Patent Grant
11958575
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.
It is known to use natural gas, which is predominantly made up of methane (CH4), for heating and generating electricity. In particular, natural gas may be burned as fuel in the combustion turbines to produce mechanical power that is converted to electric power by electric generators. However, upon combustion of the natural gas, carbon dioxide (CO2) is produced as a byproduct. 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. In this regard, the use of hydrogen as an alternative fuel to natural gas in the production of electricity has been gaining traction.
As hydrogen grows in prominence as a fuel, there is a greater need to make it more accessible. However, the primary form of hydrogen production, namely steam methane reforming, in fact results in the production greenhouse gases along with the produced hydrogen. Thus, in addition to accessibility, there is a need to minimize production of greenhouse gases in the production of hydrogen fuel.
For a more complete understanding of the present disclosure and its features and advantages, reference is now made to the following description, taken in conjunction with the accompanying drawings, in which:
Disclosed herein is a method and system for production of hydrogen fuel at an offshore marine platform. Gaseous hydrogen produced by an in situ hydrogen production system on the platform may be piped to an onshore location, or alternatively, may be liquified for transport by a liquefied hydrogen transport vessel. The offshore marine platform includes 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 gaseous hydrogen. A liquified hydrogen storage unit may be positioned adjacent the marine platform to collect in bulk liquified hydrogen produced on the platform until the liquefied hydrogen can be loaded on a transport vessel. In one or more embodiments, in addition to the floating liquified hydrogen storage unit, a floating liquified natural gas storage unit is positioned adjacent the marine platform to allow blending of produced hydrogen with natural gas prior to pipeline transfer. In other embodiments, the offshore marine platform is disposed to blend electricity produced by adjacent offshore wind turbines with electricity produced onboard the marine platform utilizing liquified natural gas stored on a liquified natural gas floating storage unit moored adjacent the marine platform. In one or more embodiments, in addition to the floating liquified natural gas storage unit moored adjacent the marine platform, a floating liquified hydrogen storage unit is positioned adjacent the marine platform so that gaseous hydrogen can be blended with natural gas prior to producing onboard electricity to be blended with electricity from the adjacent wind turbines.
With reference to
In one or more embodiments, liquefied hydrogen transport vessel 130 may be moored at moorings 133 that are spaced apart from liquefied hydrogen floating storage unit 126 and marine platform 120. In such case, a floating transfer terminal 131 may be utilized to transfer liquified hydrogen from the liquefied hydrogen floating storage unit 126 to the liquefied hydrogen transport vessel 130.
In one or more embodiments, 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. In other embodiments, marine platform 120 may be a floating vessel such as a barge or ship that can be moored in place for long term deployment. In other embodiments, marine platform 120 may be a floating vessel such as a barge or ship. Moreover, while marine platform 120 and liquified hydrogen floating storage unit 126 are shown separately, they can be integrally formed either on the marine platform 120 or the liquified hydrogen floating storage unit 126.
In one or more embodiments, marine platform 120 includes at least one platform deck 121 and three or more platform legs 123, where each platform 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.
Hydrogen fuel production system 110 may include one or more seawater intakes 129 to draw in seawater for use in the hydrogen production process. While seawater intakes 129 are not limited to a particular system for drawing in seawater, in one or more embodiments, one or more seawater intake(s) 129 may be 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. The vertical height of seawater intake 129 may be adjusted based on the season to ensure the seawater used in the process is at an optimum temperature for purification and use in the hydrogen production process. In yet other embodiments, a first plurality of seawater intakes 129 may be disposed adjacent the second end 123b of one or more platform legs 123 and a second plurality of seawater intakes 129 may be spaced apart from the second end 123b of one or more platform legs 123. In other words, the first plurality of seawater intakes 129 may be a first distance from the second end 123b of one or more legs 123 and the second plurality of seawater intakes 129 may be a second distance from the second end 123b of one or more legs 123, where the second distance is greater than the first distance. In some embodiments, the second distance may be at least twice the first distance so that seawater in different thermoclines may be used in the processes onboard marine platform 120, taking advantage of warmer mixed water at the surface and the cooler deep water below. For example, the liquefaction units or regasification systems described herein may utilize seawater at a first temperature for heat transfer, while the hydrogen production unit may utilize purified seawater at a second temperature for hydrogen production.
