Hydrogen transport, distribution and storage systems, methods and devices

Abstract

A system, method and apparatus for the transport and distribution of hydrogen, large scale storage of energy, and the most advantageous production of large quantities of "green" hydrogen at locations where it is needed as a clean transportation fuel, industrial feedstock, power source and long term storage of electricity. Hydrogen distribution pipelines are able to utilize natural gas, oil and other existing pipelines to deliver hydrogen to one or more distribution points; and in one embodiment integrate lighter than air airships to transport hydrogen between locations where pipelines do not exist or are not feasible. The disclosed hydrogen distribution pipelines are also able to use water pipes, sewers, storm drains and other existing pipelines for local distribution, saving time and money and reducing construction disruption to local communities to establish the infrastructure components necessary to make widespread use of hydrogen to help combat climate change.

Description

Technical Field

[0001] This subject matter technology typically relates to large-scale energy storage and the transportation of hydrogen from the production site to locations where end users require it and / or from which it can be distributed. While this subject matter technology can be used as a means of transporting hydrogen produced from any source, it is particularly helpful in reducing the time, capital investment, and complexity involved in obtaining necessary approvals, acquiring right-of-way, installing, transporting, and distributing “green” hydrogen, from the most advantageous production location to multiple individual end-use locations, such as power substations, commercial and industrial facilities, gas stations, and the homes of consumers who wish to use hydrogen as a clean and renewable energy source in place of fossil fuels. This subject matter technology also provides a method for storing energy that is less costly and has a significantly higher energy retention rate compared to battery technology, and offers a more cost-effective, scalable, and less maintenance-intensive option for new large-scale infrastructure compared to storing hydrogen in conventional hydrogen storage tanks. Background Technology

[0002] On September 23, 2020, Bank of America Global Research released a thematic investment report predicting that hydrogen is at a tipping point, potentially generating $2.5 trillion in direct revenue and $11 trillion in indirect infrastructure by 2050, due to the impending inflection point for hydrogen production in the renewable energy economy. Those skilled in the art recognize that although the technology for producing hydrogen from water through a process known as “electrolysis” has been used for decades, widespread use of hydrogen as an alternative to fossil fuels or for large-scale electrical energy storage has not yet reached an inflection point and achieved mainstream adoption. As the Bank of America report states, this situation is now changing because: (1) the cost of renewable energy sources such as wind and solar radiation is decreasing; (2) the cost of electrolyzer systems is decreasing and efficiency is increasing, allowing the production of hydrogen from water using this renewable energy source, with pure oxygen as the only byproduct; (3) improvements in the efficiency, durability, cost, and flexibility of fuel cells to convert hydrogen into electricity, with clean water as the only byproduct; (4) the potential end-market for green hydrogen is expanding due to global focus on decarbonization and sustainability; and (5) the legislative market for hydrogen is expanding as governments adopt increasingly proactive clean energy policies and implement regulatory requirements to decarbonize energy systems, including the grid and transportation market sectors.

[0003] According to the report, "green" hydrogen (for example, a term referring to hydrogen produced from renewable resources) could be a key component in combating global warming, providing up to 24% of global energy demand by 2050 and reducing harmful emissions by up to 30% in the process. Bank of America believes that because hydrogen is the only clean molecule that can simultaneously meet our energy needs for both transportation and power generation, it will play a significant role in achieving net-zero carbon emissions by 2050, with an increasing number of countries and companies signing legally binding commitments. The U.S. Department of Energy (DOE), through its "H2@Scale" initiative and the Office of Energy Efficiency and Renewable Energy (EERE), is also seeking to accelerate activities related to hydrogen research, development, demonstration, and implementation.

[0004] Achieving a global transition to a “hydrogen economy” faces numerous practical technical, financial, and logistical challenges. One of the relatively less-discussed long-term challenges is developing new and improved methods for transporting and distributing hydrogen from production sites to where end-users need it. Existing pipelines are unsuitable for hydrogen conversion due to a number of technical reasons, including the embrittlement of pipeline and valve materials. As authors Ulf Bossel, Baldur Eliasson, and Gordon Taylor stated in their 2004 article, “The Future of the Hydrogen Economy: Bright or Dark?”, “Most attention has been focused on the obvious benefits of hydrogen in use, while the upstream aspects of the hydrogen economy have been largely overlooked.” These authors argue that once the energy required for packaging, processing, storing, and transporting hydrogen is added to the energy required for hydrogen production, the future energy economy is “unlikely to be based on elemental hydrogen.”

[0005] This challenge stems from the fact that hydrogen's relatively low volumetric energy density makes it extremely inefficient to transport, store, and distribute; and currently constitutes one of the most significant cost and energy inefficiencies for its use as an energy carrier. This problem is exacerbated by the fact that the most economical places to produce green hydrogen naturally exist in low-cost renewable energy sources, which are remote and sparsely populated; therefore, they are often negatively correlated with the regions that most need clean-burning fuels.

[0006] Electricity costs account for 60% to 75% of the cost of green hydrogen. Therefore, locations with abundant natural sources of low-cost renewable energy capacity from solar radiation (e.g., equatorial desert regions), wind power (e.g., mountain passes and island entrances), hydropower (e.g., near large bodies of water with significant elevation variations), and / or geothermal energy (e.g., near active volcanoes or vents) enable hydrogen production at significantly lower costs per kilogram. However, these areas with abundant, low-cost renewable energy in nature are typically not located near industrial centers and densely populated areas, making transportation costs a more significant factor.

[0007] By locating production at or very close to the point of use, hydrogen transportation and distribution costs can be minimized. However, distributing production to the point of use leads to higher production costs because economies of scale are lost; densely populated centers and areas with frequent commercial and industrial activity also typically have higher electricity and land costs. Trying to strike a balance between these extremes is also a challenge. If hydrogen production is centralized to take advantage of economies of scale, longer transportation distances significantly increase transportation costs. Attempts to semi-centralize (closer to the point of use) industrial-scale hydrogen production to shorten transportation distances are often limited by space constraints, safety and aesthetic concerns, and a lack of spare renewable energy capacity.

[0008] For these reasons, delivery costs are high in all cases and must be minimized. Currently, hydrogen transport trailers and pipelines are the most common options for transporting hydrogen from the point of production to where it is used. In the former option, gaseous hydrogen is compressed from the relatively low pressure of 20-30 bar (290-435 psi) typically produced by the electrolyzer to 180 bar (~2600 psi) or higher; and transported in long cylinders stacked on trailers transported by tractors, trains, or ships. Hexagon Lincoln is a global leader in manufacturing Class 4 carbon fiber cylinders, which are 70% lighter than steel, and produces Titan® tanks up to 40 inches in length that can store hydrogen at pressures of 950 bar (approximately 13750 psi). The company calls these cylinders Mobile Pipeline®, providing a ready-made solution for storing and transporting hydrogen to locations not on the power grid, or where pipelines are not economically or logistically feasible. While feasible in the short term, transporting hydrogen in this way is labor-intensive, expensive, and generally not a long-term alternative to existing fossil fuel distribution infrastructure.

[0009] Although it is well known that gaseous hydrogen can be transported via pipelines like natural gas is today, experts acknowledge that the high initial capital costs of constructing new pipelines constitute a major obstacle to significantly expanding hydrogen pipeline transportation infrastructure. Therefore, researchers have focused on overcoming technical challenges, including: (1) the potential for brittleness in the steel and welds used to manufacture existing pipes; (2) the need to control hydrogen permeation and leakage; and (3) the need for lower-cost, more reliable, and more durable technologies for hydrogen compression, liquefaction, and storage. The U.S. Department of Energy's H2@Scale project and similar research efforts in other countries have focused on two potential solutions.

[0010] The first proposal, put forward by Oak Ridge National Laboratory (ORNL) and Savannah River National Laboratory (SRNL), concerns the use of fiber-reinforced polymer (FRP) pipelines, such as Fiberspar LinePipe™, a wound product manufactured by National Oilwell Varco (NOV) consisting of an internal thermoplastic pressure barrier reinforced with high-strength glass fibers embedded in an epoxy resin matrix. FRP pipelines have the advantage of being commercially available through NOV and its competitors; and have been widely used in the oil and gas industry for many years.

[0011] NOV estimates that its more than 80 million feet (over 15,000 miles) of Fiberspar LinePipe is used for oilfield services and can be used for a variety of temperature and terrain-specific installations, including laying on the ground, burying in traditional open trenches, plowing, and installation within faulty steel pipes for repairs. Its FRP pipes range in diameter from 2" to 6" and have continuous lengths up to 9,000 feet (2,740 meters), allowing for rapid installation on reels. Based on testing conducted by SRNL and ORNL, SRNL and the American Society of Mechanical Engineers (ASME) have coded FRP pipes with diameters not exceeding 6" in ASME B31.12 (“Hydrogen Line Specification”) for the transmission of gaseous hydrogen at 2,500 psi, with a design life of 50 years.

