Systems and methods for the production of hydrogen from geological formations

Abstract

NOT VISIBLE DUE TO STATUS OF PATENT

Description

Systems and Methods for the Production of Hydrogen from Geological FormationsTECHNICAL FIELD

[0001] This relates to systems and methods for the production of hydrogen from geological formations.BACKGROUND

[0002] Hydrogen is required for many chemical processes, and hydrogen production is crucial in any industrialized society. Currently, millions of tons of hydrogen are produced worldwide for use in oil refining, the production of ammonia, and the production of methanol, as a few examples. The global requirement for hydrogen is expected to grow exponentially over the coming decades.

[0003] Hydrogen production is currently based on different but related industrial methods for generating hydrogen gas. Currently, the four main sources for the commercial production of hydrogen include natural gas, oil, coal, and electrolysis of water. Fossil fuels are the dominant source of industrial hydrogen. The majority of hydrogen is produced by steam reforming of natural gas and other light hydrocarbons, partial oxidation of heavier hydrocarbons, and coal gasification. Other methods of hydrogen production include biomass gasification and methane pyrolysis. What is needed in the art are systems and methods for the in-situ production of hydrogen from geologic formations.GENERAL DESCRIPTION

[0004] Systems and methods are disclosed for recovering hydrogen from geological formations with rock matrices. The rock matrices may be permeable or impermeable. A fluid injector is used for the injection of a first fluid into the geological formation. Hydrogen is produced by either increasing reactive surface area or adjusting the chemical composition of the fluid, or both. The produced hydrogen is then recovered.

[0005] In some embodiments, a method for recovering hydrogen from geological formations, includes: injecting a fluid into a geological formation including an impermeable rock matrix, wherein the fluid reacts with the impermeable rock matrix resulting in production of hydrogen; accelerating hydrogen production by increasing reactive surface area and / or adjusting a chemical composition of the fluid; and receiving backflow fluid and produced hydrogen at a surface location.

[0006] In some embodiments, a method for recovering hydrogen from geological formations, includes: drilling a well into a geological formation, wherein the geological formation includes an impermeable rock matrix; injecting a fluid through the well into the geological formation, wherein the fluid reacts with the impermeable rock matrix in the geological formation resulting in production of hydrogen; accelerating hydrogenproduction by increasing reactive surface area and / or adjusting a chemical composition of the fluid; and receiving backflow fluid and produced hydrogen at a surface location.

[0007] In some embodiments, a method for recovering hydrogen from geological formations, includes: injecting a fluid into a geological formation including a permeable rock matrix, wherein the fluid reacts with the permeable rock matrix resulting in production of hydrogen; accelerating hydrogen production by: (i) increasing reactive surface area, (ii) manipulating temperature and / or pressure, and / or (iii) adjusting a chemical composition of the fluid; and receiving injected fluid and produced hydrogen.

[0008] In some embodiments, a method for recovering hydrogen from geological formations, includes: drilling a well into a geological formation, wherein the geological formation includes a permeable rock matrix; injecting a fluid through the well into the geological formation, wherein the fluid reacts with the permeable rock matrix in the geological formation resulting in production of hydrogen; accelerating hydrogen production by increasing reactive surface area and / or adjusting a chemical composition of the fluid; and accumulating injected fluid and produced hydrogen at one of a trap and a topographical high.

[0009] In some embodiments, a system for recovering hydrogen from geological formations, includes: a geological formation including rock matrices, wherein the rock matrices are one of permeable and impermeable; a fluid injector configured to inject a fluid into the geological formation; accelerating hydrogen production by at least one of: increasing a reactive surface area by or with hydraulic fracturing, electric fracturing, matrix acidization with encapsulated acids, explosives, propellants, controlled explosions, wellbore stimulation, and / or well architecture management; and / or adjusting a chemical composition of the fluid; and recovering produced hydrogen.

[0010] In some embodiments, the systems and methods include precipitation and subsequent growth of secondary minerals in a porosity of the geological formation to generate stresses on the rock matrix, which can be sufficient to fracture the rock and open a new reactive surface area.

[0011] The general description is provided to give a general introduction to the described subject matter as well as a synopsis of some of the technological improvements and / or advantages it provides. The general description and background are not intended to identify essential aspects of the described subject matter, nor should they be used to constrict or limit the scope of the claims. For example, the scope of the claims should not be limited based on whether the recited subject matter includes any or all aspects noted in the general description and / or addresses any of the issues noted in the background.DESCRIPTION OF DRAWINGS

[0012] The preferred and other embodiments are described in association with the accompanying drawings in which:

[0013] Fig. 1 depicts natural hydrogen production settings and an example of stimulated hydrogen production.

[0014] Fig. 2 depicts an embodiment of hydrogen production from an impermeable formation.

[0015] Fig. 3 depicts an embodiment of hydrogen production from a permeable formation.

[0016] Fig. 4 depicts an embodiment of hydrogen production workflow.DETAILED DESCRIPTION OF EMBODIMENTS

[0017] Before any embodiments of the present disclosure are explained in detail, it is to be understood that the systems and methods disclosed herein are not limited in their application to the details of construction and the arrangement of components set forth in the following description or illustrated in the accompanying drawings. The systems and methods disclosed herein are capable of other embodiments and of being practiced or of being carried out in various ways. It should be noted that there are many different and alternative configurations, devices, and technologies to which the disclosed embodiments may be applied. The full scope of the embodiments is not limited to the examples that are described below.

[0018] In the following examples of the illustrated embodiments, references are made to the accompanying drawings which form a part hereof, and in which is shown by way of illustration various embodiments in which the systems, methods, processes, and / or apparatuses disclosed herein may be practiced. It is to be understood that other embodiments may be utilized, and that structural and functional changes may be made without departing from the scope of the present disclosure.

[0019] Disclosed herein are systems and methods for the production of hydrogen from geological formations.

[0020] Hydrogen is getting more and more momentum in the energy transition and its usage is expected to increase fivefold by 2050. In this context, the production of natural hydrogen appears as one of the cleanest and cheapest solutions. Naturally occurring hydrogen is produced in the subsurface, where in anoxic conditions, water meets reactive minerals containing Fe2+. The reaction of the iron-bearing minerals leads to the release of iron in solution and its subsequent oxidation to Fe3+while water is reduced to hydrogen. The general reaction can be written as:2FeO + H20 - Fe2O3+ H2(1)

[0021] Serpentinization of olivine Mg(2-X)FexSiO4is one of the main geochemical reactions leading to the reduction of water and the production of naturally occurring hydrogen, but other iron-bearing minerals can lead to the same process (magnetite, pyroxenes, amphibole, biotite, siderite, minnesotaite, serpentine (e.g., greenalite), spinels, pyrite and other iron-bearing sulfide minerals, biotite, clay, chlorite etc.).

[0022] Serpentinization of olivine, is fastest between 250°C and 300°C, leading to rapid and substantial production of hydrogen. These conditions of temperature occur most often at mid-oceanic ridges, at hot spots, or at different orogenic settings where the geothermal gradient is high and ultramafic rocks are present (ultramafic rocks = olivine + pyroxene bearing rocks). Other minerals such as magnetite seem to have a lower temperature optimum — e.g., no more than 250°C.

