyrolysis, chemical looping, or electrolysis. 【0058】 In some embodiments, a method for analyzing the isotope composition of hydrogen in ammonia may include determining the source of the hydrogen raw material used in ammonia production; determining the proportion of the hydrogen raw material derived from a source including subterranean hydrogen, coal, steam methane reforming, pyrolysis, chemical looping, or electrolysis; quantifying the proportion of the hydrogen raw material derived from the source; and verifying the proportion of the hydrogen raw material derived from the source. 【0059】 In some embodiments, a method for analyzing the isotopic composition of hydrogen and carbon in methanol may include determining the source of the hydrogen or carbon feedstock used in methanol production, determining the proportion of hydrogen derived from a source including at least one of subterranean hydrogen, coal, steam methane reforming, pyrolysis, chemical looping, or electrolysis, determining the proportion of carbon derived from a source including at least one of coal combustion, natural gas combustion, biomass incineration, ammonia synthesis, steel manufacturing, synthesis of lime and other chemicals, waste incineration, gas treatment, air capture, or other forms, quantifying the proportion of hydrogen feedstock or carbon derived from a source including one or more of subterranean hydrogen, coal, steam methane reforming, pyrolysis, chemical looping, or electrolysis, verifying the proportion of hydrogen feedstock and carbon derived from a source including one or more of subterranean hydrogen, coal, steam methane reforming, pyrolysis, chemical looping, or electrolysis, and verifying the proportion of carbon derived from a source including one or more of coal combustion, natural gas combustion, biomass incineration, ammonia synthesis, steel manufacturing, synthesis of lime and other chemicals, waste incineration, gas treatment, air capture, or other forms. 【0060】 In some embodiments, a method for analyzing the hydrogen and carbon isotope composition in synthetic / electrolysis fuels such as renewable or low-carbon kerosene, diesel, jet fuel, plastics, synthetic methane, or other hydrogen carriers includes determining the sources of hydrogen and carbon feedstocks in synthetic / electrolysis fuels such as renewable or low-carbon kerosene, diesel, jet fuel, plastics, synthetic methane, or other hydrogen carriers, quantifying the proportion of hydrogen derived from a source including one or more of the sources of geogenic hydrogen, coal, steam methane reforming, pyrolysis, chemical looping, or electrolysis in the synthetic / electrolysis fuel, quantifying the proportion of carbon derived from a source including one or more of coal combustion, natural gas combustion, biomass incineration, ammonia synthesis, steelmaking, synthesis of lime and other chemicals, waste incineration, gas treatment, air capture, or other forms in the electrolysis fuel, verifying the proportion of hydrogen derived from a source including one or more of the sources of geogenic hydrogen, coal, steam methane reforming, pyrolysis, chemical looping, or electrolysis in the electrolysis fuel, and verifying the proportion of carbon derived from a source including one or more of coal combustion, natural gas combustion, biomass incineration, ammonia synthesis, steelmaking, synthesis of lime and other chemicals, waste incineration, gas treatment, air capture, or other forms in the electrolysis fuel. 【0061】 In some embodiments, a method for analyzing the isotopic composition of hydrogen and carbon in a hydrogen carrier may include determining the sources of hydrogen and carbon raw materials in the hydrogen carrier, quantifying the proportion of hydrogen derived from at least one source including at least one of geogenic hydrogen, coal, steam methane reforming, pyrolysis, chemical looping, or electrolysis in the hydrogen carrier, quantifying the proportion of carbon derived from at least one source including at least one of coal combustion, natural gas combustion, biomass incineration, ammonia synthesis, steel manufacturing, lime and other chemical synthesis, waste incineration, gas treatment, air capture, or other forms in the hydrogen carrier, verifying the proportion of hydrogen derived from at least one source including at least one of geogenic hydrogen, coal, steam methane reforming, pyrolysis, chemical looping, or electrolysis in the hydrogen carrier, and verifying the proportion of carbon derived from at least one source including at least one of coal combustion, natural gas combustion, biomass incineration, ammonia synthesis, steel manufacturing, lime and other chemical synthesis, waste incineration, gas treatment, air capture, or other forms in the hydrogen carrier. 【0062】 In some embodiments, a method for determining the source of hydrogen in natural gas may include determining the source of hydrogen in at least one of a natural gas pipeline, a hydrogen pipeline, an oil pipeline, a water pipeline, a railway vehicle, a truck, or an industrial facility. The method may include comparing the measured isotopic ratio of hydrogen from a sample with data on the isotopic ratio of hydrogen for known hydrogen samples. 【0063】 In some embodiments, a method for quantifying or differentiating the source of hydrogen in natural gas may include quantifying or differentiating the source of hydrogen in at least one of a natural gas pipeline, a hydrogen pipeline, an oil pipeline, a water pipeline, a railway vehicle, a truck, or an industrial facility. 【0064】 In some embodiments, a method for certifying a source of hydrogen in natural gas for a US IRS (United State Internal Revenue Service) 45V production tax credit, a Low Carbon Fuel Standard, or other hydrogen incentives, subsidies, or credit programs may include certifying a source of hydrogen in at least one of a natural gas pipeline, a hydrogen pipeline, an oil pipeline, a water pipeline, a railroad car, a truck, or an industrial facility. 【0065】 In some embodiments, a method for determining a source of hydrogen includes determining a source of hydrogen in a fluid collected from the surface or underground for the purpose of exploring for oil, natural gas, hydrogen, carbon dioxide, helium, or other gases, and determining a source of hydrogen in a fluid collected from the surface or underground for the purpose of drilling, including measurements during drilling, drill stem tests, or pressure volume temperature (PVT) operations, for oil, natural gas, hydrogen, carbon dioxide, helium, or other gases, and determining a source of hydrogen in a fluid collected from the surface or underground for the purpose of producing oil, natural gas, hydrogen, carbon dioxide, helium, or other gases, and determining a source of hydrogen in a fluid collected from the surface or underground for the purpose of monitoring and evaluating oil, natural gas, hydrogen, carbon dioxide, helium, or other gases in an underground storage tank, and determining a source of hydrogen in a fluid collected from the surface or underground for the purpose of monitoring and evaluating the storage of oil, natural gas, hydrogen, carbon dioxide, helium, or other gases in an underground cavity, and determining a source of hydrogen in a fluid collected from the surface or underground for the purpose of monitoring and evaluating the storage of oil, natural gas, hydrogen, carbon dioxide, helium, or other gases in an above-ground tank, an underground tank, or other industrial facilities, and determining a source of hydrogen in a fluid collected from the surface or underground for the purpose of monitoring and evaluating the presence of leaks, fugitive emissions, or other gas emissions in a borehole, an oil, natural gas, or hydrogen well, a pipeline, a water well, a surface outcrop, a spring, or other storage facilities. 