[0012] Researchers estimate that using FRP pipes will save approximately 20% in costs compared to steel pipes because it can be installed in narrower right-of-way areas and can achieve significantly longer cross-sectional lengths than steel, minimizing welding requirements and eliminating the need for coatings or X-rays, as FRP pipes are non-corrosive. According to ORNL estimates, the total capital investment for an FRP hydrogen pipeline (in 2007 US dollars) would be slightly less than $600,000 per mile, including approximately $350,000 per mile for FRP pipes, materials, and installation; and an estimated $250,000 per mile for right-of-way acquisition and permitting fees. ORNL's research notes that this cost advantage is significant compared to the estimated $636,000 capital investment for 16-inch steel pipes.

[0013] Researchers believe a second alternative involving pipeline transportation is to adapt the vast natural gas distribution infrastructure to accommodate hydrogen, a promising approach to developing hydrogen delivery infrastructure. Spurred by the EU's Climate-Neutral European Hydrogen Strategy in July 2020 and the G20's interest in developing hydrogen technologies, German pipeline operators Nowega and Gascade, together with Siemens Energy, compiled and published a comprehensive white paper in October 2020 examining practical aspects of converting natural gas pipelines into pillars of the future hydrogen energy transition. Their proposal considers converting existing natural gas pipelines and storage facilities to transport mixtures of natural gas and hydrogen (up to approximately 20% hydrogen), and research indicates this can be achieved with only modest modifications to the pipelines without causing embrittlement of pipeline and / or valve materials. However, under this alternative, hydrogen must be separated and purified at the extraction point. For efficient use in fuel cells, the extracted hydrogen must have a purity of at least 99.9%; recent modeling activities have identified significant costs associated with achieving this.

[0014] The applicant's earlier patent application serial number 12 / 290453, filed on October 29, 2008, now U.S. Patent No. 8,336,810 ('810 patent), describes the use of lighter-than-air airships to transport hydrogen from locations where natural conditions allow for most economical production to locations with high market demand. However, this early disclosure is limited to providing a means of transporting hydrogen to one or a few destinations and does not address the challenges associated with widespread distribution. Summary of the Invention

[0015] This technology overcomes these long-standing problems and limitations of existing technologies, providing a method for transporting hydrogen from production sites to areas where hydrogen is most needed, storing it on a large scale, and distributing it widely to end users in these market areas. This method requires less time, significantly reduces capital costs, and greatly reduces the complexity associated with land use, right-of-way acquisition, licensing, construction, and ongoing maintenance.

[0016] This invention provides a system, method, and apparatus for the cost-effective transport, storage, and widespread distribution of hydrogen from production sites to where it is most needed. This invention overcomes many technical limitations in hydrogen transport, storage, and distribution, and significantly reduces high installation costs, delays, land use, and licensing barriers.

[0017] Many regions have invested heavily in long-distance natural gas and oil pipelines; cities, towns, and many rural communities worldwide have invested heavily in water supply, sewer, and storm drain systems. In this article, all these pipelines and systems, including those currently in use, those that may have been decommissioned, and those yet to be built, are collectively referred to as “existing pipelines.” Without limitation, as used herein, the term “existing pipeline” also includes underground utility lines, rail lines, and pipelines, including those intended for future systems such as hyperloops. Land for these existing pipelines has been acquired; right-of-way and permits have been granted; and significant investments have been made in excavating, installing, and maintaining these existing pipeline systems. Many of these existing pipelines have sufficient capacity to also function as hydrogen distribution pipelines, capable of transporting and distributing hydrogen of any purity.

[0018] This subject matter includes the construction of hydrogen distribution lines by inserting a “hydrogen delivery line” into one or more existing pipelines. Such a hydrogen delivery line is made of a material such as (but not limited to) FRP pipe according to ASME specifications to deliver pressurized hydrogen contained within a larger diameter line that provides a means of collecting any hydrogen leaking from the hydrogen delivery line. A purge gas or inert gas or liquid, referred to herein as “purge gas” or “sweeper gas,” flows outside the hydrogen delivery line to remove any hydrogen leaking from the line. Such purge gas can be nitrogen, CO2, etc.; and, depending on the circumstances and individual operator preference, the product flowing through such an existing line can itself be used as such a purge gas, provided that a hydrogen leak into the existing line does not pose a safety risk or an unacceptable level of contamination.

[0019] In other cases, where hydrogen leakage into the contents of the existing pipeline is unacceptable to the operator or poses a safety risk (e.g., when the existing pipeline carries water or contains ambient air), the hydrogen delivery pipeline must operate within an intermediate "safety line." This safety line is made of any material compatible with both the hydrogen and the contents of the existing pipeline; and in this case, purge gas flows within a channel located between the outer surface of the hydrogen delivery pipeline and the inner surface of the safety line.

[0020] In one preferred embodiment, the contents of the cleaning line are continuously tested for hydrogen levels, and the data collected is monitored to detect leaks in the hydrogen delivery line. If a leak is detected exceeding a predetermined threshold level considered acceptable, the flow of hydrogen into the delivery line can be manually shut off or programmed to shut off automatically until the leak is corrected. In another preferred embodiment, multiple hydrogen sensors are located throughout the system at varying intervals, enabling more precise identification of locations where hydrogen leaks exceed predetermined threshold levels, and allowing the area of ​​concern to be isolated and removed from service until the leak is corrected, while simultaneously restoring system balance.

[0021] In an optional preferred embodiment, a lighter-than-air airship can be used in conjunction with the system described above. The airship can transport large quantities of hydrogen from the most economically viable geographical location for production to a destination at a strategic location relative to the existing pipeline distribution system. Once at the destination, a hydrogen-carrying tank can be connected to the inlet of the aforementioned hydrogen pipeline, and the hydrogen is released into the system. In another preferred embodiment, the hydrogen transported by airship can be in a liquid (cryogenic) state, and upon arrival at the destination, an evaporator is used to convert the hydrogen from liquid to gaseous form.

[0022] In at least one aspect, this subject matter relates to a hydrogen distribution system for delivering hydrogen from a hydrogen supply source to at least one end-user location. The system includes an existing pipeline and a hydrogen delivery pipeline configured to deliver pressurized hydrogen. The hydrogen delivery pipeline is located within the existing pipeline such that a purge gas within the existing pipeline flows around the exterior of the hydrogen delivery pipeline and removes any hydrogen leaking from the hydrogen delivery pipeline. At least one inlet to the hydrogen delivery pipeline is configured to allow hydrogen to be injected into the hydrogen delivery pipeline. At least one outlet from the hydrogen delivery pipeline is configured to allow hydrogen to be discharged from the hydrogen delivery pipeline.

[0023] In some embodiments, the existing pipeline is a gas delivery pipeline, and the purge gas is one of the following gases: natural gas; or synthetic natural gas. In some cases, the system includes a safety pipeline located inside the existing pipeline and surrounding the hydrogen delivery pipeline, such that a passage is formed between the outside of the hydrogen delivery pipeline and the inside of the safety pipeline. The size of the passage allows the purge gas to flow through the existing pipeline and along the outside of the hydrogen delivery pipeline. In some cases, the safety pipeline is made of plastic or composite material. In some cases, the existing pipeline is a water pipeline, a sewer pipeline, or a stormwater drainage pipeline. In some embodiments, the existing pipeline includes a gas delivery pipeline connected to at least one of the following: a water pipe; a sewer; or a stormwater drain. At least one inlet into the hydrogen delivery pipeline may then occur in the gas delivery pipeline, and hydrogen is discharged from the hydrogen delivery pipeline after the hydrogen has been delivered through the water pipe, sewer, or stormwater drainage pipeline.

[0024] In some embodiments, the system includes at least one hydrogen sensor located at the outlet of an existing pipeline, the at least one hydrogen sensor being configured to monitor the presence and quantity of hydrogen leaking from the hydrogen delivery pipeline into the purge gas. In some cases, the system includes at least two in-line hydrogen sensors located at different locations within the existing pipeline. The system may include a data system configured to monitor at least two in-line hydrogen sensors to determine the hydrogen level at each in-line hydrogen sensor. The system may further include a recording system configured to individually record the hydrogen level detected by each in-line hydrogen sensor. Additionally, the system may include a programmable alarm system configured to trigger an alarm based on the hydrogen level. In some embodiments, the system includes at least one shutdown valve configured to selectively isolate and close a section of the hydrogen delivery pipeline upon triggering by an alarm from the programmable alarm system. In some embodiments, the hydrogen delivery pipeline is an FRP pipe coded for hydrogen.

[0025] In some embodiments, the system includes at least one coupling device, each coupling device connecting a first section of the hydrogen delivery line within the existing pipeline to a second section of the hydrogen delivery line outside the existing pipeline. In some cases, the hydrogen delivery line is made of FRP pipe coded for hydrogen, and the second section of the hydrogen delivery line is a storage area.