In any event, hydrogen production unit 122 utilizes hydrogen (H 2) from raw materials sourced onboard marine platform 120, i.e., purified water, to produce the liquified hydrogen. Moreover, electricity for hydrogen production unit 122 is provided to marine platform 120 for the production of hydrogen by offshore wind turbines 132 disposed in the vicinity of marine platform 120.
Marine platform 120 also includes a water purification unit 140 to purify seawater where the hydrogen production unit 122 utilizes purified water from the water purification unit 140 to produce hydrogen for use in the hydrogen production unit 122.
In one or more embodiments, prior to liquefaction, a portion of the produced hydrogen may be transmitted to an onshore or near shore location or terminal via a seabed conveyance system 144, such as the illustrated hydrogen gas pipeline conveyance system 144 shown extending away from the marine platform 120 along the seabed 127. Alternatively, or in addition thereto, a portion of the produced hydrogen may be utilized onboard marine platform 120 to generate electricity. In other words, a first portion of the produced hydrogen is liquified and stored on liquefied hydrogen floating storage unit 126, while a second portion of the produced hydrogen is utilized onboard marine platform 120 for power production. Thus, in one or more embodiments, marine platform 120 may include one or more combustion turbines 148 for combusting the second portion of the produced hydrogen to provide mechanical power that is converted to electric power by one or more electric generators 150. In this regard, the combustion turbines 148 are in fluid communication, either directly or indirectly, with the hydrogen production unit 122 in order to utilize at least a portion of the produced hydrogen for fuel in the combustion turbines 148. It will be appreciated that combustion turbines 148 may include other devices utilized to combust fuel to produce power, including, without limitation, internal combustion engines.
In yet other embodiments, conveyance system 144 may be an electrical cable in addition to or as an alternative to a hydrogen gas pipeline. Where conveyance system 144 is an electrical cable, excess power from offshore wind turbines 132 may be transmitted to shore from marine platform 120. In any event, conveyance system 144 is shown extending away from marine platform 120 along the seabed 127. In one or more embodiments, conveyance system 144 extends from adjacent the second end 123b of a leg 123.
With reference to
While 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. Seawater drawn in and pumped to the water purification unit 140 where the water purification unit 140 is utilized to at least partially purifying the pumped seawater to yield purified water, after which, the hydrogen production unit 122 is used to generate gaseous hydrogen from the purified water. In one or more embodiments, 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 unit 122.
Turning to
In the illustrated embodiment, a liquified natural gas floating storage unit 226 having storage tanks 228 is provided adjacent marine platform 120 and disposed to bulk store liquefied natural gas (LNG1) delivered by a liquified natural gas transport vessel 230. The percentage amount of hydrogen in the delivered natural gas may be minimal, such as less than 0.5% in some embodiments, or less than 1% in other embodiments or less than 3% in yet other embodiments. In still other embodiments, the percentage of hydrogen in the delivered natural gas is simply less than a desired percentage of hydrogen in a blended fuel. In any event, hydrogen fuel production system 210 therefore includes a first pump to transfer by pumping the delivered natural gas LNG1 from floating storage unit 226 to marine platform 120 for processing.
Hydrogen fuel production system 210 produces gaseous hydrogen as described above utilizing water purification unit 140 to deliver purified water to hydrogen production unit 122. In one or more embodiments, the electricity for hydrogen production unit 122 is provided to marine platform 120 for the production of hydrogen by offshore wind turbines 132 disposed in the vicinity of marine platform 120. In addition, liquefied natural gas delivered to floating storage unit 226 is regasified by regasification system 232 to produce natural gas for blending, after which the produced hydrogen and delivered natural gas are mixed together in desired proportions by blending unit 234 which includes a gaseous hydrogen input, a gaseous natural gas input and a blended fuel output, where the blended fuel is natural gas with an increased hydrogen content. Thus, each of regasification system 232 and hydrogen production unit 122 are in fluid communication with blending unit 234 which produces a blended fuel from the input gasses. Although the blending process and blended fuel as described herein are not limited to a particular blending ratio, in one or more embodiments, the blended fuel comprises no more than about 25% hydrogen. In other embodiments, the proportion of hydrogen to natural gas in the blended fuel may be higher. Moreover, as combustion turbines and other industrial equipment are specifically designed to accommodate higher percentages of hydrogen as a combustion fuel, the blended ration may correspondingly increase.
