WO2023244125A2 - Système de production offshore de carburant - Google Patents

Système de production offshore de carburant Download PDF

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Publication number
WO2023244125A2
WO2023244125A2 PCT/NO2023/050142 NO2023050142W WO2023244125A2 WO 2023244125 A2 WO2023244125 A2 WO 2023244125A2 NO 2023050142 W NO2023050142 W NO 2023050142W WO 2023244125 A2 WO2023244125 A2 WO 2023244125A2
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WIPO (PCT)
Prior art keywords
marine platform
ammonia
hydrogen
liquified
methane
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Application number
PCT/NO2023/050142
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English (en)
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WO2023244125A3 (fr
Inventor
Svein Borge Hellesmark
Göran HERMANSSON
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Stena Power & Lng Solutions As
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Priority claimed from US18/334,860 external-priority patent/US11970404B2/en
Application filed by Stena Power & Lng Solutions As filed Critical Stena Power & Lng Solutions As
Publication of WO2023244125A2 publication Critical patent/WO2023244125A2/fr
Publication of WO2023244125A3 publication Critical patent/WO2023244125A3/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
    • C01B3/04—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by decomposition of inorganic compounds, e.g. ammonia
    • C01B3/047—Decomposition of ammonia
    • 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
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01C—AMMONIA; CYANOGEN; COMPOUNDS THEREOF
    • C01C1/00—Ammonia; Compounds thereof
    • C01C1/003—Storage or handling of ammonia
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01C—AMMONIA; CYANOGEN; COMPOUNDS THEREOF
    • C01C1/00—Ammonia; Compounds thereof
    • C01C1/02—Preparation, purification or separation of ammonia
    • C01C1/04—Preparation of ammonia by synthesis in the gas phase
    • C01C1/0405—Preparation of ammonia by synthesis in the gas phase from N2 and H2 in presence of a catalyst
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B35/00—Vessels or similar floating structures specially adapted for specific purposes and not otherwise provided for
    • B63B35/44—Floating buildings, stores, drilling platforms, or workshops, e.g. carrying water-oil separating devices
    • B63B2035/4473—Floating structures supporting industrial plants, such as factories, refineries, or the like
    • 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
    • C01B2203/80—Aspect of integrated processes for the production of hydrogen or synthesis gas not covered by groups C01B2203/02 - C01B2203/1695
    • C01B2203/84—Energy production

Definitions

  • the present disclosure generally relates to production of fuel for power generation, and more particularly to the production of hydrogen utilizing offshore fuel production facilities.
  • natural gas which is predominantly made up of methane (CH4)
  • natural gas may be burned as fuel in the combustion turbines to produce mechanical power that is converted to electric power by electric generators.
  • CO2 carbon dioxide
  • the environmental impacts of greenhouse gases such as carbon dioxide are known, and therefore, there is a desire to reduce carbon dioxide emissions in the production of electricity by identifying other fuels for combustion turbines.
  • hydrogen as an alternative fuel to natural gas in the production of electricity has been gaining traction.
  • FIG. 1 is an offshore marine system for hydrogen production utilizing liquified ammonia.
  • FIG. 2 is one embodiment of an ammonia cracking system to be used in the offshore marine system of FIG. 1.
  • FIG. 3 is the offshore marine system of FIG. 1 with a liquified natural gas floating storage unit and blending unit for the production of blended fuel.
  • FIG. 4 is an offshore marine system for ammonia production and storage.
  • FIG. 5 is one embodiment of a water purification unit to be used in the offshore marine system of FIG. 4.
  • FIG. 6 is one embodiment of a gaseous hydrogen production system to be used in the offshore marine system of FIG. 4.
  • FIGS. 7A and 7B illustrate one embodiment of a nitrogen production system to be used in the offshore marine system of FIG. 4.
  • FIG. 8 is another embodiment of a nitrogen production system to be used in the offshore marine system of FIG. 4.
  • FIG. 9 is one embodiment of an ammonia production system to be used in the offshore marine system of FIG. 4.
  • FIG. 10 is another embodiment of an ammonia production system to be used in the offshore marine system of FIG. 4.
  • FIG. 11 is another embodiment of an ammonia production system to be used in the offshore marine system of FIG. 4.
  • FIG. 12 is an offshore marine system for hydrogen production utilizing liquified methane.
  • FIG. 13 is one embodiment of a hydrogen production system of FIG. 12 using methane feedgas.
  • FIG. 14 is an offshore marine system for synthetic methane production.
  • FIG. 15 is a schematic of the offshore marine system of FIG. 14.
  • FIG. 16 is one embodiment of a methane production system used on the offshore marine system of FIG. 14.
  • Disclosed herein is a method and system for production of hydrogen fuel at an offshore marine platform where liquified ammonia is delivered and cracked in order to produce gaseous hydrogen, which gaseous hydrogen may be piped to an onshore location for use as fuel in the production of electricity, or alternatively, may be used at the offshore platform to produce electricity.
  • an ammonia cracking system carried on a marine platform is semi -permanently installed offshore.
  • a liquified ammonia storage unit may be positioned adjacent the marine platform to deliver bulk liquified ammonia to the platform for cracking.
  • a liquified ammonia floating storage unit and a floating liquified natural gas storage unit are positioned adjacent the marine platform to allow blending of produced hydrogen with natural gas prior to combustion or pipeline transfer.
  • the hydrogen fuel production system includes an offshore marine platform having a water purification unit for purifying seawater collected from adjacent the marine platform. The purified water is used in an onboard hydrogen production system to produce hydrogen. An onboard nitrogen production system is used to produce nitrogen, after which the in situ produced hydrogen and nitrogen are utilized by an onboard ammonia production system to produced liquified ammonia.
  • the hydrogen fuel production system includes an offshore marine platform having methane treatment system for conversion of methane into hydrogen for production of electricity onboard the marine platform.