【0066】 In some embodiments, a method for determining the material composition of hydrogen using the isotopic composition of hydrogen may include ammonia, methanol, synthetic or electrolytic fuels, plastics, various other sources of green hydrogen, various other chemicals in which hydrogen is used as a raw material, surface areas or fluids collected from the ground including springs and surface emissions for the purpose of monitoring and evaluating the storage of petroleum, natural gas or hydrogen in above-ground tanks, underground tanks, or other industrial facilities, or leakage, escape, vagrant, or other gas emissions in boreholes, oil, natural gas or hydrogen wells, pipelines, wells, surface emissions, springs, or other storage facilities. The method may include using the isotopic composition of at least one hydrogen in the fluid collected from the surface area or underground for the purpose of monitoring and evaluating the presence of such emissions. 【0067】 The analytical techniques for determining the isotopic composition, source, ratio, etc. of hydrogen, carbon, or other chemical components disclosed herein can be used in any of the methods disclosed herein. 【0068】 In the production of natural resources from subterranean formations, a well or borehole is drilled into the ground to a location where the natural resources are believed to be located. Similarly, in the isolation of greenhouse gases or other waste in subterranean formations, a well or borehole is drilled into the ground to a location where the greenhouse gases or other waste are to be injected, stored, and isolated. These natural resources may be hydrogen; helium; carbon dioxide; hydrogen sulfide; methane or other hydrocarbon gases; hydrogen sulfide storage tanks; hydrogen storage tanks; helium storage tanks; carbon dioxide storage tanks; natural gas storage tanks; hydrogen sulfide-rich storage tanks; hydrocarbon-rich storage tanks; helium-rich storage tanks; the natural resources may be fresh water; brackish water; salt water; it may be a heat source for geothermal energy; or it may be other natural resources, ore deposits, minerals, metals or gemstones located underground. 【0069】 These resource-containing strata can be hundreds, thousands, or tens of thousands of feet below the surface of the earth, including beneath the bottom of a body of water, such as beneath the ocean floor, or beneath other natural resources, such as beneath an aquifer. These strata may also extend over areas of different sizes, shapes, and volumes. 【0070】 Typically and by way of a general illustrative example, in the drilling of a well, an initial borehole is made into the earth, such as into the surface of land or the ocean floor, and then smaller diameter boreholes are drilled to extend the overall depth of the borehole. In this way, as the overall borehole gets deeper, its diameter gets smaller, resulting in what can be envisioned as a telescoping assembly of holes having the largest diameter hole at the uppermost part of the borehole closest to the surface. 【0071】 Thus, as an example, the start of a seafloor drilling process can generally be described as follows. When a drilling rig is placed on the water surface over the area where drilling is to be performed, the first borehole is created by drilling a 36-inch hole into the ground to a depth of about 200 - 300 feet below the seafloor. A 30-inch casing is inserted into this first borehole. This 30-inch casing can also be referred to as a conductor. The 30-inch conductor may or may not be cemented in place. During this drilling operation, risers are generally not used, and cuttings from the borehole, e.g., the earth and other materials removed from the borehole by the drilling activity, are returned to the seafloor. Next, a 26-inch diameter borehole is drilled inside the 30-inch casing, and the depth of the borehole is extended to about 1,000 - 1,500 feet. This drilling operation may also be performed without using a riser. Thereafter, a 20-inch casing is inserted into the 30-inch conductor and the 26-inch borehole. This 20-inch casing is cemented in place. The 20-inch casing has a wellhead fixed to it. (In other operations, additional smaller diameter boreholes may be drilled, smaller diameter casings may be inserted into those boreholes, and wellheads may be fixed to those smaller diameter casings.) Thereafter, a BOP (blow out preventer) is fixed to the riser, lowered to the seafloor by the riser, and the BOP is fixed to the wellhead. From this point on, all drilling activities within the borehole are performed through the riser and the BOP. 【0072】 Note that riserless seafloor drilling operations are also contemplated. 【0073】 In onshore drilling processes, the steps are similar, but large-diameter pipes of 30 inches to 20 inches are not typically used. Thus, generally, there is typically a surface casing with a diameter of about 13 3 / 8 inches. This can extend from the surface, for example, the wellhead and BOP, to depths of tens to hundreds of feet. One of the purposes of the surface casing is to address environmental concerns of protecting groundwater by preventing surface casing airflow from entering the groundwater aquifer, or preventing surface casing airflow of greenhouse gases or combustible gases from entering the groundwater aquifer or the atmosphere. The surface casing should have a large enough diameter to allow the drilling string, production equipment such as an electronic submersible pump (ESP), and circulating mud to pass through. Below the casing, one or more intermediate casings of different diameters can be used. (It should be understood that sections of the borehole may not be cased and are called open holes.) These can have a diameter range of about 9 inches to about 7 inches, although larger and smaller sizes may be used and can extend to depths of thousands to tens of thousands of feet. A section of the well located in a reservoir, such as a formation section containing natural resources, can be called a pay zone. Inside the casing and extending from the production zone of the pay zone or borehole to the surface wellhead is the production pipe. There can be a single production pipe or multiple production pipes within a single borehole, and each of the production pipes may terminate at a different depth. 