Hydrogen transport, distribution and storage systems, methods and apparatus

Abstract

Systems, methods, and apparatus for transporting and distributing hydrogen, storing energy on a large scale, and interconnecting locations where large quantities of "green" hydrogen can be most advantageously produced with cities, towns, and rural communities where hydrogen is needed for clean transportation fuel, industrial feedstock, power generation, and long-term storage of electricity. The hydrogen distribution pipeline enables the use of existing natural gas, oil, and other pipelines to transport hydrogen to one or more distribution points, and in one embodiment incorporates lighter-than-air airships to transport hydrogen between locations where pipelines do not exist or are impractical. The disclosed hydrogen distribution pipeline also enables the use of existing water, sewer, stormwater, and other pipelines for localized distribution, thereby saving time, money, and reducing construction disruption for communities in establishing these infrastructure elements necessary for widespread use of hydrogen to address climate change.

Description

Technical Field

[0001] This technology generally relates to the storage of energy on a large scale and the transportation of hydrogen from where it is produced to where it is needed by end-users and / or to where it can be distributed to such end-users from there. This technology can be used as a means for transporting hydrogen produced from any source, but it is particularly useful for shortening the time, capital investment, and complexity involved in the installation, transportation, and distribution of "green" hydrogen from a location where the most advantageous production of hydrogen is possible to multiple individual end-use locations such as securing the necessary approvals, obtaining rights of way, electric utilities, commercial and industrial facilities, filling stations, and the homes of consumers who desire to use hydrogen as a clean renewable energy source instead of fossil fuels. This technology also provides an energy storage method that is low in cost, has a significantly higher energy retention rate compared to battery technology, is more cost-effective for new hydrogen in a larger infrastructure than storing hydrogen in conventional storage tanks, is more easily scalable, and offers lower maintenance options.

Background Art

[0002] On September 23, 2020, Bank of America Global Research published a Thematic Investing Report predicting that hydrogen is at a turning point, as it is approaching the point where it can be economically produced from renewable energy sources, and that it could generate $2.5 trillion in direct revenue and $11 trillion in indirect infrastructure by 2050. Those skilled in the art recognize that while the technology to produce hydrogen from water through a process known as "electrolysis" has been used for decades, the widespread systematic use of hydrogen as a fossil fuel alternative or for large-scale electrical energy storage has not yet reached an inflection point and has not achieved mainstream use. According to the Bank of America report, this situation is changing as follows: (1) Lower costs of renewable energy from wind and solar radiation; (2) Lower costs and improved efficiency of electrolytic cell systems that can produce hydrogen from water using such renewable energy, with pure oxygen as the sole byproduct; (3) Improved efficiency, durability, cost and flexibility of fuel cells that convert hydrogen back into electricity using clean water as the sole byproduct; (4) Expansion of the potential end market for green hydrogen as a result of global attention to decarbonization and sustainability; (5) A regulated market for hydrogen by governments adopting increasingly proactive clean energy policies and imposing regulatory requirements to decarbonize energy systems, including the power grid and transportation market sectors.

[0003] According to this report, "green" hydrogen (a term referring, for example, hydrogen produced from renewable resources) could become a crucial component in the fight against global warming, accounting for up to 24% of global energy requirements and reducing harmful emissions by up to 30% by 2050. Bank of America argues that hydrogen will play a significant role for an increasing number of countries and companies signing legally binding commitments to achieve net-zero carbon emissions by 2050, as it is the only clean molecule that can simultaneously meet our energy needs for transportation and power generation. Consequently, many governments, particularly within the European Union, including Canada, China, and Australia, are beginning to offer strong policy support, including increased carbon pricing and financing, to develop hydrogen production capacity and related infrastructure. The U.S. Department of Energy (DOE) is also aiming to accelerate hydrogen research, development, demonstration, and implementation activities through its "H2@Scale" initiative and the Energy Efficiency Renewable Energy (EERE) Office.

[0004] Bringing about a global transition to a "hydrogen economy" faces several practical technical, financial, and logistical challenges. One long-standing, relatively understated challenge involves developing new and improved means of transporting and distributing hydrogen from where it is produced to where end-users need it. Existing pipelines are not suitable for conversion to hydrogen for several technical reasons, including the embrittlement of pipe and valve materials. In a 2004 paper titled "The Future of the Hydrogen Economy: Bright or Bleak?", authors Ulf Bossel, Baldur Eliasson, and Gordon Taylor explain that "while the obvious benefits of hydrogen in use are most readily apparent, the upstream aspects of the hydrogen economy have been largely ignored." These authors argue that when the energy required to package, handle, store, and transport hydrogen is added to the energy required to produce it, the future energy economy is "unlikely to be based on elemental hydrogen."

[0005] The challenge stems from the fact that hydrogen's relatively low volumetric energy density makes its transport, storage, and distribution highly inefficient, currently constituting one of the most significant cost and energy inefficiencies in its use as an energy carrier. This problem is exacerbated by the fact that the locations from which low-cost renewable energy sources exist naturally and from which green hydrogen can often be produced most economically are remote and sparsely populated, and consequently tend to be inversely correlated with the locations where clean combustion fuel is most needed.

[0006] Electricity prices account for 60-75% of the cost of green hydrogen. Therefore, locations with large natural sources of low-cost renewable energy from solar radiation (such as equatorial desert regions), wind energy (such as mountain roads and island entrances), hydropower (such as near large bodies of water with significant elevation changes), and / or geothermal energy (such as near active volcanoes or vents) make it possible to produce hydrogen at a significantly lower cost per kilogram. However, these locations where large-capacity, low-cost renewable energy sources naturally exist are generally not close to industrial centers and high population densities, making transportation costs a far more significant factor.

[0007] The transportation and distribution costs of hydrogen can be minimized by locating production sites at or very close to the point of use. However, distributing production to the point of use increases production costs because economies of scale are lost. Furthermore, densely populated metropolises and overcrowded areas with high levels of commercial and industrial activity generally have higher electricity and land costs. Attempts to balance these extreme situations are also difficult. When hydrogen is centrally produced to take advantage of economies of scale, long transportation distances can significantly increase delivery costs. Attempts to semi-centrally produce industrial-scale hydrogen (closer to the point of use) to shorten transportation distances are often constrained by space limitations, safety and aesthetic concerns, and the lack of excess renewable energy capacity.

[0008] For these reasons, delivery costs are critical in all cases and must be minimized. Currently, hydrogen transport trailers and pipelines are the most commonly used options for delivering hydrogen from the production site to where it will be used. In the former option, gaseous hydrogen is compressed from the relatively low pressure of 20-30 bar (290-435 psi) typically produced by electrolyzers to over 180 bar (approximately 2,600 psi) and transported in long cylinders stacked on trailers carried by tractors, trains, or ships. Hexagon Lincoln is a global leader in the manufacture of Type 4 rated carbon fiber cylinders, which are 70% lighter than steel and are manufactured in Titan® tanks up to 40 feet in length, holding up to 950 bar (approximately 13,750 psi) of hydrogen. Such cylinders, called Mobile Pipeline®, provide a simple solution for storing hydrogen and transporting it to locations not on the power grid or where building pipelines is economically or logistically impractical. While practical in the short term, transporting hydrogen in this way is labor-intensive and expensive, and generally not scalable as a long-term alternative to existing fossil fuel transport and distribution infrastructure.

[0009] While it is well known that gaseous hydrogen can be transported via pipelines, just like natural gas today, experts recognize that the high initial capital costs of constructing new pipelines constitute a major barrier to dramatically expanding hydrogen pipeline delivery infrastructure. For this reason, researchers are focusing on overcoming technical concerns, including (1) the potential for hydrogen to embrittle the steel and welds used to manufacture existing steel pipelines, (2) the need to control hydrogen permeation and leakage, and (3) the need for lower-cost, more reliable, and more durable hydrogen compression, liquefaction, and storage technologies. The U.S. Department of Energy's H2@Scale program and similar research efforts in other countries are focusing on two potential solutions.

[0010] The first of these, improved by Oak Ridge National Laboratory (ORNL) and Savannah River National Laboratory (SRNL), involves the use of fiber-reinforced polymer (FRP) pipelines such as Fiberspar LinePipe™, a roll-type product consisting of an internal thermoplastic pressure barrier reinforced with high-strength glass fibers embedded in an epoxy matrix manufactured by National Oilwell Varco (NOV). FRP pipes 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 over 80 million feet (over 15,000 miles) of its Fiberspar LinePipe will be used in oilfield operations in a wide range of temperature and terrain-specific installations, including surface laying, embedding in conventional open trenches, tilling, and installation inside broken steel pipelines for repair purposes. Its FRP pipes are available in continuous lengths up to 9,000 feet (2,740 m) on reels, with diameters between 2" and 6". Based on tests conducted by SRNL and ORNL, SRNL and the American Society of Mechanical Engineers (ASME) have specified FRP pipes up to 6" in diameter in ASME B31.12 ("Hydrogen Piping Code") for gaseous hydrogen transmission up to 2,500 psi and a design life of 50 years.

[0012] Researchers estimate that using FRP pipelines would result in approximately 20% savings compared to steel pipes because they can be installed in much narrower passages and can be obtained in much longer sections than steel, thereby minimizing welding requirements, and avoiding the need for coating or X-rays because FRP pipelines are non-corrosive. According to ORNL's estimates, the total capital expenditure ($2007) for an FRP hydrogen pipeline would be slightly under $600,000 per mile, including approximately $350,000 per mile for FRP pipelines, materials, and equipment, and an estimated $250,000 per mile for obtaining passages and permits. According to ORNL's research, this cost is favorable compared to the estimated capital expenditure of $636,000 for a 16-inch steel pipeline.