  • the hydrogen fuel production system includes an offshore marine platform having a water purification unit for purifying seawater collected from adjacent the marine platform.
  • the purified water is used in an onboard hydrogen production system to produce hydrogen.
  • An onboard carbon dioxide source provides carbon dioxide for reaction with the produced hydrogen to form synthetic methane in a methanation reactor disposed onboard the marine platform.
  • a hydrogen fuel production system 10 includes an offshore marine platform 20 disposed for receipt of liquified ammonia from a liquified ammonia storage unit 26 positioned on or adjacent to marine platform 20.
  • the liquified ammonia storage unit 26 is a liquified ammonia floating storage unit 26 moored adjacent the marine platform 20 and disposed to transfer liquified ammonia to marine platform 20 for processing into gaseous hydrogen fuel.
  • the liquified ammonia floating storage unit 26 may include a plurality of bulk storage tanks 28 for receipt of liquified ammonia delivered from a liquified ammonia transport vessel 30.
  • the total liquified cargo storage capacity of the liquified ammonia transport vessel 30 is smaller than the total liquified ammonia storage capacity of the liquified ammonia storage unit 26 such that liquified ammonia storage unit 26 can be utilized as a collection or gather point for bulk storage of smaller volumes of liquified ammonia delivered by liquified ammonia transport vessel 30.
  • liquified ammonia floating storage unit 26 has a first total liquified ammonia storage volume and liquified ammonia transport vessel 30 has a second total liquified ammonia storage volume that is less than the first total liquified ammonia storage volume.
  • marine platform 20 includes at least one platform deck 21 and three or more platform legs 23, where each platform leg 23 has a first end 23a and a second end 23b.
  • Platform deck 21 is disposed adjacent the first end 23a of each platform leg 123 and supported above the ocean surface 25.
  • the second end 23b of each platform leg 123 may engage the seabed 27.
  • Hydrogen fuel production system 10 may include one or more seawater intakes 29 to draw in seawater for use in the hydrogen production process. While seawater intakes 29 are not limited to a particular system for drawing in seawater, in one or more embodiments, one or more seawater intake(s) 29 may be disposed adjacent the second end 23b of a platform leg 23 of marine platform 20 to draw in cooler water from the adjacent body of seawater, while in other embodiments, seawater intake 29 is disposed between the first and second leg ends 23a, 23b, respectively, of a platform leg 23, adjacent the ocean surface 25, to draw in warmer water from the adjacent body of seawater. The vertical height of seawater intake 29 may be adjusted based on the season to ensure the seawater used in a particular process onboard marine platform 20 is at an optimum temperature.
  • the pretreatment unit 38 may be an expansion valve wherein liquified ammonia converts to gaseous ammonia as the ammonia passes through the expansion valve.
  • pretreatment unit 38 may be a heat exchanger for heating liquified ammonia, i.e., cryogenic ammonia, pumped from floating storage unit 26. Upon heating, the liquified ammonia converts into gaseous ammonia.
  • pretreatment unit 38 may be considered a regasification unit for converting liquified ammonia to gaseous ammonia.
  • the ammonia is introduced into cracking reactor 40 which produces a product gas mixture of hydrogen and nitrogen from the gaseous ammonia.
  • the product gas mixture may be introduced into a hydrogen purification unit 42 onboard marine platform 20 in order to produce purified hydrogen from the product gas mixture.
  • the combustion turbines 48 are in fluid communication, either directly or indirectly, with the ammonia cracking system 36 or hydrogen purification unit 42 in order to utilize at least a portion of the produced hydrogen for fuel in the combustion turbines 148. Nitrogen from the hydrogen purification unit 42 may be released into the atmosphere. Additionally, in one or more embodiments, heat produced from the combustion turbines 48 may be utilized by ammonia cracking system 36, as a heat source for pretreatment unit 38 and/or cracking reactor 40 or for other heating purposes. Likewise, electricity produced from the electric generators 50 may be utilized by ammonia cracking system 36 to operate ammonia cracking system 36.
  • FIG. 2 one embodiment of ammonia cracking system 36 is illustrated in more detail by a flow diagram.
  • a cryogenic pump 54 is utilized to pump liquified ammonia along a flowline 57 from a cryogenic storage tank 28, such as may be carried on liquified ammonia floating storage unit 26, to cracking reactor 40.
  • a pretreatment unit 38 may be disposed along flowline 57.
  • pretreatment unit 38 is shown as heat exchanger 38 that is utilized to convert the liquified ammonia to gaseous ammonia.
  • Heat exchanger 38 includes a vessel 55, with a liquified ammonia inlet 56, and a gaseous ammonia outlet 58.
  • Cracking reactor 40 includes a reactor vessel 72 where gaseous ammonia is dissociated in a reaction chamber 73.
  • cracking reactor 40 may be a catalytic cracking reactor 40 having a catalyst 74 disposed therein.
  • catalyst 74 may be nickel or other metallic catalyst, but may be any other type of catalyst.
  • heat from a heat source 76 is applied to reactor vessel 72 to supply heat to reaction chamber 73.
  • the heat from heat source 76 may be applied via a heat exchanger 78 disposed adjacent reactor vessel 72.
  • the heat source 76 may be heating coils or elements disposed adjacent reactor vessel 72. It will be understood that the disclosure is not limited to a particular type of cracking reactor, nor individual components thereof described herein.
  • gaseous ammonia is dissociated within cracking reactor 40 to yield a product gas mixture of hydrogen and nitrogen, which gaseous product mixture exits cracking reactor 40 via a product gas outlet 80.
  • the product gas mixture exiting cracking reactor 40 via product gas outlet 80 can then be introduced into a hydrogen purification unit 82 for further processing.
  • hydrogen purification unit 82 may include an inlet 84 in fluid communication with the product gas outlet 80 of the cracking reactor 40.
