Boat landing structure

Abstract

The invention relates to a boat landing structure for an offshore structure, the offshore structure comprising at least one hydrogen processing apparatus. The boat landing structure comprises at least one ladder structure, at least one fender structure, and at least one fluid line integrated into the ladder structure and / or fender structure, and / or at least one electric line having a voltage of at least 1 kV integrated into the ladder structure and / or fender structure.

Description

[0001] Ship landing device

[0002] The invention relates to a ship landing device for an offshore structure, wherein the offshore structure comprises at least one hydrogen processing device (e.g., a hydrogen production device), wherein the ship landing device comprises at least one conductor structure and at least one impact body protection structure. Furthermore, the invention relates to a foundation set, an offshore hydrogen production system, and a method.

[0003] Hydrogen, especially hydrogen gas, is increasingly being used as an energy carrier these days. Hydrogen can be produced from water through electrolysis. Electrolysis involves the application of electrical energy or power to force a redox reaction, thereby generating hydrogen.

[0004] In order to reduce carbon dioxide (CO2) emissions during hydrogen production, one goal is to increasingly use so-called renewable energy sources as the energy source(s) to supply the at least one electrolysis plant in the hydrogen production system. A renewable or regenerative energy source is defined in particular as an energy source that is practically inexhaustible and / or regenerates relatively quickly.

[0005] Among the most important renewable energies is wind energy, in which a wind turbine converts the kinetic energy of the wind into electrical energy. Wind farms and wind energy systems are increasingly being built offshore. Compared to onshore locations, wind conditions, particularly the (average) wind speeds and wind frequency, are better offshore. An offshore wind farm typically comprises several offshore wind turbines, which are connected to at least one offshore substation via a power cable network, particularly with several submarine cables. The offshore substation can, in turn, be connected to an onshore substation via another power cable network with at least one submarine cable (usually at least two submarine cables running in parallel).The generated electrical energy can be fed into a (public) distribution grid via the onshore substation.

[0006] It is known from the state of the art to construct a hydrogen production system near the coast, which is supplied with electrical energy by such an offshore wind farm. This allows the hydrogen production system to be (directly) electrically connected to the onshore substation.

[0007] However, this approach has several disadvantages: For example, there is usually a large distance between the offshore substation or the offshore wind farm site and the onshore substation, which must be bridged using the aforementioned submarine cables. However, submarine cables are significantly more expensive than hydrogen pipelines. Furthermore, the energy losses during electrical energy transmission are greater than when producing hydrogen. Finally, a hydrogen pipeline generally allows for significantly larger energy transmission volumes than a separate power cable network.

[0008] For these reasons, there are increasing considerations for establishing hydrogen production systems at an offshore location. Basically, two approaches are known from the state of the art for an offshore hydrogen production system. In the first, so-called central approach, the offshore hydrogen production system with all production facilities (e.g.

[0009] Electrolysis plant, water treatment plant, nitrogen plant, cooling water plant, hydrogen treatment plant, including a hydrogen drying plant, hydrogen compression plant, etc.) are installed on a central offshore platform. The central offshore platform is located adjacent to the offshore wind farm, in particular to the at least one offshore substation of the offshore wind farm. The hydrogen production system located on a central offshore platform can then be supplied with electrical energy by the adjacent offshore wind farm. This can at least reduce the disadvantages of an offshore wind farm and an onshore hydrogen production system.

[0010] As an alternative to the centralized approach, a so-called decentralized approach is known from the state of the art. In the decentralized approach, the offshore hydrogen production system is divided into numerous decentralized micro-hydrogen production systems, with each micro-hydrogen production system having all production facilities in the form of micro-production plants (e.g., micro-electrolysis plant, micro-water treatment plant, micro-nitrogen plant, micro-cooling water plant, micro-hydrogen treatment plant, such as a micro-hydrogen drying plant, and / or a micro-hydrogen compression plant, etc.). Each micro-hydrogen production system is installed in or on an offshore wind turbine.The advantage of the decentralized approach is that the existing installation space of an offshore wind turbine is used and the respective micro-hydrogen production system is supplied with electrical energy directly by the respective wind turbine.

[0011] Compared to the centralized approach, however, the decentralized approach entails increased maintenance effort. Regular maintenance of the respective micro-hydrogen production systems at each offshore wind turbine is required. Such maintenance requires landing at the respective offshore wind turbine. This requires numerous landing operations and thus a high level of effort. To make matters worse, loading operations are only possible under certain weather and / or sea conditions, which can significantly delay maintenance procedures. This, in turn, can lead to reduced yield. A further disadvantage is that each micro-hydrogen production system must meet stringent safety requirements, particularly with regard to explosion protection. The main reason for this is the risk of explosive atmospheres occurring.