【0074】 Fluid communication between a formation and a wellbore can be significantly increased by the use of hydraulic fracturing or other stimulation techniques. The first use of hydraulic fracturing dates back to the late 1940s to early 1950s. Generally, a hydraulic fracturing treatment involves forcing a fluid into the formation through a wellbore, and the fluid enters the subterranean formation and fractures, for example, breaking or fracturing a rock formation. These fractures create channels or flow paths that can have cross-sections ranging from a few microns, a few millimeters, several millimeters, and potentially exceeding several millimeters. The fractures can also extend in all directions from the wellbore by a few feet, several feet, dozens of feet, or more. The fractures can be kept open by using proppants (e.g., sands or other mineral particles of various sizes) that are forced into the wellbore in a single operation along with the fracturing fluid. Note that the longitudinal axis of the wellbore in the reservoir may not be vertical, may be at an angle (tilted up or down), or may be horizontal. 【0075】 As used herein, unless otherwise expressly stated, the terms "hydrogen exploration and production", "carbon dioxide exploration and production", "helium exploration and production", "hydrogen sulfide exploration and production", "exploration and production activities", "E&P", "E&P activities", and terms similar to these terms should be construed as broadly as possible and include surveying, geological analysis, chemical evaluation, wellbore planning, reservoir planning, reservoir management, wellbore drilling, completion and finishing activities, hydrogen production, hydrogen flow from a wellbore, hydrogen extraction, secondary and tertiary recovery from a wellbore, hydrogen flow management from a wellbore, carbon dioxide injection, carbon dioxide sequestration, carbon dioxide mineralization, hydrogen sulfide injection, hydrogen sulfide sequestration, hydrogen sulfide mineralization, and any other upstream activities. 【0076】 As used herein, unless otherwise expressly stated, the terms "sulfur mineralization," "sulfur sequestration," "sulfur mitigation," "carbon dioxide mineralization," "carbon dioxide sequestration," "carbon dioxide mitigation," "carbon mineralization," "carbon sequestration," "carbon mitigation," and similar terms, shall be interpreted in the broadest possible sense to include surveying, geological analysis, well planning, reservoir planning, reservoir management, well drilling, workover and completion activities, sulfur injection, dihydrogen sulfide injection, carbon injection, carbon dioxide injection, sulfur spill management, dihydrogen sulfide, carbon, carbon dioxide into the well, and any other upstream activities. 【0077】 As used herein, unless otherwise expressly stated, the term "earth" is to be interpreted in the broadest possible sense to include all natural materials, such as ground, rock, and man-made materials, such as concrete, borehole casing, piping, or fill, which are present or may be found in the ground. 【0078】 As used herein, unless otherwise expressly stated, the terms "offshore" and "offshore drilling operations" and similar terms are used in the broadest sense and include drilling operations in any body of water, whether fresh or salt water, man-made or naturally occurring, such as, for example, rivers, lakes, canals, inland seas, oceans, seas such as the North Sea, gulfs and bays such as the Gulf of Mexico. As used herein, unless otherwise expressly stated, the term "offshore drilling rig" is to be interpreted in the broadest possible sense and includes fixed towers, tugs, platforms, barges, jack-ups, floating platforms, drillships, dynamically-positioned drillships, semi-submersible drilling rigs, and dynamically-positioned semi-submersible drilling rigs. As used herein, unless otherwise expressly stated, the term "seabed" is to be interpreted in the broadest possible sense and includes the surface beneath or at the bottom of any body of water, whether fresh or salt water, man-made or naturally occurring. 【0079】 As used herein, unless otherwise expressly indicated, the term "borehole" should be construed as broadly as possible and includes openings made in the ground that are substantially longer than they are wide, such as wells, wellbores, well holes, microholes, slim holes, and other terms commonly used or known to define these narrow and long passages. Wells further include exploration wells, discovery wells, production wells, abandoned wells, re-drilled wells, re-worked wells, re-cycled wells, and injection wells. They include both cased wells and uncased wells, as well as sections of those wells. An uncased well, or a section of a well, is also referred to as an open hole, borehole, open borehole, open bore, open hole section. A borehole may further have segments or sections having different directions, and may have straight sections and curved sections, and combinations thereof. Thus, unless otherwise specifically defined herein, the "bottom", "bottom surface" of a borehole and similar terms refer to the opening of the borehole, the surface of the earth, or the end or portion of the borehole that is furthest along the path of the borehole from the starting point of the borehole. The terms "side" and "wall" of a borehole should be construed as broadly as possible and include the longitudinal surface of the borehole, whether or not a casing or liner is present, such that these terms include the sides of an open borehole or the sides of a casing disposed within the borehole. A borehole can be composed of a single flow path, multiple flow paths, connected flow paths (e.g., branched configurations, fishbone configurations, two-plane configurations, three-plane configurations, four-plane configurations, pitchfork configurations, feather configurations, or comb-type configurations), as well as combinations and variations thereof. 【0080】 Boreholes are generally formed and advanced by using a mechanical excavation device having a rotary excavation tool (e.g., a bit). For example, generally when creating a borehole in the ground, the excavation bit extends into the ground, enters the ground, and rotates to create a hole. To perform the excavation operation, the bit must be pressed against the material to be removed with sufficient force to exceed the shear strength, compressive strength, or a combination thereof of the material. The material cut from the ground is generally known as cutting or excavation cutting, e.g., waste, which can be slices of rock, dust, rock fibers, and other types of materials and structures that can be generated by the interaction of the bit with the ground. This cutting is typically removed from the borehole by the use of a fluid, which can be a fluid, foam or gas, or other materials known in the art. 【0081】 As used herein, unless otherwise expressly stated, the term "excavation pipe" should be construed as broadly as possible and includes all forms of pipe used in excavation activities and refers to a single section or a piece of pipe. In this specification, the terms "stand of excavation pipe", "excavation pipe stand", "stand of pipe", "stand", and similar terms should be construed as broadly as possible and typically include two, three, or four sections of excavation pipe connected by joints having, for example, screw joints and joined together. In this specification, the terms "excavation string", "string", "string of excavation pipe", "string of pipe", and similar terms should be construed in the broadest definition and include stands or multiple stands joined together for the purpose of use in a borehole. Thus, an excavation string can include many stands and hundreds of sections of excavation pipe. 