[0023] Fig. 1 depicts naturally occurring hydrogen production settings as well as an example of stimulated hydrogen. Due to the requirement of temperature, natural hydrogen is often produced at high depth 1 and slowly migrates to the surface 2 where it might accumulate or simply leak to the atmosphere. One goal for natural hydrogen production is to capture the migrating stream 3 or to tap into an accumulation to produce hydrogen 4.

[0024] The systems and methods for hydrogen production disclosed herein mimic and stimulate the hydrogen-producing reaction in selected locations 5. Since hydrogen is a small and very mobile molecule, attempting to intersect a stream can be complicated and risky. Hydrogen accumulation 4 is generally not viewed as a common occurrence, which makes exploiting it less appealing or certain than other options. Stimulated hydrogen 5 relies on finding accessible iron-bearing geological formations to produce hydrogen by stimulating the reaction.

[0025] In order to produce hydrogen from geological formations, in some embodiments, a well may be drilled in the formation into which fluid (water, in some embodiments) is injected. This fluid reacts with the rock, and hydrogen flows from the formation either back to the well in the case of impermeable rocks (Fig. 2), or towards a trap and will accumulate in a topographical high (Fig. 3). Fig. 2 depicts an embodiment of hydrogen production from an impermeable formation. The injection and the production are performed by the same well in the depicted embodiment. Fig. 3 depicts an embodiment of hydrogen production from a permeable formation. Fluid is injected by one well while produced hydrogen migrates to a geological trap where it is collected in the depicted embodiment.

[0026] In general, the target formations do not have a temperature sufficient to allow for economic reaction rates. In other words, the production of hydrogen may be toosmall to lead to a significant stream. To make stimulated hydrogen economic, the chemical production of H2can be accelerated.

[0027] The kinetics of hydrogen production are linked to several steps: the hydrolysis (dissolution) of the primary minerals (e.g., olivine, pyroxenes, amphiboles, siderite...); the oxidation itself; and the inhibition of secondary mineral uptake. If some minerals (e.g., serpentinite, brucite) precipitate faster than oxidation occurs, they may scavenge the Fe2+from the solution, thus preventing it from oxidizing.

[0028] While current literature notes some trends in the kinetics of H2production associated with temperature and pressure, for instance, the presence of some ions such as Ni2+, Al3+, or the presence of some mineral phases (magnetite, spinel), no engineered methods to accelerate the production of hydrogen in the context of stimulated hydrogen currently exist.

[0029] Another fundamental parameter in the production of hydrogen is the specific surface area, i.e., the geometrical area of the rock in contact with the fluid. As dissolution of minerals is a surface process, the rate of hydrogen production is a linear function of the specific surface area.

[0030] Figs. 2-3 depict potential methods to accelerate and improve hydrogen production in an in-situ stimulated hydrogen setting. In some embodiments, this acceleration may be performed both by adjusting the chemical composition of the fluid injected in the subsurface and by optimizing the reactive surface area of the rock in contact with the fluid. In some embodiments, the process may be optimized by removing specific chemicals from the fluid prior to injection. In some embodiments, dissolved oxygen, nitrates, and / or sulfates may be removed from the fluid using chemical processes (such as media-based ion exchange technology), and / or membrane filtration prior to injection.

[0031] Fig. 4 depicts an embodiment of hydrogen production workflow. After initial rock analysis, a preliminary plan for stimulation and catalysis may be designed. The plan can be adapted according to production data.1. Chemical methods to accelerate the chemical reaction leading to hydrogen production and recovery

[0032] In some embodiments, the following solutions may be used to increase the reaction rate of primary mineral hydrolysis and iron oxidation, as well as inhibit the precipitation of unwanted secondary minerals. In some embodiments, they may be used alone, in combination, and at different concentrations:• pH modifiers — e.g., and not limited to: NaOH, HCL• Organic and inorganic compounds — e.g., and not limited to: NH3, CO2, HCO3“, co32-.• Metallic ions: e.g., and not limited to: Ni, Al, and all other metallic ions in the redox list (e.g., Cu, Ti, Cr, Mn, Co, Zn, and the like).• Various metallic compounds / colloids / nanoparticles (magnetite or every size, metal particles (Fe, Cu, Al, Ti, V, Cr, Mn, Co, Zn, and the like), metal oxide particles (e.g., metal oxides of any of the previously mentioned metals, and the like), spinels (Mg, Fe, Al, Ni), metal alloy particles (e.g., Ni, Fe).

[0033] Each of these compounds and components may be used individually, together, sequentially, and in variable amounts. In some embodiments, it is possible to use the same species with different sequential amounts.2. Physical ways to accelerate the chemical reaction• Temperature and pressure manipulation using all or part of the heat and / or pressure generated by in-situ hydrogen production (i.e., exothermic reaction, waste heat from compression, etc.).• Huff & Puff methods whereby the fluids (aqueous solutions) are pumped out of the formation and replaced by a new fluid (solution), which, in some embodiments, may be similar, or different depending on the evolution of the reactivity. (See Fig. 4)3. Stimulation methods for increasing the reactive surface area

[0034] In some embodiments, the following solutions may be used to increase the reactive surface area of the formation and thus physically enhance the reaction rate.• Hydraulic fracturing and electric fracturing. In some embodiments, the actual composition of the fluid used for hydraulic fracturing may include compounds and species described in Section 1 for enhanced optimization.• Matrix acidization with encapsulated acids. In some embodiments, this may be combined with the chemical enhancement described in Section 1.• Well architecture using technologies to increase footprint into formations and optimize intersections with the fracturing network, such as lateral drilling with a jetdrill or a whipstock• Near wellbore stimulation increasing fluid flow by utilizing Plasma Pulse Technology• Use of one or more of explosives, propellant, and controlled explosions to increase and fragment the near wellbore.Additional Embodiments

[0035] The precipitation and subsequent growth of secondary minerals in the porosity of the geological formation can generate stresses on the rock matrix, known sometimes to be sufficient for fracturing the rock and open new reactive surface area.

[0036] The embodiments described above and illustrated in the figures are presented by way of example only and are not intended as a limitation upon the concepts and principles of the present disclosure. As such, it will be appreciated by one having ordinary skill in the art that various changes in the elements and their configuration and arrangement are possible without departing from the spirit and scope of the present disclosure as set forth in the appended claims.Illustrative Embodiments

[0037] The following is a description of various embodiments of the disclosed subject matter. Each embodiment may include one or more of the various features, characteristics, or advantages of the disclosed subject matter. The embodiments are intended to illustrate a few aspects of the disclosed subject matter and should not be considered a comprehensive or exhaustive description of all possible embodiments.

[0038] Pl. A method for recovering hydrogen from geological formations, comprising: injecting a fluid into a geological formation comprising an impermeable rock matrix, wherein the fluid reacts with the impermeable rock matrix resulting in production of hydrogen; accelerating hydrogen production by increasing reactive surface area and / or adjusting a chemical composition of the fluid; and receiving backflow fluid and produced hydrogen at a surface location.