[0013] A second alternative involving pipeline transport, which researchers see as a promising way to grow hydrogen delivery infrastructure, is adapting expanded natural gas transport and distribution infrastructure to accommodate hydrogen. Inspired by the EU's "Hydrogen Strategy for a Climate-Neutral Europe" of July 2020, as well as indicators of G20, German, and Japanese interest in the development of hydrogen technologies, German pipeline operators Nowega and Gascade, together with Siemens Energy, produced and published in October 2020 a comprehensive white paper studying the practical aspects of repurposing natural gas pipelines as pillars of a future hydrogen-based energy transition. The company's proposal envisions converting existing natural gas pipelines and storage facilities to carry a mixture of natural gas and hydrogen (up to approximately 20% hydrogen), based on research showing that this can be achieved with only minor modifications to the pipelines and without resulting in embrittlement of pipe and / or valve materials. However, in this alternative, hydrogen must be separated and purified at the point of extraction. For efficient use in fuel cells, extracted hydrogen must have a purity of at least 99.9%. Recent modeling activities have identified the significant costs associated with achieving this.

[0014] The applicant's earlier patent application No. 12 / 290,453, now U.S. Patent No. 8,336,810 ('810 patent), filed on 29 October 2008, describes the use of airships lighter than air to transport hydrogen from locations where natural conditions make hydrogen production most economical to locations with strong market demand. However, this earlier disclosure is limited to providing means for transporting hydrogen to one or a few destinations and does not address issues related to broad distribution, etc. [Prior art documents] [Patent Documents]

[0015] [Patent Document 1] U.S. Patent No. 8,336,810 [Overview of the Initiative]

[0016] This technology overcomes the long-standing problems and limitations of conventional technologies, providing a means of transporting hydrogen from the site of production to the areas where it is most needed, with far less time, capital costs, and complexity associated with land use, right of way acquisition, permits, construction and ongoing maintenance, large-scale storage, and extensive distribution to end-users across such market areas.

[0017] This technology provides systems, methods, and apparatus for cost-effectively transporting, storing, and widely distributing hydrogen from its production site to where it is most needed. This technology overcomes many of the technical constraints associated with hydrogen transport, storage, and distribution, significantly reducing the extremely high installation costs, delays, land use, and permissible barriers.

[0018] Many regions have invested heavily in long-distance natural gas and oil pipelines. Similarly, every city, most towns, and many rural communities worldwide have invested heavily in water, sewage, and storm drainage systems. Collectively, in this specification, all of these pipelines and systems—including those currently in use, those that may be decommissioned, and those yet to be constructed—are referred to as “existing pipelines.” The term “existing pipelines” as used herein also includes, but is not limited to, underground utility lines, rail lines, and tubes, including future systems such as Hyperloop. The land on which these existing pipelines are constructed has been acquired, access rights and permits have been granted, and significant investments have been made to excavate, install, and maintain these existing pipeline systems. Many of these existing pipelines have sufficient potential to be used as hydrogen distribution pipelines, capable of transporting and distributing hydrogen at any level of purity.

[0019] This technology involves preparing a hydrogen distribution pipeline by inserting a "hydrogen delivery line" into one or more of these existing pipelines. Such a hydrogen delivery line is made of (but not limited to) materials such as ASME-specified FRP pipes for carrying pressurized hydrogen, and the pressurized hydrogen is contained inside a larger diameter pipe that provides means for collecting hydrogen leaking from the hydrogen delivery line. A sweeper or inert gas or liquid, referred herein as a "purge gas" or "sweeper gas," is flowed outside the hydrogen delivery line to remove hydrogen leaking from such line. Such a purge gas may be nitrogen, CO2, etc., and depending on the circumstances and the preferences of the individual operator, the product flowing through such existing pipelines may be used as such a sweeper gas if the leakage of hydrogen into the existing pipeline does not cause a safety risk or an unacceptable level of contamination.

[0020] In other cases, if a potential leak of hydrogen into the contents of such an existing pipeline is unacceptable to the operator or could pose a safety risk (for example, if the existing pipeline carries water or contains ambient air), the hydrogen delivery line must run inside an intermediate "safety pipe." This safety pipe is made of any material compatible with hydrogen and the contents of the existing pipeline, and the purge gas flows inside a channel located between the outer surface of the hydrogen delivery line and the inner surface of the safety pipe.

[0021] In a preferred embodiment, the contents of a sweeper line are continuously tested for hydrogen levels, and the data collected therefrom is monitored to detect leaks in the hydrogen delivery line. If a leak is detected that exceeds a predetermined threshold level considered acceptable, the flow of hydrogen to the hydrogen delivery line may be programmed to be manually shut off or automatically shut off until the leak is corrected. In another preferred embodiment, multiple hydrogen sensors are placed at various intervals throughout the system, thus allowing for more precise identification of the location of hydrogen leaks exceeding a predetermined threshold level, enabling an area of ​​interest to be isolated and removed from service until the leak is corrected, during which time the system balance can be restored.

[0022] In an optional preferred embodiment, an airship lighter than air can be used in conjunction with the aforementioned system. The airship can transport large quantities of hydrogen from a geographically most economically produced location to a strategically located endpoint relative to the existing pipeline distribution system. Upon arrival at this location, its hydrogen-carrying tanks may be connected to an inlet to the hydrogen pipeline described above, and the hydrogen is discharged into the system. In another preferred embodiment, the transport of hydrogen using the airship can be in a liquid (cryogenic) state, and upon delivery at the destination, a vaporizer is used to convert the hydrogen from liquid to gaseous form.

[0023] In at least one embodiment, the technology relates to a hydrogen distribution system for transporting hydrogen from a hydrogen source to at least one end-user location. The system includes an existing pipeline and a hydrogen delivery line configured to carry pressurized hydrogen. The hydrogen delivery line is installed inside the existing pipeline, and a sweeper gas in the existing pipeline flows around the outside of the hydrogen delivery line to purge any hydrogen leaking from the hydrogen delivery line. 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 is configured to allow hydrogen to be withdrawn from the hydrogen delivery line.

[0024] In some embodiments, the existing pipeline is a gas transmission pipeline, and the sweeper gas is either natural gas or synthetic natural gas. In some cases, the system includes a safety pipe positioned inside the existing pipeline and around the hydrogen delivery line, such that a flow path is formed between the outside of the hydrogen delivery line and the inside of the safety pipe. The flow path is sized to allow the sweeper gas to flow through the existing pipeline along the outside of the hydrogen delivery line. In some cases, the safety pipe is made of plastic or a composite material. In some cases, the existing pipeline is a water pipeline, a sewer pipeline, or a stormwater pipeline. In some embodiments, the existing pipeline includes a gas transmission line connected to at least one of the water pipe, sewer pipe, or stormwater pipe. At least one inlet to the hydrogen delivery line can then be generated within the gas transmission pipeline, and the hydrogen drawn from the hydrogen delivery line is generated after the hydrogen has been transported through the water pipe, sewer pipe, or stormwater pipe.

[0025] In some embodiments, the system includes at least one hydrogen sensor disposed at the outlet of an existing pipeline, and the at least one hydrogen sensor is configured to monitor the presence and amount of hydrogen leaked from the hydrogen delivery line into the sweeper gas. In some cases, the system includes at least two in-line hydrogen sensors disposed at different locations within the existing pipeline. The system can include a data system configured to monitor the at least two in-line hydrogen sensors to determine the hydrogen level of each in-line hydrogen sensor. The system can further include a recording system configured to separately record the hydrogen levels detected by each in-line hydrogen sensor. Additionally, the system can include a programmable alarm system configured to trigger an alarm based on the hydrogen level. In some embodiments, the system includes at least one shut-off valve configured to selectively isolate and close a section of the hydrogen delivery line when triggered by an alarm from the programmable alarm system. In some embodiments, the hydrogen delivery line is an FRP pipe defined for use with hydrogen.

[0026] In some embodiments, the system includes at least one coupling device, and each coupling device connects a first section of the hydrogen delivery line inside 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 an FRP pipe defined for use with hydrogen, and the second section of the hydrogen delivery line is a storage area.

[0027] In some embodiments, the hydrogen delivery line includes at least one hydrogen sensor. Each hydrogen sensor can be configured to separately generate data related to the detected hydrogen level. The system can further include means for monitoring the hydrogen level detected by each of the hydrogen sensors. The system can also include alarm means (e.g., a processor having a display, or other audio or visual output device) configured to generate an alarm when the detected hydrogen level indicates that hydrogen is leaking from the hydrogen delivery line.

[0028] In some embodiments, the system includes at least one shut-off valve. Each shut-off valve is connected to a joint. The shut-off valves are arranged at each interval of a predetermined length of the hydrogen delivery line, and each shut-off valve and joint are configured to selectively close. The system can include a processor configured to identify the location of a hydrogen leak based on the hydrogen level detected by the hydrogen sensor. Each shut-off valve and joint can be configured to close to isolate the hydrogen delivery line around a predetermined length of the hydrogen delivery line where the hydrogen leak is identified.

[0029] In some embodiments, the system includes a valve connected to an existing pipeline and controlling the flow therethrough. The system can then include a first riser connected to the existing pipeline on a first side of the valve. Further, the system can include a second riser connected to the existing pipeline on a second side of the valve. The hydrogen delivery line can then be configured to direct hydrogen through the risers and joints to bypass the valve.

[0030] In at least one aspect, the technology relates to a method for transporting hydrogen from a production site to at least one end-user location. The hydrogen is produced from an energy source at the production site. The hydrogen is then stored in at least one hydrogen storage vessel. The hydrogen delivery line is located or installed within an existing pipeline configured to carry pressurized hydrogen. A sweeper gas is injected around the outside of the hydrogen delivery line to purge any hydrogen leaking from the hydrogen delivery line. Hydrogen is injected into the hydrogen delivery line from at least one hydrogen storage vessel. The hydrogen is then drawn from the hydrogen delivery line at the end-user's location.