[0012] To mitigate the described disadvantages, it is known from the internal state of the art to carry out hydrogen production decentrally using respective micro-electrolysis systems of respective offshore hydrogen production wind turbines and, for example, to carry out water treatment for decentralized hydrogen production centrally using a water treatment plant located on a central offshore treatment structure and / or to carry out hydrogen treatment centrally using a hydrogen treatment plant located on a central offshore treatment structure and / or to generate inert gas using an inert gas generation plant located on a central offshore treatment structure. This combined approach combines, in particular, the advantages of the decentralized and centralized approaches.

[0013] However, such an offshore hydrogen production system requires the installation of fluid lines, for example in the form of a media network, between the at least two offshore structures in order to convey flowable media or fluids between the aforementioned offshore structures. For example, the (wet) hydrogen generated decentrally on an offshore hydrogen production wind turbine can be transported via a first fluid line to another offshore structure in the form of a central offshore treatment structure with a hydrogen treatment plant, and / or the water treated by a central water treatment plant can be transported via a second fluid line from a central offshore treatment structure to the at least one decentralized offshore hydrogen production wind turbine.

[0014] However, laying at least one fluid line for conveying a fluid between two offshore structures is very complex. For example, it is necessary to connect a first end of the fluid line to a fluid connection of the first offshore structure, then run the fluid line, for example, to the underwater bed and along this (e.g. buried) to the other offshore structure, there run the fluid line upwards and connect the other end of the fluid line to another fluid connection of the other offshore structure. In addition to the high cost of laying such a line, the high safety standards that must be maintained, especially for a hydrogen pipeline, are problematic. In addition, the wave load on the foundation increases if additional fluid lines, particularly in the form of steel pipes, are used on an outer wall of the foundation of an offshore structure.

[0015] Therefore, the object of the invention is to provide a possibility in which the disadvantages of the prior art are at least reduced and in particular the laying of at least one fluid line in an offshore structure is simplified, at the same time the high safety standards are maintained and the wave load is reduced.

[0016] The object is achieved according to a first aspect of the invention by a ship landing device according to claim 1 for an offshore structure. The offshore structure comprises, in particular, at least one hydrogen processing device. The ship landing device comprises at least one conductor structure. The ship landing device comprises at least one impact body protection structure. The ship landing device comprises at least one fluid line integrated in the conductor structure and / or the impact body protection structure, which is connectable in particular to the hydrogen processing device. Alternatively or additionally, the ship landing device comprises at least one electrical line integrated in the conductor structure and / or the impact body protection structure, operable with a voltage of at least 1 kV.

[0017] By providing, in contrast to the prior art, a ship landing device for an offshore structure in which at least one line (fluid line for conducting a fluid or line operable with a voltage of at least 1 kV) is integrated or passed through the conductor structure and / or the hydrogen processing device, the disadvantages of the prior art are at least reduced and, in particular, laying a fluid line in an offshore structure is simplified, while at the same time the high safety standards are maintained and the wave load is reduced.

[0018] According to the invention, it has been recognized that a structure already present on the offshore structure, in particular the foundation of the offshore structure, and which is at least partially hollow, can additionally be used to accommodate a line and to guide this line safely along an outer foundation wall of the foundation of the offshore structure to a fluid connection of the offshore structure or the foundation of the offshore structure. In particular, due to the impact body protection structure of the ship landing device, an additional protection device for the at least one fluid line can be omitted. A further advantage here is that material consumption can be reduced, in particular by using at least one cavity present in the conductor structure and / or impact body protection structure as a fluid line. In addition, wave loading is reduced, and at least the number of additional structures on the foundation can be reduced.

[0019] A ship landing device according to the invention is used for landing at an offshore structure using a watercraft (e.g., a Crew Transfer Vessel (CTV)). A ship landing device can be attached to an outer wall of the offshore structure, in particular to an outer foundation wall of a foundation of the offshore structure.

[0020] A ship landing device according to the invention comprises at least one (usually exactly one) ladder structure and at least one (usually exactly one) impact body protection structure. If necessary, a ladder structure (or an impact body protection structure) can be manufactured and assembled in a plurality of segments (e.g., vertically stacked), in particular if the foundation structure is also constructed from several segments (e.g.,

[0021] Monopile with transition piece (TP). A tight connection between the segments can then be provided for the conveyance of liquid or gaseous media, or a continuous inner pipe can be inserted into the cavities.