[0026] In some embodiments, the hydrogen delivery line includes at least one hydrogen sensor. Each hydrogen sensor can be configured to generate data associated with a detected hydrogen level. The system may further include means for monitoring the hydrogen level detected by each hydrogen sensor. The system may also include an alarm device (e.g., a processor with a display or other audio or visual output device) configured to generate an alarm when the detected hydrogen level indicates a leak of hydrogen from the hydrogen delivery line.

[0027] In some embodiments, the system includes at least one shut-off valve. Each shut-off valve is connected to a coupler. The shut-off valves are located at each interval along a predetermined length of the hydrogen delivery line, and each shut-off valve and coupler is configured to selectively close. The system may include a processor configured to identify the location of a hydrogen leak based on hydrogen levels detected by a hydrogen sensor. Each shut-off valve and coupler may be configured to close to isolate the hydrogen delivery line around the predetermined length of the hydrogen delivery line where the leak was identified.

[0028] In some embodiments, the system includes a valve connected to the existing pipeline to control the flow rate through the existing pipeline. The system may then include a first riser of the existing pipeline connected to a first side of the valve. Furthermore, the system may include a second riser of the existing pipeline connected to a second side of the valve. The hydrogen delivery pipeline may then be configured to guide hydrogen through the riser and coupler, bypassing the valve.

[0029] In at least one aspect, this subject matter relates to a method for transporting hydrogen from a production location to at least one end-user location. The hydrogen is produced from energy at the production location. The hydrogen is then stored in at least one hydrogen storage container. A hydrogen delivery line is located within or placed within an existing pipeline, the hydrogen delivery line being configured to deliver pressurized hydrogen. A purge gas is injected around the exterior of the hydrogen delivery line to remove any hydrogen leaking from the hydrogen delivery line. Hydrogen is injected from the at least one hydrogen storage container into the hydrogen delivery line. The hydrogen is discharged from the hydrogen delivery line at the end-user location.

[0030] In some embodiments, the energy source is stationary at the production location. In some cases, transporting hydrogen includes using at least one of the following: trucks; trains; or ships. In some cases, transporting hydrogen also includes using a lighter-than-air airship. In some embodiments, transporting hydrogen using the lighter-than-air airship includes: pumping the hydrogen into at least two containers. After pumping the hydrogen into the at least two containers, the containers are loaded onto the lighter-than-air airship. The lighter-than-air airship flies to a destination. The containers are unloaded from the lighter-than-air airship only at the destination location. At least one empty container is loaded onto the lighter-than-air airship. At least one empty container is returned to the production location. In some embodiments, the stationary energy source is a renewable energy source, which is at least one of the following: wind power, solar power, hydropower, biomass, or geothermal energy. In some cases, the hydrogen storage container is made of FRP pipe coded for hydrogen.

[0031] In some embodiments, the existing pipeline is a gas pipeline, and the purge gas is one of the following gases: natural gas; or synthetic natural gas. In some cases, the endpoint includes a support with at least two anchor points configured to secure the lighter-than-air airship with tie-down cables. The support may be configured to rotate to face the direction of oncoming wind.

[0032] In some embodiments, the method includes placing a safety pipeline inside the existing pipeline and around the outside of the hydrogen delivery pipeline. In some embodiments, the existing pipeline is one of the following: a water pipeline; a sewer pipeline; a stormwater drainage pipeline; an underground utility corridor; a railway line; or a conduit. In some cases, the existing pipeline includes a gas delivery pipeline connected to at least one of the following: a water pipe, a sewage pipe, or a stormwater drain. The hydrogen is then injected into the at least one inlet in the gas delivery pipeline. In this case, the removal of the hydrogen from the hydrogen delivery pipeline occurs after the hydrogen has been transported through the stormwater drain.

[0033] In some embodiments, the at least one end-user location is a power substation. In some cases, the at least one end-user location is a commercial or industrial facility. In some embodiments, the method includes utilizing hydrogen from industrially processed feedstocks. In some cases, the at least one end-user location is a filling station for distributing hydrogen to fuel cell vehicles. In some cases, the filling station can compress the hydrogen to a pressure suitable for distribution to hydrogen fuel cell vehicles. In some cases, the filling station can compress the hydrogen to a pressure suitable for distribution to hydrogen fuel cell trucks. In some embodiments, the at least one end-user location is a residential property.

[0034] In at least one aspect, this subject matter relates to a method for storing and utilizing energy. The method includes storing hydrogen in at least one spool of FRP pipe coded for hydrogen storage. An energy production system uses the hydrogen as fuel. Electricity is then generated through the energy production system.

[0035] In some embodiments, the method further includes positioning at least one hydrogen sensor in at least one spool of the FRP tube. The at least one hydrogen sensor detects hydrogen leakage from at least one spool of the FRP tube. When a hydrogen leakage is detected, electronic data proving the hydrogen leakage is generated. The electronic data is monitored, and at least one safety measure is taken in response to the detection of a hydrogen leakage. The method may further include installing a shut-off valve and a coupler at predetermined intervals along the FRP tube. In some cases, the method includes precisely locating the location of the hydrogen leak based on the electronic data and using the shut-off valve to isolate the predetermined length of FRP tube containing the location of the hydrogen leak. In some cases, the method further includes, after isolating the FRP tube containing the location of the hydrogen leak, using the coupler to remove and replace the predetermined length of FRP tube containing the location of the hydrogen leak. In some cases, the predetermined length is a spool of the FRP tube.

[0036] In some embodiments, the hydrogen is produced from a renewable energy source, which is at least one of the following: wind power, solar power, hydropower, biomass, or geothermal energy. In some cases, the energy generation system is a gas turbine. In some cases, the energy generation system is a fuel cell.

[0037] These and other elements of the subject matter are described using the following figures and written description. Attached Figure Description

[0038] Figure 1(a) is a schematic diagram illustrating the production, storage, and optional transportation of “green” hydrogen, while Figure 1(b) is a schematic diagram illustrating its removal from these transportation vehicles, storage in tanks, and distribution to various end users.

[0039] Figure 2 This is a flowchart illustrating the principles of the disclosed technology.

[0040] Figure 3(a) shows the components of a system for transporting hydrogen using a lighter-than-air airship, which is particularly advantageous in certain situations where other alternatives are impractical or uneconomical.

[0041] Figure 3(b) is a side view of a hydrogen pipeline according to the principles disclosed in this technology.

[0042] Figure 3(c) is a cross-sectional view of Figure 3(b), showing the use of safety lines in addition to hydrogen delivery lines.

[0043] Figure 3(d) is a detailed cross-sectional view of the hydrogen distribution pipeline and related components used for transporting and distributing hydrogen as shown in Figure 3(b).

[0044] Figures 4(a)–4(d) depict a map illustrating a case study involving the production of green hydrogen from wind and / or geothermal energy on the Big Island of Hawaii and its transport and widespread distribution on the more densely populated Oahu Island. Specifically, Figure 4(a) depicts the transport of hydrogen between endpoints on the Big Island of Hawaii and Oahu via lighter-than-air airships. Figure 4(b) depicts the transport of this hydrogen from the main terminal to key distribution nodes on Oahu. Figure 4(c) shows an example where pipelines can be used to deliver hydrogen to critical storage and distribution locations. Figure 4(d) illustrates opportunities for the widespread distribution of this green hydrogen to numerous end-user locations via water, sewer, and stormwater drainage pipelines.

[0045] While implementations are described herein by way of example, those skilled in the art will recognize that implementations are not limited to the described examples or drawings. It should be understood that the drawings and their detailed description are not intended to limit implementations to the specific forms disclosed, but rather are intended to cover all modifications, equivalents, and alternatives falling within the spirit and scope of this disclosure as defined by the appended claims. In this application, the word “may” is used in a permissive sense (i.e., meaning potential) rather than a mandatory sense (i.e., meaning mandatory). Similarly, the words “comprising,” “including,” and “including” mean including but not limited to. Furthermore, as used herein, the terms “interconnect,” “connection,” “coupling,” or “attachment” can refer to two or more components connected together, whether the connection is permanent (e.g., welded or glued) or temporary (e.g., bolted, fixed by a physical object, or secured in place by friction or tension), direct or indirect (i.e., through an intermediate), mechanical, chemical, optical, or electrical. Detailed Implementation

[0046] This subject matter describes improvements to the existing technology, including a novel and unique system, method, and apparatus for transporting hydrogen from the most advantageous locations for hydrogen production, storing hydrogen on a large scale, and then distributing it to one or more end-use points in a more cost-effective manner, overcoming many long-standing technical challenges in achieving the transition from fossil fuels to a hydrogen economy. As described in the background section, cities, most towns, and many rural communities worldwide have extensive pipelines for natural gas, oil, and other types of fuels. Furthermore, all cities, towns, and many rural communities have made significant investments in water supply, sewer, and stormwater drainage systems as critical public infrastructure. The land for these existing pipelines has been acquired; right-of-way and regulatory approvals have been granted; and substantial investments have been made in excavating, installing, and maintaining them. As disclosed herein, a method and apparatus capable of safely transporting and distributing hydrogen within such existing pipelines enables a more cost-effective hydrogen delivery network than any other known or currently proposed alternative.