In one or more embodiments, a portion of the blended fuel may be transmitted to an onshore or near shore location or terminal via a conveyance system 144, such as the illustrated gas pipeline conveyance system 144. Alternatively, or in addition thereto, a portion of the blended fuel may be utilized onboard marine platform 120 to generate electricity. Thus, marine platform 120 may include one or more combustion turbines 148 for combusting the blended fuel to provide mechanical power that is converted to electric power by one or more electric generators 150. In this case, conveyance system 144 may be an electrical cable in addition to or as an alternative to a gas pipeline for the blended fuel. Where conveyance system 144 is an electrical cable, excess electricity from offshore wind turbines 132 may be transmitted to shore from marine platform 120 along with electricity produced from electric generators 150. In some embodiments, electricity from offshore wind turbines 132 may be utilized to produce hydrogen for mixing with natural gas, while electricity from electric generators 150 may be transmitted via conveyance system 144.
In the illustrated embodiment, a first liquified natural gas floating storage unit 226 having storage tanks 228 is provided adjacent marine platform 120 and disposed to bulk store liquefied natural gas delivered by a liquified natural gas transport vessel 230. This delivered natural gas stored on floating storage unit 226 is characterized as storing liquefied natural gas having the first percentage of hydrogen (LNG1). Hydrogen fuel production system 310 therefore includes a first pump to transfer by pumping LNG1 from floating storage unit 226 to marine platform 120 for processing. In addition, a second liquified natural gas floating storage unit 326 having storage tanks 328 is provided adjacent marine platform 120 and disposed to bulk store liquefied natural gas having the second percentage of hydrogen (LNG2), namely liquified blended fuel for transport to other locations. This blended fuel is comprised of natural gas having a second percentage of hydrogen that is greater than the first percentage of hydrogen. Hydrogen fuel production system 310 therefore includes a second pump to transfer by pumping LNG2 from marine platform 120 to floating storage unit 326 for collection and storage prior to shipping.
A liquified natural gas transport vessel 230 may then be used to loaded with the liquified blended fuel from second liquified natural gas floating storage unit 326 for transport to other locations. In one or more embodiments, the same liquified natural gas transport vessel 230 utilized to deliver liquified natural gas to first floating storage unit 226, following unloading, may then be loaded with liquefied blended fuel from second floating storage unit 326. In one or more embodiments, liquefied natural gas transport vessel 230 may be moored at moorings 133 that are spaced apart from liquefied natural gas floating storage unit 126 and marine platform 120. In such case, a floating transfer terminal 131a may be utilized to transfer liquified natural gas from the liquified natural gas transport vessel 230 to the liquified natural gas floating storage unit 226. Likewise, following blending, a floating transfer terminal 131b may be utilized to transfer liquified blended fuel from the liquified natural gas floating storage unit 326 to the liquified natural gas transport vessel 230.
To accommodate both first floating storage unit 226 and second floating storage unit 326 in close proximity to marine platform 120, marine platform 120 may have at least a first side 120a and a second side 120b with first floating storage unit 226 moored adjacent the first side 120a of marine platform 120 and second floating storage unit 326 moored adjacent the second side 120b of marine platform 120. It will be appreciated that in some embodiments, first side 120a and second side 120b may oppose one as opposite sides of marine platform 120 to allow both the liquified natural gas floating storage unit 326 and the liquified hydrogen floating storage unit 226 to be closely moored adjacent marine platform 120 at the same time. In any event, the liquified natural gas floating storage unit 326 may include a plurality of bulk storage tanks 328 for receipt of blended liquified natural gas produced onboard marine platform 120.
Hydrogen fuel production system 310 produces gaseous hydrogen as described above utilizing water purification unit 140 to deliver purified water to hydrogen production unit 122. In one or more embodiments, the electricity for hydrogen production unit 122 is provided to marine platform 120 for the production of hydrogen by offshore wind turbines 132 disposed in the vicinity of marine platform 120. In addition, liquefied natural gas from floating storage unit 226 is regasified by regasification system 232 to produce natural gas, after which the produced hydrogen and natural gas are mixed together in desired proportions by blending unit 234. Thus, each of regasification system 232 and hydrogen production unit 122 are in fluid communication with blending unit 234 which produces a blended fuel from the input gasses. Although the blending process and blended fuel as described herein are not limited to a particular blending ratio, in one or more embodiments, the blended fuel comprises no more than about 25% hydrogen. In other embodiments, the proportion of hydrogen in the blended fuel may be higher.
The blended fuel from blending unit 234 is then conveyed to liquefaction unit 224 where the blended fuel is liquified before loading onto second liquified natural gas floating storage unit 326.
