WO2023106935A1 - Procédé de décomposition thermo-catalytique pour production d'hydrogène en milieu marin et en haute mer - Google Patents

Procédé de décomposition thermo-catalytique pour production d'hydrogène en milieu marin et en haute mer Download PDF

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Publication number
WO2023106935A1
WO2023106935A1 PCT/NO2022/050306 NO2022050306W WO2023106935A1 WO 2023106935 A1 WO2023106935 A1 WO 2023106935A1 NO 2022050306 W NO2022050306 W NO 2022050306W WO 2023106935 A1 WO2023106935 A1 WO 2023106935A1
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gas
decomposition
fuel
hydrogen
reactor
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PCT/NO2022/050306
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English (en)
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Juha Laukka
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Rotoboost As
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Priority claimed from NO20211486A external-priority patent/NO20211486A1/no
Priority claimed from NO20211487A external-priority patent/NO20211487A1/no
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Publication of WO2023106935A1 publication Critical patent/WO2023106935A1/fr

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    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B3/00—Hydrogen; Gaseous mixtures containing hydrogen; Separation of hydrogen from mixtures containing it; Purification of hydrogen
    • C01B3/02—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen
    • C01B3/22—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by decomposition of gaseous or liquid organic compounds
    • C01B3/24—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by decomposition of gaseous or liquid organic compounds of hydrocarbons
    • C01B3/26—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by decomposition of gaseous or liquid organic compounds of hydrocarbons using catalysts
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/04—Integrated processes for the production of hydrogen or synthesis gas containing a purification step for the hydrogen or the synthesis gas
    • C01B2203/0465—Composition of the impurity
    • C01B2203/049—Composition of the impurity the impurity being carbon
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/08—Methods of heating or cooling
    • C01B2203/0805—Methods of heating the process for making hydrogen or synthesis gas
    • C01B2203/0811—Methods of heating the process for making hydrogen or synthesis gas by combustion of fuel
    • C01B2203/0816—Heating by flames
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/08—Methods of heating or cooling
    • C01B2203/0872—Methods of cooling
    • C01B2203/0883—Methods of cooling by indirect heat exchange
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/10—Catalysts for performing the hydrogen forming reactions
    • C01B2203/1041—Composition of the catalyst
    • C01B2203/1047—Group VIII metal catalysts
    • C01B2203/1052—Nickel or cobalt catalysts
    • C01B2203/1058—Nickel catalysts
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/10—Catalysts for performing the hydrogen forming reactions
    • C01B2203/1041—Composition of the catalyst
    • C01B2203/1076—Copper or zinc-based catalysts
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/12—Feeding the process for making hydrogen or synthesis gas
    • C01B2203/1258—Pre-treatment of the feed
    • C01B2203/1264—Catalytic pre-treatment of the feed
    • C01B2203/127—Catalytic desulfurisation
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/14—Details of the flowsheet
    • C01B2203/148—Details of the flowsheet involving a recycle stream to the feed of the process for making hydrogen or synthesis gas