[0031] In some embodiments, the energy source is fixed at the production site. In some cases, transporting hydrogen involves using at least one of trucks, trains, or ships. In some cases, transporting hydrogen further involves transporting hydrogen using an airship that is lighter than air. In some embodiments, transporting hydrogen using an airship that is lighter than air involves pressurizing the hydrogen into at least two containers. After pressurizing the hydrogen into at least two containers, the containers are loaded onto the airship that is lighter than air. The airship that is lighter than air flies to the destination location. The containers are unloaded from the airship that is lighter than air at the destination location. At least one empty container is loaded onto the airship that is lighter than air. At least one empty container is returned to the production site. In some embodiments, the fixed energy source is a renewable energy source that is at least one of wind, solar, hydro, biomass, or geothermal. In some cases, the hydrogen storage containers are made of FRP pipes specified for use with hydrogen.

[0032] In some embodiments, the existing pipeline is a gas transmission pipeline, and the sweeper gas is either natural gas or synthetic natural gas. In some cases, the terminus site includes a cradle having at least two anchor points configured to secure a lighter-than-air airship with tie-down cables. The cradle may be configured to rotate to face the direction of the opposing wind.

[0033] In some embodiments, the method includes the step of placing safety pipes inside an existing pipeline and around the outside of the hydrogen delivery line. In some embodiments, the existing pipeline is one of the following: a water pipeline, a sewer pipeline, a stormwater pipeline, an underground utility corridor, a rail line, or a tube. In some cases, the existing pipeline includes a gas delivery line connected to at least one of the water pipes, sewer pipes, or stormwater pipes, in which case the injection of hydrogen into at least one inlet is carried out within the gas delivery pipeline. In such cases, the removal of hydrogen from the hydrogen delivery line is carried out after the hydrogen has been delivered through the water pipes, sewer pipes, or stormwater pipes.

[0034] In some embodiments, at least one end-user location is an electric power plant substation. In some cases, at least one end-user location is a commercial or industrial facility. In some embodiments, the method includes a step of utilizing hydrogen in an industrial process feedstock. In some cases, at least one end-user location is a refueling station for distributing hydrogen to fuel cell vehicles. The refueling station may optionally be able to compress hydrogen to a pressure suitable for distribution to hydrogen fuel cell vehicles. The refueling station may optionally be able to compress hydrogen to a pressure suitable for distribution to hydrogen fuel cell trucks. In some embodiments, at least one end-user location is a residence.

[0035] In at least one aspect, the technology relates to a method for storing energy and utilizing the stored energy. The method includes the step of storing hydrogen in at least one spool of an FRP pipe specified for use with hydrogen. Hydrogen is supplied to an energy generation system. Electricity is then generated using the energy generation system.

[0036] In some embodiments, the method further includes the step of placing at least one hydrogen sensor on at least one spool of an FRP pipe. The at least one hydrogen sensor detects a hydrogen leak from at least one spool of the FRP pipe. Electronic data is generated to certify the hydrogen leak when one is detected. The electronic data is monitored, and at least one safety action is taken in response to the detection of a hydrogen leak. The method may further include the steps of installing a shut-off valve and connecting it at predetermined intervals along the FRP pipe for a predetermined length. In some cases, the method includes the steps of locating the hydrogen leak based on the electronic data and isolating a predetermined length of the FRP pipe containing the hydrogen leak using the shut-off valve. In some cases, after isolating the FRP pipe containing the hydrogen leak, the method further includes the step of removing and replacing the predetermined length of the FRP pipe containing the hydrogen leak using a fitting. In some cases, the predetermined length is one spool of the FRP pipe.

[0037] In some embodiments, hydrogen is produced from a renewable energy source, which is at least one of wind, solar, hydro, 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.

[0038] These and other elements of this technology are described with reference to the following drawings and specification. [Brief explanation of the drawing]

[0039] [Figure 1(a)]Figure 1(a) is a schematic diagram illustrating the generation, storage, and optional means of transport of "green" hydrogen. [Figure 1(b)] Figure 1(b) is a schematic diagram showing the extraction of hydrogen from these means of transport, its storage in tanks, and the distribution of such hydrogen to various end uses. [Figure 2] Figure 2 is a block flow diagram illustrating the principle of this technology. [Figure 3(a)] Figure 3(a) shows the components of a system for transporting hydrogen using an airship that is lighter than air, which is particularly advantageous in certain situations where other alternatives are not practical or economical. [Figure 3(b)] Figure 3(b) is a side view of a hydrogen pipeline in accordance with the principles disclosed in this technology. [Figure 3(c)] Figure 3(c) is a cross-sectional view of Figure 3(b) when a safety pipe is used in addition to the hydrogen delivery line. [Figure 3(d)] Figure 3(d) is a detailed cross-sectional view of the hydrogen distribution pipeline and related elements for transporting and distributing hydrogen shown in Figure 3(b). [Figure 4] Figures 4(a) to 4(d) illustrate exemplary cases of green hydrogen production from wind and / or geothermal energy on the Big Island of Hawaii, as well as its transportation and widespread distribution on the densely populated island of Oahu. Specifically, Figure 4(a) shows the transportation of hydrogen via an airship, which is lighter than air, between the Big Island and the Oahu terminus. Figure 4(b) shows the transportation of this hydrogen from the main terminal to key distribution nodes on Oahu. Figure 4(c) shows an example where gas transmission lines can be used to transport hydrogen to key storage and distribution locations. Figure 4(d) shows the opportunity for widespread distribution of such green hydrogen to numerous end-user locations via water, sewer, and rainwater pipelines. [Modes for carrying out the invention]

[0040] While embodiments are described herein by example, those skilled in the art will recognize that embodiments are not limited to the examples or drawings described herein. It should be understood that the drawings and their detailed description are not intended to limit the practice to any particular form disclosed, but rather to encompass all modifications, equivalents, and substitutes that fall within the spirit and scope of this disclosure, as defined by the appended claims. Where used throughout this application, the word “may” is used in a permissive sense (i.e., meaning it is possible) rather than a mandatory sense (i.e., meaning it must be done). Similarly, the words “include,” “including,” and “includes” mean to include, but are not limited to, including. Furthermore, as used herein, the terms “interconnected,” “connected,” “linked,” or “attached” may refer to two or more components connected together, whether the connection is permanent (e.g., welded or glued) or temporary (e.g., bolted, held by a physical object, or held in place by friction or tension), direct or indirect (i.e., through an intermediary), mechanical, chemical, optical, or electrical.

[0041] This technology describes improvements to the prior art, including novel and unique systems, methods, and apparatus for transporting hydrogen from its most advantageous production sites, storing it on a large scale, and then distributing it to one or more end-use points, in a manner that overcomes several long-standing technical challenges to enable a more cost-effective transition from fossil fuels to hydrogen economics. As described in the background technology section, cities, most towns, and many rural communities worldwide are ubiquitous with expandable natural gas, oil, and other types of pipelines. Furthermore, all cities, towns, and many rural communities have made substantial investments in water, sewage, and stormwater drainage systems as essential public infrastructure. The land for these existing pipelines has been acquired, access rights and regulatory approvals have already been granted, and substantial investments have been made to excavate, install, and maintain them. Methods and apparatus that enable the secure transport and distribution of hydrogen within such existing pipelines, as disclosed herein, enable a hydrogen delivery network that is far more cost-effective than other known or currently proposed alternatives.

[0042] In a preferred embodiment, adapting such an existing pipeline for hydrogen transport and distribution involves inserting a hydrogen delivery line contained within a larger diameter safety pipe into the existing pipeline, although under certain conditions, the use of a safety pipe may be optional. As described in detail below, the hydrogen delivery line is preferably made of FRP pipe or equivalent material specified for use with pressurized hydrogen. The safety pipe (or the existing pipeline, if applicable) surrounding it serves as a means of collecting any hydrogen that may leak from the hydrogen delivery line. A sweeper or inert purge gas flowing outside the hydrogen delivery line removes any hydrogen leaked from the hydrogen delivery line. At least one hydrogen sensor is used to test the sweeper or purge gas for hydrogen content, and the hydrogen flow may be shut off if the level of hydrogen leaking into the gas exceeds a predetermined threshold level. In another preferred embodiment, optical fiber lines can be installed to carry signals from hydrogen sensors placed throughout the system, thus allowing for the localization of hydrogen leaks exceeding a predetermined threshold level, where the area requires repair, is isolated, and quickly corrected.

[0043] These and other aspects of the technology are disclosed with reference to the following illustrative figures.

[0044] Figure 1 consists of Figure 1(a) and Figure 1(b). Figure 1(a) shows alternative means for the production, storage, and transport of “green” hydrogen 101. As shown therein, hydrogen gas 101 is produced by electrolysis using one or more electrolytic cells 102, which may use any of several well-known techniques such as alkaline and proton exchange membrane (PEM) electrolysis, and in the future, solid oxide electrolysis or another novel technique may be utilized. As illustrated, the electrolytic cell 102 produces hydrogen 101 by passing an electric current 103 through the anode (+) and cathode (-) suspended in water 104 to release H2 and O2 molecules.

[0045] Electricity 103 is preferably generated from renewable sources such as kinetic energy from a wind turbine 105, solar radiation collected from a solar cell 106, turbine power from a hydroelectric source 107, or geothermal energy 108. Other energy sources such as off-peak or decimated power, as well as new forms of renewable energy such as biofuels produced from landfills and wastewater treatment plants, and gasification of biomass, municipal solid waste, and agricultural residues and biological waste can also be used. Renewable energy projects from voltage stepping and transmission 109 result in significant power losses, and it is generally most efficient to power the electrolytic cell as close to the renewable power source 103 as reasonably possible. It is also possible to produce hydrogen using fossil fuels, and in fact, it is well understood that more than 99% of the hydrogen produced today is made using fossil fuels. Although not shown in Figure 1(a), in any embodiment, hydrogen 101 can be produced using nuclear and fossil fuel sources (including, but not limited to, grid power based on coal or natural gas combustion plants as power source 103, steam methane reforming, and coal gasification) without deviating from the principles relating to hydrogen transport, large-scale storage, and distribution systems described below.