[0039] P2. The method of Pl, further comprising at least one of a rock analysis step and a planning step prior to fluid injection.

[0040] P3. The method of P2, wherein planning is iterative.

[0041] P4. The method of any one of P1-P3, wherein the fluid is injected into the surface location where the backflow fluid is received.

[0042] P5. The method of any one of P1-P4, wherein one or more pH modifiers, organic compounds, inorganic compounds, metallic ions, metallic compounds, and / or metallic colloids are added to the fluid to increase chemical reactivity.

[0043] P6. The method of P5, wherein one or more of the pH modifiers are added to the fluid, and wherein the pH modifiers comprise one or more of NaOH and HC1.

[0044] P7. The method of any one of P5-P6, wherein one or more of the organic compounds and / or the inorganic compounds are added to the fluid, and wherein the organic compounds and / or the inorganic compounds comprise NH3, CO2, HCO3“, co32-.

[0045] P8. The method of any one of P5-P7, wherein one or more of the metallic ions are added to the fluid, and wherein the metallic ions comprise one or more of Ni, Al, Cu, Ti, Cr, Mn, Co, Zn.

[0046] P9. The method of any one of P5-P8, wherein one or more of the metallic compounds and / or the metallic colloids are added to the fluid, and wherein the metallic compounds and / or the metallic colloids comprise one or more of magnetite, Fe particles, Cu particles, Al particles, Mg spinels, Fe spinels, Al spinels, Ni spinels, and / or alloy particles including one or more of Ni, Fe, Cu, Cr, Co, Zn.

[0047] P10. The method of any one of P5-P9, wherein one or more of the pH modifiers, the organic compounds, the inorganic compounds, the metallic ions, the metallic compounds, and / or the metallic colloids are used at different concentrations, in different amounts, sequentially, and / or synchronously.

[0048] Pll. The method of any one of P1-P10, wherein the hydrogen production is accelerated by manipulating temperature and / or pressure using at least a portion of heat and / or pressure generated by the hydrogen production.

[0049] P12. The method of Pll, wherein the portion of the heat and / or pressure generated by the hydrogen production results from an exothermic reaction and / or waste heat from compression.

[0050] P13. The method of any one of P1-P12, wherein the fluid is a first fluid, the method comprising: removing the first fluid from the geological formation; and injecting a second fluid into the geological formation.

[0051] P14. The method of P13, wherein the second fluid is a different composition than the first fluid.

[0052] P15. The method of any one of P1-P14, wherein increasing the reactive surface area comprises: hydraulic fracturing, electric fracturing, matrix acidization with encapsulated acids, explosives, propellants, controlled explosions, wellbore stimulation, and / or well architecture management.

[0053] P16. The method of P15, wherein increasing the reactive surface area comprises the well architecture management, and wherein the well architecture management comprises increasing a footprint and / or optimizing intersections with a fracturing network.

[0054] P17. The method of P16, wherein optimizing the intersections with the fracturing network comprises lateral drilling.

[0055] P18. The method of any one of P1-P17, comprising removing dissolved oxygen, nitrates, and / or sulfates from the fluid before injecting the fluid into the geological formation.

[0056] P19. A method for recovering hydrogen from geological formations, comprising: drilling a well into a geological formation, wherein the geological formation comprises an impermeable rock matrix; injecting a fluid through the well into the geological formation, wherein the fluid reacts with the impermeable rock matrix in the geological formation resulting in production of hydrogen; accelerating hydrogen production by increasing reactive surface area and / or adjusting a chemical composition of the fluid; and receiving backflow fluid and produced hydrogen at a surface location.

[0057] P20. The method of P19, further comprising a rock analysis and / or planning prior to fluid injection.

[0058] P21. The method of P20, wherein the planning is iterative.

[0059] P22. The method of any one of P19-P21, wherein the fluid is injected into the surface location where the backflow fluid is received.

[0060] P23. The method of any one of P19-P22, wherein one or more pH modifiers, organic compounds, inorganic compounds, metallic ions, metallic compounds, and / or metallic colloids are added to the fluid to increase chemical reactivity.

[0061] P24. The method of P23, wherein one or more of the pH modifiers are added to the fluid, and wherein the pH modifiers comprise one or more of NaOH and HC1.

[0062] P25. The method of any one of P23-P24, wherein one or more of the organic compounds and / or the inorganic compounds are added to the fluid, and wherein the organic compounds and / or the inorganic compounds comprise NH3, CO2, HCO3“, co32-.

[0063] P26. The method of any one of P23-P25, wherein one or more of the metallic ions are added to the fluid, and wherein the metallic ions comprise one or more of Ni, Al, Cu, Ti, Cr, Mn, Co, Zn.

[0064] P27. The method of any one of P23-P26, wherein one or more of the metallic compounds and / or the metallic colloids are added to the fluid, and wherein the metallic compounds and / or the metallic colloids comprise one or more of magnetite, Fe particles, Cu particles, Al particles, Mg spinels, Fe spinels, Al spinels, Ni spinels, and / or alloy particles including one or more of Ni, Fe, Cu, Cr, Co, Zn.

[0065] P28. The method of any one of P23-P27, wherein one or more of the pH modifiers, the organic compounds, the inorganic compounds, the metallic ions, the metallic compounds, and / or the metallic colloids are used at different concentrations, in different amounts, sequentially, and / or synchronously.

[0066] P29. The method of any one of P19-P28, wherein the hydrogen production is accelerated by manipulating temperature and / or pressure using at least a portion of heat and / or pressure generated by the hydrogen production.

[0067] P30. The method of P29, wherein the portion of the heat and / or pressure generated by the hydrogen production results from an exothermic reaction and / or waste heat from compression.

[0068] P31. The method of any one of P19-P30, wherein the fluid is a first fluid, the method comprising: removing the first fluid from the geological formation; and injecting a second fluid into the geological formation.

[0069] P32. The method of P31, wherein the second fluid is a different composition than the first fluid.

[0070] P33. The method of any one of P19-P32, wherein increasing the reactive surface area comprises: hydraulic fracturing, electric fracturing, matrix acidization with encapsulated acids, explosives, propellants, controlled explosions, wellbore stimulation, and / or well architecture management.

[0071] P34. The method of P33, wherein increasing the reactive surface area comprises the well architecture management, and wherein the well architecture management comprises increasing a footprint and / or optimizing intersections with a fracturing network.

[0072] P35. The method of P34, wherein optimizing the intersections with the fracturing network comprises lateral drilling.

[0073] P36. The method of any one of P19-P35, comprising removing dissolved oxygen, nitrates, and / or sulfates from the fluid before injecting the fluid into the geological formation.

[0074] P37. A method for recovering hydrogen from geological formations, comprising: injecting a fluid into a geological formation comprising a permeable rock matrix, wherein the fluid reacts with the permeable rock matrix resulting in production of hydrogen; accelerating hydrogen production by: (i) increasing reactive surface area, (ii) manipulating temperature and / or pressure, and / or (iii) adjusting a chemical composition of the fluid; and receiving injected fluid and produced hydrogen.