In one or more embodiments, a portion of the blended fuel may be transmitted to an onshore or near shore location or terminal via a conveyance system 144, such as the illustrated gas pipeline conveyance system 144. Alternatively, or in addition thereto, a portion of the blended fuel may be utilized onboard marine platform 120 to generate electricity. Thus, marine platform 120 may include one or more combustion turbines 148, such as shown in
Moreover, in the case where blended fuel is utilized in the combustion turbines 148, the combustion turbines are in fluid communication, either directly or indirectly, with the blending unit 234 in order to utilize at least a portion of the blended fuel in the combustion turbines 148.
In any event, the delivered natural gas LNG1 is regassified and blended with gaseous hydrogen from a hydrogen source at marine platform 120. In some embodiments, the hydrogen source at marine platform 120 is liquid hydrogen stored adjacent marine platform 120 on a liquified hydrogen floating storage unit 426, which liquid hydrogen is regassified on board marine platform 120. Hydrogen fuel production system 410 therefore includes a first pump to transfer by pumping the delivered natural gas LNG1 from floating storage unit 226 to marine platform 120 for processing. Specifically, the delivered natural gas and hydrogen are then blended to produce a blended fuel, namely natural gas with a desired percentage of hydrogen comprising the blended fuel.
In one or more embodiments, the liquified hydrogen from floating storage unit 426 is produced on marine platform 120 as described above with respect to
In yet other embodiments, gaseous hydrogen may be produced onboard marine platform 120 and a portion of the produced hydrogen may be used directly in the blending process without first liquefying and storing the hydrogen on floating storage unit 426. In such case, floating storage unit 426 may be used to store the excess hydrogen produced onboard marine platform 120.
In this same vein, it will be appreciated that the percentage of hydrogen that can be blended with natural gas for use in industry will increase over time as equipment is upgraded or manufactured to utilize fuel with higher percentages of hydrogen. Floating storage unit 426 affords the flexibility to provide higher percentages of hydrogen for blending as industry demands change.
In one or more embodiments, liquefied natural gas transport vessel 230 may be moored at moorings 133 that are spaced apart from liquefied natural gas floating storage unit 226 and marine platform 120. In such case, a floating transfer terminal 131 may be utilized to transfer liquified natural gas from liquefied natural gas transport vessel 230 to liquefied natural gas floating storage unit 226.
While hydrogen may be delivered to liquefied hydrogen floating storage unit 426, in the embodiment shown in
Hydrogen fuel production system 410 produces gaseous hydrogen as described above utilizing water purification unit 140 to deliver purified water to hydrogen production unit 122. Liquefaction unit 124 converts the produced gaseous hydrogen to liquified hydrogen for storage. In one or more embodiments, the electricity for hydrogen production unit 122 is provided to marine platform 120 for the production of hydrogen by offshore wind turbines 132 disposed in the vicinity of marine platform 120.
Prior to blending in blending unit 234, liquefied natural gas from first floating storage unit 226 is regasified by first regasification system 232 to produce natural gas, and liquified hydrogen from second floating storage unit 426 is regasified by second regasification system 233, after which the resulting gaseous hydrogen and gaseous natural gas are mixed together in desired proportions by blending unit 234. Thus, each of first regasification system 232 and second regasification system 233 are in fluid communication with blending unit 234 which produces a blended fuel from the input gasses. Although the blending process and blended fuel as described herein are not limited to a particular blending ratio, in one or more embodiments, the blended fuel comprises no more than about 25% hydrogen. In other embodiments, the proportion of hydrogen in the blended fuel may be higher.
In one or more embodiments, a portion of the blended fuel may be transmitted to an onshore or near shore location or terminal via a conveyance system 144, such as the illustrated gas pipeline conveyance system 144. Alternatively, or in addition thereto, a portion of the blended fuel may be utilized onboard marine platform 120 to generate electricity. Thus, marine platform 120 may include one or more combustion turbines 148 such as is shown in
Moreover, in the case where blended fuel is utilized in the combustion turbines 148, the combustion turbines are in fluid communication, either directly or indirectly, with the blending unit 234 in order to utilize at least a portion of the blended fuel in the combustion turbines 148.