[0046] The generated hydrogen 101 can be compressed to a desired pressure using a compressor 110 and then stored as gaseous hydrogen in a storage container 111(a), or it can be liquefied in a liquefaction system 112 and stored as cryogenic hydrogen in a storage container 113(a). Unless consumed in the same place where such hydrogen was produced, hydrogen is generally transported by one of four methods. As described in the background technology section, two of the most commonly used means of hydrogen transport involve hydrogen transport trailers 114 specifically designed to transport either gaseous or liquefied (cryogenic) hydrogen, and pipelines 115 that include lines specifically constructed for transporting hydrogen, as well as pipelines that carry mixtures of hydrogen and natural gas.

[0047] There are currently 115 dedicated hydrogen pipelines in the United States, ranging from 450 to 800 miles, mostly located along the Gulf Coast and estimated to connect hydrogen producers (refineries) to established long-term customers. In Europe, there are estimated to be 700 to 1,100 miles of hydrogen pipelines, the longest of which extends 250 miles from northern France to Belgium. Furthermore, in response to the aforementioned challenges, it has been proposed to blend up to 20% hydrogen into natural gas as a way to utilize the more than 180,000 miles of natural gas transmission lines (also represented by pipeline 115 in Figure 1).

[0048] Two other modes of hydrogen transport are also shown in Figure 1(a). The first of these modes includes the use of trains and large cargo ships, collectively shown as ship 116. These include Kawasaki Heavy Industries' plan to complete the construction of the world's first liquefied hydrogen carrier, Suisofrontier (Kawasaki Hull 1740), by the end of 2020. Furthermore, the distribution of hydrogen using airships 117, which are lighter than air, is described, as disclosed in the applicant's Patent No. 810.

[0049] Next, referring to Figure 1(b), which shows the extraction of hydrogen 101 from these transport means 114-117, the hydrogen 101 is stored in gaseous form 111(b) or cryogenic form 113(b) for regasification using vaporizer 118 and distribution of such hydrogen to various end uses.

[0050] Those skilled in the art will understand that, as shown by lines 119(a) to 119(e), local distribution of hydrogen 101 is currently carried out solely by the use of hydrogen transport trailers 114, or, in very limited cases, by dedicated hydrogen pipelines 115. Figure 1(b) shows five such end uses of hydrogen that already exist or have been proposed. Line 119(a) shows the distribution of hydrogen 101 for use 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. Line 119(b) shows the distribution of hydrogen 101 for use directly or via fuel cells 123 in residential applications 124, including heating and cooking 125 and power 126.

[0051] Lines 119(c) and 119(d) illustrate the distribution of hydrogen 101 for use in commercial and industrial applications 127. Line 119(c) illustrates its distribution for use in one or more fuel cells 128 to generate electricity 129, and line 119(d) illustrates the distribution of hydrogen 101 to provide fuel or process feedstock for various applications as a carbon-free alternative to fossil fuels. Distribution line 119(e) illustrates the distribution of hydrogen 101 to refueling stations 130 for distributing hydrogen 101 to fuel cell vehicles, including forklifts 131, consumer and fleet passenger cars 132, hydrogen buses 133, heavy trucks 134, and other equipment, industrial equipment such as drones and airplanes (not shown). It is then proposed that such fuel cell vehicles provide auxiliary power, as shown by line 135, which illustrates a fuel cell passenger car 132 supplying electricity to residential applications 124-126. Although not shown, larger fuel cell vehicles, such as bus 133 and heavy-duty truck 134, may be powered during emergencies and power grid outages via vehicle-to-grid (VTG) services, as well as by connecting to individual critical loads such as hospitals and communications equipment to support civil defense, humanitarian, and disaster relief activities.

[0052] Referring here to Figure 2, a block flow diagram illustrating the method according to this technology is shown. The ellipse 201 represents the selection of a geographical location that can be used to produce green hydrogen 101, preferably near a low-cost renewable energy source such as wind 105, solar 106, hydroelectric 107, or geothermal 108, as specified by the rectangular box 202. It is considered preferable that such hydrogen 101 be produced using energy 103 from a renewable energy source and water 104 via electrolysis 102, etc., but this does not preclude other energy sources and production methods that are known and may be developed in the future. If the transport of hydrogen 101 via hydrogen transport trailers or pipelines is not logistically or economically feasible, optional steps 203-209 may be taken to transport the hydrogen 101 to a location where it can be introduced into the main distribution line (as shown in the rectangular box 214, described in more detail below).

[0053] The rectangular box 203 illustrates an optional step of collecting hydrogen produced from multiple sources. A non-limiting example of when this may yield the lowest cost alternative is when the electrolytic cell is located directly adjacent to a physically separated wind turbine in a general area. In such a case, rather than having to invest in batteries and lossy electrical transmission cables to distribute the collected power, each production source can power its own electrolytic cell unit, and the hydrogen produced is collected locally for transport to a single load location. If necessary, such any hydrogen storage is stored at a pressure of up to 2500 psi or more in the future using FRP pipes, as shown in the rectangular box 204 in a preferred embodiment. When used in place of a conventional gas storage tank 111(a), such FRP pipes can be contained within a large spool 313, as will be described in more detail with respect to Figure 313 in Figure 3(b) below.

[0054] The rectangular box 205 shows that such hydrogen gas 101 can be compressed or liquefied as desired and / or preferred by the operator for storage and / or transport. At an appropriate time, one or more empty containment vessels are filled with liquid or gaseous hydrogen, as shown in the rectangular box 206. In non-limiting examples, such containment vessels may be adiabatic cryogenic tanks manufactured by Worthington Industries in the case of liquid hydrogen, or Titan® high-pressure tanks manufactured by Hexagon Lincoln in the case of gaseous hydrogen.

[0055] 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, represented by the rectangular box 207, is preferably performed immediately after the arrival of the airship 117 to minimize turnaround time. In an efficiently designed system, such a transport vehicle returns empty containers from completed pre-deliveries, replaces them with pre-filled containers, and then immediately departs for the destination delivery point of such hydrogen 101. As suggested by the use of the general term “vehicle” in the caption for the rectangular box 207, a lighter-than-air airship is considered preferable in certain situations, but any number of alternative land, air, or sea transport vehicles may be used without departing from the principles of the present art. The rectangular box 208 then illustrates the transport of the hydrogen-filled containers to the intended destination using the selected means of transport.

[0056] Upon arrival at the destination, rectangular box 209 indicates that the filled containers are preferably unloaded from the transport vehicle and the empty containers are loaded in their place. If an airship 117 is used, this container exchange helps stabilize the hull by minimizing the weight difference that must be addressed by releasing or recompressing the lifting gas, or by mechanical restraint or the use of ballast. Once the container exchange is complete, the transport vehicle can depart on a return trip 225 to the preferred manufacturing site, and the aforementioned process, as specified by boxes 202-209, is repeated. While the transport vehicle is on its return journey, ground personnel at the manufacturing site can replenish the empty containers with hydrogen 101 (i.e., step 206), and personnel at the destination can release the hydrogen 101 from the filled containers.

[0057] When the container is filled with liquid (cryogenic) hydrogen, the container is connected to one or more vaporizers 118 to return the liquid to gaseous hydrogen form. This step is shown by a rectangular box 210. A rectangular box 211 indicates an optional step in which the operator wishes to temporarily store the gaseous hydrogen product in a storage container 111(b) before introducing the gaseous hydrogen product into the distribution main line in step 214. Such optional hydrogen storage is shown by a rectangular box 212 in a preferred embodiment and uses FRP pipes, as will be described in more detail with respect to Figure 313 in Figure 3(b) below.

[0058] Alternatively, in addition to the aforementioned options using conventional storage containers 111(b) and FRP pipes 313, the gaseous hydrogen container used in transport step 208 or the vaporizer unit shown in step 210 may be directly connected to the main distribution line, according to the operator's preference. As described above, the use of hydrogen transport trailers is optional, and if the hydrogen production facility is located at the same location as the terminal, the main distribution line may be filled immediately after steps 202, 203, or 204, if necessary.

[0059] To ensure proper operation of the hydrogen pipeline, before introducing gaseous hydrogen 101 into the main distribution line, the operator preferably monitors the inlet line pressure and adjusts it to an optimal pressure level, as indicated by the rectangular box 213. Once the inlet line pressure is adjusted in this manner, gaseous hydrogen is released through the inlet into the main distribution line, as indicated by the rectangular box 214. To ensure proper flow, as indicated by the rectangular box 215, the operator monitors the line pressure and adjusts it to ensure that an optimal pressure level is maintained.

[0060] If the intended end uses of such hydrogen 101 are widely dispersed, the rectangular box 216 indicates that the gaseous hydrogen 101 will then be transported to one or more distribution points from which it can be used or supplied to a wider distribution network, depending on the operator's preference and local market conditions. In a preferred embodiment, such primary distribution lines tend to interconnect hydrogen pipelines between these points using existing gas or oil transmission pipelines. To provide a “shock absorber” to this distribution network, the operator may optionally store the gaseous hydrogen 101 on a large scale using spools of FRP pipe 313 and / or conventional tank storage units 111(b), as shown in the rectangular box 217.

[0061] Before introducing gaseous hydrogen 101 into the local hydrogen distribution line, the operator monitors the inlet line pressure, preferably as indicated by the rectangular box 218, and adjusts it to an optimal pressure level to ensure proper operation of the distribution network. Once such an inlet line pressure is properly adjusted, gaseous hydrogen 101 is introduced into the distribution network line through one or more supply valves, as indicated by the rectangular box 219.

[0062] In a preferred embodiment, such a network distribution line utilizes existing water, sewer, and stormwater pipelines for hydrogen piping between local distribution points and end-user locations. By using this system and method, hydrogen 101 is distributed to end-users as widely as possible at the lowest cost, but is not limited to, (1) meeting the needs of grid services 122, as shown in the rectangular box 220; (2) extending reach to individual homes to meet residential electricity demand 126, providing fuel for heating, cooking, and hydrogen vehicles 125, as shown in the rectangular box 221; and (3) meeting commercial and industrial uses 127 and electricity demand 129, as shown in the rectangular box 222, as well as delivering gaseous hydrogen to locations where hydrogen refueling stations 130 are located. Upon reaching the location of such a refueling station 130, the operator can use a compressor to increase the pressure of hydrogen 101 to 10,000 psi for passenger cars, 5,000 psi for heavy tractors, or other desired distribution pressures as shown in the rectangular box 223, and distribute the hydrogen 101 for use in fuel cell vehicles as shown in the rectangular box 224.