[0022] A ladder structure is used, in particular, for ascending and descending, for example, between a watercraft (landed at the ship landing device) and a platform or device of the offshore structure supported by the foundation of the offshore structure. A ladder structure can, in particular, comprise a plurality of rungs arranged parallel to one another, which are arranged on two stiles running parallel to one another. It is understood that, in other variants of the invention, other forms of ladder structures are also conceivable, such as a single-stile ladder, a ladder with three stiles, interrupted and / or offset / twisted ladder segments, and / or the like.

[0023] In an installed state of the ship landing device, i.e., a state in which the ship landing device is attached to the foundation and, in particular, the foundation is installed at an installation site of the offshore structure, the preferably at least two spars can, in particular, lie in a substantially vertical plane and, in particular, extend substantially vertically upwards from the direction of the underwater bed. A spar can, in particular, be cylindrical, preferably hollow-cylindrical. It is understood that a spar can also have a different cross-sectional shape, such as oval, rectangular, etc.

[0024] A conductor structure can be formed at least partially from metal (in particular steel) and / or a composite material (e.g. carbon fiber composite, glass fiber composite, etc.).

[0025] A shock body protection structure according to the invention can comprise at least one elongated shock body (also referred to as a "bumper" or impact strip), preferably two (parallel) elongated shock bodies. In the installed state of the ship landing device, the preferably at least two elongated shock bodies can lie in a substantially vertical plane and, in particular, extend substantially vertically upwards from the direction of the underwater floor. An elongated shock body can, in particular, be cylindrical, preferably hollow-cylindrical. It is understood that an elongated shock body can also have a different cross-sectional shape, such as oval, rectangular, etc.

[0026] The impact body protection structure and the ladder structure are in particular connected to one another, for example via at least one connecting piece that is, for example, welded or screwed on. In particular, an elongated impact body is located on the outer side of a spar of the ladder structure. This enables a watercraft to impact against the two elongated impact bodies in particular for landing or to press against the elongated impact bodies using motor power (and to maintain this landing position), so that at least one user can use the ladder structure located between the elongated impact bodies to climb up and down between the landed watercraft and a platform or device of the offshore structure. The impact body protection structure can be formed at least partially from metal (in particular steel) and / or a composite material (e.g. carbon fiber composite, glass fiber composite, etc.).

[0027] According to the invention, it has been recognized that the structure of the ship landing platform, which is already arranged on an offshore structure, can be used to lay at least one fluid line and / or one electrical line operable with a voltage of at least 1 kV along the outer wall of the foundation of the offshore structure. In the installed state of the ship landing platform, the at least one line can be arranged through a cavity of the conductor structure and / or a cavity of the impact body protection structure. Particularly preferably, the at least one fluid line can be formed by a cavity or the inner wall of an elongated (and in particular vertically extending) cavity of the conductor structure and / or the impact body protection structure. In particular, the at least one integrated line can run in a substantially vertical direction.

[0028] In the present case, a line integrated in the conductor structure and / or in the impact body protection structure comprises in particular that a portion of an overall line is arranged, in particular guided, within the conductor structure and / or in the impact body protection structure.

[0029] According to a preferred embodiment of the ship landing device according to the invention, the at least one fluid line can be a hydrogen line. The hydrogen line can be configured to conduct hydrogen, in particular wet or pre-dried hydrogen. The hydrogen line can be, in particular, a hydrogen line of a hydrogen pipeline network of an offshore hydrogen production system according to the invention. The hydrogen pipeline network can be configured to conduct the hydrogen produced by a micro-electrolysis system of an offshore hydrogen production wind turbine to a central offshore processing structure with a hydrogen processing plant.

[0030] The (central) hydrogen processing plant can be set up to process (produced) hydrogen.

[0031] A particular advantage of a hydrogen pipeline routed along the outer wall of the offshore structure, especially the foundation, is that, unlike a hydrogen pipeline routed inside the foundation, sufficient explosion protection can be provided more easily. While there is a risk of an explosive mixture forming inside the foundation or offshore structure in areas with potential sparking, this risk does not exist on the outer wall or outdoors if sufficient distance is maintained from sparking components.

[0032] In both variants, an explosive atmosphere can form, which always occurs when more than 4% hydrogen is present in the air. However, the problem inside is that there are numerous spark sources (e.g.

[0033] Switchgear, the internal conductor system, generator in the nacelle) are practically unavoidable. Externally, the components can be positioned in such a way that no sparking is to be expected where an explosive atmosphere may be present. This could be, for example, a zone of 1 m around the upper end of the ship landing device. If a hydrogen line were to leak, an explosive atmosphere would arise here and within the ship landing device. Sparking can then be easily excluded in these areas by not positioning any sparking components such as lights etc. there and by ensuring that all metal parts are well earthed (to avoid possible electrostatic charging).