  • the gaseous product mixture from cracking reactor 40 may first be utilized in heat exchanger 38 to preheat liquified ammonia from cryogenic storage tanks 28 before the gaseous product mixture is introduced into hydrogen purification unit 82.
  • marine platform 20 may further include an LNG regasification unit 96 and a blending unit 98 disposed to receive gaseous hydrogen and gaseous natural gas and produce a blended natural gas.
  • LNG regasification unit 96 and a blending unit 98 disposed to receive gaseous hydrogen and gaseous natural gas and produce a blended natural gas.
  • a liquified natural gas floating storage unit 90 may also be provided at marine platform 20.
  • liquified natural gas floating storage unit 90 is shown as a liquified natural gas floating storage unit 90 moored adjacent the marine platform 20 and having bulk storage tanks 92 for receipt of liquified natural gas (LNG1) delivered from an external source 94, such as a liquified natural gas transport vessel.
  • LNG1 liquified natural gas
  • the amount of hydrogen in the delivered natural gas may be minimal, such as less than .5% in some embodiments, or less than 1% in other embodiments or less than 3% in yet other embodiments.
  • the percentage of hydrogen in the delivered natural gas is simply less than a desired percentage of hydrogen in a blended fuel.
  • marine platform 20 may have at least a first side 20a and a second side 20b with liquified ammonia floating storage unit 26 moored adjacent the first side 20a of marine platform 20 and liquified natural gas floating storage unit 90 moored adjacent the second side 20b of marine platform 20.
  • LNG regasification unit 96 is utilized to convert the delivered liquified natural gas back into gaseous natural gas, after which the natural gas can be blended with the purified hydrogen in blending unit 98 to produce a blended fuel having a higher percentage of hydrogen than the originally delivered LNG1.
  • LNG1 as delivered may have a first percentage of hydrogen and the blended fuel (LNG2) may have a second percentage of hydrogen that is higher than the first percentage of hydrogen.
  • the blended fuel can then be transmitted so another location via pipeline 44 and/or combusted as fuel in combustion turbines 48.
  • purified hydrogen may be transmitted via pipeline 44 while blended fuel may be utilized onboard marine platform 20 in combustion turbines 48. It will be appreciated that combustion turbines 48 may not be rated or designed to combust purified hydrogen, and thus the need for blending at marine platform 20, but unblended purified hydrogen may be desired at another location, thus the transmission of unblended, purified hydrogen via pipeline 44.
  • the above-described system is desirable because it moves the handling of toxic ammonia away from populated areas, reducing the dangers associated with handling of ammonia. Moreover, it provides a solution to the bulk transport and storage of ammonia at a hydrogen fuel production system prior to dissociation in the production of hydrogen fuel.
  • FIG. 4 another embodiment of hydrogen fuel production system 110 is shown in which a marine platform 120 is positioned offshore and includes an ammonia production system 136 for the production of liquified ammonia, which liquified ammonia is then bulk stored in a liquified ammonia storage unit 126 on or adjacent marine platform 120.
  • liquified ammonia storage unit 126 is a liquified ammonia floating storage unit 126 and may include a plurality of bulk storage tanks 128 for receipt of liquified ammonia produced onboard marine platform 120.
  • Hydrogen fuel production system 10 therefore includes a first pump to transfer by pumping the produced liquified ammonia NH3 from marine platform 20 to floating storage unit 26.
  • marine platform 120 may be a jack-up platform, a semi-submersible platform, a barge, a buoyant vessel, a fixed platform, a spar platform, or a tension-leg platform which is fixed to the ocean floor or otherwise moored for long periods of deployment in a single location.
  • marine platform 120 may be a floating vessel such as a barge or ship that can be moored in place for long term deployment.
  • marine platform 120 may be a floating vessel such as a barge or ship.
  • marine platform 120 and liquified ammonia floating storage unit 126 are shown separately, they can be integrally formed either on the marine platform 120 or the liquified ammonia floating storage unit 126.
  • Electricity may be provided to marine platform 120 for the production of ammonia by offshore wind turbines 51 disposed in the vicinity of marine platform 120.
  • marine platform 120 includes at least one platform deck 121 and three or more platform legs 123, where each leg 123 has a first end 123a and a second end 123b.
  • Platform deck 121 is disposed adjacent the first end 123a of each platform leg 123 and supported above the ocean surface 125.
  • the second end 123b of each platform leg 123 may engage the seabed 127.
  • liquified ammonia floating storage unit 126 is moored in close proximity to the marine platform 120 so that a continuous flow of liquified ammonia can be maintained therebetween as the liquified ammonia is produced without the need for an intermediate storage, it being understood that in instances where ammonia production unit 136 has a low output volume, the low volume may not allow the liquid to be readily pumped to a storage unit that is a distance removed from the marine platform 120 or directly to a liquified ammonia transport vessel 130.
  • liquified ammonia floating storage unit 126 is desirable because it can be utilized as a collection reservoir for liquified ammonia produced onboard marine platform 120 until a sufficient quantity of liquified ammonia has been produced for transport to another location by liquified ammonia transport vessel 130.
  • liquified ammonia floating storage unit 126 has a first total liquified ammonia storage volume and liquified ammonia transport vessel 130 has a second total liquified ammonia storage volume that is less than the first total liquified ammonia storage volume.
  • ammonia production system 136 utilizes hydrogen (H2) and nitrogen (N2) sourced onboard marine platform 120 to produce the liquified ammonia.
  • marine platform 120 includes a water purification unit 140, a hydrogen production system 142, and a nitrogen production system 146, where the hydrogen production system 142 utilizes purified water from the water purification unit 140 to produce hydrogen for use in the ammonia production system 136.