【0082】 As used herein, unless otherwise expressly indicated, the terms "formation", "reservoir", "payzone" and similar terms should be construed as broadly as possible and include all subterranean locations, regions, and geological features that may contain, may potentially contain, or are thought to contain hydrogen, carbon dioxide, helium, hydrogen sulfide, or natural gas. 【0083】 As used herein, unless otherwise expressly indicated, the terms "field", "oilfield", "gas field" and similar terms should be construed as broadly as possible and include any area of land, seabed, or water that is gently or directly associated with geological formations, particularly resource-bearing formations, and thus a field may have one or more exploration and production wells associated therewith, a field may have one or more government agencies or private resource leases associated therewith, and one or more fields may be directly associated with a resource-bearing formation. 【0084】 As used herein, unless otherwise expressly indicated, the terms "conventional hydrogen," "conventional carbon dioxide," "conventional helium," "conventional hydrogen sulfide," "conventional natural gas," "conventional," "conventional production," and similar terms shall be construed as broadly as possible and shall include hydrogen, carbon dioxide, helium, or hydrogen sulfide trapped within subterranean structures. Generally, in these conventional formations, hydrogen, carbon dioxide, helium, hydrogen sulfide, or natural gas has migrated through permeable or semi-permeable formations to regions where it is trapped or accumulated. Generally, in conventional formations, non-porous and relatively impermeable layers are above or surround regions of accumulated hydrogen, carbon dioxide, helium, hydrogen sulfide, or natural gas, essentially trapping the hydrogen, carbon dioxide, helium, hydrogen sulfide, or natural gas within the accumulation. Conventional storage tanks have been the source of most of the natural gas, hydrogen, carbon dioxide, helium, and hydrogen sulfide observed to date. As used herein, unless otherwise expressly indicated, the terms "non-conventional hydrogen," "non-conventional carbon dioxide," "non-conventional helium," "non-conventional hydrogen sulfide," "non-conventional natural gas," "non-conventional," "non-conventional production," and similar terms shall be construed as broadly as possible and shall include hydrogen, carbon dioxide, helium, hydrogen sulfide, or natural gas that is held within impermeable rock or has not migrated to a trap or accumulation region. 【0085】 As used in the specification, unless otherwise expressly indicated, the term "gold hydrogen" shall be construed as broadly as possible and generally refers to hydrogen produced from underground, by drilling into a subterranean system and recovering hydrogen, or by stimulating iron-rich rock, ferroan rock, pyrite, iron-rich sandstone, iron-rich sediment, uranium- and thorium-rich rock, or uranium- and thorium-rich sediment, with or without fracturing, or by other forms of mechanical stimulation that can provide an abundant source of low-emission, low-cost, fully dispatchable energy. 【0086】 As used herein, unless otherwise expressly indicated, the term "molecule" should be construed as broadly as possible and generally refers to a group of atoms bonded together and represents the smallest basic unit of a chemical compound that can participate in a chemical reaction. 【0087】 As used herein, unless otherwise expressly indicated, room temperature is 25 °C. Also, standard temperature and pressure are 25 °C and 1 atmosphere. 【0088】 Generally, as used herein, unless otherwise expressly indicated, the term "about" means to encompass a variation or range of ±10%, experimental or instrumental errors associated with obtaining the recited value, and preferably the greater of these. 【0089】 As used herein, unless otherwise expressly indicated, the recitation of a range of values in this specification is merely intended as a shorthand method for referring individually to each separate value within that range. Unless otherwise indicated in this specification, each individual value within the range is incorporated into the specification as if it were individually recited herein. 【0090】 The term "CO2e" is used to define the equivalence of carbon dioxide with other more potent greenhouse gases (e.g., methane and nitrous oxide) based on the 100-year global warming potential according to the IPCC AR5 methodology. The term "carbon intensity" means the life cycle CO2e produced per unit mass of the product. 【0091】 CO2 is widely recognized as a greenhouse gas (GHG), and the continued accumulation of CO2 and other GHGs in the atmosphere is expected to cause problematic changes in the Earth's ecosystem and contribute to numerous other problems such as ocean acidification and sea-level rise. The two major causes of global carbon emissions are the use of fossil fuels for power generation and transportation. 【0092】 Given the risk of CO2 emissions, significant efforts have been made to find alternatives to existing high-carbon energy sources or ways to decarbonize existing energy sources. However, many of these low-carbon alternatives are either economically unviable or lack sufficient dispatchability to replace current options. 【0093】 The term "sulfur equivalent" of "SO x " is used to define the offset equivalence of hydrogen sulfide or sulfur dioxide for sulfur emissions. The term "sulfur intensity" means the life-cycle SO x produced per unit mass of the product. 【0094】 Sulfur is widely recognized as a toxic and harmful air pollutant in various forms including, but not limited to, hydrogen sulfide, sulfur dioxide, sulfuric acid, and sulfates. Deposition of sulfur in soil, waterways, and other environments is expected to cause problematic changes to the Earth's ecosystem and contribute to numerous other problems such as acid rain, soil acidification, forest destruction, ocean acidification, and other harmful effects. The major causes of global hydrogen sulfide emissions are related to the extraction and refining of oil and natural gas, pulp and paper manufacturing, rayon fiber production, waste treatment, landfills, sewage treatment plants, and general waste treatment. Additionally, natural factors such as volcanoes, hot springs, fumaroles, geysers, vents, "acidic" natural gas fields, biodegraded oil fields, or geothermal power plants also constitute major natural sources of hydrogen sulfide. 【0095】 Given the risk of hydrogen sulfide and other forms of sulfur emissions, significant efforts have been made to find sulfur removal technologies, develop low-sulfur fuels, or ways to desulfurize existing energy sources and processes. However, many of these low-sulfur alternatives either create their own cost barriers, are economically unviable, or limit the dispatchability of energy sources. 【0096】 Based on the risk of sulfur emissions, the US EPA (IRC 45H) has developed a cap-and-trade sulfur credit program for offsets, sulfur reduction, and isolation. The US IRS 45Q tax credit program is a similar tax credit program for carbon dioxide sequestration. 