[0034] According to a further embodiment of the ship landing device according to the invention, the at least one fluid line can be an inert gas line. The inert gas line can be configured to conduct an inert gas, in particular to conduct nitrogen. The inert gas line can be part of an inert gas network of an offshore hydrogen production system according to the invention. A central offshore processing structure of the offshore hydrogen production system can comprise an inert gas generation plant. The inert gas generation plant can be configured to generate an inert gas. The inert gas line network can, in particular, be configured to supply the respective micro-electrolysis systems of the offshore hydrogen production wind turbines of the offshore hydrogen production system with the generated inert gas.In particular, at least the respective micro-electrolysis plants are connected or coupled to the inert gas generation plant of the first central offshore processing structure via the inert gas pipeline network. For example, the inert gas generation plant may comprise a gas storage facility, particularly in the form of a pressure accumulator, configured for (temporary) storage of the generated inert gas.

[0035] The inert gas generated and supplied via the inert gas pipeline network is used in a micro-electrolysis plant, for example, to purge (all) gas-laden system components of the product gases hydrogen and oxygen. The generated inert gas can also replace instrument air or compressed air, which may be required, for example, for valve operation.

[0036] Preferably, a nitrogen generation system configured to generate nitrogen can be provided as the inert gas generation system. It is understood that, in variants of the invention, other inert gas generation systems can also be provided alternatively or additionally. By generating inert gas centrally, maintenance costs for the offshore hydrogen production system can be reduced.

[0037] According to a further embodiment of the ship landing device, the at least one fluid line can be a water line. The water line can be configured to conduct treated water. The water line can, in particular, be part of a water line network of an offshore hydrogen production system according to the invention. In particular, a central offshore treatment structure of the offshore hydrogen production system can comprise at least one water treatment plant. The water treatment plant can be configured to treat the water such that it can be used in a micro-electrolysis plant for hydrogen production. In particular, the water treatment plant can treat seawater for electrolysis.

[0038] The water treatment plant can preferably be a seawater desalination plant with membrane-based pressure filtration. Such a seawater desalination plant can be configured to treat the water, in particular by reverse osmosis, ultrafiltration, and / or electrodialysis (also called electrodeionization (EDI)), or treat the seawater accordingly. Such treatment can be used, particularly in an energy-efficient manner, to treat seawater that can be used for water electrolysis in a micro-electrolysis plant. The treated water can also be referred to as ultrapure water or "demine water." In order to supply the decentralized micro-water treatment plants of the offshore hydrogen production system with the treated water, in particular the ultrapure water, the offshore hydrogen production system can comprise at least one water pipeline network.

[0039] According to a further embodiment of the ship landing device, the at least one fluid line can be another water line configured to conduct ambient water, in particular seawater. In particular, the water line can be a cooling water line for conducting ambient water to a component of the offshore structure to be cooled. For example, a micro-electrolysis system can comprise a pre-cooling module configured to cool the produced hydrogen (e.g., to down to 3°C). In particular, the cooling can comprise the partial condensation and separation of the condensed water. As already described, at least one of the aforementioned fluid lines is integrated into the conductor structure and / or the impact body protection structure, preferably at least two of the described fluid lines. In particular, all of the aforementioned fluid lines can be integrated into the conductor structure and / or the impact body protection structure.

[0040] According to a preferred embodiment of the ship landing device according to the invention, the at least one line (fluid line and / or electrical line operable with a voltage of at least 1 kV) can be integrated into at least one spar of the ladder structure. As already described, a longitudinal axis of a spar of a ladder structure runs at least substantially in a vertical direction in the installed state of the ship landing device. Furthermore, a spar is in particular a hollow cylinder or a similar hollow body. The elongated cavity of a spar can therefore be used particularly advantageously as a fluid line or for laying a line (fluid line and / or electrical line operable with a voltage of at least 1 kV) through said cavity.

[0041] Alternatively, preferably in addition to the at least one spar, the at least one line (fluid line and / or electrical line operable with a voltage of at least 1 kV) can be integrated into at least one elongated impact body of the impact body protection structure. As already described, a longitudinal axis of an elongated impact body of an impact body protection structure runs at least substantially in a vertical direction in the installed state of the ship landing device. In addition, an impact body is in particular a hollow cylinder or a similar hollow body. The elongated cavity of an elongated impact body can therefore be used particularly advantageously as a fluid line or for laying a line (fluid line and / or electrical line operable with a voltage of at least 1 kV) through said cavity.According to a further embodiment of the ship landing device, the at least one electrical line can be integrated into the conductor structure and / or the impact body protection structure. The at least one electrical line can be, in particular, a medium-voltage cable (for example, operable at a voltage between 1 kV and 60 kV, preferably between 6 kV and 52 kV, particularly preferably between 11 kV and 33 kV) and / or a high-voltage cable (for example, operable at a voltage between 60 kV and 800 kV, preferably between 66 kV and 550 kV). In particular, the electrical line can be a power cable and preferably be part of a medium-voltage network or high-voltage network of an offshore hydrogen production system according to the invention.