[0075] P38. The method of P37, further comprising a rock analysis and / or planning prior to fluid injection.

[0076] P39. The method of P38, wherein the planning is iterative.

[0077] P40. The method of any one of P37-P39, wherein the fluid is injected from a first location and at least one of the injected fluid and the produced hydrogen is received at a second location.

[0078] P41. The method of P40, wherein the first location is a surface well.

[0079] P42. The method of any one of P40-P41, wherein the second location is a geological trap.

[0080] P43. The method of any one of P37-P43, wherein one or more pH modifiers, organic compounds, inorganic compounds, metallic ions, metallic compounds, and / or metallic colloids are added to the fluid to increase chemical reactivity.

[0081] P44. The method of P43, wherein one or more of the pH modifiers are added to the fluid, and wherein the pH modifiers comprise one or more of NaOH and HC1.

[0082] P45. The method of any one of P43-P44, wherein one or more of the organic compounds and / or the inorganic compounds are added to the fluid, and wherein the organic compounds and / or the inorganic compounds comprise NH3, CO2, HCO3“, co32-.

[0083] P46. The method of any one of P43-P45, wherein one or more of the metallic ions are added to the fluid, and wherein the metallic ions comprise one or more of Ni, Al, Cu, Ti, Cr, Mn, Co, Zn.

[0084] P47. The method of any one of P43-P46, wherein one or more of the metallic compounds and / or the metallic colloids are added to the fluid, and wherein the metallic compounds and / or the metallic colloids comprise one or more of magnetite, Fe particles, Cu particles, Al particles, Mg spinels, Fe spinels, Al spinels, Ni spinels, and / or alloy particles including one or more of Ni, Fe, Cu, Cr, Co, Zn.

[0085] P48. The method of any one of P43-P47, wherein one or more of the pH modifiers, the organic compounds, the inorganic compounds, the metallic ions, the metallic compounds, and / or the metallic colloids are used at different concentrations, in different amounts, sequentially, and / or synchronously.

[0086] P49. The method of any one of P37-P48, wherein the hydrogen production is accelerated by manipulating temperature and / or pressure using at least a portion of heat and / or pressure generated by the hydrogen production.

[0087] P50. The method of P49, wherein the portion of the heat and / or pressure generated by the hydrogen production results from an exothermic reaction and / or waste heat from compression.

[0088] P51. The method of any one of P37-P50, wherein the fluid is a first fluid, the method comprising: removing the first fluid from the geological formation; and injecting a second fluid into the geological formation.

[0089] P52. The method of P51, wherein the second fluid is a different composition than the first fluid.

[0090] P53. The method of any one of P37-P52, wherein increasing the reactive surface area comprises: hydraulic fracturing, electric fracturing, matrix acidization with encapsulated acids, explosives, propellants, controlled explosions, wellbore stimulation, and / or well architecture management.

[0091] P54. The method of P53, wherein increasing the reactive surface area comprises the well architecture management, and wherein the well architecture management comprises increasing a footprint and / or optimizing intersections with a fracturing network.

[0092] P55. The method of P54, wherein optimizing the intersections with the fracturing network comprises lateral drilling.

[0093] P56. The method of any one of P37-P55, comprising removing dissolved oxygen, nitrates, and / or sulfates from the fluid before injecting the fluid into the geological formation.

[0094] P57. A method for recovering hydrogen from geological formations, comprising: drilling a well into a geological formation, wherein the geological formation comprises a permeable rock matrix; injecting a fluid through the well into the geological formation, wherein the fluid reacts with the permeable rock matrix in the geological formation resulting in production of hydrogen; accelerating hydrogen production by increasing reactive surface area and / or adjusting a chemical composition of the fluid; and accumulating injected fluid and produced hydrogen at one of a trap and a topographical high.

[0095] P58. The method of P57, further comprising a rock analysis and / or planning prior to fluid injection.

[0096] P59. The method of P58, wherein the planning is iterative.

[0097] P60. The method of any one of P57-P59, wherein the fluid is injected from a first location and at least one of the injected fluid and the produced hydrogen is received at a second location.

[0098] P61. The method of P60, wherein the first location is a surface well.

[0099] P62. The method of any one of P60-P61, wherein the second location is a geological trap.

[0100] P63. The method of any one of P57-P62, wherein one or more pH modifiers, organic compounds, inorganic compounds, metallic ions, metallic compounds, and / or metallic colloids are added to the fluid to increase chemical reactivity.

[0101] P64. The method of P63, wherein one or more of the pH modifiers are added to the fluid, and wherein the pH modifiers comprise one or more of NaOH and HC1.

[0102] P65. The method of any one of P63-P64, wherein one or more of the organic compounds and / or the inorganic compounds are added to the fluid, and wherein the organic compounds and / or the inorganic compounds comprise NH3, CO2, HCO3“, co32-.

[0103] P66. The method of any one of P63-P65, wherein one or more of the metallic ions are added to the fluid, and wherein the metallic ions comprise one or more of Ni, Al, Cu, Ti, Cr, Mn, Co, Zn.

[0104] P67. The method of any one of P63-P66, wherein one or more of the metallic compounds and / or the metallic colloids are added to the fluid, and wherein the metallic compounds and / or the metallic colloids comprise one or more of magnetite, Fe particles, Cu particles, Al particles, Mg spinels, Fe spinels, Al spinels, Ni spinels, and / or alloy particles including one or more of Ni, Fe, Cu, Cr, Co, Zn.

[0105] P68. The method of any one of P63-P67, wherein one or more of the pH modifiers, the organic compounds, the inorganic compounds, the metallic ions, the metallic compounds, and / or the metallic colloids are used at different concentrations, in different amounts, sequentially, and / or synchronously.

[0106] P69. The method of any one of P57-P68, wherein the hydrogen production is accelerated by manipulating temperature and / or pressure using at least a portion of heat and / or pressure generated by the hydrogen production.

[0107] P70. The method of P69, wherein the portion of the heat and / or pressure generated by the hydrogen production results from an exothermic reaction and / or waste heat from compression.

[0108] P71. The method of any one of P57-P70, wherein the fluid is a first fluid, the method comprising: removing the first fluid from the geological formation; and injecting a second fluid into the geological formation.

[0109] P72. The method of P71, wherein the second fluid is a different composition than the first fluid.

[0110] P73. The method of any one of P57-P72, wherein increasing the reactive surface area comprises: hydraulic fracturing, electric fracturing, matrix acidization with encapsulated acids, explosives, propellants, controlled explosions, wellbore stimulation, and / or well architecture management.

[0111] P74. The method of P73, wherein increasing the reactive surface area comprises the well architecture management, and wherein the well architecture management comprises increasing a footprint and / or optimizing intersections with a fracturing network.

[0112] P75. The method of P74, wherein optimizing the intersections with the fracturing network comprises lateral drilling.

[0113] P76. The method of any one of P57-P75, comprising removing dissolved oxygen, nitrates, and / or sulfates from the fluid before injecting the fluid into the geological formation.