【0097】 In power generation, alternatives to high-emission sources (such as gas and coal) that are reliable and low-cost are either dispatchable and expensive (such as nuclear, hydro, green hydrogen, or blue hydrogen), or inexpensive and intermittent (such as solar and wind, and in some cases green hydrogen). There is only one existing low-cost and dispatchable source, which is geothermal. However, geothermal resources are limited, many of the economically productive geothermal resources have already been developed and are approaching the end of their life, and many geothermal resources have already declined. Therefore, without significant technological progress, the growth outlook for geothermal energy resources is limited. 【0098】 Green hydrogen (hydrogen produced from water without using fossil fuels) is produced by electrolysis driven by solar, wind, hydro, renewable natural gas combustion, or geothermal energy, and can be a reliable source of low-carbon energy when combined with storage, but its applicability is limited by high capital investment costs, intermittent production due to intermittent energy sources or high energy costs during grid connection, and the high cost and low availability of suitable hydrogen storage resources. Furthermore, electrolysis consumes significantly more energy to produce hydrogen than the energy stored in the hydrogen, resulting in low round-trip efficiency in the system. 【0099】 Blue hydrogen faces a similar set of problems as green hydrogen, using a low-cost, high-emission fuel source such as coal or natural gas and adding an expensive and parasitic carbon capture facility to convert this low-cost, high-emission energy source into a high-cost, low-emission supply source. Thus, while large amounts of hydrogen can be formed in the process of preventing subsequent greenhouse gases from reaching the atmosphere, the newly developed hydrogen resources are not cost-competitive compared to other forms of energy derived from fossil fuels. Furthermore, due to the challenge of finding carbon sequestration resources that can be used to permanently store the carbon recovered from these processes, as a result, the opportunities to deploy these technologies are limited today. 【0100】 Natural hydrogen (or "gold hydrogen") is produced from underground by excavating and stimulating iron-rich rocks, ferroan rocks, pyrite, iron-rich sandstone, iron-rich sediments, uranium- and thorium-rich rocks, and uranium- and thorium-rich sediments, with or without crushing, or by other forms of mechanical stimulation, and can provide an abundant source of low-emission, low-cost, and fully dispatchable energy. 【0101】 Each of these energy sources, and their respective advantages and limitations, are also relevant to transportation. Considering transportation fuels, historically the main sources of fuel have been diesel and gasoline, both of which are derived from crude oil production. Furthermore, in recent years, electric vehicles have been expanding their market share, but the cost of electric vehicles is still higher than that of equivalent vehicles powered by fossil fuels, and there are limitations regarding cost, charging time, and the main resources for batteries and energy storage. Considering the weight of the battery, long-haul electric truck transportation also has challenges, and most long-haul truck manufacturers are looking for affordable low-carbon options such as hydrogen fuel truck transportation. 【0102】 Natural hydrogen produced by enhanced hydrogen production reactions is the answer to the challenges of low-carbon or negative-carbon, low-cost, and reliable transportation in long-haul trucking and potentially other forms of transportation. For other types of transportation, natural hydrogen as a compressed or liquefied product or as a feedstock for synthetic fluid fuels ("e-fuel") is a reliable low-cost, low-carbon or negative-carbon solution. Additionally, natural hydrogen can be combined with nitrogen to produce carbon-free ammonia products, which are widely discussed as potential alternatives to bunker fuels for ships and as feedstocks for synthetic fertilizer manufacturing. 【0103】 Direct emissions reduction: Since there is no direct CO2 emissions from the combustion or typical use of hydrogen, the reduction of CO2 emissions varies depending on what hydrogen replaces. In many cases, low-carbon (or negative-carbon) hydrogen will replace hydrogen from steam methane reforming (SMR) as a chemical feedstock for ammonia production, oil refining, and other chemical manufacturing. In some cases, low-carbon (or negative-carbon) hydrogen may replace natural gas, diesel fuel, gasoline, or jet fuel as a heat source or transportation fuel. 【0104】 In the case of ammonia production and purification, natural gas is used to produce hydrogen via the steam methane reforming reaction, which is used as a chemical feedstock in both the purification process and the ammonia production process. Today, over 95% of hydrogen is produced using natural gas in steam methane reformers (SMRs). The carbon intensity of hydrogen production using SMR without carbon capture is 10.4 tons of CO2 emitted per ton of hydrogen produced. Thus, the direct replacement of hydrogen produced by the SMR process with natural hydrogen results in a CO2 reduction of 10.4 tons CO2 / ton H2. 【0105】 In power generation using gas turbines, hydrogen needs to replace an amount equivalent to the energy (BTU) of natural gas. The energy density of hydrogen is 290 BTU / cf or 51,682 BTU / lb. In comparison, the energy density of natural gas is 983 BTU / cf or 20,267 BTU / lb, while the carbon intensity of natural gas is 52.91 kg CO2 / mmBTU CH4 or 54.87 kg CO2 / mcf CH4, or 3.5 kg CO2 / kg CH4. 【0106】 Since hydrogen has an energy density 2.6 times higher per unit mass than natural gas, only 40% of the total tonnage of fuel is required to achieve the same energy output. Therefore, when 1 ton of H2 is burned for power generation, the consumption of natural gas is reduced by approximately 2.6 tons, and thus the CO2 emissions are reduced by 9.1 tons. 【0107】 When comparing natural hydrogen produced by enhanced hydrogen production reactions with hydrogen produced by electrolysis, the amount of carbon reduction varies depending on the carbon intensity of the electricity used in the electrolysis process. There can be significant indirect emissions associated with electrolysis, but there are no direct emissions. However, natural hydrogen produced by enhanced hydrogen production reactions, as part of various EHP (enhanced hydrogen production) processes, has the potential to result in a reduction in direct emissions of carbon dioxide, sulfur, or both sulfur and carbon dioxide, and this process includes those that directly sequester carbon dioxide emissions, sulfur emissions, and a combination of carbon dioxide and sulfur emissions in a permanent mineral form. For carbon dioxide when H2S and CO2 are involved in the EHP process, there is a reduction in direct emissions of approximately 10 tons of CO2 emitted per ton of hydrogen produced compared to hydrogen produced by electrolysis (or other forms of hydrogen production). The integration of this process achieves net carbon-negative hydrogen production. 