[0047] In a preferred embodiment, adapting this existing pipeline for transporting and distributing hydrogen requires inserting a hydrogen delivery line, contained within a larger diameter safety line, into the existing pipeline, although the use of the safety line may be optional under certain conditions. As described in detail below, the hydrogen delivery line is preferably made of FRP pipe or an equivalent material coded for pressurizing hydrogen. The surrounding safety line (or, alternatively, the existing pipeline) serves as a means of collecting any hydrogen that may leak from the hydrogen delivery line. A purge or inert purging gas flowing outside the hydrogen delivery line removes any hydrogen leaking from it. At least one hydrogen sensor is used to test the hydrogen content in the purge or purging gas and can shut off the hydrogen flow if the level of leaked hydrogen in the gas exceeds a predetermined threshold level. In another preferred embodiment, fiber optic lines can be installed to carry signals from hydrogen sensors located throughout the system, allowing the location of hydrogen leaks exceeding predetermined threshold levels, isolation, and rapid correction of areas requiring maintenance.

[0048] These and other aspects of the subject matter are disclosed by using the following illustrative drawings.

[0049] Figure 1 consists of Figure 1(a) and Figure 1(b). Figure 1(a) illustrates an alternative method for the production, storage, and transportation of “green” hydrogen 101. As shown, hydrogen 101 is produced by electrolysis using one or more electrolyzers 102. Electrolyzers 102 can use any of several known technologies, such as alkaline and proton exchange membrane (PEM) electrolysis, and in the future, solid oxide electrolysis or other new technologies may be utilized. As shown, electrolyzers 102 produce hydrogen 101 by passing an electric current 103 through an anode (+) and a cathode (-) suspended in water 104 to release H2 and O2 molecules.

[0050] Electricity 103 is preferably generated from renewable energy sources, such as kinetic energy from wind turbines 105, solar radiation collected from photovoltaic cells 106, turbine power from water sources 107, or geothermal energy 108. Other energy sources may also be used, such as off-peak or reduced-peak electricity, and new forms of renewable energy, such as biofuels from landfills and wastewater treatment plants, and the gasification of biomass, municipal solid waste, agricultural residues, and green waste. It is well known that renewable energy projects suffer significant power losses due to voltage stepping and transmission 109, generally making it most efficient to power the electrolyzer as close as possible to the renewable power source 103. It is also well known that fossil fuels can be used to produce hydrogen; in fact, over 99% of hydrogen currently produced is made using fossil fuels. Although not shown in Figure 1(a), in an alternative embodiment, nuclear energy and sources using fossil fuels (including, but not limited to, grid power based on coal or natural gas plants as power source 103, steam methane reforming, and coal gasification) can be used to produce hydrogen 101 without departing from the principles associated with hydrogen transport, large-scale storage, and distribution systems described below.

[0051] The generated hydrogen 101 can be compressed to the required pressure using compressor 110 and then stored as gaseous hydrogen in storage container 111(a), or liquefied using liquefaction system 112 and stored as cryogenic hydrogen in storage container 113(a). Unless this hydrogen is consumed at the same location where it was produced, it is typically transported in one of four ways. As described in the background section, the two most common methods of hydrogen transport are hydrogen transport trailers 114 and pipelines 115 specifically designed for transporting gaseous or liquefied (cryo) hydrogen, including pipelines specifically constructed for transporting hydrogen, and pipelines for transporting mixtures of hydrogen and natural gas.

[0052] It is estimated that the United States currently has 450 to 800 miles of dedicated hydrogen pipelines, mostly along the Gulf Coast, connecting hydrogen producers (refineries) with established long-term customers. In Europe, an estimated 700 to 1100 miles of hydrogen pipelines exist, the longest stretching 250 miles from northern France to Belgium. Furthermore, in response to previously discussed challenges, the possibility of blending up to 20% hydrogen with natural gas has been proposed as a way to utilize the more than 180,000 miles of natural gas transmission pipelines (also represented by pipeline 115 in Figure 1).

[0053] Figure 1(a) also depicts two other hydrogen transport modes. The first involves the use of trains and large cargo ships, collectively referred to as vessels 116. This includes the Suiso Frontier (Kawasaki hull number 1740), which Kawasaki Heavy Industries plans to complete by the end of 2020, the world's first liquefied hydrogen transport ship. Furthermore, the distribution of hydrogen using lighter-than-air airships 117 has been described, for example, as disclosed in the applicant's '810 patent.

[0054] Next, turning to Figure 1(b), it is depicted that hydrogen 101 is removed from these transport devices 114 to 117, and the hydrogen 101 is stored in the form of gaseous 111(b) or cryogenic 113(b) for regasification using evaporator 118 and for distribution to various end users.

[0055] Those skilled in the art will understand that, as shown in pipelines 119(a)-119(e), the local distribution of hydrogen 101 is currently only carried out using hydrogen transport trailer 114 or, in very limited circumstances, a dedicated hydrogen pipeline 115. Figure 1(b) illustrates five end uses of this hydrogen that already exist or have been proposed. Pipeline 119(a) shows the distribution of hydrogen 101 used as fuel in one or more turbine generators 120 and / or fuel cells 121 to generate electricity that can be added to the power grid 122. Pipeline 119(b) shows the distribution of hydrogen 101 used directly or via fuel cell 123 in residential applications 124, including for heating and cooking 125 and for electricity 126.

[0056] Pipelines 119(c) and 119(d) describe the distribution of hydrogen 101 for commercial and industrial applications 127. Pipeline 119(c) shows the distribution used in one or more fuel cells 128 to generate electricity 129; pipeline 119(d) depicts the distribution of hydrogen 101 to provide a carbon-free alternative to fossil fuels as fuel or process feedstock for various uses. Distribution line 119(e) shows the distribution of hydrogen 101 to refueling station 130 for distributing hydrogen 101 to fuel cell vehicles including industrial equipment such as forklifts 131, consumer and fleet passenger vehicles 132, hydrogen buses 133, heavy-duty trucks 134, and other equipment, drones, and aircraft (not shown). Conversely, such fuel cell vehicles are proposed to provide supplemental power, as shown by pipeline 135, which depicts a fuel cell passenger vehicle 132 providing power for residential applications 124-126. Although not shown, large fuel cell vehicles such as bus 133 and heavy truck 134 can provide power during emergencies and grid outages via vehicle-to-grid (VTG) services and by connecting to individual critical loads such as hospitals and communications equipment to support civil defense, humanitarian and disaster relief operations.

[0057] Now for reference Figure 2 A flowchart illustrating a method according to the subject matter is shown. Ellipse 201 represents the selection of a geographical location, preferably close to a low-cost renewable energy source that can be used to produce green hydrogen 101, such as wind 105, solar 106, hydropower 107, or geothermal energy 108, as shown in rectangle 202. While it is considered preferred to use energy 103 from renewable energy sources and water 104 (e.g., by electrolysis 102) to produce such hydrogen 101, this does not preclude other known and potentially future-developed energy sources and production methods. Where transporting hydrogen 101 by hydrogen transport trailer or pipeline is logically or economically infeasible, optional steps 203 through 209 may be taken to transport hydrogen 101 to a location where it can be introduced into a main distribution pipeline (as shown in rectangle 214, described in more detail below).

[0058] Rectangle 203 illustrates an optional step for collecting hydrogen produced from multiple sources. This can lead to a non-limiting example of a low-cost alternative when the electrolyzer is located directly near physically separated wind power equipment in a general area. In this case, there is no need to invest in batteries and lossy transmission cables to distribute the collected power; each production source can power its own electrolyzer unit, and the produced hydrogen is collected locally and transported to a single loading location. If needed, in a preferred embodiment, this optional hydrogen storage will be carried out in the future using FRP pipes at pressures up to 2500 psi or higher, as shown in rectangle 204. When used in place of the conventional gas storage tank 111(a), this FRP pipe can be held in a large spool 313, as described more specifically below with respect to illustration 313 in Figure 3(b).

[0059] Rectangle 205 describes that this hydrogen 101 can be compressed or liquefied as needed and / or in a manner deemed preferred by the operator for storage and / or transport. Where appropriate, as shown in rectangle 206, one or more empty sealed containers can be filled with liquid or gaseous hydrogen. As a non-limiting example, for liquid hydrogen, such a sealed container could be an insulated cryogenic tank manufactured by Worthington Industries, and for gaseous hydrogen, it could be a Titan manufactured by Hexagon Lincoln. ® High-pressure storage tank.