[0063] Each of the aforementioned steps ends at ellipse 226, thereby completing the sequence. As will be apparent to those skilled in the art, not all of the steps shown in Figure 2 are required to implement the principles of the technical disclosure, and therefore some of them are optional, and it is clear that each of the steps shown is attractive and enhances the usefulness of the system. Similarly, it should be understood that the order in which these steps are shown in Figure 2 is merely illustrative, and under various circumstances that will be apparent to those skilled in the art, such steps may be performed in a different order without deviating from the principles of this technical disclosure.

[0064] Referring next to Figures 3(a) to 3(d), several alternative means for transporting and distributing hydrogen 101 according to the principles of the disclosed technology are shown. Not all of these means are necessary, and therefore, depending on the specific circumstances, operators may want to use some, but not all, of the principles shown in Figures 3(a) to 3(d). This will be apparent to those skilled in the art.

[0065] For the reasons explained in the background technology, very attractive and low-cost renewable energy sources occur naturally, but there are many places worldwide where it is not logistically or economically feasible to transport electricity and / or hydrogen 101 from there by pipeline to places where there is an active market for such green energy. In some cases, airships, which are lighter than air, can be used to address such needs. The exoskeleton 301 in Figure 3(a) corresponds to a cross-sectional view of an exemplary airship exoskeleton as known in the art. The upper approximately 85% of the exoskeleton region is preferably used for lifting gas, and the remaining lower approximately 15% is mainly for cargo storage. As will be explained below, this region can be used as an attractive means of transporting hydrogen 101 in such circumstances.

[0066] In a preferred embodiment, the rated hydrogen cylinder module 302 is pre-filled with gaseous hydrogen 101 as described in step 206, at or near an airship landing site close to the location where such hydrogen 101 is most advantageously generated, as described with respect to step 202 in Figure 2. As a non-limiting example, assuming a 40-foot-long Titan® tank manufactured by Hexagon Lincoln, the company's standard Titan® 4 module of Type 4 composite carbon fiber hydrogen cylinder 302 measures 40 feet long (L) × 8 feet wide (W) × 8 feet high (H) (12.19 m × 2.44 m × 2.44 m) and can transport 610 kg of hydrogen at 250 bar (approximately 3,625 psi). The module is approved by the U.S. Department of Transportation and has an empty weight of 34,500 pounds (15,649 kg) and a filled weight of 35,850 pounds (16,259 kg). The number of such hydrogen cylinder modules 302 and the total volume of hydrogen 101 that can be transported per day depend on the operating time, distance traveled, the desired number of trips that do not require refueling, and the average cruising speed of the airship, which is lighter than air.

[0067] As described above, loading such pre-filled cylinders 302 onto the airship can be achieved by any number of methods. In one preferred embodiment, the cylinder module 302 may be loaded onto the airship using a rapid loading and unloading system that includes parallel rails arranged in rows inside the hull, which receive and hold the cylinder module 302 by suspending it from rail wheels in a gondola manner, as is known in the art. In another preferred embodiment, the pre-filled cylinders 302 can be left on the transport trailer 303 during the transport of the airship. The selection of the best method is based on various factors, including minimizing loading and unloading time, but for the purposes of this illustration, it is assumed that the cylinders 302 will be left on the trailer. Thus, as described with respect to the rectangular box 207 in Figure 2, once the airship arrives and is secured in the desired location, in one preferred embodiment, a tractor cab 304 can be attached to the transport trailer 303 and its complete rig can be carried directly into the cargo bay of the airship.

[0068] For reasons that will be readily apparent to those skilled in the art, it is advantageous that the total weight of the airship, which is lighter than air, be kept relatively constant during the loading process. To minimize any sudden weight changes, in one preferred embodiment when the filled cylinders 302 are brought onto the airship, a second tractor cab 304 uses its transport trailer 303 to unload the empty cylinder modules 302 from the airship, resulting in a moderate weight change of approximately 1,350 pounds for 610 kg of hydrogen.

[0069] After this exchange is performed, the tractor cab 304 transports the empty cylinder module 302 to a location where it will be refilled, the module transport trailer 303 is released, and the tractor cab 304 can be used to transport another cylinder module 302. The empty cylinders are left at the refilling location to be refilled with hydrogen 101 at the appropriate time, and the refilling process can be carried out from an on-site storage unit 111(a) or another storage unit or upstream production source, as shown in the rectangular box 206 in Figure 2. In efficient operation, while a tractor unloading empty cylinders 302 transports them to the appropriate location, the hydrogen transport trailer 303 carrying the pre-filled cylinders 302 to the airship is detached from its corresponding tractor cab 304, allowing its driver to use it for the next operation. In one optional embodiment, the hydrogen transport trailer 303 and its pre-filled cylinder module 302 are secured to the cargo bay floor 305 of the airship using cables 306.

[0070] After taking into account the weight of the required fuel, once the airship's weight reaches its maximum load limit, the cargo bay doors are closed, and the airship, being lighter than air, ascends to the desired altitude and flies to the destination of the gaseous hydrogen 101 being carried in the filled hydrogen cylinders 302. As shown in the rectangular box 209, upon arrival at its intended destination, the process described above is performed in reverse order, with the filled cylinder modules 302 being unloaded from the airship and the other already empty cylinder modules 302 being loaded at that location. During the duration of such an airship flight, hydrogen 101 can be released from the filled cylinder modules 302 left at the destination, while the empty cylinders 302 left at the origin are pre-filled at or near the hydrogen 101 production site. Although this process has been described in relation to the transport of gaseous hydrogen 101, cryogenic (liquid) hydrogen 101 can also be transported using the procedure described above, thereby further minimizing the total cost per kilogram of hydrogen 101 at the point of receipt by the end user.

[0071] Upon arrival at the intended destination, depending on local conditions and other factors readily understood by those skilled in the art, the hydrogen 101 can be transported and / or distributed using the cylinder module 302, hydrogen transport trailer 303, and tractor cab 304. Alternatively, it may be advantageous to use one or more hydrogen transport trailers 114 and / or pipelines 115. In a preferred embodiment, the transport and distribution of hydrogen 101 utilizes the following technical disclosures.

[0072] Referring here to Figure 3(b), pipe 307 represents an existing pipeline such as a gas or oil pipeline, a water or sewer pipe, a storm drain pipe, or any other pipeline whose route may be useful for transporting and / or distributing hydrogen 101. In a preferred embodiment, as shown in Figure 3(b), the hydrogen delivery line 308 passing through the interior of the safety pipe 309 is inserted into the existing pipeline 307 for the purpose of transporting and / or distributing gaseous hydrogen 101 using the right of way and capital investment required to acquire land and / or the necessary land rights, secure regulatory approvals, and install and maintain such existing pipeline 307. Rapid discharge fittings and fittings 310 are preferably used for inserting the hydrogen delivery line 308 into the safety pipe 309, as well as for other safety, practical, and maintenance purposes described below.

[0073] Those skilled in the art recognize that in the United States, various regulated public utilities and master limited partnerships (MLPs) own and manage 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 largely controlled by transmission system operators (TSOs), which operate like private companies despite being publicly managed. In other countries, there is a mix of private ownership under some form of public regulation, public or indigenous collective ownership, or a combination thereof. In some cases, water, sewer, and stormwater pipelines may also be owned by similar interests or local government agencies. Thus, based on the amount of hydrogen 101 per mile passing through such existing pipelines 307, a monetary return on these existing pipelines 307 can be increased based on any number of possible contractual arrangements that would enable the installation of such safety pipes 309 in exchange for compensation to the existing pipeline owners.

[0074] In the case of gas and oil pipelines, this new revenue opportunity could help offset the risk of low revenue as the amount of fossil fuels transmitted decreases and the use of hydrogen increases in the future. Furthermore, such configurations would significantly reduce both the time and initial capital investment required to establish hydrogen infrastructure, drastically lower negotiated rates that can be delivered to end users at the cost per kilogram of hydrogen consumed, and at the same time help extend and transition the lifespan of these already "sunk" oil and gas investments.

[0075] If it is necessary to accommodate physical obstructions such as shut-off valves 311 in such existing pipelines 307, risers 312 (or equivalents located below ground) may be installed to allow a continuous flow of hydrogen 101 through the hydrogen delivery line 308 without adversely affecting the proper function of such elements and the control functions of the existing pipelines 307. Risers 312 or equivalents may also be used to make rapid discharge fittings and fittings 310 more easily accessible in order to assist in the separation and repair of one or more sections of the hydrogen delivery line 308 and to allow the use of two or more other unrelated existing pipeline 307 systems to deliver the hydrogen delivery line 308 to a desired location without mixing the contents of such existing pipelines 307. Those skilled in the art will readily understand that fully automated electronic metering equipment can be used to monitor the amount of hydrogen 101 flowing through such hydrogen delivery line 308 to ensure a fair and equitable allocation of transmission fees among the owners of multiple existing pipelines 307, and, in a preferred embodiment, among investors in the upgrades and improvements necessary to enhance such systems of hydrogen 101.