Definitions

  • thermo-catalytic decomposition process for hydrogen production in marine and offshore environment A thermo-catalytic decomposition process for hydrogen production in marine and offshore environment
  • the invention relates to the field of new energy technologies for offshore installations and ships, where annual greenhouse gas emissions from the global shipping industry need to be reduced by more than 50% from 2008 to 2050 in response to mandatory regulations issued by the International Maritime Organization (IMO).
  • IMO International Maritime Organization
  • the focus of this field is on new energy technologies in the marine industry and in the ship manufacturing industry that are aimed at sustainable carbon reduction and environmental protection of ships.
  • Fossil fuels currently provide 99% of the industry's final energy demand.
  • IMO International Maritime Organization
  • the policy framework sets key targets, including reducing the annual greenhouse gas emissions from ships engaged in international navigation by at least half compared with the level in 2008 by 2050.
  • the carbon emission intensity of ships engaged in international navigation will be reduced by at least 40% on average, and the carbon emission intensity in 2050 will be reduced by 50% compared with the level in 2008.
  • LNG Liquid natural gas
  • Current transitional new energy technologies for ships include methanol, ammonia, hydrogen etc., or to perform post-combustion carbon capture.
  • the present technology differs from other carbon capture technologies in present technology on achieving direct capture as solid carbon from the fuel, which reduces the initial formation of CO2.
  • Partial or full direct utilization of hydrogen as a fuel is a foreseen long term energy solution.
  • hydrogen storage requires over 3 times more space than LNG storage and provides much less energy per unit volume than conventional fossil fuels. It is well suited as a blend-in or drop-in fuel since already smaller amounts of hydrogen can improve the combustion properties of traditional fuels when used for traditional combustion units such as turbines, engines and boilers.
  • the present invention evades the need for hydrogen storage and is more flexible to adapt to various application scenarios.
  • Electric ships or hydrogen production through electrolysis processes cannot practically be applied in marine transportation. This is because large batteries are very expensive, consume a large amount of the ship's transport volume (reducing the maximum cargo volume), and impose a huge additional weight on the ship (reducing the maximum cargo weight). This is difficult to achieve in terms of economics, operational feasibility and range of energy supply especially for long ocean voyages..
  • the present invention requires much less space and additional weight onboard, and is thus much more adaptable to a large variety of application scenarios.
  • Methanol is a low flash point fuel.
  • the ambient temperature on board is usually higher than the flash point of methanol and ethanol, and this introduces risks when ships apply alcohol fuels.
  • Methanol fuel may cause corrosion to metal materials, and if no corresponding protective measures are taken, it may cause corrosion to the engine.
  • CO2 reduction can also be realized via post combustion carbon capture (CCS) where CO2 is captured into compressed or liquid form via processing exhaust gases.
  • CCS post combustion carbon capture
  • Compressed/liquid CO2 takes up a lot of storage space onboard.
  • the compression/liquefaction process consumes a lot of electricity thus making it unattractive for marine ships not having the required installed power generation onboard.
  • the catalyst used is a molten salt such as a metal halide, which may have some solid metal additives in a carbon complex.
  • the predominant catalyst is a liquid metal mixture, not a salt as a simple salt based catalyst would not have a high enough conversion rate required for the present invention.
  • Salt is used in present innovation optionally to enhance carbon separation. Not as the main catalyst.
  • the present invention proposes a hydrogen production process for thermo- catalytic decomposition of floating/marine/marine units with zero/reduced carbon, which is highly achievable in terms of economy, practicality and safety:
  • the by-product of present process solid carbon, has a high commercial value, thus greatly improving the economy.
  • the method according to the invention is applicable to a wide range of applications: in marine engine applications, this technology will be used to produce partial or main fuel for internal combustion engines, fuel cells, turbines or boilers; in marine vessels, platforms, FPSOs, FSRUs or offshore barges, this technology will be used to achieve zero carbon energy supply.
  • This method is performed as a pyrolysis process and differs from other known hydrogen production method in that there is produced solid carbon and not gaseous carbon dioxide.
  • the reactor temperature is maintained at approximately 800-1050 °C for fast reaction kinetics and good conversion yield in the presence of catalyst with the help of an external heat source. Other temperatures may also exist.
  • the produced hydrogen may be used as a drop in fuel together with LNG/bio-methane for any fuel consumer (such as engine, burner, fuel cell).
  • the hydrogen rich gas can be used directly without any further processing.
  • This use of produced hydrogen as part of fuel mixture will lower the CO2 emissions from vessel.
  • the fuel consumer such as engine, boiler, turbine, fuel cell
  • the produced hydrogen may also be used in fuel cells requiring high purity hydrogen as input, the produced hydrogen rich gas can be further processed with a hydrogen purifying equipment.