[0114] P77. A system for recovering hydrogen from geological formations, comprising: a geological formation comprising rock matrices, wherein the rock matrices are one of permeable and impermeable; a fluid injector configured to inject a fluid into the geological formation; accelerating hydrogen production by at least one of: increasing a reactive surface area by or with hydraulic fracturing, electric fracturing, matrix acidization with encapsulated acids, explosives, propellants, controlled explosions, wellbore stimulation, and / or well architecture management; and / or adjusting a chemical composition of the fluid; and recovering produced hydrogen.

[0115] P78. The system of P77, further comprising a rock analysis and / or planning prior to fluid injection.

[0116] P79. The system of P78, wherein the planning is iterative.

[0117] P80. The system of any one of P77-P79, wherein the fluid is injected from a first location and at least one of the injected fluid and the produced hydrogen is recovered at a second location.

[0118] P81. The system of P80, wherein the first location is a surface well.

[0119] P82. The system of any one of P80-P81, wherein the second location is a geological trap.

[0120] P83. The system of any one of P77-P82, wherein one or more pH modifiers, organic compounds, inorganic compounds, metallic ions, metallic compounds, and / or metallic colloids are added to the fluid to increase chemical reactivity.

[0121] P84. The system of P83, wherein one or more of the pH modifiers are added to the fluid, and wherein the pH modifiers comprise one or more of NaOH and HC1.

[0122] P85. The system of any one of P83-P84, wherein one or more of the organic compounds and / or the inorganic compounds are added to the fluid, and wherein the organic compounds and / or the inorganic compounds comprise NH3, CO2, HCO3“, co32-.

[0123] P86. The system of any one of P83-P85, wherein one or more of the metallic ions are added to the fluid, and wherein the metallic ions comprise one or more of Ni, Al, Cu, Ti, Cr, Mn, Co, Zn.

[0124] P87. The system of any one of P83-P86, wherein one or more of the metallic compounds and / or the metallic colloids are added to the fluid, and wherein the metallic compounds and / or the metallic colloids comprise one or more of magnetite, Fe particles, Cu particles, Al particles, Mg spinels, Fe spinels, Al spinels, Ni spinels, and / or alloy particles including one or more of Ni, Fe, Cu, Cr, Co, Zn.

[0125] P88. The system of any one of P83-P87, wherein one or more of the pH modifiers, the organic compounds, the inorganic compounds, the metallic ions, themetallic compounds, and / or the metallic colloids are used at different concentrations, in different amounts, sequentially, and / or synchronously.

[0126] P89. The system of any one of P77-P88, wherein the hydrogen production is accelerated by manipulating temperature and / or pressure using at least a portion of heat and / or pressure generated by the hydrogen production.

[0127] P90. The system of P89, wherein the portion of the heat and / or pressure generated by the hydrogen production results from an exothermic reaction and / or waste heat from compression.

[0128] P91. The system of any one of P77-P90, wherein the fluid is a first fluid, the system comprising: removing the first fluid from the geological formation; and injecting a second fluid into the geological formation.

[0129] P92. The system of P91, wherein the second fluid is a different composition than the first fluid.

[0130] P93. The system of any one of P77-P92, wherein at least one of dissolved oxygen, nitrates, and / or sulfates are removed from the fluid prior to injection using at least one of media-based ion exchange technology, and / or membrane filtration.

[0131] P94. The system of any one of P77-P93, wherein increasing the reactive surface area comprises the well architecture management, and wherein the well architecture management comprises increasing a footprint and / or optimizing intersections with a fracturing network.

[0132] P95. The system of P94, wherein optimizing the intersections with the fracturing network comprises lateral drilling.

[0133] P96. The systems and methods of any of the above claims wherein precipitation and subsequent growth of secondary minerals in a porosity of the geological formation generates stresses on the rock matrix, known sometimes to be sufficient for fracturing the rock and opening a new reactive surface area.General Terminology and Interpretative Conventions

[0134] Articles such as “the,” “a,” and “an” shall be interpreted as connoting the singular or plural. Also, the word “or” when used without a preceding “either” (or other similar language indicating that “or” is unequivocally meant to be exclusive - e.g., only one of x or y, etc.) shall be interpreted to be inclusive (e.g., “x or y” means one or both x or y).

[0135] The term “and / or” shall also be interpreted to be inclusive (e.g., “x and / or y” means one or both x or y). In situations where “and / or” or “or” are used as a conjunction for a group of three or more items, the group shall be interpreted toinclude one item alone, all the items together, or any combination or number of the items.

[0136] The phrase “based on” shall be interpreted to refer to an open set of conditions unless unequivocally stated otherwise (e.g., based on only a given condition). For example, a step described as being based on a given condition can be based on the recited condition and one or more unrecited conditions.

[0137] The term “can,” when used as an auxiliary verb, shall refer to an optional or noncompulsory capability of the described subject matter that is not required to be present in any given embodiment.

[0138] The terms have, having, contain, containing, include, including, and characterized by shall be interpreted to be synonymous with the terms comprise and comprising — i.e., the terms are inclusive or open-ended and do not exclude additional unrecited subject matter. The use of these terms shall also be understood as disclosing and providing support for narrower alternative embodiments where these terms are replaced by “consisting of,” “consisting of the recited subject matter plus impurities and / or trace amounts of other materials,” or “consisting essentially of.”

[0139] Certain features described in the context of separate embodiments can also be implemented in combination in a single embodiment. Conversely, various features described in the context of a single embodiment can also be implemented in multiple embodiments separately or in any suitable subcombination. Moreover, although features may be described in certain combinations and even initially claimed as such, one or more features from a claimed combination can be excised from the combination, and the claimed combination may be directed to a subcombination or variation of a subcombination.

[0140] Many aspects or features are described as being optional, e.g. through the use of the term “can” or otherwise. For the sake of brevity and legibility, this document does not explicitly recite each combination and / or permutation that may be obtained by choosing from the set of optional aspects or features. However, this document is to be interpreted as explicitly disclosing all such combinations and / or permutations. For example, something described as having three optional aspects may be embodied in seven different ways, namely with only one of the three aspects, with any two of the three aspects, or with all three of the aspects.

[0141] Any methods described in this document should not be interpreted to require the steps to be performed in a specific order unless expressly stated otherwise or doing so is literally impossible. The methods should also be interpreted to provide support to perform the recited steps in any sequence unless expressly stated otherwise.

[0142] The example configurations described in this document do not represent all the examples that may be implemented or that are within the scope of the claims. The term “example” shall be interpreted to mean “serving as an example, instance, or illustration,” and not “preferred” or “advantageous over other examples.”

[0143] Unless otherwise indicated, all numbers or expressions, such as those expressing dimensions, physical characteristics, or the like, used in the specification (other than the claims) are understood to be modified in all instances by the term “approximately.” At the very least, and not as an attempt to limit the application of the doctrine of equivalents to the claims, each numerical parameter recited in the specification or claims which is modified by the term “approximately” should be construed in light of the number of recited significant digits and / or by applying ordinary rounding techniques.