  • water purification unit 140 utilizes reverse osmosis and includes a water purification vessel 152 having a first chamber 154 and a second chamber 156 with a semi-permeable membrane 158 disposed between the first and second chambers 154, 156.
  • a seawater inlet 160 is provided in the first chamber 154 and a purified water outlet 162 is provided in the second chamber 156.
  • Water purification unit 140 also includes a pump 164 for pressurizing the seawater in the first chamber 154. Pump 164 is in fluid communication with a seawater intake 129 to draw in seawater for purification.
  • seawater intake 129 is disposed adjacent the second end 123b of a platform leg 123 of marine platform 120 to draw in cooler water from the adjacent body of seawater, while in other embodiments, seawater intake 129 is disposed between the first and second leg ends 123a, 123b, respectively, of a platform leg 123, adjacent the ocean surface 125, to draw in warmer water from the adjacent body of seawater.
  • semi-permeable membrane 158 may be any membrane known for use in reverse osmosis, in one or more embodiments, semi -permeable membrane 158 may be a thin polyamide layer ( ⁇ 200 nm) deposited on top of a polysulfone porous layer (about 50 microns) on top of a non-woven fabric support sheet and having a pore size of approximately 0.0001 micron.
  • a purified water storage vessel 166 is fluidically disposed between the purified water outlet 162 of the water purification unit 140 and the hydrogen production system 142.
  • hydrogen production system 142 utilizes electrolysis to produce hydrogen.
  • a hydrogen production vessel 170 is provided, having a first chamber 172 and a second chamber 174 with a membrane 176 disposed between the first and second chambers 172, 174.
  • membrane 176 is a proton exchange membrane (PEM) or alkaline membrane.
  • PEM proton exchange membrane
  • purified water 177 from water purification unit 140 is delivered to hydrogen production vessel 170 via a purified water inlet 178 provided in hydrogen production vessel 170.
  • An anode assembly 180 having an anode 182 extending into first chamber 172 is provided on a first side 176a of the membrane 176, and a cathode assembly 184 having a cathode 186 extending into second chamber 174 is provided on a second side 176b of membrane 176.
  • a power supply 188 electrically couples anode assembly 180 and cathode assembly 184.
  • purified water 177 may be provided in either first chamber 172, second chamber 174 or both, depending on the hydrogen production system 142.
  • a purified water inlet 178 may likewise be provided in either first chamber 172, second chamber 174 or both.
  • an oxygen outlet 190 is provided in first chamber 172 for allowing oxygen 192 to pass therethrough, and a hydrogen outlet 194 is provided in second chamber 174 for allowing hydrogen 196 to pass therethrough.
  • electricity is provided to power supply 188 from wind turbines 51 (see FIG. 4), while in other embodiments, electricity may be provided to power supply 188 from another source, such as electric generators disposed onboard marine platform 120.
  • marine platform 120 also includes a nitrogen production system 146.
  • nitrogen production system 146 Although not limited to a particular nitrogen production system, one embodiment of nitrogen production system 146 is shown in FIG. 7 as a pressure swing adsorption (PSA) nitrogen production system, and another embodiment of nitrogen production system 146 is shown in FIG. 8 as a membrane nitrogen production system. Nitrogen production system 146 may also utilize cryogenic distillation as is known in the art.
  • PSA pressure swing adsorption
  • FIG. 8 membrane nitrogen production system.
  • Nitrogen production system 146 may also utilize cryogenic distillation as is known in the art.
  • Nitrogen production system 146 includes at least one nitrogen production pressure vessel 200.
  • nitrogen production system 146 includes two or more pressure vessels, such as a first pressure vessel 200 and second pressure vessel 202. Regardless of the number of pressure vessels, each pressure vessel 200, 202 of nitrogen production system 146 includes an absorbent assembly 204 disposed to absorb oxygen O2 from a pressurized air stream 205 delivered to pressure vessel 200 by an air compressor 206.
  • Absorbent assembly 204 may be formed of any material utilized to absorb or remove oxygen from air stream 205, and may include an absorbent bed or absorbent membrane as is known in the art.
  • absorbent assembly may be a carbon absorbent bed having a carbon molecular sieve.
  • First pressure vessel 200 includes at least a first port 208 into which pressurized air stream 205 enters first pressure vessel 200.
  • First pressure vessel 200 includes at least a second port 210 from which a nitrogen stream 212 leaves first pressure vessel 200.
  • second pressure vessel 202 includes at least a first port 214 into which pressurized air stream 205 enters second pressure vessel 202.
  • Second pressure vessel 202 includes at least a second port 216 from which a nitrogen stream 212 leaves second pressure vessel 202.
  • Various piping, valves and additional ports may be utilized as is known in the art.
  • nitrogen production system 146 may include a nitrogen production reaction vessel 230 formed of an elongated cylinder 232 formed along a primary axis 233 having a first end 234 and a second end 236 with a cylinder wall 238 extending between the first end 234 and the second end 236.
  • Elongated cylinder 232 is enclosed by a first end wall 232a enclosing the first end 234 of elongated cylinder 232 and a second end wall 232b enclosing the second end 236 of elongated cylinder 232.
  • a polymer fiber membrane 246 is disposed in the reaction vessel 230 between the compressed air inlet 242 and the byproduct outlet 244.
  • the cylinder wall 238 defines an interior 248 of elongated cylinder 232, wherein the compressed air inlet 242 is disposed axially at the first end 234 of the cylinder 232 and the nitrogen gas outlet 240 is disposed axially at the second end 236 of the cylinder 232 and the byproduct outlet 244 is disposed in the cylinder wall 238 radially outward from the primary axis 233.
  • compressed air stream 205 is introduced into the interior 248 of the cylinder 232.