Thus, a system for offshore production of fuel has been described. The system may include an offshore marine platform; a water purification unit on the marine platform; at least one hydrogen production unit on the marine platform in fluid communication with the water purification unit; a hydrogen liquefaction system on the marine platform in fluid communication with the hydrogen production unit; and a liquified hydrogen floating storage unit moored adjacent the marine platform and in fluid communication with the hydrogen liquefaction system. In other embodiments, the system may include an offshore marine platform; a plurality of offshore wind turbines in the vicinity of marine platform and disposed to provide electricity to the marine platform; a water purification unit on the marine platform; at least one hydrogen production unit on the marine platform in fluid communication with the water purification unit; a hydrogen liquefaction system on the marine platform in fluid communication with the hydrogen production unit; and a liquified hydrogen floating storage unit moored adjacent the marine platform and in fluid communication with the hydrogen liquefaction system. In other embodiments, the system may include an offshore marine platform; a water purification unit on the marine platform; at least one hydrogen production unit on the marine platform in fluid communication with the water purification unit; a liquified natural gas floating storage unit moored adjacent the marine platform; a regasification system on the marine platform and in fluid communication with the liquified natural gas floating storage unit, the regasification system disposed to convert the liquefied natural gas to gaseous natural gas; and a blending unit on the marine platform and in fluid communication with each of the regasification system and the at least one hydrogen production unit, the blending unit disposed to receive gaseous natural gas with a first percentage of hydrogen and blend the received natural gas with gaseous hydrogen to produce blended natural gas with a second percentage of hydrogen. In other embodiments, the system may include an offshore marine platform; a plurality of offshore wind turbines in the vicinity of marine platform and disposed to provide electricity to the marine platform; a water purification unit on the marine platform; at least one hydrogen production unit on the marine platform in fluid communication with the water purification unit and disposed to produce gaseous hydrogen; 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, the first regasification system disposed to convert the liquefied natural gas to gaseous natural gas; and a blending unit on the marine platform and in fluid communication with the regasification system and the at least one hydrogen production unit, the blending unit disposed to receive gaseous natural gas with a first percentage of hydrogen and blend the received natural gas with gaseous hydrogen to produce blended natural gas with a second percentage of hydrogen. In other embodiments, the system may include an offshore marine platform; a water purification unit on the marine platform; at least one hydrogen production unit on the marine platform in fluid communication with the water purification unit; a first liquified natural gas floating storage unit moored adjacent the marine platform and having storage tanks with liquified natural gas having a first percentage of hydrogen stored therein; a second liquified natural gas floating storage unit moored adjacent the marine platform and having storage tanks with liquefied natural gas having a second percentage of hydrogen stored therein; a regasification system on the marine platform and in fluid communication with the first liquified natural gas floating storage unit, the regasification system disposed to convert the liquefied natural gas with a first percentage of hydrogen to gaseous natural gas with a first percentage of hydrogen; a blending unit on the marine platform and in fluid communication with each of the regasification system and the at least one hydrogen production unit, the blending unit disposed to receive the gaseous natural gas with a first percentage of hydrogen and blend the received natural gas with gaseous hydrogen to produce the gaseous natural gas having a second percentage of hydrogen; and a liquefaction unit in fluid communication with the blending unit and the second liquified natural gas floating storage unit, the liquefaction system disposed to convert the gaseous natural gas having the second percentage of hydrogen into liquefied natural gas having the second percentage of hydrogen for storage on the second liquified natural gas floating storage unit. In other embodiments, the system may include an offshore marine platform; a source of hydrogen at the marine platform; a first liquified natural gas floating storage unit moored adjacent the marine platform and having storage tanks with liquified natural gas having a first percentage of hydrogen stored therein; a second liquified natural gas floating storage unit moored adjacent the marine platform and having storage tanks with liquefied natural gas having a second percentage of hydrogen stored therein; a regasification system on the marine platform and in fluid communication with the first liquified natural gas floating storage unit, the regasification system disposed to convert the liquefied natural gas with a first percentage of hydrogen to gaseous natural gas with a first percentage of hydrogen; and a blending unit on the marine platform and in fluid communication with each of the regasification system and the source of hydrogen, the blending unit disposed to receive the gaseous natural gas with a first percentage of hydrogen and blend the received natural gas with hydrogen to produce the gaseous natural gas having a second percentage of hydrogen; and a