[0144] All disclosed ranges are to be understood to encompass and provide support for claims that recite any subranges or any individual values subsumed by each range. For example, a stated range of 1 to 10 should be considered to include and provide support for claims that recite any subranges or individual values that are between and / or inclusive of the minimum value of 1 and the maximum value of 10; that is, all subranges beginning with a minimum value of 1 or more and ending with a maximum value of 10 or less (e.g., 5.5 to 10, 2.34 to 3.56, and so forth) or any values from 1 to 10 (e.g., 3, 5.8, 9.9994, and so forth), which values can be expressed alone or as a minimum value (e.g., at least 5.8) or a maximum value (e.g., no more than 9.9994).

[0145] All disclosed numerical values are to be understood as being variable from 0- 100% in either direction and thus provide support for claims that recite such values (either alone or as a minimum or a maximum - e.g., at least <value> or no more than <value>) or any ranges or subranges that can be formed by such values. For example, a stated numerical value of 8 should be understood to vary from 0 to 16 (100% in either direction) and provide support for claims that recite the range itself (e.g., 0 to 16), any subrange within the range (e.g., 2 to 12.5) or any individual value within that range expressed individually (e.g., 15.2), as a minimum value (e.g., at least 4.3), or as a maximum value (e.g., no more than 12.4).

[0146] The terms recited in the claims should be given their ordinary and customary meaning as determined by reference to relevant entries in widely used general dictionaries and / or relevant technical dictionaries, commonly understood meanings by those in the art, etc., with the understanding that the broadest meaning imparted by any one or combination of these sources should be given to the claim terms (e.g., two or more relevant dictionary entries should be combined to provide the broadest meaning of the combination of entries, etc.) subject only to the following exceptions: (a) if a term is used in a manner that is more expansive than its ordinary and customary meaning, the term should be given its ordinary and customary meaningplus the additional expansive meaning, or (b) if a term has been explicitly defined to have a different meaning by reciting the term followed by the phrase “as used in this document shall mean” or similar language (e.g., “this term means,” “this term is defined as,” “for the purposes of this disclosure this term shall mean,” etc.). References to specific examples, use of “i.e.,” use of the word “invention,” etc., are not meant to invoke exception (b) or otherwise restrict the scope of the recited claim terms. Other than situations where exception (b) applies, nothing contained in this document should be considered a disclaimer or disavowal of claim scope.

[0147] None of the limitations in the claims shall be interpreted as invoking 35 U.S.C. 112(f) unless the words “means for” or “step for” are explicitly recited in the claim.

[0148] Unless explicitly stated otherwise or otherwise apparent from context, terms such as “processing,” “computing,” “calculating,” “determining,” “displaying,” or the like, refer to the action and processes of an electronic computing device including a processor and memory.

[0149] The subject matter recited in the claims is not coextensive with and should not be interpreted as coextensive with any embodiment, feature, or combination of features described or illustrated in this document. This is true even if only a single embodiment of the feature or combination of features is illustrated and described.Composition Related Terminology and Interpretative Conventions

[0150] Values expressed as a percentage, parts of, or a ratio are by weight unless expressly stated otherwise.

[0151] The description of a group or class of materials as suitable or preferred for a given purpose shall be understood as disclosing that a single member of the group or class or a mixture of any two or more members of the group or class are equally suitable or preferred.

[0152] The description of constituents in chemical terms refers to the constituents: (a) at the time of addition to any combination specified in the description and / or (b) generated in situ by chemical reactions with other constituents. The description of the constituents does not preclude other chemical interactions among the constituents of a mixture once mixed unless expressly stated otherwise.

[0153] The description of materials in ionic form additionally implies the presence of sufficient counter ions to produce electrical neutrality for the composition.Incorporation by Reference

[0154] The entire content of each document listed below is incorporated by reference into this document (the documents below are collectively referred to as the “incorporated documents”). If the same term is used in both this document and one ormore of the incorporated documents, then it should be interpreted to have the broadest meaning imparted by any one or combination of these sources unless the term has been explicitly defined to have a different meaning in this document. If there is an inconsistency between any incorporated document and this document, then this document shall govern. The incorporated subject matter should not be used to limit or narrow the scope of the explicitly recited or depicted subject matter.Priority patent documents incorporated by reference:- U.S. Prov. App. No. 63 / 608,941, titled “Systems and Methods for the Production of Hydrogen from Geological Formations,” filed on 12 Dec 2023.

Claims

WHAT IS CLAIMED IS:

1. A method for recovering hydrogen from geological formations, comprising: injecting a fluid into a geological formation comprising an impermeable rock matrix, wherein the fluid reacts with the impermeable rock matrix resulting in production of hydrogen; accelerating hydrogen production by increasing reactive surface area and / or adjusting a chemical composition of the fluid; and receiving backflow fluid and produced hydrogen at a surface location.

2. The method of claim 1, further comprising at least one of a rock analysis step and a planning step prior to fluid injection.

3. The method of claim 2, wherein planning is iterative.

4. The method of claim 1, wherein the fluid is injected into the surface location where the backflow fluid is received.

5. The method of claim 1, wherein one or more pH modifiers, organic compounds, inorganic compounds, metallic ions, metallic compounds, and / or metallic colloids are added to the fluid to increase chemical reactivity.

6. The method of claim 5, wherein one or more of the pH modifiers are added to the fluid, and wherein the pH modifiers comprise one or more of NaOH and HC1.

7. The method of claim 5, wherein one or more of the organic compounds and / or the inorganic compounds are added to the fluid, and wherein the organic compounds and / or the inorganic compounds comprise NH3, CO2, HCO3“, CO32-.

8. The method of claim 5, wherein one or more of the metallic ions are added to the fluid, and wherein the metallic ions comprise one or more of Ni, Al, Cu, Ti, Cr, Mn, Co, Zn.

9. The method of claim 5, wherein one or more of the metallic compounds and / or the metallic colloids are added to the fluid, and wherein the metallic compounds and / or the metallic colloids comprise one or more of magnetite, Fe particles, Cu particles, Al particles, Mg spinels, Fe spinels, Al spinels, Ni spinels, and / or alloy particles including one or more of Ni, Fe, Cu, Cr, Co, Zn.

10. The method of claim 5, wherein one or more of the pH modifiers, the organic compounds, the inorganic compounds, the metallic ions, the metallic compounds, and / or the metallic colloids are used at different concentrations, in different amounts, sequentially, and / or synchronously.

11. The method of claim 1, wherein the hydrogen production is accelerated by manipulating temperature and / or pressure using at least a portion of heat and / or pressure generated by the hydrogen production.

12. The method of claim 11, wherein the portion of the heat and / or pressure generated by the hydrogen production results from an exothermic reaction and / or waste heat from compression.

13. The method of claim 1, wherein the fluid is a first fluid, the method comprising: removing the first fluid from the geological formation; and injecting a second fluid into the geological formation.

14. The method of claim 13, wherein the second fluid is a different composition than the first fluid.

15. The method of claim 1, wherein increasing the reactive surface area comprises: hydraulic fracturing, electric fracturing, matrix acidization with encapsulated acids, explosives, propellants, controlled explosions, wellbore stimulation, and / or well architecture management.