  • the purifier 5b may be a pressure swing adsorber or hydrogen purifier based on membrane technology to produce hydrogen gas with very high purity.
  • a further possibility for the produced hydrogen may be that a fraction of the produced hydrogen (or hydrogen rich gas) can be utilized as heat source for heating the reactor chamber. This heating would produce no (or very little) CO2 emissions.
  • the reactor comprises a catalyst to crack the feed gas stream to produced hydrogen gas and solid carbon.
  • the catalyst that are used may preferably be liquid metal made primarily of nickel, bismuth or copper. It may also be a combination the metals.
  • the reaction bed may also contain similar catalyst as fixed bed, fluidized bed, moving bed, or boiling bed. Other possible catalyst materials may also be used.
  • Present invention can simultaneously both significantly reduce the greenhouse gas emissions, and improve the economy of fossil energy use, by optimizing the overall energy savings and emission reduction performance of the marine industry.
  • the present invention is in the field of marine new energy technology, and introduce a thermo-catalytic decomposition hydrogen production process of floating/marine/marine installations with zero/reduced carbon emissions. More specifically, the present invention refers to a system method for converting natural gas or other hydrocarbons on LNG storage and LNG energy supply vessels, which are the mainstream in the marine field nowadays, into hydrogen for use as an energy supply fuel for ships or marine installations, and capture the carbon in the natural gas or other hydrocarbons into solid storage for downstream applications at the time of use, thus achieving low/zero carbon emissions from ship energy supply systems.
  • the invention adopts a novel liquid phase catalyst, which is well separated from hydrogen and product carbon, not easily entrained, and minimal loss in normal operation. It fundamentally solves the problem of intermittent catalyst addition and is suitable for floating / onboard marine environment.
  • the invention uses a catalyst reactor, coupled with a downstream high- efficiency carbon separator, allowing the presented technology to operate with long operating cycle, easy to operate and maintain, and suitable for offshore facilities and marine shipping environments.
  • the invention also relates to a method for thermo-catalytic cracking og hydrogen for offshore facility and marine, wherein the method comprises the following steps: i) leading low-temperature liquified hydrocarbon fuel gas from an offshore facility storage tank or a marine LNG-storage tank, to a gasifier/vaporizer through a low-temperature pump, and heating the low-temperature liquefied fuel gas to gasify the liquified fuel gas, and obtain a gasified fuel gas, ii) heating a cryogenic fuel gas in the upper gas phase space of the storage tank (e.g.
  • Figure 1 discloses a first embodiment of the hydrogen production system according to the present invention.
  • Figure 2 discloses a second embodiment of the hydrogen production system according to the present invention.
  • Figure 3 discloses a third embodiment of the hydrogen production system according to the present invention.
  • Figure 4 discloses a fourth embodiment of the hydrogen production system according to the present invention.
  • the offshore/marine facility storage tank 1 is used to store hydrocarbon gases, preferably LNG storage tank, and the low temperature liquefied fuel gas A1 is transported to the gasifier/vaporizer 3 through the low temperature pump 2, which is a heat exchanger, using glycol water to heat the low temperature liquefied fuel gas to heat the low temperature liquefied fuel gas into gas, to get the gasified fuel gas B.
  • the low temperature pump 2 which is a heat exchanger, using glycol water to heat the low temperature liquefied fuel gas to heat the low temperature liquefied fuel gas into gas, to get the gasified fuel gas B.
  • This part of the fuel gas will be divided into several streams B1 , B2, and part of it is used in the system for heating part of it for after gasification, part of the fuel gas B4 is preconditioned by the pretreatment system 4 to (e.g.) remove the sulfur component of the feed gas to obtain feed gas C suitable for injection into the reactor 6, which is heated by the preheater 5 to get the reaction feed gas D.
  • the heated reaction feed gas D enters the decomposition reactor 6 to participate in the reaction, and the reaction product E is obtained after the decomposition reactor, 6 and the reaction product E, mainly contains solid carbon, hydrogen, unreacted raw gas, and part of the entrained catalyst, is led to a separation tank 7, for removal of solid carbon.
  • the separated solid carbon will enter the solid carbon collection tank 14, and the gas phase decomposition gas F will be cooled by a cooler 8, where the high temperature decomposition gas will be cooled by cooling water, and then compressed by a compressor 9 (optional) and transported to a decomposition gas buffer tank 10.
  • a part of the fuel gas B3 from the gasifier/vaporizer 3 is mixed with air I into a burner 13 for combustion, and the heat generated by combustion provides heat for the decomposition reaction in the decomposition reactor 6, and the high temperature exhaust gas J from combustion enters ta preheater 5 for heating the feed gas C to the reactor 6.
  • Part of the fuel gas B2 from the gasifier/vaporizer 3 enters a gas buffer tank 11 , and when needed, the fuel gas E from the gas buffer tank 11 is mixed with the decomposition gas Q from the buffer tank 10 and through the control valve 20 and then enters the engine system 12 as fuel. When needed, the fuel gas is mixed with the decomposition gas through the control valve 20 and then enters the engine system 12 as fuel.