[0060] Once these containers are filled, in a preferred embodiment, they can be loaded onto a lighter-than-air airship 117 using a standard tractor cab, forklift, or other material handling equipment. This step, indicated by rectangle 207, is preferably performed shortly after the arrival of airship 117 to minimize transfer time. In an efficiently designed system, this transport vehicle will return empty containers from previously completed deliveries, replace these containers with pre-filled ones, and then immediately depart for the destination delivery point of the hydrogen 101. Although lighter-than-air airships are considered preferred in certain situations, as suggested by the general term "vehicle" used in the title of rectangle 207, any number of alternative land, air, or sea transport vehicles can be used without departing from the subject matter's technical principles. Rectangle 208 then depicts the transport of the hydrogen-filled containers to the intended destination using the selected transport vehicle.

[0061] Upon arrival at the destination, rectangle 209 depicts the filled containers preferably being unloaded from the transport vehicle, and the empty containers being loaded into their positions. In the case of the airship 117, this exchange of containers helps stabilize the spacecraft by minimizing weight differences that would otherwise have to be addressed by releasing or recompressing the booster gas, or by using mechanical tethering devices or ballast. Once the container exchange is complete, the transport vehicle is able to depart on return trip 225 to the preferred production site, where the aforementioned process specified by rectangles 202 to 209 is repeated. During the period when the transport vehicle is making the return trip, ground crew at the production site can refill the empty containers with more hydrogen 101 (i.e., step 206), and personnel at the destination can vent hydrogen 101 from the filled containers.

[0062] If the container is filled with liquid (cryogenic) hydrogen, it is connected to one or more evaporators 118 to convert the liquid back into gaseous hydrogen. This step is described by rectangle 210. Rectangle 211 shows an optional step in step 214 where the operator wishes to temporarily store the gaseous hydrogen product in storage container 111(b) before introducing it into the main distribution line. In a preferred embodiment, this optional hydrogen storage will use FRP tubing, as shown in rectangle 212, and more specifically with respect to illustration 313 on Figure 3(b) below.

[0063] Alternatively, in addition to the above-described option of using conventional storage container 111(b) and FRP pipe 313, the gaseous hydrogen container used in transport step 208 or the evaporator unit described in step 210 can be directly connected to the main distribution line according to the operator's preference. As mentioned above, the use of hydrogen transport trailers is optional; if the hydrogen production facility and the terminal location are in the same location, the main distribution line can be filled directly after steps 202, 203, or 204, depending on the circumstances.

[0064] To ensure proper operation of the hydrogen pipeline, the operator should monitor the inlet line pressure and adjust it to the optimal level before introducing gaseous hydrogen 101 into the main distribution line, as shown in rectangle 213. Once the inlet line pressure is adjusted, gaseous hydrogen is released into the main distribution line through the inlet, as shown in rectangle 214. To ensure proper flow, as shown in rectangle 215, the operator will monitor and adjust the line pressure to maintain the optimal pressure level.

[0065] If the intended end use of this hydrogen 101 is widespread distribution, rectangle 216 depicts the subsequent delivery of gaseous hydrogen 101 to one or more distribution points, whereby, depending on operator preference and local market conditions, this hydrogen 101 may be used or supplied to a wider distribution network. Therefore, in a preferred embodiment, such a main distribution line may tend to utilize existing natural gas or oil pipelines to interconnect the hydrogen lines between these points. To provide a “shock absorber” for this distribution network, the operator may selectively use spools of FRP pipe 313 and / or conventional storage tanks 111(b) to store gaseous hydrogen 101 on a large scale, as shown in rectangle 217.

[0066] To ensure proper operation of the distribution network, operators should monitor the inlet line pressure and adjust it to the optimal level before introducing gaseous hydrogen 101 into the local hydrogen distribution line, as shown in rectangle 218. Once this inlet line pressure has been properly regulated, gaseous hydrogen 101 is introduced into the distribution network line through one or more feed valves, as shown in rectangle 219.

[0067] In a preferred embodiment, this network distribution pipeline utilizes existing water, sewer, and stormwater drainage pipes as hydrogen pipelines between local distribution points and end-user locations. Adopting this system and method will result in the lowest-cost, widest possible distribution of hydrogen 101 to end users, including but not limited to (1) meeting power grid service needs 122, as shown in rectangle 220; (2) extending coverage to individual homes to provide heating, cooking, and fuel for hydrogen vehicles 125 and to meet residential electricity needs 126, as shown in rectangle 221; (3) meeting commercial and industrial applications 127 and electricity needs 129, as shown in rectangle 222; and delivering gaseous hydrogen to the location of hydrogen refueling stations 130. Once at such refueling stations 130, operators can use compressors to increase the pressure of hydrogen 101 in passenger vehicles to 10,000 psi; 5,000 psi in heavy-duty tractors; or such other required distribution pressure, as shown in rectangle 223, whereby hydrogen 101 can be distributed for fuel cell vehicles, as shown in rectangle 224.

[0068] Each of the above steps ends at ellipse 226, thus completing the sequence. As will be apparent to those skilled in the art, in order to practice the principles disclosed herein, it is not necessary to... Figure 2 All the steps shown, and therefore some of them are optional, are clearly attractive and increase the system's usefulness. Similarly, it should be understood that... Figure 2The order in which these steps are described is merely illustrative, and in various circumstances that will be apparent to those skilled in the art, these steps may be performed in a different order without departing from the principles disclosed herein.

[0069] Turning to Figures 3(a)-3(d), a number of alternative devices for transporting and distributing hydrogen 101 according to the principles of the disclosed technology are shown. It will be apparent to a person skilled in the art that not all of these devices are necessary, and therefore an operator may wish to employ some, but not all, of the principles shown in Figures 3(a)-3(d) depending on the specific circumstances.

[0070] For the reasons described in the background art, there are many places around the world where very attractive low-cost renewable energy sources naturally emerge, but it is logistically or economically infeasible to transport electricity and / or hydrogen 101 to these active green energy markets via pipelines. In some cases, lighter-than-air airships can be used to meet these needs. The exoskeleton 301 in Figure 3(a) corresponds to a cross-sectional view of an exemplary airship exoskeleton known in the art. The upper portion of the exoskeleton region, approximately 85%, is preferably used for lifting gas, while the lower portion, approximately 15%, is primarily used for cargo storage. As described below, in this case, the region can be used as an attractive means of transporting hydrogen 101.

[0071] In a preferred embodiment, as described in step 206, the rated hydrogen cylinder module 302 is pre-filled with gaseous hydrogen 101 at or near the airship landing point, the airship landing point being close to the location most advantageous for generating this hydrogen 101, as per [reference to...]. Figure 2 As described in step 202. As a non-limiting example, suppose a 40' long Titan was manufactured by Hexagon Lincoln. ® Storage tanks, the company's standard Titan ® The 4-module Type 4 composite carbon fiber hydrogen cylinder 302 measures 40'L x 8'W x 8'H (12.19m x 2.44m x 2.44m) and can transport 610 kg of hydrogen at 250 bar (approximately 3625 psi). The module is approved by the U.S. Department of Transportation with an unloaded weight of 34,500 lbs (15,649 kg) and a fully loaded weight of 35,850 lbs (16,259 kg). The number of these hydrogen cylinder modules 302 and the total volume of hydrogen 101 that can be transported per day will depend on operating time, distance traveled, expected number of flights without refueling, and the average cruising speed of the lighter-than-air airship.

[0072] As previously described, loading such pre-filled gas cylinders 302 onto the airship can be accomplished by any number of methods. In a preferred embodiment, the gas cylinder module 302 can be loaded onto the airship using a rapid loading and unloading system comprising rows of parallel rails located within the airship hull, which receive and hold the gas cylinder module 302 by suspending it from rail wheels in a pod-like manner, as is known in the art. In another preferred embodiment, the pre-filled gas cylinder 302 can be held on a transport trailer 303 during transport of the airship. Although the choice of the optimal method will be based on various factors, including minimizing loading and unloading time, for the purposes of this description, it is assumed that the gas cylinder 302 remains on the trailer. Therefore, as per [the relevant information]... Figure 2 As described in rectangle 207, once the airship arrives and is secured in the desired position, in a preferred embodiment, the tractor cab 304 is connected to the transport trailer 303, allowing the entire equipment to be driven directly into the airship's cargo hold.

[0073] For reasons readily understood by those skilled in the art, it is advantageous to maintain a relatively constant total weight of the lighter-than-air airship during loading. To minimize any sudden weight changes, in a preferred embodiment, as the filled gas cylinder 302 is driven onto the airship, the second tractor cab 304 uses its transport trailer 303 to unload the empty gas cylinder module 302 from the airship, resulting in a modest weight change of approximately 1350 pounds for 610 kg of hydrogen.