[0076] In a preferred embodiment, a large spool 313 of FRP pipeline may be used for the storage of gaseous hydrogen 101 instead of a conventional hydrogen tank 111. Such alternative storage based on a spool of FRP pipe 313 offers several less obvious advantages beyond the current state of the art to provide hydrogen storage on a large scale and / or to provide a “shock absorber” for power grids. In particular, as stated in the background art disclosure, FRP pipes have an existing ASME code with a 50-year effective life and require minimal maintenance, whereas conventional gaseous hydrogen storage tanks 111 have a much shorter life and require expensive maintenance and recertification approximately every five years. Furthermore, large-diameter FRP pipes can be extruded in-situ, thereby avoiding the difficult transportation logistics associated with large quantities of hydrogen storage tanks 111 (or the cost and technical problems associated with using underground cavities for such storage) and increasing the ability to rapidly scale up at new locations. On-site extrusion of FRP pipes has the added advantage of allowing the shipment of bulk materials such as resin and avoiding the "air transport" required when shipping finished pipes. Furthermore, optical sensors, hydrogen sensors, electrical signal lines, power cables, and capillary tubes can be incorporated into the layered structure of the FRP pipe to ensure that hydrogen leaks are quickly identified. A shut-off valve combined with a rapid release fitting and fitting 310 at the end of one or more spools of the FRP pipe allows the operator to quickly isolate and replace a damaged section or adjust the total storage capacity.

[0077] Utilizing FRP pipe 313 spools for H2@scale, when estimated over a 50-year service life, results in substantially lower total lifetime costs than conventional hydrogen 101 storage solutions, taking into account savings in installation costs, delays in field approval, avoidance of recertification requirements, and reduced replacement costs. Furthermore, when used in conjunction with fuel cells for the purpose of reconverting hydrogen 101 back into electricity, utilizing FRP pipe 313 spools is estimated to cost less than 1 / 10 (10%) of battery storage in large-scale energy storage devices, with many other advantages including much longer energy retention time, longer service life, and, depending on the type of battery, significantly fewer constraints on natural resources and / or waste disposal issues. The aforementioned cost savings are significant and counterintuitive, given the significantly larger ratio of surface area to total volume represented by FRP pipe 313 spools compared to conventional hydrogen storage tanks 111, and the general preference for battery storage held by those skilled in the art.

[0078] Referring next to Figure 3(c), a detailed view of the cross-section AA of Figure 3(b) is shown 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 or synthesis gas, crude oil or other liquid petroleum products, biofuels, various other industrial gases, drinking water and non-drinking water, sewage, slurry, rainwater, and other liquids. Where there is sufficient volume, the safety pipe 309 (and thus including the hydrogen delivery line 308) may pass inside the existing pipeline 307 for the purpose of transporting gaseous hydrogen 101 as described above. This avoids contamination and, if necessary or desirable, allows for the transport of more pure hydrogen 101. In a preferred embodiment, a flow path or sweeper line 315 between the outer surface of the hydrogen delivery line 308 and the inner surface of the safety pipe 309 is used as a sweep line for the appropriate purge gas to be introduced to dilute and collect any gaseous hydrogen 101 that may leak from the hydrogen delivery line 308.

[0079] In an optional alternative embodiment, subject to regulatory approval, if the contents 314 of the existing pipeline 307 consist of a gas or liquid that can function as a suitable sweeper gas for collecting hydrogen 101 that may leak from the hydrogen delivery line 308, the safety pipe 309 may be omitted, provided that the operator of the existing pipeline 307 is not concerned with such a leak contaminating the contents 314 of the existing pipeline 307. Non-limiting examples of contents 314 of the existing pipeline 307 that may enable the use of this optional alternative embodiment are synthetic natural gas (SNG), liquid natural gas (LNG), nitrogen, carbon dioxide, or helium.

[0080] Figure 3(d) shows an enlarged view of the cross-section BB in Figure 3(c) in the region between the two vertical dashed lines 330 drawn above it. In particular, this portion of Figure 3(d) shows the existing pipeline 307 and its contents 314, as well as the safety pipe 309 and its contents. As described above, in a preferred embodiment, the contents of the safety pipe 309 include a hydrogen delivery line 308, its contents of gaseous hydrogen 101, and a sweeper line 315 that serves as a passage for sweeping away hydrogen leaks 323. In a non-limiting example, the safety pipe 309 is a 6-inch diameter flexible pipe made of any material including, but not limited to, metals, plastics, and composites that are suitable for both hydrogen and a selected purge gas flowing through the sweeper line 315, and the hydrogen delivery line 308 is a 3-inch FRP pipe suitable for carrying gaseous hydrogen 101 at any pressure from atmospheric pressure up to the maximum allowable operating pressure of the hydrogen delivery line 308.

[0081] According to steps 214 and 218 of Figure 2, gaseous hydrogen 101 is injected into the hydrogen delivery line 308 via the inlet valve 316 from a hydrogen storage tank 111 or another storage system (including, in a preferred embodiment, one from a spool-type FRP pipe storage system 313), an upstream hydrogen pipeline, a hydrogen production or vaporization system, a compressor, or other source. If necessary, according to steps 213, 215, 217, or 219 of Figure 2, such injection is monitored using a pressure gauge 317 to ensure that the hydrogen 101 is at an appropriate pressure before and after injection into the hydrogen delivery line 308. Important information regarding the injection of hydrogen 101, such as the amount released, purity, and pressure, is preferably captured at this point and other suitable points for control and billing purposes, such as the outlet point where the hydrogen 101 is delivered to the end user and withdrawn from the system (reset in Figure 3(d) by arrow 324). This data is transmitted to the receiver 319 by the wireless transmitter 318(a), which is connected to the active monitoring system 320 to record, analyze, plot, and initiate appropriate preventive, response, and / or billing and reward actions for other data.

[0082] The sweeper 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 such purge gas, and this data is preferably transmitted to a receiver 319 by a wireless transmitter 318(b) and then uploaded to an active monitoring system 320. Additional hydrogen sensors, such as sensor 322(b), can be strategically placed along the sweeper line 315 to individually monitor the level of hydrogen contained in the purge gas (if any) as it passes through each sensor location, and this data is similarly communicated to the monitoring system 320 via a wireless (or direct) connection 318(c) and may be combined with other data already present 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 appropriately 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 a hydrogen leak 323 from the hydrogen delivery line 308. Similarly, those skilled in the art will understand that, at appropriate times, the purge gas in the sweeper line 315, after being used in the manner shown, may be sold as a by-product of the system, reused once or multiple times within the sweeper line 315, or, at the operator's discretion, responsibly disposed of as waste. These options are represented by arrow 325.

[0083] In an optional alternative embodiment in which the existing pipeline 307 is used to transport synthetic natural gas or another product 314 that can be used as a sweeper gas for the aforementioned system, such a hydrogen sensor 322 is rather used to detect hydrogen leaks 323 and to monitor the hydrogen level in the contents 314 to ensure the operation of the system without adversely affecting its safety or efficiency. Those skilled in the art will understand that in this optional alternative embodiment, the contents 314 of the existing pipeline 307 itself can sweep / purge any hydrogen 101 that may leak from the hydrogen delivery line 308, and such contents 314 should be actively monitored for changes in hydrogen levels to ensure that appropriate steps are taken in the event of a failure of the hydrogen delivery line 308 or an excessive leak 323 of hydrogen 101 from there.

[0084] In both preferred and optional alternative cases, if an operating personnel and / or automated software monitoring system 320 observes an excess level of hydrogen 101 in such gas, an order can be dispatched manually or using automated programming with a radio transmitter 319 communicating with receiver 318(a) to close valve 316 until the problem is identified and corrected. Those skilled in the art will understand the purpose of such emergency protocols, as well as the rapid release fittings and fittings 310, and any additional optional components commonly used in pipeline transmission of industrial gases (including, but not limited to, shut-off valves that can be used to isolate sections of hydrogen delivery lines 308 in a well-ordered system).

[0085] Figures 4(a)–4(d) illustrate a non-limiting exemplary case involving the large-scale production, transport, storage, and distribution of green hydrogen 101. While the principles of the disclosed technology are globally applicable as part of establishing a safe, low-cost, and rapidly scalable infrastructure for transport, hydrogen storage at scale, and distribution of hydrogen 101 as a fossil fuel alternative for transport and power, this example envisions the production of green hydrogen 101 at a uniquely advantageous location on the Big Island of Hawaii and its transport to Oahu, and its widespread distribution on Oahu.

[0086] Figure 4(a) shows a flight path 401 of an airship 402 that is lighter than air, connecting the Puna geothermal production site 403 on the southern tip of the Big Island of Hawaii and / or an area 404 ideally suited for a large wind farm on the island's high ground to a potential terminal site 405 on approximately 25 acres of land on Oahu. Assuming an average cruising speed of 150 to 200 miles per hour, the airship 402 could have a net payload potential of 200 to 300 tons, thereby allowing each round-trip flight of less than 4 hours to transport approximately 10,000 kg of gaseous hydrogen 101 at 3,625 psi from landing sites near production sites 403 and / or 404 on the Big Island of Hawaii to the terminal 405 indicated on Oahu. Assuming five round-trip flights per day and 360 operating days per year, one airship could transport 18 million kilograms of gaseous hydrogen-101 to Oahu annually, which would help meet the state's "Clean Energy Initiative" goals.

[0087] Figure 4(b) shows a map of the Oahu and final portion of the preferred air route 401 from airship 402 to terminal 405 near Kunia Village. A close-up detail of this area 406 shows that in one preferred embodiment, terminal 405 incorporates an optional turntable 407. The turntable 407 includes a cradle 408 with at least two anchor points on either side of the cradle 408, which are configured to connect to tie-down cables, which can then be connected to the airship 402, which is lighter than air. The airship 402 can then be secured to the cradle 408 using such tie-down cables. The turntable 407 can rotate the cradle 408 so that the airship 402, which is lighter than air, can always face directly into the wind when landing and taking off from terminal 405, and optionally, so that a tug (not shown) can pull the airship 402 into hangar 409 after the airship 402 has been securely tethered to the cradle 408.