  • the polymer fiber membrane 246 is formed into a plurality of axially extending, elongated tubes 250 parallel with primary axis 233 and disposed in the interior 248 of elongated cylinder 232. In one or more embodiments, polymer fiber membrane 246 is disposed about the interior surface of the cylinder wall 238, while in other embodiments, polymer fiber membrane 246 forms a column or bed between the first end 234 and the second end 236 of the elongated cylinder 232.
  • FIG. 9 illustrates one embodiment of ammonia production system 136.
  • the nitrogen gas and hydrogen gas are comingled and fed together into feed gas inlet 260a of a compressor 260 that compresses the comingled gases into a feed gas stream 262 of hydrogen and nitrogen.
  • Feed gas stream 262 exiting feed gas outlet 260b is then directed to a preheater 264 where the feed gas stream 262 is preheated.
  • a preheater inlet 264a is in fluid communication with feed gas outlet 260b of compressor 260.
  • the heated, pressurized feed gas stream 262 exits preheater 264 via feed gas outlet 264b, after which the heated, pressurized feed gas stream 262 is brought into contact with a catalyst assembly 266 disposed within an ammonia production reactor 268.
  • reactor 268 may be a column formed of an elongated, vertical vessel 270 having a catalyst assembly 266 disposed therein.
  • catalyst assembly 266 may be an iron or iron-based catalyst supported on a catalyst bed as is known in the industry.
  • preheater 264 may be integrally disposed within reactor 268.
  • cooling fluid passes through heat exchanger assembly 284, while in other embodiments, the hot ammonia gas stream passes through heat exchanger assembly 284.
  • liquified ammonia from liquified ammonia outlet 298 may then be collected in a cryogenic storage tank, such as 128 of liquified ammonia floating storage unit 126 shown in FIG. 4.
  • heat exchanger assembly 284 may be utilized to cool the hot ammonia gas stream 273 before introduction into condenser 282, such as is illustrated in FIG. 9.
  • a cooling fluid such as seawater or purified water from water purification unit 140 may be introduced into heat exchanger assembly 284 and circulate therein utilizing an inlet 287a and an outlet 287b.
  • a hydrogen fuel production system 400 is shown in which is a marine platform 420 is positioned offshore for receipt of liquified methane from a liquified methane storage unit 426 positioned on or adjacent to marine platform 420.
  • the liquified methane storage unit 426 is a floating storage unit moored adjacent the marine platform 420 and disposed to transfer liquified methane to marine platform 420 for processing into gaseous hydrogen fuel.
  • the floating liquified methane storage unit 426 may include a plurality of bulk storage tanks 428 for receipt of liquified ammonia delivered from a liquified methane transport vessel 430.
  • the total liquified cargo storage capacity of the liquified methane transport vessel 430 is smaller than the total liquified methane storage capacity of the liquified methane storage unit 426 such that liquified methane storage unit 426 can be utilized as a collection or gather point for bulk storage of smaller volumes of liquified methane delivered by liquified methane transport vessel 430.
  • the heated liquified methane converts into gaseous methane, after which the gaseous methane is introduced into a reactor 441 of hydrogen production system 436 which produces a product gas mixture of hydrogen and other gases from the gaseous methane.
  • the product gas mixture may be introduced into a hydrogen purification unit 442, such as is described above, in order to produce purified hydrogen from the product gas mixture.
  • the produced hydrogen may utilized onboard marine platform 420 to generate electricity.
  • the produced hydrogen is utilized onboard marine platform 420 for power production.
  • marine platform 420 includes one or more combustion turbines 448 to produce mechanical power that is converted to electric power by one or more electric generators 450.
  • Nitrogen from the hydrogen purification unit 442 may be released into the atmosphere.
  • heat produced from the combustion turbines 448 may be utilized by hydrogen production system 436, as a heat 1 source for heat exchanger 439 and/or reactor 441 or for other heating purposes.
  • electricity produced from the electric generators 450 may be utilized by hydrogen production system 436 to operate hydrogen production system 436.
  • pretreatment unit 538 is shown as heat exchanger 538 that is utilized to convert the liquified methane to gaseous methane.
  • Heat exchanger 538 includes a vessel 555, with a liquified methane inlet 556, and a gaseous methane outlet 558.
  • heated product gas mixture from production reactor 540 may be used to provide heat to heat exchanger 538.
  • heat exchanger 538 may be provided with heat from another source, such as the combustion gases resulting from operation of combustion turbines 548.
  • heat exchanger 538 is shown as separate from production reactor 540, in other embodiments, heat exchanger 538 may be integrally formed as part of production reactor 540.
  • heat from a heat source 576 is applied to reactor vessel 572 to supply heat to reaction chamber 573.
  • the heat from heat source 576 may be applied via a heat exchanger 578 disposed adjacent reactor vessel 572.
  • the heat source 576 may be heating coils or elements disposed adjacent reactor vessel 572.
  • heat source 576 may be steam, such as is used in steam reforming.
  • heat source 576 may be plasma. It will be understood that the disclosure is not limited to a particular type of hydrogen production reactor, nor individual components thereof described herein.
  • gaseous methane is dissociated within production reactor 540 to yield gaseous hydrogen and other gases, which gaseous mixture exits production reactor 540 via a product gas outlet 580.
  • the product gas mixture exiting production reactor 540 via product gas outlet 580 can then be introduced into a hydrogen purification unit 582 for further processing.
  • hydrogen purification unit 582 may include an inlet 584 in fluid communication with the product gas outlet 580 of the production reactor 540.
  • the gaseous mixture from production reactor 540 may first be utilized in heat exchanger 538 to preheat liquified methane from cryogenic storage tanks 528 before the gaseous mixture is introduced into hydrogen purification unit 582.