【0108】 Indirect Emission Reduction: Analysis of the life cycle carbon intensity of natural hydrogen using the Oil Production Greenhouse Gas Emissions Estimator (OPGEE) indicates that the life cycle carbon intensity of natural hydrogen is in the range of 0.1 - 0.4 tons CO2 / ton H2 and has additional emission reduction equivalent to the mass of carbon dioxide mineralized with sulfur by various sulfur-enhanced hydrogen production methods. Similar studies for other hydrogen production methods are not available. However, considering an average grid intensity of 0.5 tons CO2 / MWh and that electrolysis requires approximately 50 MWh / ton H2 production, the indirect emissions associated with electrolysis would be approximately 25 tons CO2 / ton H2 production assuming grid power. Of course, operators of electrolysis units can purchase renewable energy credits to artificially reduce the carbon footprint of their electricity use, but the market recognition of this as a method to reduce real-time carbon emissions may not be permanent. 【0109】 The realization of abundant natural hydrogen can achieve a significant reduction in equivalent carbon emissions. 【0110】 Targets for natural hydrogen storage tanks and stimulation of underground hydrogen production can be identified near many existing geothermal power plants. Some geothermal power plants already have hydrogen that constitutes part of the non-condensable gas released from their systems. However, with the methods and systems described herein, hydrogen can be recovered from the exhaust gas and used to increase the output of geothermal power plants. 【0111】 The systems and methods described herein utilize the coincidence of underground hydrogen resources, the coincidence of underground formations where hydrogen can be produced by enhanced hydrogen production processes, or the coexistence of other forms of synthetic hydrogen formation (e.g., electrolysis, thermolysis) and geothermal power plants. The performance of geothermal power plants is enhanced by incorporating the combustion of hydrogen produced from the above sources into the operation of the power plants. 【0112】 In some embodiments, wind electrolysis, solar electrolysis, hydro electrolysis, SMR with carbon capture, conventional SMR, and steam methane reforming may be located proximate to a geothermal power plant, and hydrogen may be used to enhance the service life and production capacity of an existing geothermal power plant. 【0113】 Some geothermal power plants (e.g., various fields in Iceland, the west coast of the United States, the circum-Pacific region, or the East African Rift Valley) are located in areas that tend to be associated with the presence of basalt rocks, iron-rich rocks, or iron-rich sediments. Geothermal power plants are operated by two main methods. (1) In the case of a flash steam plant, high-temperature water and / or steam is extracted from the ground, flash-vaporized, passed through a turbine, and then condensed and reinjected, or (2) in the case of a binary cycle plant, high-temperature water or brine is brought to the surface, heat-exchanged with an organic fluid, and that organic fluid is flash-vaporized and passed through an organic Rankine cycle turbine and then condensed. The cooled water or brine can then be slowly moved through the geothermal reservoir until it is reinjected to provide pressure support or produced again as high-temperature brine. 【0114】 Note that there is no requirement to provide or address the theory underlying the novel and groundbreaking processes, production rates, performance, or other beneficial features and characteristics that are the subject of, or are related to, embodiments of the present disclosure. However, various theories are provided herein to further advance the art in this important field, particularly in the important fields of exploration, production, and downstream conversion or utilization of hydrogen, hydrogen sulfide, carbon dioxide, and helium. These theories presented herein do not limit, restrict, or narrow the scope of protection afforded to the claimed embodiments in any way, unless otherwise explicitly stated. The present disclosure may lead to novel and hitherto unknown theories for explaining the conductivity, drainage, resource production, chemical, and functional characteristics of embodiments of the methods, articles, materials, devices, and systems of the present disclosure, and it is further understood that such later-developed theories shall not limit the scope of protection afforded to the present disclosure. 【0115】 Embodiments other than those specifically disclosed in this specification may be included without departing from the spirit or essential characteristics thereof. The described embodiments are to be considered in all respects only as illustrative and not restrictive. The various aspects and embodiments disclosed herein are for illustrative purposes and are not intended to be limiting. The embodiments of the devices, systems, activities, methods, and operations described herein may be used with, within, or by various processes, industries, and operations in addition to the embodiments of the drawings and the embodiments disclosed herein. The embodiments of the various devices, systems, methods, activities, and operations described herein may be used with other processes, industries, and operations that may be developed in the future, existing processes, industries, and operations that may be partially modified based on the teachings of this specification, and other types of gas recovery and valorization systems and methods. Further, the embodiments of the various devices, systems, activities, methods, and operations described herein may be used with each other in different and various combinations. Thus, for example, the configurations provided in the various embodiments of this specification may be used with each other. For example, the components of an embodiment having A, A' and B and the components of an embodiment having A'', C and D may be used with each other in various combinations, such as A, C, D and A, A'', C and D, etc., in accordance with the teachings of this specification. The scope of protection granted to the present invention should not be limited to the specific embodiments, examples, or specific embodiments, configurations, or arrangements described in a particular embodiment, or in a particular drawing. 【0116】 Terms indicating a degree (e.g., "about", "substantially", "generally", etc.) indicate variations that are not structurally or functionally important. In one example, when a term indicating a degree is included with a term indicating a quantity, the term indicating a degree is interpreted to mean ±10%, ±5%, or ±2% of the term indicating a quantity. In one example, when a term indicating a degree is used to modify a shape, the term indicating a degree indicates that the shape modified by the term indicating a degree has the appearance of the disclosed shape. For example, the term indicating a degree may be used to indicate that instead of sharp corners, rounded corners, instead of straight edges, curved edges, one or more protrusions extending therefrom, being elliptical, being the same as the disclosed shape, etc. may be present. 