[0042] Preferably, an additional electrical line in the form of a low-voltage cable can be integrated into the conductor structure and / or the impact body protection structure. In other words, two separate first electrical energy cable networks can preferably be provided in the form of a low-voltage cable network (e.g., 400 V cable) and a medium-voltage network (e.g., 33 kV cable) or high-voltage network. Electrical energy can be exchanged by means of an electrical line, in particular between two offshore structures or between an offshore structure and an onshore structure.

[0043] Alternatively or additionally, at least one data line can be integrated into the conductor structure and / or the impact body protection structure. In variants of the invention, the data line can be integrated into the at least one electrical line. The data line can be part of a data cable network of an offshore hydrogen production system according to the invention.

[0044] Furthermore, according to a further embodiment of the invention

[0045] Ship landing device at least one seawater reservoir in the

[0046] The seawater reservoir (also referred to as a caisson) can be formed directly by a cavity (as described above) or by a seawater pipe that can be inserted into such a cavity and, in particular, removed. A water reservoir can be provided in a simple manner, for example, for a cooling circuit and / or as a water reservoir for a water treatment system. The warmer seawater pipe can be part of the cooling system through heat transfer to the colder ambient air and / or colder surrounding seawater.

[0047] According to a preferred embodiment of the ship landing device according to the invention, a pump can be arranged at a lower end region of a spar (which can in particular form the seawater reservoir) of the ladder structure. The pump can be configured to suck in ambient water and in particular to pump the sucked-in ambient water toward the upper end region of the spar. Alternatively or additionally, a pump can be arranged at a lower end region of the elongated impact body (which can in particular form the seawater reservoir) of the impact body protection structure. The pump can be configured to suck in ambient water and in particular to pump the sucked-in ambient water toward the upper end region of the elongated impact body. In a particularly simple manner, a water reservoir can be provided, for example for a cooling circuit and / or as a water reservoir for a water treatment plant.

[0048] Preferably, the at least one pump can be removed from the corresponding lower end region by means of a rope and / or wire and / or rod and / or shaft attached to the pump, for example for inspecting and / or servicing the pump.

[0049] Furthermore, according to a further embodiment of the ship landing device according to the invention, at least one anchoring point (e.g., in the form of an eyelet) can be arranged on the ladder structure and / or the impact body protection structure. In particular, a plurality of anchoring points (eyelets) can be arranged on the ship landing device, in particular on the ladder structure and / or the impact body protection structure and / or a first connecting piece between the ladder structure and the impact body protection structure or a second connecting piece between the impact body protection structure or the ladder structure and the foundation.In other words, the vessel landing facility (also called boat mooring) can also serve as an anchoring point for adjacent floating or submerged structures in an offshore hydrogen production system according to the invention, such as an OFPV (Offshore Floating Photovoltaic) system, buoys (also for power or media transfer), storage facilities for liquids or electricity, such as floating or submarine tanks, batteries, coolers, etc.

[0050] According to a further embodiment of the ship landing device according to the invention, the ship landing device can further comprise: at least one additional elongated hollow body for receiving at least one further fluid line and / or at least one electrical line, wherein the additional elongated hollow body is fastened to the conductor structure and / or to the impact body protection structure.

[0051] In particular, in the event that at least one more fluid line and / or at least one more electrical line needs to be laid than can be integrated into the conductor structure and / or the impact body protection structure due to space constraints, at least one additional hollow body for accommodating at least one further fluid line and / or at least one electrical line can be fastened to the conductor structure and / or the impact body protection structure, for example, screwed or welded. An additional elongated hollow body for accommodating at least one further fluid line comprises, in particular, an additional elongated hollow body which forms the further fluid line. According to a preferred embodiment of the ship landing device according to the invention, in an installed state of the ship landing device, a lower end of at least one spar of the ladder structure can extend substantially to the underwater floor.Alternatively or additionally, in an installed state of the ship landing device, a lower end of at least one elongated impact body of the impact body protection structure may extend substantially to the underwater bottom. In other words, compared to a conventional ladder structure and / or impact body protection structure, at least one of these structures may be extended in the vertical direction (although this is not required for the actual landing process).