[0074] After this exchange, the tractor cab 304 transports the empty cylinder module 302 to the location where it will be refilled, and the transport trailer 303 of the module is detached, allowing the tractor cab 304 to be used to transport another cylinder module 302. The empty cylinder is left at the refill location to be filled with hydrogen 101 at an appropriate time, the filling process of which can be carried out from the on-site storage container 111(a) or another storage container or an upstream production source, such as... Figure 2 The rectangle 206 is shown. In effective operation, when the tractor unloading the empty gas cylinders 302 transports these empty cylinders to the appropriate location, the hydrogen transport trailer 303, which loads the pre-filled gas cylinders 302 onto the airship, is detached from its corresponding tractor cab 304 so that its driver can use it for the next task. In an alternative embodiment, the hydrogen transport trailer 303 and its pre-filled gas cylinder module 302 are secured to the airship's cargo hold floor 305 using cables 306.

[0075] Once the airship's weight, taking into account the weight of the required fuel, reaches its maximum payload limit, the cargo door closes, the lighter-than-air airship ascends to the desired altitude, and flies to its destination to retrieve the gaseous hydrogen 101 it carries in hydrogen-filled cylinders 302. Upon arrival at its predetermined destination, as shown in rectangle 209, the process is reversed, with the filled cylinder modules 302 unloaded from the airship and other emptied cylinder modules 302 loaded onto the airship at their locations. During the duration of this airship flight, hydrogen 101 can be released from the filled cylinder modules 302 remaining at the destination, while the empty cylinders 302 remaining at the origin are pre-filled at or near the hydrogen 101 production site. Although the process has been described for the delivery of gaseous hydrogen 101, the aforementioned process can also be used for the delivery of cryogenic (liquid) hydrogen 101 to further minimize the total cost per kilogram of hydrogen 101 at the end-user's receiving point.

[0076] Once at the intended destination, hydrogen 101 may be transported and / or distributed using cylinder module 302, hydrogen transport trailer 303, and tractor cab 304, depending on local conditions and other factors readily understood by those skilled in the art. Alternatively, it may be advantageous to use one or more hydrogen transport trailers 114 and / or pipelines 115. In a preferred embodiment, the delivery and distribution of hydrogen 101 employs the techniques disclosed below.

[0077] Referring now to Figure 3(b), pipeline 307 represents an existing pipeline, such as a natural gas or oil pipeline, a water or sewage pipeline, a storm drain, or other pipeline, the route of which may be useful for the transport and / or distribution of hydrogen 101. Hydrogen transport pipeline 308, as shown in Figure 3(b), in a preferred embodiment, operates within a safety pipeline 309, inserted into the existing pipeline 307, for the transport and / or distribution of gaseous hydrogen 101, utilizing the right-of-way and capital investment required to obtain land and / or necessary land rights, ensuring regulatory approval, and installing and maintaining such existing pipeline 307. A quick-release coupler and fitting 310 is preferably used for inserting hydrogen transport pipeline 308 into safety pipeline 309 and for other safety, practical, and maintenance purposes described below.

[0078] Those skilled in the art will know that in the United States, various regulated utility companies and master limited partnerships (MLPs) own and control transmission and distribution lines and storage facilities that connect supply areas to high-demand markets for natural gas and crude oil. In Europe, ownership of such existing pipelines is primarily controlled by transmission system operators (TSOs), who, despite being under public control, operate like private companies. In other countries, there exists some form of private ownership under public regulation, public or indigenous ownership, or a combination of both. In some cases, water supply, sewer, and stormwater drainage pipelines may be owned by similar interest groups or local government entities. Therefore, the financial return on these existing pipelines 307 can be enhanced based on any number of possible contractual arrangements that allow for the installation of such a secure pipeline 309 in exchange for compensation to the existing pipeline owner based on the volume of hydrogen 101 per mile of such existing pipeline 307.

[0079] In the case of natural gas and oil pipelines, this new revenue opportunity could help offset the risk of declining revenue as future fossil fuel transport volumes decrease and hydrogen usage increases. Furthermore, such an arrangement would significantly reduce the time and initial capital investment required to build hydrogen infrastructure and decrease the negotiated tariffs that can be passed on to end users, namely the cost of 101 per kilogram of consumed hydrogen, while also helping to extend and convert the lifetime economic value of these already “sunk” oil and gas investments.

[0080] Where it is necessary to accommodate physical obstructions (such as shut-off valve 311) in existing pipeline 307, a riser 312 (or an underground equivalent) may be installed to allow hydrogen 101 to flow continuously through hydrogen delivery pipeline 308 without adversely affecting the normal functioning of these components and control features of existing pipeline 307. The riser 312 or its equivalent may also be used to make quick-release couplers and fittings 310 more accessible to support the isolation and maintenance of one or more sections of hydrogen delivery pipeline 308, and to enable the use of two or more other unrelated existing pipeline 307 systems to route hydrogen delivery pipeline 308 to the desired location without mixing the contents of any such existing pipeline 307. Those skilled in the art will readily understand that fully automated electronic metering equipment can be used to monitor the volume of hydrogen 101 flowing through such hydrogen delivery line 308 to ensure that transmission costs are appropriately and fairly distributed among multiple existing line owners 307, and in a preferred embodiment among multiple line owners 307, thus enhancing the investment in upgrades and improvements required for such a system for hydrogen 101.

[0081] In a preferred embodiment, a large spool of FRP pipe 313 can be used for the storage of gaseous hydrogen 101, replacing the conventional hydrogen tank 111. This spool-based alternative storage using FRP pipe 313 offers numerous subtle advantages over existing technologies in terms of large-scale hydrogen storage and / or providing “shock absorption” for power distribution networks. Among other things, as described in the background disclosure, FRP pipes meet existing ASME specifications, have a 50-year service life, and require minimal maintenance, while conventional gaseous hydrogen tanks 111 have a shorter lifespan and require costly maintenance and recertification approximately every 5 years. Furthermore, the large-diameter FRP pipes can be extruded in-situ, avoiding the logistical difficulties associated with large-capacity hydrogen tanks 111 (or the costs and technical problems associated with using underground caverns for such storage) and improving the ability to rapidly scale up at new locations. The in-situ extrusion of FRP pipes also has the added advantage of allowing the transport of bulk materials such as resin and avoiding “shipping air” when transporting finished pipelines. Furthermore, optical sensors, hydrogen sensors, electrical signal lines, power cables, and capillary tubes can be integrated into the layered structure of the FRP tube to ensure rapid detection of any hydrogen leaks 101. A shut-off valve, combined with a quick-release coupler and fitting 310 at one or more spool ends of the FRP tube, allows the operator to quickly isolate and replace damaged sections or adjust the overall storage capacity.

[0082] When estimating a lifespan exceeding 50 years, utilizing spools of FRP tube 313 at H2@scale results in a significantly lower total lifespan cost compared to conventional hydrogen storage solutions, taking into account savings in installation costs, delays in field approvals, avoidance of recertification requirements, and reduced replacement costs. Furthermore, when used in conjunction with fuel cells to convert hydrogen 101 back into electricity, the cost of using spools of FRP tube 313 is estimated to be less than one-tenth (10%) of that of battery storage for large-scale energy storage, offering numerous other advantages including longer energy retention time, longer lifespan, and, depending on the battery type, significantly reduced natural resource constraints and / or waste disposal issues. Considering the significantly higher surface area to volume ratio represented by spools of FRP tube 313 compared to conventional hydrogen storage tanks 111, and the common preference of those skilled in the art for battery storage, the aforementioned cost savings are highly materialistic and counterintuitive.

[0083] Next, turning to Figure 3(c), a detailed view of section aa of Figure 3(b) is presented to illustrate the contents of the existing pipeline 307. Depending on the specific circumstances, the contents 314 of the existing pipeline 307 may be natural gas or syngas, crude oil or other liquid petroleum products, biofuels, various other industrial gases, drinking and non-drinking water, sewage, sludge, stormwater runoff, and other liquids. If sufficient volume capacity is available, a safety pipeline 309 (which in turn includes a hydrogen delivery pipeline 308) may operate within the existing pipeline 307 for the delivery of gaseous hydrogen 101, as previously described. This avoids contamination and, if necessary or required, enables the delivery of pure, higher-value hydrogen 101. In a preferred embodiment, a channel or purge line 315 between the outer surface of the hydrogen delivery pipeline 308 and the inner surface of the safety pipeline 309 is used as a purge line for introducing a suitable purge gas and for diluting and collecting any gaseous hydrogen 101 that may leak from the hydrogen delivery line 308.