[0088] Figure 4(b) also shows the installation of two new transmission pipelines. Pipeline route 410 is approximately 6 miles long and connects from Central Oahu Port and an optional airship terminal 405 to one of HawaiiGas's eight descent regulator sites 411, while the company's existing 16-inch main transmission line is currently interconnected with Oahu's synthetic natural gas (SNG) distribution system. Although this embodiment envisions a new pipeline segment, the proposed route would allow HawaiiGas to build a new distribution system to serve the Wheeler and Schofield military bases, with a second extension 412 of approximately 10 miles from Central Oahu to Waialua, to transport and distribute SNG and hydrogen 101 to the island's North Shore, which currently does not have gas service. While these pipeline extensions are considered preferable, in an alternative embodiment, transmission line extensions 410 and 411 may be extended, and these regions may be served at least temporarily by using a tractor cab 304 to drive the hydrogen transport trailer 303 and its cylinder modules 302 to one or both of these interconnection points.

[0089] Figure 4(c) shows a map 413 of the main synthetic natural gas lines owned by Hawaii Gas on the southern 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 an existing pipeline 301 for transporting hydrogen 101 to multiple strategically located distribution points in addition to interconnection point 411. Transmission pipeline 414 begins at Hawaii Gas's synthetic natural gas (SNG) plant 415(a), located in Campbell Industrial Park near the southwestern tip of the island, and extends eastward along the southern part of Oahu, delivering SNG via a drop regulator to interconnection point 411 and seven interconnected SNG distribution systems.

[0090] HawaiiGas' SNG plant 415(a) currently produces SNG from naphtha, a liquid petroleum raw material. Therefore, in a preferred embodiment, the company's total daily demand for naphtha is replaced by less than 20% of the green hydrogen 101 produced and transported daily from Oahu, and transported from Terminal 405 by tractor cabs 304 and transport trailers 303, or by using new pipelines 410 and existing pipelines 414 as pipes 301 of the disclosed technology. Using this technology, the remainder of the green hydrogen 101 could also be transported from interconnection point 411 to descent regulator site 415(b) near Pearl City, descent regulator site 415(c) near Honolulu International Airport, and descent regulator site 415(d) at the eastern end of transmission line 414, supplying the company's largest SNG distribution system at Pier 38 in Honolulu Harbor, near downtown Honolulu. Furthermore, in one preferred embodiment, hydrogen 101 can be transported to other distribution points between downtown Honolulu and Hawaii Kai 416 using HawaiiGas' 10, 8, 6, and 4-inch lines, with selectively smaller diameter hydrogen delivery lines 308 and safety pipes 309.

[0091] Figure 4(d) shows a Honolulu area map of water and sewage 417 and storm drain pipes 418 for the most densely populated area of ​​the island at the southeastern tip of Oahu, indicated in highlighted section 419. The density of such existing pipelines within the area illustrates the range of potential distribution possible by using the disclosed technology. Those skilled in the art will understand that this is likely to apply to communities around the world where hydrogen distribution is needed.

[0092] From the foregoing disclosure, it will be understood that while certain embodiments are described herein for illustrative purposes, various modifications can be made without departing from the spirit and scope of the appended claims and the elements described herein. Furthermore, while certain embodiments are presented as optional or preferred embodiments, not all such embodiments are necessary and can therefore be incorporated as indicated by the circumstances to achieve the desired results. Furthermore, while certain embodiments are presented below in the form of certain claims, the inventors intend various embodiments in the form of any available claims. Various modifications and changes can be made, as will be apparent to those skilled in the art who are interested in this disclosure. It is intended to encompass all such modifications and changes, and therefore the above description should be considered illustrative rather than restrictive. The present invention includes the following embodiments. [1] Existing pipelines and A hydrogen delivery line configured to carry pressurized hydrogen, wherein the hydrogen delivery line is positioned within the existing pipeline such that a sweeper gas in the existing pipeline flows around the outside of the hydrogen delivery line to purge any hydrogen leaking from the hydrogen delivery line. A device comprising at least one inlet to the hydrogen delivery line, configured to allow hydrogen to be injected into the hydrogen delivery line, A configuration comprising at least one outlet from the hydrogen delivery line, which allows hydrogen to be drawn from the hydrogen delivery line, including, A hydrogen distribution system for transporting hydrogen from a hydrogen source to at least one end-user location. [2] The hydrogen distribution system according to [1], wherein the existing pipeline is a gas transmission pipeline, and the sweeper gas is either natural gas or synthetic natural gas. [3] The hydrogen distribution system according to [1], further comprising a safety pipe positioned inside the existing pipeline and around the hydrogen delivery line, wherein a flow path is formed between the outside of the hydrogen delivery line and the inside of the safety pipe, and the flow path is sized to allow the sweeper gas to flow through the existing pipeline and along the outside of the hydrogen delivery line. [4] The hydrogen distribution system according to [3], wherein the safety pipe is made of plastic or a composite material. [5] The hydrogen distribution system described in [3], wherein the existing pipeline is one of a water pipeline, a sewer pipeline, or a rainwater pipeline. [6] The existing pipeline includes a gas transmission line connected to at least one of the following: a water pipe, a sewer pipe, or a rainwater pipe. The at least one inlet to the hydrogen delivery line is located within the gas transmission pipeline. The hydrogen drawn from the hydrogen delivery line is generated after the hydrogen has been delivered through water pipes, sewer pipes or rainwater pipes. [3] The hydrogen distribution system described. [7] The hydrogen distribution system according to [2], further comprising at least one hydrogen sensor located at the outlet of the existing pipeline and configured to monitor the presence and amount of hydrogen leaked from the hydrogen delivery line into the sweeper gas. [8] The existing pipeline includes at least two inline hydrogen sensors located at different locations within it, A data system configured to monitor at least two of the aforementioned inline hydrogen sensors and determine the hydrogen level of each inline hydrogen sensor, A recording system configured to separately record the hydrogen level detected by each inline hydrogen sensor, A programmable alarm system configured to trigger an alarm based on the hydrogen level, The hydrogen distribution system described in [2] further includes the following: [9] The hydrogen distribution system according to [5] further includes at least one hydrogen sensor located at the outlet of the safety pipe, configured to monitor the presence and amount of hydrogen leaked from the hydrogen delivery line into the safety pipe.

[10] At least two inline hydrogen sensors are positioned at different locations within the safety pipe, A data system configured to monitor at least two of the aforementioned inline hydrogen sensors and determine the hydrogen level of each inline hydrogen sensor, A recording system configured to separately record the hydrogen level detected by each inline hydrogen sensor, A programmable alarm system configured to trigger an alarm based on the hydrogen level, The hydrogen distribution system described in [5] further includes the following:

[11] The hydrogen distribution system according to [8] further includes at least one shut-off valve configured to selectively isolate and close a section of the hydrogen delivery line when triggered by the alarm of the programmable alarm system.

[12] The hydrogen distribution system according to

[10] further includes at least one shut-off valve configured to selectively isolate and close a section of the hydrogen delivery line when triggered by the alarm of the programmable alarm system.

[13] The hydrogen distribution system according to [1], wherein the hydrogen delivery line is an FRP pipe specified for use with hydrogen.

[14] The hydrogen distribution system according to [1], further comprising at least one coupling device, each coupling device connecting a first section of the hydrogen delivery line inside the existing pipeline to a second section of the hydrogen delivery line outside the existing pipeline.

[15] The hydrogen distribution system according to

[14] , wherein the hydrogen delivery line is made of FRP pipe specified for use with hydrogen, and the second section of the hydrogen delivery line is a storage area.

[16] The hydrogen distribution system according to

[15] , wherein the hydrogen delivery line includes at least one hydrogen sensor, each of which is configured to separately generate data relating to the detected hydrogen level.

[17] Means for monitoring the hydrogen level detected by each of the at least one hydrogen sensor, Alarm means configured to generate an alarm when the detected hydrogen level indicates that hydrogen is leaking from the hydrogen delivery line, The hydrogen distribution system described in

[16] further includes the following:

[18] At least one shut-off valve, each shut-off valve connected to a fitting, the shut-off valves positioned at intervals of a predetermined length of the hydrogen delivery line, and each shut-off valve and fitting configured to be selectively closed, The system further includes a processor configured to locate 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 fitting is configured to close and isolate the hydrogen delivery line around the predetermined length of the hydrogen delivery line where the hydrogen leak has been identified. The hydrogen distribution system described in

[17] .

[19] A valve connected to the existing pipeline and controlling the flow through the existing pipeline, A first riser connected to the existing pipeline on the first side of the valve, A second riser connected to the existing pipeline on the second side of the valve, It further includes, The hydrogen delivery line is configured to guide hydrogen through the riser and fittings, bypassing the valve. [1] The hydrogen distribution system described above.

[20] The steps include producing hydrogen from an energy source at the manufacturing site, The steps include storing the hydrogen in at least one hydrogen storage container, The steps include: 1. Placing a hydrogen delivery line inside an existing pipeline, wherein the hydrogen delivery line is configured to carry pressurized hydrogen; The steps include injecting sweeper gas around the outside of the hydrogen delivery line in order to purge hydrogen leaking from the hydrogen delivery line, The steps include injecting hydrogen from at least one hydrogen storage container into the hydrogen delivery line, The steps include drawing the hydrogen from the hydrogen delivery line at at least one end-user location, A method for transporting hydrogen from a production site to at least one end-user location, including [the specified method].

[21] The energy source is fixed at the manufacturing location. The method for transporting the hydrogen further comprises the step of transporting the hydrogen using at least one of trucks, trains, or ships, according to

[20] .

[22] The energy source is fixed at the manufacturing location. The method for transporting the hydrogen further comprises the step of transporting the hydrogen using an airship that is lighter than air, according to

[20] .

[23] The step of transporting the hydrogen using an airship that is lighter than air is, The steps include pumping the hydrogen into at least two containers, The steps include: pumping the hydrogen into at least two of the containers, and then loading the containers onto an airship that is lighter than air; The steps include flying the aforementioned airship, which is lighter than air, to the destination location, The steps include unloading the container from the airship, which is lighter than air, at the aforementioned terminal location, The steps include loading at least one empty container onto the airship, which is lighter than air, The steps include returning the at least one empty container to the manufacturing location, The method described in

[22] , including the method described in

[22] .

[24] The method according to

[22] , wherein the fixed energy source is a renewable energy source that is at least one of wind, solar, hydro, biomass, or geothermal energy.