【0117】 (Appendix) (Appendix 1) A method for evaluating the molecular composition of a fluid, comprising: analyzing the proportion of the fluid derived from the source to determine the source of the fluid; quantifying the proportion of the fluid; evaluating the relationship of chemical species in the fluid to verify the source of the fluid. A method comprising the above. 【0118】 (Appendix 2) The method according to Appendix 1, wherein the fluid comprises a gas or a gas mixture containing at least one of hydrogen, helium, noble gas, ammonia, carbon dioxide, hydrogen sulfide, nitrogen, or hydrocarbon gas. 【0119】 (Appendix 3) The method according to Appendix 1, wherein analyzing the proportion of the fluid comprises measuring an element, a molecule, an isotope, or an isotope ratio to identify and characterize the source of the fluid. 【0120】 (Appendix 4) The method according to Appendix 1, wherein the source comprises at least one of subterranean hydrogen, underground formation, coal, steam methane reforming, pyrolysis, autothermal reforming, chemical looping of gas, or electrolysis. 【0121】 (Appendix 5) Quantifying or classifying the source of hydrogen in the fluid, Authenticating the source of the hydrogen in the fluid, wherein the source includes at least one of a natural gas pipeline, a hydrogen pipeline, an oil pipeline, a water pipeline, a railway vehicle, a truck, an industrial and storage facility, a spring, a surface outcrop, an underground storage tank, or a borehole for a mine shaft of oil, natural gas, water, or hydrogen, and authenticating, the method according to Appendix 1, further comprising. 【0122】 (Appendix 6) The method according to Appendix 1, further comprising monitoring for leakage or gas emissions at the source of the fluid. 【0123】 (Appendix 7) The method according to Appendix 1, further comprising verifying and authenticating the proportion of the carbon dioxide stored in the underground storage tank, including the pores or mineralization of the carbon dioxide stored in the underground storage tank. 【0124】 (Appendix 8) The method further includes determining the residence time of the fluid in the underground formation, and determining the residence time is, Analyzing the concentrations of noble gases and the isotopic composition of water, carbon dioxide, or other underground fluids, Using a rock sample core, cutting, or outcrop to analyze the timing of mineral crystallization or recrystallization to derive the timing of hydrogen generation in the underground formation, Measuring uranium, thorium, potassium, or the mineralogical composition and the crustal noble gas content in the mineral, and analyzing the core, cutting, or outcrop to derive the timing of hydrogen generation in the underground formation, the method according to Appendix 1, including. 【0125】 (Appendix 9) The method according to appendix 8, further comprising distinguishing the source of the hydrogen generation according to the timing of the hydrogen generation in the underground formation. 【0126】 (Appendix 10) The method according to appendix 1, further comprising determining the gas saturation rate and the gas-water ratio with respect to hydrogen, methane, natural gas, or carbon dioxide in the fluid, wherein the fluid is collected from the surface or an underground formation. 【0127】 (Appendix 11) A method for analyzing an isotope composition, the method comprising: analyzing the fluid to determine the source of the fluid; analyzing the fluid to determine the proportion of the hydrogen raw material derived from the source of the fluid; quantifying the proportion of the hydrogen raw material derived from the source of the fluid; authenticating the proportion of the hydrogen raw material derived from the source of the fluid; and the like. 【0128】 (Appendix 12) The method according to appendix 11, wherein the fluid comprises at least one of hydrogen, helium, hydrogen sulfide, nitrogen, methane or hydrocarbon gas, water, methanol, synthetic fuel, ammonia, or carbon dioxide. 【0129】 (Appendix 13) The method according to appendix 11, wherein the source comprises at least one of subterranean hydrogen, coal, natural gas, biomass, ammonia, steel manufacturing, chemical synthesis, waste incineration, gas treatment, air recovery, natural gas pipeline, hydrogen pipeline, oil pipeline, water pipeline, railway vehicle, truck, steam methane reforming, pyrolysis, chemical looping, or electrolysis. 【0130】 (Appendix 14) The method according to appendix 11, further comprising verifying and authenticating the proportion of carbon dioxide stored in an underground storage tank containing pores or mineralization. 【0131】 (Appendix 15) Further including determining the carbon raw material in the hydrogen carrier and quantifying the proportion of carbon derived from the hydrogen carrier, wherein the hydrogen carrier includes at least one of coal combustion, natural gas combustion, biomass incineration, ammonia synthesis, steel manufacturing, chemical synthesis, waste incineration, or atmospheric recovery, the method according to Appendix 11. 【0132】 (Appendix 16) The method according to Appendix 11, wherein analyzing the fluid includes comparing the measured isotope ratio of hydrogen from the sample with the data of the isotope ratio of hydrogen for a known hydrogen sample. 【0133】 (Appendix 17) Further including authenticating the hydrogen source in at least one of a natural gas pipeline, a hydrogen pipeline, an oil pipeline, a water pipeline, a railway vehicle, a truck, or an industrial facility, the method according to Appendix 11. 【0134】 (Appendix 18) Further including determining the material composition of hydrogen using the isotope composition of hydrogen to determine, quantify, and verify the proportion of hydrogen, methane or other natural gas, or carbon dioxide derived from the source, the method according to Appendix 11. 【0135】 (Appendix 19) A system for determining information including one or more characteristics of water, hydrogen, methane or other natural gas, carbon dioxide, or noble gas, wherein the system is a chemical analyzer, the molecular composition of a fluid including one or more of the hydrogen, methane or other natural gas, or carbon dioxide, the gas saturation rate and gas-water ratio with respect to the hydrogen, methane or other natural gas, or carbon dioxide, the residence time of hydrogen or carbon dioxide in the fluid, the mass of water, The concentration of helium and other noble gases, and the concentration of isotopes of said helium or other noble gases, and configured to determine said information including at least one of a source of hydrogen, carbon dioxide, or natural gas, a chemical analyzer; A computing device operably connected to said chemical analyzer, wherein said computing device is configured to electronically communicate said information to a remote computing device, and 【0136】 (Appendix 20) The remote computing device is operably coupled to the computing device, and the remote computing device a source of said fluid, a proportion of a hydrogen source derived from said source of said fluid, an amount of the proportion of said hydrogen source derived from said source of said fluid, The system according to Appendix 19, configured to determine. 【0137】 (Appendix 21) The system according to Appendix 19, wherein said chemical analyzer includes at least one of an isotope ratio mass spectrometer, a cavity ring-down spectrometer, a residual gas analyzer, a quadrupole mass spectrometer, a radon detector, a scintillation counter, a gas chromatograph, a gas chromatograph equipped with a flame ionization detector, or a thermal conductivity detector.