[0084] In an alternative implementation, subject to regulatory approval, when the contents 314 of the existing pipeline 307 consist of a gas or liquid, the safety line 309 may be omitted. This gas or liquid can be used as a suitable purge gas to collect any hydrogen 101 that may leak from the hydrogen delivery pipeline 308, provided that the operator of the existing pipeline 307 is not concerned about such a leak contaminating the contents 314 of the existing pipeline 307. Non-limiting examples of the contents 314 of the existing pipeline 307 that may be used in this alternative implementation are synthetic natural gas (SNG), liquid natural gas (LNG), nitrogen, carbon dioxide, or helium.

[0085] Figure 3(d) shows an enlarged view of section BB of Figure 3(c) in the area between the two vertical dashed lines 330 drawn thereon. Specifically, this portion of Figure 3(d) shows the existing line 307 and its contents 314, and the safety line 309 and its contents. As described above, in a preferred embodiment, the contents of the safety line 309 include a hydrogen delivery line 308, its gaseous hydrogen contents 101, and a purge line 315, which serves as a channel for purging any hydrogen leaks 323. In a non-limiting example, the safety line 309 is a 6" diameter flexible tube made of any material, including but not limited to metals, plastics, and composites, compatible with both hydrogen and a selected purge gas flowing through the purge line 315, and the hydrogen delivery line 308 is a 3" FRP tube suitable for delivering gaseous hydrogen 101 at any pressure from atmospheric pressure to the maximum permissible operating pressure of the hydrogen delivery line.

[0086] according to Figure 2In steps 214 and 218, gaseous hydrogen 101 is injected into hydrogen delivery line 308 via inlet valve 316 from hydrogen storage tank 111 or another storage system (including, but not limited to, in a preferred embodiment, from a spooled FRP pipe storage system 313), upstream hydrogen pipeline, hydrogen production or evaporation system, compressor, or other source. If applicable, according to... Figure 2 In steps 213, 215, 217, or 219, pressure gauge 317 monitors this injection to ensure that hydrogen 101 is at the appropriate pressure before and after injection into hydrogen delivery line 308. For control and billing purposes, including but not limited to the point where hydrogen 101 is delivered to the end user and removed from the system (as indicated by arrow 324 in Figure 3(d)), it is preferable to capture key information about the hydrogen 101 injection, including the released volume, purity, and pressure, at this point and other appropriate points. This data is transmitted by wireless transmitter 318(a) to receiver 319, which in turn connects to active monitoring system 320 to record, analyze, plot, and initiate appropriate preventative, responsive, and / or billing and reimbursement actions against other data.

[0087] The purge line 315 is filled with purge gas from the storage tank 321. A hydrogen sensor 322(a) is used to establish a baseline level of hydrogen contained in this purge gas; and this data is preferably transmitted by a wireless transmitter 318(b) to a receiver 319 and then uploaded to the active monitoring system 320. Additional hydrogen sensors, such as sensor 322(b), can be strategically positioned along the purge line 315 to individually monitor the hydrogen level (if any) contained in the purge gas as it passes the location of each sensor; and this data can similarly be transmitted to the monitoring system 320 via a wireless (or direct) connection 318(c) and combined with other data already in the system 320 to create a real-time map of the system and monitor for operational anomalies. Those skilled in the art will understand that the aforementioned use of well-placed hydrogen sensors 322, active monitoring, real-time computing and intuitive displays, and / or processors enables such a system to detect and locate the source of any hydrogen leak 323 from the hydrogen delivery line 308. Similarly, those skilled in the art will understand that, where appropriate, after the purging gas in the purge line 315 has been used in the indicated manner, it can be sold as a byproduct of the system, reused once or multiple times in the purge line 315, or disposed of responsibly as waste at the operator's discretion. These alternatives are indicated by arrow 325.

[0088] In an alternative implementation where the existing pipeline 307 is used for the delivery of synthetic natural gas or another product 314 that can be used as a purge gas in the aforementioned system, such a hydrogen sensor 322 is preferred to be used to monitor the hydrogen level in the contents 314 to detect hydrogen leaks 323 and ensure the operation of the system without adversely affecting its safety or efficiency. Those skilled in the art will understand that in the aforementioned alternative implementation, the contents 314 of the existing pipeline 307 are themselves capable of purging / flushing any hydrogen 101 that may leak from the hydrogen delivery pipeline 308, and changes in the hydrogen level in such contents 314 should be actively monitored to ensure appropriate steps are taken in the event of a failure in the hydrogen delivery pipeline 308 or an excessive leakage of hydrogen 101 from it 323.

[0089] In preferred and optional alternatives, if an operator and / or automated software monitoring system 320 observes an excessive level of hydrogen 101 in the gas, a command can be sent manually or using automated programming to close valve 316 using a wireless transmitter 318(a) communicating with receiver 319 until the problem is located and corrected. Those skilled in the art will understand the purpose of such an emergency protocol, as well as the quick-release coupler and fittings 310, and additional optional components typically used for pipeline transport of industrial gases, including, but not limited to, shut-off valves that can be used to isolate sections of hydrogen delivery lines 308 in an ordered system.

[0090] Figures 4(a)-4(d) illustrate a non-limiting illustrative case involving the production, transportation, large-scale storage, and distribution of Green Hydrogen 101. This case assumes the production of Green Hydrogen 101 at a uniquely advantageous location on the Big Island of Hawaii, its transportation to Oahu, and its widespread distribution there. The principles of the disclosed technology are applicable globally as part of establishing a safe, low-cost, and rapidly scalable transportation infrastructure, storage@scale, and the distribution of Hydrogen 101 as an alternative to fossil fuels for transportation and electricity.

[0091] Figure 4(a) illustrates a flight path of approximately 275 miles 401 for a lighter-than-air airship 402, connecting the Puna geothermal production site 403 at the southern tip of Hawaii Island and / or an area 404 ideally suited to the island's elevation of a large wind farm to a potential terminal location 405 on approximately 25 acres of land on Oahu. Assuming an average cruising speed between 150 and 200 miles per hour, airship 402 could have a net payload potential between 200 and 300 tons, enabling each round trip of 4 hours or less to transport approximately 10,000 kg of gaseous hydrogen 101 at a pressure of 3,625 psi from a landing point near production sites 403 and / or 404 on Hawaii Island to terminal 405, as demonstrated on Oahu. Assuming five round trips per day and 360 days of operation per year, one airship could deliver 18 million kg of gaseous hydrogen 101 to Oahu annually, contributing to the state's Clean Energy Initiative goals.

[0092] Figure 4(b) shows a map of Oahu and the final portion of the preferred flight path 401 from airship 402 to terminal 405 near Kunia Village. Close-up detail 406 of the area shows that, in a preferred embodiment, terminal 405 includes an optional turntable 407. Turntable 407 includes a bracket 408 with at least two anchor points on opposite sides of the bracket 408, the anchor points being configured to connect to a tethering cable, which in turn can be connected to the lighter-than-air airship 402. Such a tethering cable can then be used to secure airship 402 to bracket 408. Turntable 407 allows bracket 408 to rotate so that the lighter-than-air airship 402 can always be directly facing the wind during landing and takeoff from terminal 405, and optionally, once airship 402 is securely attached to bracket 408, allows a tugboat (not shown) to pull airship 402 into pylon 409.

[0093] Figure 4(b) also shows the installation of two new delivery pipelines. Pipeline 410, approximately 6 miles long, connects from central Oahu and an optional airship terminal 405 to one of HawaiiGas's eight downstream regulating sites 411, where the company's existing 16-inch main transmission line currently interconnects with Oahu's synthetic natural gas (SNG) distribution system. Although this embodiment envisions a new pipeline segment, the proposed route would enable HawaiiGas to establish a new distribution system serving the Wheeler and Schofield military bases in central Oahu, and transport and distribute SNG and hydrogen 101 to the island's north shore, which currently lacks natural gas service, via a second approximately 10-mile extension 412 from central Oahu to Waialua. While these pipeline extensions are considered preferred, in an alternative embodiment, transmission line extensions 410 and 411 may be delayed and these areas may be served at least temporarily by using a tractor cab 304 to drive a hydrogen transport trailer 303 and its cylinder module 302 to one or both of these interconnection points.

[0094] Figure 4(c) shows a map 413 of Hawaiian Gas's main synthetic natural gas pipelines on the south side of Oahu. Among these existing assets, the company owns and operates a 22-mile-long, 16-inch-diameter steel transmission pipeline 414, which, in a preferred embodiment, will serve as existing pipeline 301 for transporting hydrogen 101 to multiple strategically located distribution points and connection points 411. Transmission pipeline 414 originates from Hawaiian Gas's synthetic natural gas (SNG) plant 415(a), located near Campbell Industrial Park at the southwestern tip of the island, and extends eastward along the south side of Oahu, delivering SNG to connection point 411 and seven interconnected SNG distribution systems via a downflow regulator.