[0052] By extending at least one spar (preferably at least two spars) and / or at least one elongated impact body (preferably at least two spars) at least substantially to the underwater bottom, a (safe) guide for the at least one line (preferably a plurality of fluid lines and in particular the at least one electrical line) to the underwater bottom can be provided. While this extension requires additional material, the overall requirement for secondary steel or a composite material is lower. Furthermore, the overall wave load can be lower than with a solution using separate external fluid lines.

[0053] According to a further embodiment of the ship landing device according to the invention, the cross-sectional area of ​​the at least one spar can taper (continuously and / or step-like) from an upper end of the spar to the lower end. Alternatively or additionally, the cross-sectional area of ​​the at least one elongate impact body can taper (continuously and / or step-like) from an upper end of the elongate impact body to the lower end. This can, in particular, reduce the material required to manufacture a spar and / or an elongate impact body. According to a particularly preferred embodiment of the ship landing device according to the invention, the at least one spar can be formed from at least two telescopic spar elements. In variants of the invention, three or more telescopic spar elements can be provided.Alternatively or additionally, the at least one elongated impact body can be formed from at least two telescopic impact body elements. In variants of the invention, three or more telescopic impact body elements can be provided.

[0054] A telescopic spar or a telescopic impact body can be formed, in particular, from two or more coaxially nested cylindrical or prismatic, sometimes even slightly conical, partial tubes. Other cross-sectional shapes are conceivable. Preferably, each of the inner telescopic elements (e.g., telescopic spar elements and / or telescopic impact body elements) can be axially extended from the next largest element, which directly encloses it.

[0055] Furthermore, a telescopic beam or a telescopic impact body can comprise at least one seal, which, at least in an extended state, seals the transition between two telescopic elements. Seals can preferably be integrated into the upper and lower ends of a telescopic beam element and / or into the upper and lower ends of a telescopic impact body element. A seal can, for example, be self-sealing when two telescopic elements have been moved to their (fully) extended position or have been remotely activated.

[0056] In addition to ensuring watertightness at at least one connection point, a seal can preferably also serve to fix the horizontal position of the respective ends of the telescopic spar elements or telescopic impact body elements relative to each other, thus preventing, in particular, wave- or flow-induced movements. Excessive wear can thereby be prevented, in particular. The sealed telescopic spar elements or telescopic impact body elements can also provide vertical support / fixation for the telescopic tube elements.

[0057] Where necessary, the lower ends of each telescopic element can be secured to at least one support point on the foundation, e.g., by means of a self-locking or reversible locking mechanism (e.g., twist-lock mechanism). The at least one locking mechanism can, for example, be attached to the position of the support point on the foundation and / or to a respective end of the telescopic elements or segments (e.g., telescopic spar elements and / or telescopic impact body elements) in their fully extended position.

[0058] According to a further embodiment of the ship landing device according to the invention, at least one anti-kink element can be arranged at a lower end of at least one spar of the ladder structure. Alternatively or additionally, at least one anti-kink element can be arranged at a lower end of at least one elongated impact body of the impact body protection structure. A anti-kink element or bending protection element is, in particular, a cable guide designed to prevent a fluid line or the electrical line from bending beyond the permissible bending radius of the fluid line or the electrical line. The risk of damage to the fluid line or the electrical line can be reduced. In particular, a respective anti-kink element can be provided if a spar or an impact body extends substantially to the underwater floor (in particular a seabed).Preferably, an anti-kink element or a similar protection system for a fluid line and / or an electrical line can be pre-installed at the end of a telescopic spar or a telescopic locking body and can be tightened, for example, from a main work platform as soon as all telescopic elements have been lowered into place and, in particular, secured. According to a further preferred embodiment of the ship landing device according to the invention, the at least one fluid line can be a return channel of a cooling circuit, wherein the return channel is routed along the electrical line, in particular for cooling the electrical line. In particular, it has been recognized that the cooling water for cooling a component of the offshore structure to be cooled can, after cooling, also be used to cool an electrical line, in particular a medium-voltage cable or a high-voltage cable.While the electrical cable can reach a permissible temperature of preferably up to 105 °C (e.g. 95 °C), the heated cooling water has a maximum temperature between approx. 50 °C and 60 °C.

[0059] For example, the return channel can be directly adjacent to the electrical line. For example, the electrical line and the return channel can each be integrated into the same spar or the same elongated impact body as an independent line (and in particular lying next to one another). The electrical line can also be at least partially passed through the return channel. For example, an elongated cavity of a spar or the elongated cavity of an elongated impact body can be formed as a fluid line and the electrical line can be routed through this elongated cavity. The cooling water flows directly past the electrical line to be cooled. Reliable and efficient operation of the electrical line, particularly in geographical locations with high temperatures, can be ensured, in particular without the need to install additional cooling.In some cases, a smaller cable cross-section may prove sufficient due to the cooling effect, which reduces the cable procurement costs and enables easier installation.