liquefaction unit in fluid communication with the blending unit and the second liquified natural gas floating storage unit, the liquefaction system disposed to convert the gaseous natural gas having the second percentage of hydrogen into liquefied natural gas having the second percentage of hydrogen for storage on the second liquified natural gas floating storage unit; a first pump disposed to convey liquified natural gas having the first percentage of hydrogen from the first liquified natural gas floating storage unit to the regasification system; and a second pump disposed to convey liquified natural gas having the second percentage of hydrogen from the liquefaction unit to the second liquified natural gas floating storage unit. In other embodiments, the system may include an offshore marine platform; a water purification unit on the marine platform; at least one hydrogen production unit on the marine platform in fluid communication with the water purification unit; a liquified natural gas floating storage unit moored adjacent the marine platform and having storage tanks with liquified natural gas having a first percentage of hydrogen stored therein; a liquified hydrogen floating storage unit moored adjacent the marine platform and having storage tanks with liquefied hydrogen stored therein; a first liquefaction unit in fluid communication with the hydrogen production unit and the liquefied hydrogen floating storage unit, the first liquefaction system disposed to convert the gaseous hydrogen into liquefied hydrogen for storage on the liquefied hydrogen storage unit; a first regasification system on the marine platform and in fluid communication with the liquified natural gas floating storage unit, the first regasification system disposed to convert the liquefied natural gas with a first percentage of hydrogen to gaseous natural gas with a first percentage of hydrogen; a second regasification system on the marine platform and in fluid communication with the liquified hydrogen floating storage unit, the second regasification system disposed to convert the liquefied hydrogen to gaseous hydrogen; and a blending unit on the marine platform and in fluid communication with each of the first regasification system and the second regasification system, the blending unit disposed to receive the gaseous natural gas with a first percentage of hydrogen and blend the received natural gas with gaseous hydrogen to produce the gaseous natural gas having a second percentage of hydrogen. In other embodiments, the system may include an offshore marine platform; a liquified natural gas floating storage unit moored adjacent the marine platform and having storage tanks with liquified natural gas having a first percentage of hydrogen stored therein; a liquified hydrogen floating storage unit moored adjacent the marine platform and having storage tanks with liquefied hydrogen stored therein; a first regasification system on the marine platform and in fluid communication with the liquified natural gas floating storage unit, the first regasification system disposed to convert the liquefied natural gas with a first percentage of hydrogen to gaseous natural gas with a first percentage of hydrogen; a second regasification system on the marine platform and in fluid communication with the liquified hydrogen floating storage unit, the second regasification system disposed to convert the liquefied hydrogen to gaseous hydrogen; a blending unit on the marine platform and in fluid communication with each of the first regasification system and the second regasification system, the blending unit disposed to receive the gaseous natural gas with a first percentage of hydrogen and blend the received natural gas with gaseous hydrogen to produce the gaseous natural gas having a second percentage of hydrogen; a first pump disposed to convey liquified natural gas having the first percentage of hydrogen from the liquified natural gas floating storage unit to the first regasification system; and a second pump disposed to convey liquified hydrogen from the liquified hydrogen floating storage unit to the second regasification system.
Any of the foregoing offshore production of fuel systems may further include, alone or in combination, any of the following:
Likewise, a method for offshore production of fuel has been described. The method may include pumping seawater to a water purification unit mounted on an offshore marine platform affixed to the seabed; utilizing the water purification unit to at least partially purifying the pumped seawater to yield purified water; utilizing a hydrogen production unit mounted on the offshore marine platform to produce gaseous hydrogen from the purified water; liquifying at least a portion of the gaseous hydrogen onboard the marine platform; transferring the liquified hydrogen to a liquified hydrogen floating storage unit moored adjacent the marine platform for storage of the liquefied hydrogen on the liquified hydrogen floating storage unit; and transferring liquified hydrogen stored on the liquified hydrogen floating storage unit to a liquefied hydrogen transport vessel. In other embodiments, the method may include supplying electricity to an offshore marine platform from a plurality of offshore wind turbines; pumping seawater to a water purification unit mounted on an offshore marine platform affixed to the seabed; utilizing the water purification unit to at least partially purifying the pumped seawater to yield purified water; utilizing a hydrogen production unit mounted on the offshore marine platform to produce gaseous hydrogen from the purified water; liquifying the gaseous hydrogen onboard the marine platform; and transferring the liquified hydrogen to a liquified hydrogen floating storage unit moored adjacent the marine platform; wherein the electricity from the offshore wind turbines is utilized at least by the hydrogen