[0095] Hawaiian Gas Company’s Synthetic Natural Gas (SNG) plant 415(a) currently produces SNG using naphtha (a liquid petroleum feedstock). Therefore, in a preferred embodiment, the company’s total daily demand for naphtha will be replaced by less than 20% of green hydrogen 101 produced and transported daily from Oahu, which is transported from terminal 405 via tractor cab 304 and transport trailer 303 or via new pipeline 410 and existing pipeline 414 as pipeline 301 in the publicly disclosed technology. This technology can also be used to transport the remaining portion of green hydrogen 101 from connection point 411 to emission regulation sites 415(b) near Pearl City; 415(c), near Honolulu International Airport; and 415(d), located at the eastern end of transmission line 414, and serving the company’s largest SNG distribution system at Honolulu Port Pier 38 near downtown Honolulu. In addition, in a preferred embodiment, using selective smaller diameter hydrogen delivery lines 308 and safety lines 309, Hawaii Gas’s 10, 8, 6 and 4-inch lines can be used to deliver hydrogen 101 to other distribution points between downtown Honolulu and Hawaii’s Kai District 416.

[0096] Figure 4(d) shows a map of water supply and sewage pipes 417 and stormwater drainage pipes 418 in the Honolulu area, representing the most densely populated area at the southeastern tip of Oahu, as highlighted in section 419. The density of existing pipelines in this area illustrates the breadth of potential distribution that could be achieved using the disclosed techniques. Those skilled in the art will understand that this could be true for communities around the world that require hydrogen distribution.

[0097] As will be understood from the foregoing disclosure, although specific implementations have been described herein for illustrative purposes, various modifications may be made without departing from the spirit and scope of the appended claims and the elements described therein. Furthermore, while certain aspects have been presented as optional or preferred embodiments, none of these embodiments are essential and may therefore be combined as appropriate to achieve the desired result. Moreover, although certain aspects are presented in the form of certain claims in the appended document, the inventors contemplate presenting various aspects in any available claim form. Various modifications and changes are possible and will be apparent to those skilled in the art who benefit from this disclosure. It is intended to encompass all such modifications and variations; therefore, the foregoing description should be considered illustrative rather than restrictive.

Claims

1. A hydrogen distribution system for delivering hydrogen from a hydrogen supply source to at least one end-user location, comprising: Existing pipelines; A hydrogen delivery line configured to deliver pressurized hydrogen, the hydrogen delivery line being located within the existing pipeline such that a channel is formed between the outside of the hydrogen delivery line and the inside of the existing pipeline, the channel being sized to allow the flow of a non-flammable purge gas and to remove any hydrogen leaking from the hydrogen delivery line. At least one hydrogen sensor is disposed within the channel and is configured to monitor the presence and content of hydrogen within the channel; A programmable alarm system configured to trigger and alarm based on hydrogen levels detected by the at least one hydrogen sensor; At least one inlet to the hydrogen delivery line is configured to allow hydrogen to be injected into the hydrogen delivery line; At least one outlet from the hydrogen delivery line, configured to allow hydrogen to be extracted from the hydrogen delivery line; and A safety pipeline, located inside the existing pipeline and surrounding the hydrogen delivery pipeline, forms a channel between the outside of the hydrogen delivery pipeline and the inside of the safety pipeline, the size of which allows the purge gas to flow through the channel and along the outside of the hydrogen delivery pipeline.

2. The hydrogen distribution system according to claim 1, wherein, The existing pipeline is a gas transmission pipeline, and the purging gas is one of the following gases: natural gas; or synthetic natural gas.

3. The hydrogen distribution system according to claim 1, wherein, The safety pipeline is made of one of the following materials: plastic; or metal.

4. The hydrogen distribution system according to claim 1, wherein: The existing pipelines include gas pipelines connected to at least one of the following: water pipes; sewers; or storm drains; The at least one inlet for entering the hydrogen transmission pipeline exists in the transmission pipeline; as well as Hydrogen is discharged from the hydrogen delivery pipeline after the hydrogen has been transported through water pipes, sewers, or storm drains.

5. The hydrogen distribution system according to claim 2, further comprising: At least one hydrogen sensor is located at the outlet of the existing pipeline, the at least one hydrogen sensor being configured to monitor the presence and quantity of hydrogen leaking from the hydrogen delivery pipeline into the purge gas.

6. The hydrogen distribution system according to claim 2, further comprising: At least two online hydrogen sensors are located at different locations within the existing pipeline; A data system configured to monitor the at least two online hydrogen sensors to determine the hydrogen level at each online hydrogen sensor; A recording system configured to record the hydrogen level detected by each online hydrogen sensor; as well as A programmable alarm system configured to trigger an alarm based on the hydrogen level.

7. The hydrogen distribution system according to claim 6, further comprising: At least one shut-off valve is configured to selectively isolate and close a section of the hydrogen delivery pipeline when triggered by an alarm from the programmable alarm system.

8. The hydrogen distribution system according to claim 1, further comprising: At least one coupling device, each coupling device connecting a first section of the hydrogen delivery pipeline within the existing pipeline to a second section of the hydrogen delivery pipeline outside the existing pipeline.

9. The hydrogen distribution system according to claim 8, wherein, The hydrogen delivery pipeline is made of FRP pipe for hydrogen, and the second section of the hydrogen delivery pipeline is a storage area.

10. The hydrogen distribution system according to claim 9, further comprising: At least one shut-off valve, each shut-off valve connected to a coupler, the shut-off valve being located at each interval along a predetermined length of the hydrogen delivery pipeline, each shut-off valve and coupler being configured to selectively close; as well as The processor is configured to identify the location of a hydrogen leak based on the hydrogen level detected by each of the at least one hydrogen sensor. Each shut-off valve and coupler is configured to close to isolate the hydrogen delivery line around the predetermined length of the hydrogen delivery line where a hydrogen leak has been identified.

11. The hydrogen distribution system according to claim 1, further comprising: A valve, which is connected to the existing pipeline to control the flow rate through the existing pipeline; The first riser connects to the existing pipeline on the first side of the valve; as well as The second riser connects to the existing pipeline on the second side of the valve. The hydrogen delivery pipeline is configured to guide hydrogen through the first riser, the second riser, and the coupler to bypass the valve.

12. A method for transporting hydrogen from a production location to at least one end-user location, comprising: Hydrogen is produced from energy at the production location. The hydrogen is stored in at least one hydrogen storage container; A hydrogen delivery pipeline is positioned within an existing pipeline such that a channel is formed between the exterior of the hydrogen delivery pipeline and the interior of the existing pipeline. At least one hydrogen sensor is disposed within the channel and configured to monitor the presence and content of hydrogen within the channel. A programmable alarm system is configured to trigger and alarm based on the hydrogen level detected by the at least one hydrogen sensor. The hydrogen delivery pipeline is configured to deliver pressurized hydrogen. A safety pipeline is located inside the existing pipeline and surrounds the hydrogen delivery pipeline such that a channel is formed between the exterior of the hydrogen delivery pipeline and the interior of the safety pipeline. The size of the channel allows purge gas to flow through the channel and along the exterior of the hydrogen delivery pipeline. The purge gas is injected around the outside of the hydrogen delivery line to remove any hydrogen leaking from the hydrogen delivery line; Injecting hydrogen from the at least one hydrogen storage container into the hydrogen delivery pipeline; and The hydrogen is removed from the hydrogen delivery pipeline at at least one end-user location.

13. The method according to claim 12, wherein: The energy source is fixed at the production location; and Methods of transporting hydrogen also include using at least one of the following: trucks; trains; ships; or airships lighter than air.

14. The method according to claim 13, wherein, Transporting hydrogen using airships lighter than air includes: The hydrogen gas is pumped into at least two containers; After the hydrogen is pumped into the at least two containers, the containers are loaded onto the airship, which is lighter than air. To make the airship, which is lighter than air, fly to the destination; The container is unloaded from the lighter-than-air airship at the endpoint. Load at least one empty container onto the lighter-than-air airship; and Return the at least one empty container to the production location.

15. The method according to claim 12, wherein, The energy source is a renewable energy source, which is at least one of the following: wind energy, solar energy, hydropower, biomass, or geothermal energy.

16. The method according to claim 12, wherein, The at least one hydrogen storage container is made of FRP pipe for hydrogen.

17. The method according to claim 12, wherein: The existing pipelines include gas transmission pipelines connected to at least one of the following: storm drains; underground utility corridors; railway lines; or pipelines. The injection of the hydrogen into at least one inlet of the hydrogen delivery pipeline occurs within the pipeline. as well as The removal of hydrogen from the hydrogen delivery pipeline occurs after the hydrogen has been transported through one of the following: a storm drain, an underground utility corridor, a railway line, or a pipeline.

18. The method according to claim 12, wherein, The at least one end-user location is a commercial or industrial facility or a residence.

19. The method according to claim 18, wherein, The refueling station compresses the hydrogen to a pressure suitable for distribution to hydrogen fuel cell vehicles or hydrogen fuel cell trucks.

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