  • hydrogen purification unit 582 is preferred in some embodiments, it will be appreciated that the disclosure is not limited to use of a hydrogen purification unit. Moreover, the disclosure is not limited to a particular type of hydrogen purification unit. Thus, hydrogen purification unit 582 may include, but is not limited to, a pressure swing adsorption (PSA) system having two or more pressure vessels with at least a nitrogen absorbent in each vessel; a membrane separation system utilizing gaseous mixture flow through a membrane to separate hydrogen from other gases; a electrochemical separation system; and a distillation system.
  • PSA pressure swing adsorption
  • purified hydrogen exits hydrogen purification unit 582 through outlet 586.
  • outlet 586 is in fluid communication with one or more combustion turbines 448 mounted on marine platform 420 so that the produced hydrogen can be utilized as fuel in the combustion turbines 448 in order to generate electricity which electricity is then transmitted to remote locations via conveyance system 444, in which case, conveyance system 44 may be an electrical cable.
  • conveyance system may include both a pipeline for conveying a first portion of the hydrogen produced on marine platform 420 and an electrical cable for conveying electricity produced on marine platform 420 using a second portion of the hydrogen produced on marine platform 420.
  • liquified methane storage unit 626 is a liquified methane floating storage unit 626 and may include a plurality of bulk storage tanks 628 for receipt of liquified methane produced onboard marine platform 620.
  • Hydrogen fuel production system 610 therefore includes a first pump to transfer by pumping the produced liquified methane from marine platform 620 to liquified methane floating storage unit 626.
  • marine platform 620 may be a jack-up platform, a semi-submersible platform, a barge, a buoyant vessel, a fixed platform, a spar platform, or a tension-leg platform which is fixed to the ocean floor or otherwise moored for long periods of deployment in a single location.
  • marine platform 620 may be a floating vessel such as a barge or ship that can be moored in place for long term deployment.
  • marine platform 620 may be a floating vessel such as a barge or ship.
  • marine platform 620 and liquified methane floating storage unit 626 are shown separately, they can be integrally formed either on the marine platform 620 or the liquified methane floating storage unit 626. Electricity may be provided to marine platform 620 for the production of methane by one or more offshore wind turbines 51 disposed in the vicinity of marine platform 620.
  • marine platform 620 includes a deck 621 and three or more platform legs 623, where each leg 623 has a first end 623a and a second end 623b.
  • Deck 621 is disposed adjacent the first end 623a of each platform leg 623 and supported above the seawater surface 625.
  • the second end 623b of each platform leg 623 may engage the seabed 627.
  • methane production system 636 utilizes hydrogen (H2) sourced onboard marine platform 620 and a carbon source, such as carbon monoxide (CO) or carbon dioxide (CO2), to produce the liquified methane in a methanation process.
  • H2 hydrogen
  • CO carbon monoxide
  • CO2 carbon dioxide
  • methane produced using hydrogenation as described herein is often referred to as synthetic methane.
  • marine platform 620 includes a water purification unit 640, and a hydrogen production system 642, where the hydrogen production system 642 utilizes purified water from the water purification unit 640 to produce hydrogen.
  • carbon source 643 may be a carbon capture system forming a part of combustion turbine 648 and disposed to receive exhaust gas from combustion turbines 648 on the marine platform 620.
  • carbon source 643 may be a regasification system 645 onboard marine platform 620 for to convert liquified carbon dioxide delivered from an external source, such as a transport vessel similar to transport vessel 630, to gas for use in hydrogen production system 642.
  • carbon source 643 may be a direct air capture (DAC) system 647 onboard marine platform 620 to capture carbon dioxide directly from ambient air. As with the seawater and electricity from offshore wind turbines 51 located in the vicinity of marine platform 620, air for the DAC system 647 is acquired or sourced in situ at or adjacent marine platform 620.
  • DAC direct air capture
  • the produced hydrogen is utilized in combination with carbon from a carbon source 643 to produce methane in the methane production system 636.
  • water purification unit 640 of methane production system 636 is the same as the water purification unit 140 shown in FIG. 6, which utilizes reverse osmosis and includes a water purification vessel 152 having a first chamber 154 and a second chamber 156 with a semi-permeable membrane 168 disposed between the first and second chambers 154, 156.
  • a seawater inlet 160 is provided in the first chamber 154 and a purified water outlet 162 is provided in the second chamber 156.
  • Water purification unit 140 also includes a pump 164 for pressurizing the seawater in the first chamber 154. Pump 164 is in fluid communication with a seawater intake 629 shown in FIG. 13 to draw in seawater for purification.
  • seawater intake 629 is disposed adjacent the second end 623b of a platform leg 623 of marine platform 620 to draw in cooler water from the adjacent body of seawater, while in other embodiments, seawater intake 629 is disposed between the first and second leg ends 623a, 623b, respectively, of a platform leg 623, adjacent the seawater surface 625, to draw in warmer water from the adjacent body of seawater.
  • semi-permeable membrane 168 of FIG. 6 may be any membrane known for use in reverse osmosis
  • semi-permeable membrane 168 may be a thin polyamide layer ( ⁇ 200 nm) deposited on top of a polysulfone porous layer (about 60 microns) on top of a non-woven fabric support sheet and having a pore size of approximately 0.0001 micron.
  • a purified water storage vessel 166 is fluidically disposed between the purified water outlet 162 of the water purification unit 140 and the hydrogen production system 642.
  • purified water 177 from water purification unit 140 or 640 as the case may be is delivered to hydrogen production vessel 170 via a purified water inlet 178 provided in hydrogen production vessel 170.
  • An anode assembly 180 having an anode 182 extending into first chamber 172 is provided on a first side 176a of the membrane 176, and a cathode assembly 184 having a cathode 186 extending into second chamber 174 is provided on a second side 176b of membrane 176.
  • a power supply 188 electrically couples anode assembly 180 and cathode assembly 184.
  • purified water 177 may be provided in either first chamber 172, second chamber 174 or both, depending on the hydrogen production system 142.
  • a purified water inlet 178 may likewise be provided in either first chamber 172, second chamber 174 or both.