16. The method of claim 15, wherein increasing the reactive surface area comprises the well architecture management, and wherein the well architecture management comprises increasing a footprint and / or optimizing intersections with a fracturing network.

17. The method of claim 16, wherein optimizing the intersections with the fracturing network comprises lateral drilling.

18. The method of claim 1, comprising removing dissolved oxygen, nitrates, and / or sulfates from the fluid before injecting the fluid into the geological formation.

19. A method for recovering hydrogen from geological formations, comprising: drilling a well into a geological formation, wherein the geological formation comprises an impermeable rock matrix; injecting a fluid through the well into the geological formation, wherein the fluid reacts with the impermeable rock matrix in the geological formation resulting in production of hydrogen; accelerating hydrogen production by increasing reactive surface area and / or adjusting a chemical composition of the fluid; and receiving backflow fluid and produced hydrogen at a surface location.

20. The method of claim 19, further comprising a rock analysis and / or planning prior to fluid injection.

21. The method of claim 20, wherein the planning is iterative.

22. The method of claim 19, wherein the fluid is injected into the surface location where the backflow fluid is received.

23. The method of claim 19, wherein one or more pH modifiers, organic compounds, inorganic compounds, metallic ions, metallic compounds, and / or metallic colloids are added to the fluid to increase chemical reactivity.

24. The method of claim 23, wherein one or more of the pH modifiers are added to the fluid, and wherein the pH modifiers comprise one or more of NaOH and HC1.

25. The method of claim 23, wherein one or more of the organic compounds and / or the inorganic compounds are added to the fluid, and wherein the organic compounds and / or the inorganic compounds comprise NH3, CO2, HCO3“, CO32-.

26. The method of claim 23, wherein one or more of the metallic ions are added to the fluid, and wherein the metallic ions comprise one or more of Ni, Al, Cu, Ti, Cr, Mn, Co, Zn.

27. The method of claim 23, wherein one or more of the metallic compounds and / or the metallic colloids are added to the fluid, and wherein the metallic compounds and / or the metallic colloids comprise one or more of magnetite, Fe particles, Cu particles, Al particles, Mg spinels, Fe spinels, Al spinels, Ni spinels, and / or alloy particles including one or more of Ni, Fe, Cu, Cr, Co, Zn.

28. The method of claim 23, wherein one or more of the pH modifiers, the organic compounds, the inorganic compounds, the metallic ions, the metallic compounds, and / or the metallic colloids are used at different concentrations, in different amounts, sequentially, and / or synchronously.

29. The method of claim 19, wherein the hydrogen production is accelerated by manipulating temperature and / or pressure using at least a portion of heat and / or pressure generated by the hydrogen production.

30. The method of claim 29, wherein the portion of the heat and / or pressure generated by the hydrogen production results from an exothermic reaction and / or waste heat from compression.

31. The method of claim 19, wherein the fluid is a first fluid, the method comprising: removing the first fluid from the geological formation; and injecting a second fluid into the geological formation.

32. The method of claim 31, wherein the second fluid is a different composition than the first fluid.

33. The method of claim 19, wherein increasing the reactive surface area comprises: hydraulic fracturing, electric fracturing, matrix acidization with encapsulated acids, explosives, propellants, controlled explosions, wellbore stimulation, and / or well architecture management.

34. The method of claim 33, wherein increasing the reactive surface area comprises the well architecture management, and wherein the well architecture management comprises increasing a footprint and / or optimizing intersections with a fracturing network.

35. The method of claim 34, wherein optimizing the intersections with the fracturing network comprises lateral drilling.

36. The method of claim 19, comprising removing dissolved oxygen, nitrates, and / or sulfates from the fluid before injecting the fluid into the geological formation.

37. A method for recovering hydrogen from geological formations, comprising: injecting a fluid into a geological formation comprising a permeable rock matrix, wherein the fluid reacts with the permeable rock matrix resulting in production of hydrogen; accelerating hydrogen production by: (i) increasing reactive surface area, (ii) manipulating temperature and / or pressure, and / or (hi) adjusting a chemical composition of the fluid; and receiving injected fluid and produced hydrogen.

38. The method of claim 37, further comprising a rock analysis and / or planning prior to fluid injection.

39. The method of claim 38, wherein the planning is iterative.

40. The method of claim 37, wherein the fluid is injected from a first location and at least one of the injected fluid and the produced hydrogen is received at a second location.

41. The method of claim 40, wherein the first location is a surface well.

42. The method of claim 40, wherein the second location is a geological trap.

43. The method of claim 37, wherein one or more pH modifiers, organic compounds, inorganic compounds, metallic ions, metallic compounds, and / or metallic colloids are added to the fluid to increase chemical reactivity.

44. The method of claim 43, wherein one or more of the pH modifiers are added to the fluid, and wherein the pH modifiers comprise one or more of NaOH and HC1.

45. The method of claim 43, wherein one or more of the organic compounds and / or the inorganic compounds are added to the fluid, and wherein the organic compounds and / or the inorganic compounds comprise NH3, CO2, HCO3“, CO32-.

46. The method of claim 43, wherein one or more of the metallic ions are added to the fluid, and wherein the metallic ions comprise one or more of Ni, Al, Cu, Ti, Cr, Mn, Co, Zn.

47. The method of claim 43, wherein one or more of the metallic compounds and / or the metallic colloids are added to the fluid, and wherein the metallic compounds and / or the metallic colloids comprise one or more of magnetite, Fe particles, Cu particles, Al particles, Mg spinels, Fe spinels, Al spinels, Ni spinels, and / or alloy particles including one or more of Ni, Fe, Cu, Cr, Co, Zn.

48. The method of claim 43, wherein one or more of the pH modifiers, the organic compounds, the inorganic compounds, the metallic ions, the metallic compounds, and / or the metallic colloids are used at different concentrations, in different amounts, sequentially, and / or synchronously.

49. The method of claim 37, wherein the hydrogen production is accelerated by manipulating temperature and / or pressure using at least a portion of heat and / or pressure generated by the hydrogen production.

50. The method of claim 49, wherein the portion of the heat and / or pressure generated by the hydrogen production results from an exothermic reaction and / or waste heat from compression.

51. The method of claim 37, wherein the fluid is a first fluid, the method comprising: removing the first fluid from the geological formation; and injecting a second fluid into the geological formation.

52. The method of claim 51, wherein the second fluid is a different composition than the first fluid.

53. The method of claim 37, wherein increasing the reactive surface area comprises: hydraulic fracturing, electric fracturing, matrix acidization with encapsulated acids, explosives, propellants, controlled explosions, wellbore stimulation, and / or well architecture management.

54. The method of claim 53, wherein increasing the reactive surface area comprises the well architecture management, and wherein the well architecture management comprises increasing a footprint and / or optimizing intersections with a fracturing network.