  • the present system involves a main reaction taking place in a reactor 6 which reacts at a temperature of about 600-1150°C.
  • This system also involves a high temperature valve 15a, 15b, 15c, which consists of a high temperature resistant material and a specific sealing structure, capable of withstanding very high temperatures, at a high temperature of about 600-1150°C, for transporting the high temperature decomposition gas after the reaction, for transporting the high temperature catalyst from the separation tank 7 back to the reactor, and for transporting the high temperature solid carbon separated from the separation tank to the solid carbon collection tank.
  • a high temperature valve 15a, 15b, 15c which consists of a high temperature resistant material and a specific sealing structure, capable of withstanding very high temperatures, at a high temperature of about 600-1150°C, for transporting the high temperature decomposition gas after the reaction, for transporting the high temperature catalyst from the separation tank 7 back to the reactor, and for transporting the high temperature solid carbon separated from the separation tank to the solid carbon collection tank.
  • the system also involves a high temperature pump 16, which is a submerged pump in the reactor 6, consisting of a high temperature resistant material, fluid passage structure, and sealing system for transporting liquid catalyst , or catalyst formed of small solid particles at high temperatures of about 600- 1150°C.
  • a high temperature pump 16 which is a submerged pump in the reactor 6, consisting of a high temperature resistant material, fluid passage structure, and sealing system for transporting liquid catalyst , or catalyst formed of small solid particles at high temperatures of about 600- 1150°C.
  • the system also involves a high temperature resistant level measuring instrument 17a, 17b, which uses a non-contact way (laser or radar, etc.) to measure the level height in the reactor 6 and separation tank 7 at high temperatures.
  • a high temperature resistant level measuring instrument 17a, 17b which uses a non-contact way (laser or radar, etc.) to measure the level height in the reactor 6 and separation tank 7 at high temperatures.
  • the system also involves a high temperature measurement system 18a, 18b, placed in the reactor 6 and separation tank 7, respectively, which consists of hot spot thermocouple, protection tube, etc.
  • the protection tube prevents the thermocouple from being corroded by high temperature catalyst and high temperature decomposition gas to ensure the normal operation of the thermocouple.
  • the system also involves a structural design for the main reaction section, which consists of high temperature and corrosion resistant materials, sealed system structural design, system self-adaptive functions at high temperatures of 600-1150°C and suitable for use in marine environment.
  • the term "fuel gas" streams should be interpreted as a fluid suitable for use as a fuel or energy supply in an energy generation system.
  • the feed fuel stream may be natural gas, biogas, LPG, naphtha, diesel, and other hydrocarbons.
  • the most common component of the feed fuel stream is methane, but other hydrocarbons suitable for hydrogen conversion may also be used.
  • the fuel stream can be in the gas phase, such as evaporated gas from a tank or from a fuel gas supply system. It can also be in liquid phase directly from the tank and evaporated in a preheat stage prior to the reactor.
  • mixture should be interpreted as a fluid stream containing a mixture of the main fuel stream and the resulting hydrogen-rich gas that will be fed into the energy generation system of the marine vessel or facility.
  • GHG greenhouse gas
  • FPSO Floating Liquefied Natural Gas Production, Storage and Offloading Unit.
  • FSRU a natural gas floating storage and regasification unit.
  • the term "energy generation system” shall be interpreted to mean a device that provides energy to marine equipment such as engines, fuel cells, boilers, turbines, etc. This applies to marine vessels or facilities that are fueled by hydrocarbon gas (e.g., vaporized LNG) or gas generated at the platform, which may use hydrogen-rich gas or mixed fuel streams as fuel or feedstock to produce energy. It may also utilize high purity hydrogen in a chemical processing system or fuel cell.
  • the energy generation system may be, for example, an internal combustion engine for propulsion systems, power generation or the like. It can also be a fuel cell used to generate electricity.
  • gas cracking system should be interpreted as a system in which at least a portion of the fuel stream undergoes a cracking process to break down into hydrogen and solid carbon. This method is carried out in a thermo-catalytic decomposition process at high temperatures and in the absence of oxygen, where the elemental carbon is produced as solid carbon instead of carbon dioxide.
  • fuel supply system shall be interpreted as a system that moves the feed fuel stream from the fuel storage facility to the energy generation system.
  • hydrogen rich gas shall be interpreted as the crude hydrogen gas obtained during the cracking process after the carbon has been removed.
  • the resulting hydrogen-rich gas is not only pure hydrogen, but may also include some residual fuel feed. This indicates that the gas includes other residual components in addition to hydrogen.
  • Hydrogen rich gas can also refer to desorption gas, which is hydrogen rich waste gas from a hydrogen purifier when high purity hydrogen is required as a product of a conventional fuel cell. Desorption gas can be used to heat the reactor. Both gases include residual components other than hydrogen.
  • feed should be interpreted as the fuel, energy or feed that is fed to a process such as a cracking process or energy production process.