[25] The method according to

[20] , wherein the at least one hydrogen storage vessel is made of FRP pipe specified for use with hydrogen.

[26] The aforementioned existing pipeline is a gas transmission pipeline. The sweeper gas is either natural gas or synthetic natural gas. The method described in

[20] .

[27] The method according to

[23] , wherein the terminus location includes a cradle having at least two anchor points configured to secure the airship, which is lighter than air, with tie-down cables.

[28] The method according to

[27] , wherein the cradle is configured to rotate so as to face the direction of the opposing wind.

[29] The step of placing safety pipes inside the existing pipeline and around the outside of the hydrogen delivery line. The method described in

[20] , further including the method described in

[20] .

[30] The method according to

[29] , wherein the existing pipeline is one of a water pipeline, a sewer pipeline, a stormwater pipeline, an underground utility corridor, a rail line, or a tube.

[31] The existing pipeline includes a gas transmission line connected to at least one of the following: a water pipe, a sewer pipe, or a rainwater pipe. The step of injecting the hydrogen into at least one inlet in the hydrogen delivery line is performed within the gas transmission pipeline. After the hydrogen has been delivered through water pipes, sewer pipes, or rainwater pipes, the hydrogen is removed from the hydrogen distribution line. The method described in

[20] .

[32] The method according to

[30] , wherein the at least one end-user location is a substation of an electric utility.

[33] The method according to

[30] , wherein the at least one end-user location is a commercial or industrial facility.

[34] The method according to

[33] , further comprising the step of using the hydrogen as a raw material for an industrial process.

[35] The method according to

[30] , wherein the at least one end-user location is a refueling station for distributing hydrogen to fuel cell vehicles.

[36] The method according to

[35] , wherein the refueling station compresses the hydrogen to a pressure suitable for distribution to a hydrogen fuel cell vehicle.

[37] The method according to

[35] , wherein the refueling station compresses the hydrogen to a pressure suitable for distribution to hydrogen fuel cell trucks.

[38] The method according to

[30] , wherein the at least one end-user location is a residence.

[39] A step of storing hydrogen in at least one spool of an FRP pipe specified for use with hydrogen, The steps include refueling the energy generation system with hydrogen, A step of generating electricity using the aforementioned energy generation system, A method of storing energy and utilizing the stored energy, including [specific examples of energy storage methods].

[40] The steps include: placing at least one hydrogen sensor in at least one spool of the FRP pipe; A step of detecting hydrogen leakage from the at least one spool of the FRP pipe using the at least one hydrogen sensor, The steps include generating electronic data to prove a hydrogen leak when the aforementioned hydrogen leak is detected, The steps include monitoring the electronic data and performing at least one safety action in response to detecting the hydrogen leak, The method described in

[39] , further including the method described in

[39] .

[41] The method according to

[40] , further comprising the step of installing shut-off valves and connecting them along the FRP pipe at predetermined intervals of length.

[42] The steps include identifying the location of the hydrogen leak based on the aforementioned electronic data, The steps include: using the shut-off valve to isolate the predetermined length of the FRP pipe including the location of the hydrogen leak; The method described in

[41] , further comprising:

[43] The method according to

[42] , further comprising the step of removing and replacing the predetermined length of the FRP pipe including the hydrogen leak location using the fitting, after separating the FRP pipe including the hydrogen leak location.

[44] The method according to

[43] , wherein the predetermined length is one spool of the FRP pipe.

[45] The method according to

[39] , wherein the hydrogen is produced from a renewable energy source which is at least one of wind, solar, hydro, biomass, or geothermal energy.

[46] The energy generation system is a gas turbine, according to the method in

[39] .

[47] The energy generation system is a fuel cell, the method according to

[39] .

Claims

1. Existing pipelines and A hydrogen delivery line configured to carry pressurized hydrogen, wherein a flow path is formed between the outside of the hydrogen delivery line and the inside of the hydrogen delivery line, the inside of the existing pipeline is sized to allow sweeper gas to flow inside the existing pipeline, and the hydrogen delivery line is positioned within the existing pipeline to purge hydrogen leaking from the hydrogen delivery line, At least one hydrogen sensor configured to monitor the presence and amount of hydrogen in the sweeper gas, A programmable alarm system configured to trigger an alarm based on the hydrogen level detected by at least one of the hydrogen sensors, A device comprising at least one inlet to the hydrogen delivery line, configured to allow hydrogen to be injected into the hydrogen delivery line, A configuration comprising at least one outlet from the hydrogen delivery line, which allows hydrogen to be drawn from the hydrogen delivery line, including, A hydrogen distribution system for transporting hydrogen from a hydrogen source to at least one end-user location.

2. The hydrogen distribution system according to claim 1, wherein the sweeper gas is one of nitrogen, carbon dioxide, helium, or an inert gas.

3. The hydrogen distribution system according to claim 1, further comprising a safety pipe positioned inside the existing pipeline and around the hydrogen delivery line, wherein a flow path is formed between the outside of the hydrogen delivery line and the inside of the safety pipe, and the flow path is sized to allow the sweeper gas to flow through the safety pipe along the outside of the hydrogen delivery line.

4. The hydrogen distribution system according to claim 3, wherein the safety pipe is made of one of plastic, metal, fiber, or composite material.

5. The existing pipeline includes a gas transmission pipeline connected to at least one of the following: a water pipe, a sewer pipe, or a rainwater pipe. The at least one inlet to the hydrogen delivery line is located within the gas transmission pipeline. The hydrogen is drawn from the hydrogen delivery line after it has been delivered through at least one of the water pipes, sewer pipes, or rainwater pipes. The hydrogen distribution system according to claim 3.

6. The hydrogen distribution system according to claim 1, wherein the at least one hydrogen sensor is located at the outlet of the existing pipeline.

7. The existing pipeline includes at least two inline hydrogen sensors located at different locations within it, A data system configured to monitor at least two of the inline hydrogen sensors and determine the hydrogen level detected by each inline hydrogen sensor, A recording system configured to separately record the hydrogen level detected by each inline hydrogen sensor, The hydrogen distribution system according to claim 2, further comprising:

8. The hydrogen distribution system according to claim 7, further comprising at least one shut-off valve configured to selectively isolate and close each section of the hydrogen delivery line when triggered by the alarm of the programmable alarm system.

9. 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 line inside the existing pipeline to a second section of the hydrogen delivery line outside the existing pipeline.

10. The hydrogen distribution system according to claim 9, wherein the hydrogen delivery line is made of FRP pipe specified for use with hydrogen, and the second section of the hydrogen delivery line is a storage area.

11. At least one shut-off valve, each shut-off valve connected to a fitting, the shut-off valves positioned at intervals of a predetermined length in the hydrogen delivery line, and each shut-off valve and fitting configured to be selectively closed, The system further includes a processor configured to locate 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 fitting is configured to close and isolate the hydrogen delivery line around the predetermined length of the hydrogen delivery line where the hydrogen leak has been identified. The hydrogen distribution system according to claim 7.

12. A valve connected to the existing pipeline and controlling the flow through the existing pipeline, A first riser connected to the existing pipeline on the first side of the valve, A second riser connected to the existing pipeline on the second side of the valve, It further includes, The hydrogen delivery line is configured to guide hydrogen through the riser and fittings, bypassing the valve. The hydrogen distribution system according to claim 1.

13. A method for transporting hydrogen from a production site to at least one end-user location, The steps include producing hydrogen from an energy source at the manufacturing site, The steps include storing the hydrogen in at least one hydrogen storage container, The steps include: locating a hydrogen delivery line inside an existing pipeline, wherein the hydrogen delivery line is configured to carry pressurized hydrogen, and there is sufficient space around the outside of the hydrogen delivery line for sweeper gas to flow; The steps include injecting sweeper gas around the outside of the hydrogen delivery line in order to purge hydrogen leaking from the hydrogen delivery line, The steps include configuring at least one hydrogen sensor for monitoring the presence and amount of hydrogen in the sweeper gas, The steps include: programming an alarm system to trigger an alarm based on the hydrogen level detected by at least one of the hydrogen sensors; The steps include injecting hydrogen from at least one hydrogen storage container into the hydrogen delivery line, The steps include drawing the hydrogen from the hydrogen delivery line at at least one end-user location, A method for transporting hydrogen from a production site to at least one end-user location, including [the specified method].

14. The energy source is fixed at the manufacturing location. The method for transporting the hydrogen further comprises the step of transporting the hydrogen using at least one of a truck, a train, a ship, or an airship that is lighter than air, according to claim 13.

15. The step of arranging the hydrogen delivery line is, The steps of positioning the safety pipe inside the existing pipeline and around the hydrogen delivery line such that a flow path is formed between the outside of the hydrogen delivery line and the inside of the safety pipe for sweeper gas to flow, The method according to claim 13, including the method described in claim 13.

16. The method according to claim 14, wherein the fixed energy source is a renewable energy source that is at least one of wind, solar, hydro, biomass, or geothermal energy.

17. The method according to claim 13, wherein the at least one hydrogen storage container is made of FRP pipe specified for use with hydrogen.

18. The existing pipeline includes a gas transmission pipeline connected to at least one of the following: water pipes, sewer pipes, rainwater pipes, underground utility corridors, rail lines, or tubes. The step of injecting the hydrogen into at least one inlet in the hydrogen delivery line is performed within the gas transmission pipeline. After the hydrogen has been delivered through water pipes, sewer pipes, rainwater pipes, underground utility corridors, rail lines, or tubes, the step of removing the hydrogen from the hydrogen delivery line is performed. The method according to claim 13.

19. The method according to claim 13, wherein the at least one end-user location is an electric power substation, a commercial or industrial facility, a refueling station for distributing hydrogen to fuel cell vehicles, or a residence.

20. The method according to claim 19, wherein the refueling station compresses the hydrogen to a pressure suitable for distribution to a hydrogen fuel cell vehicle or a hydrogen fuel cell truck.

Images