  • an oxygen outlet 190 is provided in first chamber 172 for allowing oxygen 192 to pass therethrough
  • a hydrogen outlet 194 is provided in second chamber 174 for allowing hydrogen 196 to pass therethrough.
  • electricity is provided to power supply 188 from wind turbines 61, while in other embodiments, electricity may be provided to power supply 188 from another source, such as electric generators disposed onboard marine platform 620.
  • Methane production system 636 onboard marine platform 620 is not limited to a particular configuration.
  • methane production system 636 may include a methane production reactor or column in which a catalyst system is provided to interact with gaseous hydrogen and gaseous carbon gas pumped therethrough from hydrogen production system 642 in order to produce gaseous methane.
  • methane production system 636 includes a methanation vessel 700 having a gaseous hydrogen inlet 702, a carbon dioxide inlet 704 and a gaseous methane outlet 706.
  • the methanation vessel 700 is an elongated, vertical vessel having a first lower end 700a and a second upper end 700b, wherein the gaseous hydrogen inlet 702 and the carbon dioxide inlet 704 are adjacent the first lower end 700a and the gaseous methane outlet 706 is adjacent the second upper end 700b.
  • a heat source 708 may be thermally coupled to the vessel 700 in order to provide heat for the methanation reaction.
  • the heat source may be one or more combustion turbines 648 on marine platform 620.
  • a catalyst system 710 Disposed within vessel 700 is a catalyst system 710.
  • catalyst system 710 is a metal-based catalyst suspended in a liquified disposed within the methanation vessel.
  • the metal-based catalyst is nickel. In any event, hydrogen and carbon dioxide react within vessel 700 to produce gaseous methane.
  • the system may include an offshore marine platform; at least one ammonia cracking reactor on the marine platform, the ammonia cracking reactor comprising a dissociation vessel having a reaction chamber with a catalyst bed disposed therein, a gaseous ammonia inlet, a product gas outlet, and a heat source disposed to provide heat to the reaction chamber; a regassification unit on the marine platform, with a liquified ammonia inlet and a gaseous ammonia outlet, wherein the gaseous ammonia outlet is in fluid communication with the gaseous ammonia inlet of the dissociation vessel; a liquified ammonia floating storage unit moored adjacent the marine platform and in fluid communication with the liquified ammonia inlet of the regassification unit; a cryogenic pump disposed to pump liquified ammonia from the liquified ammonia floating storage unit to the regassification unit; one or more combustion turbines on the marine platform and
  • the system may include an offshore marine platform; at least one ammonia production system on the marine platform; and a liquified ammonia floating storage unit moored adjacent the marine platform and in fluid communication with the ammonia production system.
  • the system may include an offshore marine platform; a first pump to transfer by pumping the produced liquified ammonia from marine platform to floating storage unit; a water purification unit on the marine platform, the water purification unit having a purified water outlet and a seawater inlet, the seawater inlet in fluid communication with one or more seawater intakes to draw in seawater for purification; a hydrogen production unit on the marine platform, the hydrogen production unit having a hydrogen gas outlet and a purified water inlet, the purified water inlet in fluid communication with the purified water outlet of the water purification unit; a nitrogen production system on the marine platform, the nitrogen production system having a nitrogen gas outlet; an ammonia production system on the marine platform, the ammonia production system having a hydrogen gas inlet in
  • the system may include an offshore marine platform; at least one methane cracking system disposed on the marine platform; a liquified methane floating storage unit moored adjacent the marine platform and in fluid communication with the methane cracking system; a pump to pump liquified methane from the liquified methane storage vessel to the offshore marine platform; and a hydrogen gas conveyance system extending from the offshore marine platform.
  • the catalytic cracking reactor comprises a gaseous ammonia inlet; a reactor vessel having a reaction chamber; a catalyst bed comprising nickel and disposed in the reaction chamber; a heat source disposed to provide heat to the reaction chamber; and a product gas outlet.
  • the ammonia cracking system further comprises a pretreatment unit in fluid communication with the liquified ammonia floating storage unit.
  • the conveyance system comprises both a gas pipeline and an electrical cable.
  • a hydrogen purification unit comprises a pressure swing adsorption (PSA) system.
  • PSA pressure swing adsorption
  • a first pump to transfer by pumping the produced liquified ammonia from marine platform to floating storage unit.
  • a liquified ammonia transport vessel A liquified ammonia transport vessel.
  • the marine platform is a jack-up platform affixed to an ocean floor.
  • the nitrogen production system comprising a pressure swing adsorption (PSA) nitrogen production system.
  • PSA pressure swing adsorption
  • the cylinder wall defines an interior of elongated cylinder, wherein the compressed air inlet is disposed axially at the first end of the cylinder and the nitrogen gas outlet is disposed axially at the second end of the cylinder and the byproduct outlet is disposed in the cylinder wall radially outward from the primary axis; wherein the polymer fiber membrane is disposed about the interior surface of the cylinder wall
  • the liquefaction system comprises a condenser for producing liquified ammonia from ammonia gas stream; and a heat exchanger assembly having a gaseous ammonia inlet in fluid communication with the gaseous ammonia outlet of the ammonia production reactor and a gaseous ammonia outlet in fluid communication with the condenser.
  • the catalyst assembly comprises an iron-based catalyst.
  • the ammonia production system comprises an ammonia production vessel having a first chamber and a second chamber with a membrane disposed between the first and second chambers; a purified water inlet provided in ammonia production vessel and in fluid communication with the water purification unit; a cathode assembly having a cathode extending into first chamber on a first side of the membrane; an anode assembly having an anode extending into second chamber on a second side of membrane; a power supply electrically coupling the anode assembly and cathode assembly; a gaseous nitrogen inlet in fluid communication with nitrogen production system and disposed to introduce gaseous nitrogen into the purified water disposed in first chamber; a gaseous ammonia outlet in the first chamber for allowing ammonia to pass therethrough; and a liquefaction system in fluid communication with the gaseous ammonia outlet, the liquefaction system having a liquid ammonia outlet in fluid communication with the liquified ammonia floating storage unit.