  • the piping shown in the figures connecting the various parts of the system is the piping that allows fluid to flow between the various components of the system.
  • reference numbers and descriptions refer to the fluid suitable for flow within the pipe or tube.
  • Figure 2 show second embodiment of the present invention for LNG ships, using LNG on board the ship to convert LNG into hydrogen through gas cracking system 30 to supply energy for ship operation and reduce carbon dioxide emissions in ship operation.
  • the LNG in the marine LNG storage tank as feed gas A6 or A5 is preheated to a certain temperature by preheater 5, and the preheated feed gas D is passed into the reactor to react in the reactor to produce reaction gas product E and high-density solid carbon EC1 .
  • the high- temperature reaction gas product E contains hydrogen gas generated by the reaction, unreacted feed gas, and low-density carbon carried out by the gas stream, and is separated in the gas-solid separator 7 for separation of high temperature gas product F.
  • the resulting low-density carbon EC2 is collected with the high-density carbon EC1 into the carbon storage tank on the ship for later delivery to further processing.
  • the separated high-temperature decomposition gas F is used to preheat the feed gas C in the pre-heater 5 to cool down the high-temperature decomposition gas F to become the decomposition gas G whose composition is monitored with the gas analyzer 28a, and then the cooled down decomposition G gas is passed into the hydrogen purification device 31 to separate out the pure hydrogen gas 31 A.
  • the purified hydrogen gas 31 A enters the combustion chamber 12A on the ship for combustion, and the heat generated by the combustion 12B is utilized by the ship facility.
  • the heat generated by combustion 12B may, for example, provide power to the ship's engine system, and the high temperature water vapor V1 generated by combustion is later passed into the pre-heater 5 to provide heat for preheating of feed gas C and cooled down water vapor/condensate is led into ship condensate system V2, for example for freshwater production.
  • the hydrogen purification device 31 after collecting the hydrogen, the remaining gas is unreacted feed gas 31 B, and this unreacted feed gas 31 B can be led to enter system again for secondary reaction mixed with feed gas A6 and/or A5 to produce feed gas C.
  • a special device 29 may be installed at the bottom of the reactor to maintain stable operation of the reactor in marine environment where reactor may face various movements due to weather conditions (etc.).
  • the natural gas is converted into high value-added carbon products, as well as hydrogen, which is burned to supply energy for ship navigation, changing the way of supplying energy for ship navigation by burning natural gas, achieving the goal of carbon emission reduction for ship energy supply because no carbon dioxide is produced in the process, while producing high value-added carbon products, and at the same time, providing fresh water supply for the life of ship shipping personnel.
  • FIG 3 is shown similar arrangement to Figure 1 with the key distinction that partial stream F2 of produced decomposition gas F is utilized for reactor heating in burner 13, and decomposition gas used for energy supply Q is shown as independent fuel supply to fuel consumer. This example arrangement would minimize the total CO2 emissions in very efficient way.
  • reaction product E which mainly contains solid carbon, hydrogen gas, unreacted feed gas and a small part of entrained catalyst, enters the separation tank 7 for gas, liquid and solid phase separation, and the separated solid carbon enters the solid carbon collection tank 14, and the gas phase decomposition gas F is cooled by cooler 8 (using cooling water to cool the high temperature decomposition gas) and then enters the power generation equipment or/and steam generation equipment 26 to generate electricity or/and produce steam.
  • Fuel gas B3 and air I are separately or mixed into burner 13 for combustion, and the heat generated by combustion provides heat for the decomposition reaction in decomposition reactor 6.
  • the high-temperature exhaust gas J from combustion enters preheater 5 for heating feed gas C
  • A1 low temperature liquefied fuel gas A2 fuel gas delivered to gasifier by low temperature pump; A3 gas phase low temperature fuel gas; A4 heated gas phase fuel gas; A5 compressed fuel gas; A6 gasified/vaporized fuel gas;
  • B1 ,B2,B3,B4 fuel gas fraction streams C preconditioned feed gas; D reaction feed gas; E reaction products; F decomposition gas; G cooled decomposition gas; H compressed decomposition I air; J high temperature exhaust gas; K low temperature exhaust gas; L cooling water inlet; M cooling water outlet; N1 ,N2 glycol water inlet; P1 ,P2 glycol water outlet; Q decomposition gas used for energy supply; R partial fuel gas used for energy supply after gasification; S mixed fuel gas used for energy supply
  • 15a,15b,15c high temperature valve 16 high temperature pump; 17a, 17b high temperature resistant level measuring instrument; 18a, 18b high temperature resistant temperature measuring system; 19a, 19b pressure gauge; 23 offshore oil and gas production platform; 24 oil and gas treatment facility 25 Oil storage tanks; 26 Power generation equipment or/and steam generation equipment B3,B4 fuel gas fraction stream; C preconditioned feed gas; D reaction feed gas; E reaction product; F decomposition gas; G cooled decomposition gas; H compressed decomposition gas; I air; J high temperature exhaust gas; K low temperature exhaust gas; L cooling water inlet; M cooling water outlet; N1 ,N2 glycol water inlet; P1 ,P2 glycol water outlet; T extracted oil and gas; U treated oil; B treated feed gas; V steam; W electric fuel gas for energy supply.