production unit to produce gaseous hydrogen. In other embodiments, the method may include pumping seawater to a water purification unit mounted on an offshore marine platform affixed to the seabed; utilizing the water purification unit to at least partially purifying the pumped seawater to yield purified water; utilizing a hydrogen production unit mounted on the offshore marine platform to produce gaseous hydrogen from the purified water; delivering liquefied 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; 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. In other embodiments, the method may include pumping seawater to a water purification unit mounted on an offshore marine platform affixed to the seabed; utilizing the water purification unit to at least partially purifying the pumped seawater to yield purified water; utilizing a hydrogen production unit mounted on the offshore marine platform to produce gaseous hydrogen from the purified water; delivering liquefied natural gas to the marine platform, the delivered natural gas having a first percentage of hydrogen; gasifying the delivered natural gas to produce gaseous natural gas having a first percentage of hydrogen; blending the gaseous natural gas having a first percentage of hydrogen with at least a portion of the gaseous hydrogen produced on the marine platform to produce a gaseous natural gas having a second percentage of hydrogen; and liquefying at least a portion of the natural gas having the second percentage of hydrogen. In other embodiments, the method may include providing gaseous hydrogen at an offshore marine platform; delivering liquefied natural gas to the marine platform, the delivered liquified natural gas having a first percentage of hydrogen; gasifying the delivered natural gas to produce gaseous natural gas having a first percentage of hydrogen; blending the gaseous natural gas having a first percentage of hydrogen with at least a portion of the gaseous hydrogen to produce a gaseous natural gas having a second percentage of hydrogen; and liquefying at least a portion of the natural gas having the second percentage of hydrogen. In other embodiments, the method may include providing gaseous hydrogen at an offshore marine platform; delivering liquefied natural gas to the marine platform, the delivered natural gas having a first percentage of hydrogen; gasifying the delivered natural gas to produce gaseous natural gas having a first percentage of hydrogen; blending the gaseous natural gas having a first percentage of hydrogen with at least a portion of the gaseous hydrogen to produce a gaseous natural gas having a second percentage of hydrogen; combusting a portion of the gaseous natural gas having a second percentage of hydrogen in combustion turbines in order to produce electricity onboard the marine platform; and conveying the produced electricity away from the marine platform. In other embodiments, the method may include pumping seawater to a water purification unit mounted on an offshore marine platform affixed to the seabed; utilizing the water purification unit to at least partially purifying the pumped seawater to yield purified water; utilizing a hydrogen production unit mounted on the offshore marine platform to produce gaseous hydrogen from the purified water; liquefying at least a portion of the gaseous hydrogen and storing the liquefied gaseous hydrogen on a liquified hydrogen floating storage unit moored adjacent the marine platform; delivering liquefied natural gas to the marine platform, the delivered natural gas having a first percentage of hydrogen; gasifying the delivered natural gas to produce gaseous natural gas having a first percentage of hydrogen; blending the gaseous natural gas having a first percentage of hydrogen with at least a portion of the gaseous hydrogen produced on the marine platform to produce a gaseous natural gas having a second percentage of hydrogen; combusting at least a portion of the gaseous natural gas having a second percentage of hydrogen in combustion turbines in order to produce electricity onboard the marine platform; conveying the produced electricity away from the marine platform. In other embodiments, the method may include providing gaseous hydrogen at an offshore marine platform; delivering liquefied natural gas to the marine platform, the delivered natural gas having a first percentage of hydrogen; storing the delivered liquefied natural gas in a first floating storage unit adjacent the marine platform; gasifying the delivered natural gas to produce gaseous natural gas having a first percentage of hydrogen; blending the gaseous natural gas having a first percentage of hydrogen with at least a portion of the gaseous hydrogen to produce a gaseous natural gas having a second percentage of hydrogen; and combusting at least a portion of the gaseous natural gas having a second percentage of hydrogen in combustion turbines in order to produce electricity onboard the marine platform; conveying the produced electricity away from the marine platform.
Any of the foregoing embodiments of a method may include, alone or in combination, any of the following:
Although various embodiments have been shown and described, the disclosure is not limited to such embodiments and will be understood to include all modifications and variations as would be apparent to one skilled in the art. Therefore, it should be understood that the disclosure is not intended to be limited to the particular forms disclosed; rather, the intention is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the disclosure as defined by the appended claims.
This application claims the benefit of priority to U.S. Provisional Application No. 63/366,410, filed Jun. 15, 2022 the benefit of which is claimed and the disclosure of which is incorporated by reference in its entirety.
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