Claims

[Claim 1] A method for evaluating the molecular composition of a fluid, To determine the origin of the hydrogen in the fluid, the proportion of the fluid originating from the source is analyzed, wherein the origin of the hydrogen includes at least one of the following: subterranean hydrogen, subsurface geological formations, steam methane reforming, coal, pyrolysis, autothermal reforming, gas chemical looping, or electrolysis. To quantify the aforementioned proportion of the fluid, In order to verify the origin of the hydrogen in the fluid, the relationships between chemical species in the fluid are evaluated by comparing the chemical species in the fluid with statistical data of chemical species from known sources, To quantify or classify the hydrogen source in the aforementioned fluid, To certify the source of the hydrogen in the fluid, that the source of the hydrogen originates from a natural gas pipeline, hydrogen pipeline, oil pipeline, water pipeline, railway vehicle, truck, industrial and storage facility, spring, surface seep, underground storage tank, or borehole. Methods that include... [Claim 2] The method according to claim 1, wherein the fluid comprises a gas or mixture of gases containing at least one of hydrogen, helium, noble gases, ammonia, carbon dioxide, dihydrogen sulfide, nitrogen, or hydrocarbon gases. [Claim 3] The method according to claim 1, wherein analyzing the proportion of the fluid includes measuring the elements, molecules, isotopes, or isotopic ratios of the fluid. [Claim 4] The method according to claim 1, further comprising monitoring for leakage or gas discharge in the source of the fluid. [Claim 5] The method according to claim 1, further comprising verifying and certifying the proportion of carbon dioxide stored in an underground storage tank, including porosity or mineralization of the carbon dioxide stored in the underground storage tank. [Claim 6] The method further includes determining the residence time of the fluid in the underground geological formation, and determining the residence time is Analyzing the concentrations of noble gases, and the isotopic composition of water, carbon dioxide, or other subsurface fluids, Using rock sample cores, cuttings, or outcrops, the timing of mineral crystallization or recrystallization is analyzed to derive the timing of hydrogen generation in the subsurface formation, The method according to claim 1, comprising analyzing the core, cutting, or outcrop to determine the timing of hydrogen generation in the subsurface formation by measuring the uranium, thorium, potassium, or mineralogical composition and the content of crustal noble gases in the minerals. [Claim 7] The method according to claim 6, further comprising distinguishing the hydrogen generation source based on the timing of hydrogen generation in the underground geological formation. [Claim 8] The method according to claim 1, further comprising determining the gas saturation rate and gas-water ratio with respect to hydrogen, methane, natural gas, or carbon dioxide in the fluid, wherein the fluid is collected from the surface or underground geological formation. [Claim 9] A method for analyzing isotopic composition, wherein the method is Analyzing a fluid to determine the origin of hydrogen in the fluid, wherein the origin of the hydrogen includes at least one of the following: subterranean hydrogen, subsurface geological formations, steam methane reforming, coal, pyrolysis, autothermal reforming, gas chemical looping, or electrolysis. To determine the proportion of hydrogen raw materials originating from the source of the hydrogen in the fluid, the fluid is analyzed. To quantify the proportion of the hydrogen raw material originating from the fluid supply source, To certify the proportion of the hydrogen raw material of the fluid that originates from the source, wherein the source of the fluid is one of the following: a natural gas pipeline, a hydrogen pipeline, an oil pipeline, a water pipeline, a railway vehicle, a truck, an industrial and storage facility, a spring, a surface seep, an underground storage tank, or a borehole. Methods that include... [Claim 10] The method according to claim 9, wherein the fluid comprises at least one of hydrogen, helium, dihydrogen sulfide, nitrogen, methane or hydrocarbon gas, water, methanol, synthetic fuel, ammonia, or carbon dioxide. [Claim 11] The method according to claim 9, further comprising verifying and certifying the percentage of carbon dioxide stored in an underground storage tank containing porosity or mineralization. [Claim 12] The method according to claim 9, wherein the analysis of the fluid includes measuring the isotopic ratio of hydrogen from a sample and comparing it with data on the isotopic ratio of hydrogen for known hydrogen samples. [Claim 13] The method according to claim 9, further comprising determining the material composition of hydrogen using the isotopic composition of hydrogen in order to determine, quantify, and verify the proportion of hydrogen, methane, or other natural gas or carbon dioxide originating from the said source. [Claim 14] A system for determining information including one or more properties of water, hydrogen, methane, or other natural gases, carbon dioxide, or noble gases, wherein the system A chemical analysis device, The molecular composition of the fluid containing one or more of the aforementioned hydrogen, methane, other natural gases, or carbon dioxide, The gas saturation rate and gas-water ratio for the aforementioned hydrogen, methane, or other natural gas, or carbon dioxide, The residence time of hydrogen or carbon dioxide in the aforementioned fluid, The mass of water and The concentrations of helium and other noble gases, and the concentrations of isotopes of the helium or other noble gases, By comparing the chemical species in the fluid with statistical data of chemical species from known sources, the sources of hydrogen, carbon dioxide, or natural gas are identified. A device configured to determine the origin of hydrogen in the fluid, which includes at least one of the following: underground hydrogen, subsurface geological formations, steam methane reforming, coal, pyrolysis, autothermal reforming, gas chemical looping, or electrolysis, and information including at least one of the following: Chemical analyzer and A computing device operably connected to the chemical analyzer, wherein the computing device is configured to electronically communicate the information to a remote computing device, A system that includes these features. [Claim 15] The system according to claim 14, wherein the chemical analyzer includes at least one of an isotope ratio mass spectrometer, a cavity ring-down spectrometer, a residual gas analyzer, a quadrupole mass spectrometer, a radon detector, a scintillation counter, a gas chromatograph, a gas chromatograph equipped with a flame ionization detector, or a thermal conductivity detector.

Images