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  • Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Health & Medical Sciences (AREA)
  • General Health & Medical Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Combustion & Propulsion (AREA)
  • Inorganic Chemistry (AREA)
  • Hydrogen, Water And Hydrids (AREA)

Abstract

La présente invention concerne une technologie de production d'hydrogène par craquage thermo-catalytique avec réduction ou absence de carbone pour les installations en haute mer et les navires, et comprend les étapes de processus suivantes : les hydrocarbures, de préférence du gaz naturel, sont transportés par pipeline vers l'unité de traitement préliminaire pour y être prétraités, et les hydrocarbures purifiés et chauffés seront transportés vers l'unité de réaction de décomposition thermocatalytique (unité TCD) pour produire de l'hydrogène brut et du carbone solide. L'hydrogène brut sera refroidi, séparé et pressurisé dans l'unité de post-traitement, puis utilisé comme combustible pour l'unité flottante, tandis que le carbone solide sera refroidi et séparé dans l'unité de post-traitement, puis utilisé comme produit à base de carbone solide. Cette technologie est basée sur une nouvelle unité de réaction de craquage thermocatalytique et sur le catalyseur liquide qu'elle contient, et forme un processus qui permet d'éviter le stockage d'une grande quantité d'hydrogène à bord, de réduire considérablement le coût global de l'hydrogène sans carbone pour une utilisation marine, de résoudre fondamentalement les problèmes actuels d'économie, de praticité et de sécurité de l'utilisation de l'hydrogène comme carburant dans les installations marines et en haute mer, et de faire de l'hydrogène comme carburant marin une réalité.
PCT/NO2022/050306 2021-12-10 2022-12-12 Procédé de décomposition thermo-catalytique pour production d'hydrogène en milieu marin et en haute mer WO2023106935A1 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
NO20211486A NO20211486A1 (en) 2021-12-10 2021-12-10 Method of depressurizing cryogenic marine industry tanks containing Liquified Natural Gas
NO20211487 2021-12-10
NO20211487A NO20211487A1 (en) 2021-12-10 2021-12-10 Method and system for feed supply with reduced CO2 emissions on a marine facility
NO20211486 2021-12-10

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KR102226245B1 (ko) * 2019-12-12 2021-03-10 부산대학교 산학협력단 수소연료 추진 해양 폐기물 처리 선박 및 이를 이용한 해양 폐기물의 처리 방법
WO2021232158A1 (fr) * 2020-05-19 2021-11-25 The University Of British Columbia Production d'hydrogène à partir d'hydrocarbures sans émissions de dioxyde de carbone
US20210380407A1 (en) * 2020-06-03 2021-12-09 Modern Electron Inc. Systems and methods for local generation and/or consumption of hydrogen gas
CN113701043A (zh) * 2021-08-27 2021-11-26 广东海洋大学 一种lng船上氢的制取、储存与燃用的综合系统

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CN116712947A (zh) * 2023-08-02 2023-09-08 罗托布斯特(上海)氢能科技有限公司 近海设施及船用可流动式原料气体催化热裂解系统及工艺
CN116712947B (zh) * 2023-08-02 2024-02-06 罗托布斯特(上海)氢能科技有限公司 近海设施及船用可流动式原料气体催化热裂解系统及工艺

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