  • the power supply is electrically coupled to one or more of a plurality of wind turbines.
  • the ammonia production system comprises a membrane reactor having an elongated first cylinder extending along an axis and concentrically arranged within an elongated second cylinder extending along axis, wherein the first cylinder is spaced apart from the second cylinder to form an annulus therebetween, the first cylinder defining an interior therein;
  • the first cylinder has a first end and a second end with a cylinder wall extending between ends;
  • the cylinder wall has an inner surface and an outer surface with a plurality of perforations formed in cylinder wall;
  • the second cylinder is formed of a cylinder wall having an inner surface and an outer surface; a first catalyst disposed adjacent the outer surface of the first cylinder; a heat source disposed to provide heat to the first and second cylinders; a second catalyst disposed adjacent the inner surface of the first cylinder; a nitrogen gas inlet in fluid communication with the interior of first cylinder; a hydrogen inlet in fluid communication with the annulus; and an ammonia gas outlet in fluid communication with the
  • the second catalyst is palladium.
  • the first cylinder comprises a plurality of first cylinders.
  • the nitrogen inlet is at a first end of the first cylinder and the ammonia outlet is at a second end of the first cylinder.
  • a hydrogen purification unit disposed on the marine platform and in fluid communication with the methane cracking system.
  • the methane cracking system comprises a pretreatment unit for converting liquified methane to gaseous methane; and a cracking reactor which produces a product gas mixture of at least hydrogen from the gaseous methane.
  • the methane cracking system comprises a cracking reactor having a dissociation vessel with a reaction chamber, a gaseous methane inlet, and a product gas outlet, a heat source operationally connected to the reactor to supply heat to the reaction chamber.
  • a liquified natural gas floating storage unit moored adjacent the marine platform; a first regasification system on the marine platform and in fluid communication with the liquified natural gas floating storage unit; a blending unit on the marine platform and in fluid communication with the first regasification system.
  • the conveyance system comprises an electrical cable electrically coupled to one or more electric generators on board the marine platform.
  • a hydrogen production unit on the marine platform having a hydrogen production vessel having a first chamber and a second chamber with a membrane disposed between the first and second chambers; an anode assembly having an anode extending into first chamber provided on a first side of the membrane; a cathode assembly having a cathode extending into second chamber on a second side of membrane; a power supply electrically coupled to the anode assembly and cathode assembly; an oxygen outlet in first chamber; and a hydrogen gas outlet in second chamber; and a power supply electrically couples anode assembly and cathode assembly.
  • a water purification unit on the marine platform having a water purification vessel with a first chamber and a second chamber, with a semi-permeable membrane disposed between the first and second chambers; and a pump for pressurizing the seawater in the first chamber, wherein the pump is in fluid communication with the one or more seawater intakes; wherein the seawater inlet is disposed in the first chamber; wherein the purified water outlet is disposed in the second chamber.
  • a hydrogen production unit on the marine platform having a hydrogen production vessel having a first chamber and a second chamber with a membrane disposed between the first and second chambers; an anode assembly having an anode extending into first chamber provided on a first side of the membrane; a cathode assembly having a cathode extending into second chamber on a second side of membrane; and a power supply electrically coupled to the anode assembly and cathode assembly; wherein the purified water inlet is disposed in the hydrogen production vessel and the hydrogen gas outlet is in the second chamber.
  • the step of utilizing comprises delivering liquified natural gas to the marine platform, the delivered natural gas having a first hydrogen content; gasifying the delivered natural gas to produce gaseous natural gas; and blending the gaseous natural gas with at least a portion of the gaseous hydrogen produced on the marine platform to produce a blended fuel comprising natural gas with a second hydrogen content greater than the first hydrogen content.
  • Producing carbon gas comprises operating one or more combustion turbines on the marine platform to produce exhaust gas and capturing carbon gas from the combustion turbine exhaust gas.
  • Producing carbon gas comprises operating a carbon capture system on the marine platform.
  • Producing carbon gas comprises removing carbon gas directly from air captured from adjacent the marine platform.

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Abstract

Procédé et système de production offshore de carburant faisant appel à une plateforme marine offshore sur laquelle est montée une unité de production d'ammoniac. L'unité de production d'ammoniac peut produire de l'ammoniac à l'aide de matières premières provenant de sources proches de la plateforme marine, notamment de l'eau de mer et de l'électricité provenant d'éoliennes offshore. L'ammoniac produit peut ensuite être liquéfié et transporté loin de la plateforme marine, ou acheminé vers un emplacement distant par l'intermédiaire d'un pipeline de fond marin. Une partie de l'hydrogène produit en tant que partie du processus de production d'ammoniac peut être utilisée pour faire fonctionner des turbines à combustion embarquées qui peuvent à leur tour entraîner des générateurs électriques à bord de la plateforme marine pour produire de l'électricité.
PCT/NO2023/050142 2022-06-15 2023-06-15 Système de production offshore de carburant WO2023244125A2 (fr)

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US202263366409P 2022-06-15 2022-06-15
US63/366,409 2022-06-15
US18/334,860 US11970404B2 (en) 2022-06-15 2023-06-14 System for offshore production of fuel
US18/334,860 2023-06-14

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WO2023244125A3 WO2023244125A3 (fr) 2024-02-08

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SG11202009995RA (en) * 2018-04-26 2020-11-27 Renam Properties Pty Ltd Offshore energy generation system
KR102516703B1 (ko) * 2018-10-30 2023-03-31 삼성중공업 주식회사 부유식 수소공급장치

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