[0060] Alternatively or additionally, a first fluid line and a second fluid line can be provided in the form of a return channel of a cooling circuit and, in particular, integrated into the conductor structure or the impact body protection structure. The return channel can be routed along the first fluid line to heat the first fluid line (freeze protection). For example, the first fluid line (e.g., the hydrogen line) and the second fluid line can each be integrated into the same spar or the same elongated impact body as an independent line (and, in particular, lying next to one another). For example, an elongated cavity of a spar or the elongated cavity of an elongated impact body can be formed as the first fluid line, and the second fluid line can be routed through this elongated cavity (or vice versa). The heated cooling water flows directly past the fluid line to be heated.Reliable antifreeze protection can be provided, especially in low-temperature geographical locations.

[0061] As described, on its way back to the sea, the heated cooling water return can be channeled through a return channel (e.g., a steel pipe), thus serving, in particular, as frost protection for the at least one additional fluid line. At the same time, the warm cooling water flow can also serve as a cooling medium for the at least one (even warmer) medium- or high-voltage cable, in particular to avoid potential hotspots and / or to enable smaller cable diameters.

[0062] For extended winter closures, the above-sea-level section of the water line used to convey the treated water can be emptied by injecting pressurized inert gas from the foundation platform, particularly to prevent freezing. Alternatively or additionally, a shut-off and vent valve and / or an electric heater can be used.

[0063] In the case of internal cooling of a foundation, the heat from the fluid line can be directly connected to the foundation via a return channel (e.g., a steel pipe) that serves as frost protection for the inside of the fluid lines via the heat-conducting coupling of the fluid lines. A line and / or pipe and / or cable can be secured with cable ties, heat-shrink tubing, composite clamps (half-shells), insert plates, hinged doors, or similar.

[0064] A further aspect of the invention is a foundation set. The foundation set comprises at least one foundation of an offshore structure. The offshore structure comprises at least one hydrogen processing device. The foundation set comprises at least one ship landing device as described above, which can be attached to the foundation. Furthermore, the foundation set can comprise at least one fluid line and / or at least one electrical line.

[0065] In an installed state of the foundation set (or the ship landing device), the ship landing device is (permanently) attached to the foundation of the offshore structure. The foundation serves to support at least one hydrogen processing device. Examples of hydrogen processing devices, which are not exhaustive, may include a micro-electrolysis plant, micro-water treatment plant, micro-nitrogen plant, micro-cooling water plant, micro-hydrogen processing plant, such as a micro-hydrogen drying plant, and / or a micro-

[0066] Hydrogen compression plant, and / or a central electrolysis plant, central water treatment plant, central nitrogen plant, central cooling water plant, central hydrogen treatment plant, such as a central hydrogen drying plant, and / or a central hydrogen compression plant, and / or the like. It is understood that additional devices can be supported by the foundation, such as a wind turbine, a photovoltaic system, a transformer, etc.

[0067] As described, further processing of hydrogen can include drying, compression, measurement, and / or a chemical reaction (e.g., to NH3). Examples of offshore structures include offshore hydrogen production wind turbines and central offshore processing facilities.

[0068] The foundation can be a buoyant foundation (e.g., barge foundation, semi-submersible foundation, spar foundation, and / or tension leg platform (TLP) foundation). Alternatively, the foundation can be a non-buoyant foundation (e.g., monopile, tripod, triple pile, or jacket foundation).

[0069] The foundation may comprise at least one pre-installed eyelet (or the like), configured to receive and, in particular, guide the ship landing device, in particular the ladder structure and / or the impact body protection structure, along an outer foundation wall of the foundation. The ship landing device may be inserted from above into the at least one pre-installed eyelet, in particular a plurality of eyelets. Optionally, the ship landing device may be locked or secured (e.g., by means of a screwable or weldable collar of the ship landing device). A ship landing device can be easily mounted on a foundation.

[0070] A further aspect of the invention is an offshore hydrogen production system comprising at least one offshore structure with at least one hydrogen processing device and a ship landing device attached to a foundation of the offshore structure and described above.