55. The method of claim 54, wherein optimizing the intersections with the fracturing network comprises lateral drilling.

56. The method of claim 37, comprising removing dissolved oxygen, nitrates, and / or sulfates from the fluid before injecting the fluid into the geological formation.

57. A method for recovering hydrogen from geological formations, comprising: drilling a well into a geological formation, wherein the geological formation comprises a permeable rock matrix;injecting a fluid through the well into the geological formation, wherein the fluid reacts with the permeable rock matrix in the geological formation resulting in production of hydrogen; accelerating hydrogen production by increasing reactive surface area and / or adjusting a chemical composition of the fluid; and accumulating injected fluid and produced hydrogen at one of a trap and a topographical high.

58. The method of claim 57, further comprising a rock analysis and / or planning prior to fluid injection.

59. The method of claim 58, wherein the planning is iterative.

60. The method of claim 57, wherein the fluid is injected from a first location and at least one of the injected fluid and the produced hydrogen is received at a second location.

61. The method of claim 60, wherein the first location is a surface well.

62. The method of claim 60, wherein the second location is a geological trap.

63. The method of claim 57, wherein one or more pH modifiers, organic compounds, inorganic compounds, metallic ions, metallic compounds, and / or metallic colloids are added to the fluid to increase chemical reactivity.

64. The method of claim 63, wherein one or more of the pH modifiers are added to the fluid, and wherein the pH modifiers comprise one or more of NaOH and HC1.

65. The method of claim 63, wherein one or more of the organic compounds and / or the inorganic compounds are added to the fluid, and wherein the organic compounds and / or the inorganic compounds comprise NH3, CO2, HCO3“, CO32-.

66. The method of claim 63, wherein one or more of the metallic ions are added to the fluid, and wherein the metallic ions comprise one or more of Ni, Al, Cu, Ti, Cr, Mn, Co, Zn.

67. The method of claim 63, wherein one or more of the metallic compounds and / or the metallic colloids are added to the fluid, and wherein the metallic compounds and / or the metallic colloids comprise one or more of magnetite, Fe particles, Cu particles, Al particles, Mg spinels, Fe spinels, Al spinels, Ni spinels, and / or alloy particles including one or more of Ni, Fe, Cu, Cr, Co, Zn.

68. The method of claim 63, wherein one or more of the pH modifiers, the organic compounds, the inorganic compounds, the metallic ions, the metallic compounds, and / or the metallic colloids are used at different concentrations, in different amounts, sequentially, and / or synchronously.

69. The method of claim 57, wherein the hydrogen production is accelerated by manipulating temperature and / or pressure using at least a portion of heat and / or pressure generated by the hydrogen production.

70. The method of claim 69, wherein the portion of the heat and / or pressure generated by the hydrogen production results from an exothermic reaction and / or waste heat from compression.

71. The method of claim 57, wherein the fluid is a first fluid, the method comprising: removing the first fluid from the geological formation; and injecting a second fluid into the geological formation.

72. The method of claim 71, wherein the second fluid is a different composition than the first fluid.

73. The method of claim 57, wherein increasing the reactive surface area comprises: hydraulic fracturing, electric fracturing, matrix acidization with encapsulated acids, explosives, propellants, controlled explosions, wellbore stimulation, and / or well architecture management.

74. The method of claim 73, wherein increasing the reactive surface area comprises the well architecture management, and wherein the well architecture management comprises increasing a footprint and / or optimizing intersections with a fracturing network.

75. The method of claim 74, wherein optimizing the intersections with the fracturing network comprises lateral drilling.

76. The method of claim 57, comprising removing dissolved oxygen, nitrates, and / or sulfates from the fluid before injecting the fluid into the geological formation.

77. A system for recovering hydrogen from geological formations, comprising: a geological formation comprising rock matrices, wherein the rock matrices are one of permeable and impermeable; a fluid injector configured to inject a fluid into the geological formation; accelerating hydrogen production by at least one of: increasing a reactive surface area by or with hydraulic fracturing, electric fracturing, matrix acidization with encapsulated acids, explosives, propellants, controlled explosions, wellbore stimulation, and / or well architecture management; and / or adjusting a chemical composition of the fluid; and recovering produced hydrogen.

78. The system of claim 77, further comprising a rock analysis and / or planning prior to fluid injection.

79. The system of claim 78, wherein the planning is iterative.

80. The system of claim 77, wherein the fluid is injected from a first location and at least one of the injected fluid and the produced hydrogen is recovered at a second location.

81. The system of claim 80, wherein the first location is a surface well.

82. The system of claim 80, wherein the second location is a geological trap.

83. The system of claim 77, wherein one or more pH modifiers, organic compounds, inorganic compounds, metallic ions, metallic compounds, and / or metallic colloids are added to the fluid to increase chemical reactivity.

84. The system of claim 83, wherein one or more of the pH modifiers are added to the fluid, and wherein the pH modifiers comprise one or more of NaOH and HC1.

85. The system of claim 83, wherein one or more of the organic compounds and / or the inorganic compounds are added to the fluid, and wherein the organic compounds and / or the inorganic compounds comprise NH3, CO2, HCO3“, CO32-.

86. The system of claim 83, wherein one or more of the metallic ions are added to the fluid, and wherein the metallic ions comprise one or more of Ni, Al, Cu, Ti, Cr, Mn, Co, Zn.

87. The system of claim 83, wherein one or more of the metallic compounds and / or the metallic colloids are added to the fluid, and wherein the metallic compounds and / or the metallic colloids comprise one or more of magnetite, Fe particles, Cu particles, Al particles, Mg spinels, Fe spinels, Al spinels, Ni spinels, and / or alloy particles including one or more of Ni, Fe, Cu, Cr, Co, Zn.

88. The system of claim 83, wherein one or more of the pH modifiers, the organic compounds, the inorganic compounds, the metallic ions, the metallic compounds, and / or the metallic colloids are used at different concentrations, in different amounts, sequentially, and / or synchronously.

89. The system of claim 77, wherein the hydrogen production is accelerated by manipulating temperature and / or pressure using at least a portion of heat and / or pressure generated by the hydrogen production.

90. The system of claim 89, wherein the portion of the heat and / or pressure generated by the hydrogen production results from an exothermic reaction and / or waste heat from compression.

91. The system of claim 77, wherein the fluid is a first fluid, the system comprising: removing the first fluid from the geological formation; and injecting a second fluid into the geological formation.

92. The system of claim 91, wherein the second fluid is a different composition than the first fluid.

93. The system of claim 77, wherein at least one of dissolved oxygen, nitrates, and / or sulfates are removed from the fluid prior to injection using at least one of media-based ion exchange technology, and / or membrane filtration.

94. The system of claim 77, wherein increasing the reactive surface area comprises the well architecture management, and wherein the well architecture management comprises increasing a footprint and / or optimizing intersections with a fracturing network.

95. The system of claim 94, wherein optimizing the intersections with the fracturing network comprises lateral drilling.

96. The systems and methods of any of the above claims wherein precipitation and subsequent growth of secondary minerals in a porosity of the geological formation generates stresses on the rock matrix, known sometimes to be sufficient for fracturing the rock and opening a new reactive surface area.