[0071] A further aspect of the invention is the use of a (previously described) ship landing device for guiding at least one line (fluid line or electrical line operable with a voltage of at least 1 kV) within a conductor structure of the ship landing device and / or within an impact body protection structure of the ship landing device. There are now numerous possibilities for designing and further developing the ship landing device according to the invention, the foundation set according to the invention, the hydrogen production system according to the invention, the method according to the invention, and the use according to the invention. Reference is made, on the one hand, to the patent claims subordinate to the independent patent claims, and, on the other hand, to the description of exemplary embodiments in conjunction with the drawing. The drawing shows:

[0072] Fig. 1 is a schematic view of an embodiment of an offshore hydrogen production system according to the present invention,

[0073] Fig. 2 is a schematic view of an embodiment of a ship landing device according to the present invention,

[0074] Fig. 3a is a first schematic view of an embodiment of a foundation set according to the present invention with a further embodiment of a ship landing device according to the present invention,

[0075] Fig. 3b is a further schematic view of the embodiment according to Figure 3a,

[0076] Fig. 4 is a schematic view of another embodiment of a foundation set according to the present invention with another embodiment of a ship landing device according to the present invention, and

[0077] Fig. 5 is a schematic view of another embodiment of a foundation set according to the present invention with another embodiment of a ship landing device according to the present invention.

[0078] In the following, similar reference numerals are used for similar elements. Furthermore, z denotes a vertical direction or a vertical axis, and y denotes a horizontal direction or a horizontal axis.

[0079] Figure 1 shows a schematic view of an embodiment of an offshore hydrogen production system 100 according to the present invention. For the sake of clarity, the at least one ship landing device according to the present invention has not been explicitly shown in Figure 1. It is understood that at least one foundation 126, 128, preferably all foundations 126, 128, can be equipped with a ship landing device.

[0080] The illustrated offshore hydrogen production system 100 comprises a plurality of offshore structures in the form of a plurality of offshore hydrogen production wind turbines 102 and a central offshore processing structure 108 for the decentralized offshore hydrogen production wind turbines 102. For the sake of clarity, only two offshore hydrogen production wind turbines 102 are shown here. An offshore hydrogen production system 100 can preferably comprise between 3 and 30 offshore hydrogen production wind turbines 102.

[0081] Furthermore, each offshore hydrogen production wind turbine 102 can preferably be formed substantially identically. In particular, each offshore hydrogen production wind turbine 102 comprises a wind turbine 106 and, as a hydrogen processing device, a micro-electrolysis system 104 or a micro-electrolysis module. A wind turbine 106 can comprise a tower, a nacelle, a rotor, rotor blades, a generator, etc. A wind turbine 106 is in particular configured to generate electrical energy by converting the kinetic energy of the wind into electrical energy. The electrical energy generated by a respective wind turbine 106 is in particular made available to the respective micro-electrolysis system 104.

[0082] As can be seen, a respective micro-electrolysis system 104 can be arranged on a respective foundation 126 of a respective offshore hydrogen production wind turbine 102. A micro-electrolysis system 104 (e.g., a PEM electrolyzer with multiple stacks) is configured to produce or generate hydrogen.

[0083] In particular, in the present preferred embodiment, the respective offshore hydrogen production wind turbines 102 do not have any processing systems implemented on the at least one central offshore processing structure 108 or a central offshore structure.

[0084] The illustrated central offshore treatment structure 108 comprises, as a hydrogen processing device, for example, a (central) water treatment plant 110. The water treatment plant 110 is arranged on a foundation 128 of the central offshore treatment structure 108. The water treatment plant 110 is particularly configured to treat water for hydrogen production by the micro-electrolysis systems 104 of the offshore hydrogen production wind turbines 102. In particular, the water treatment plant 110 can be configured to extract seawater from the sea 130. The extracted seawater can be treated in the water treatment plant 110 (e.g., a seawater desalination plant with membrane-based pressure filtration) and, in particular, subjected to reverse osmosis, nanofiltration, and / or electrodialysis. The water treated orTreated water is made available in particular to all micro-electrolysis plants 104 for hydrogen production.

[0085] Preferably, as shown in Figure 1, the water treatment system 110 can be formed from at least three micro water treatment systems 112 or three water treatment modules. The capacity of the at least three micro water treatment systems 112 can be designed such that two of the three micro water treatment systems 112 have sufficient capacity to supply all micro electrolysis systems 104 with (sufficient) treated water. In particular, at least one reserve micro water treatment system 112 can be arranged, which can (fully) compensate for the failure of another micro water treatment system 112. In particular, a micro water treatment system 112 can be integrated into a 20-foot container.

[0086] Optionally and preferably, the central processing structure 108 can have a (central) inert gas generation system 114. For example, the inert gas generation system 114 can generate nitrogen as the inert gas. The inert gas generation system 114 can be arranged on the foundation 128. Preferably, the inert gas generation system 114 can be integrated into a 20-foot container. In variants of the application, at least two micro inert gas generation systems can also be provided here for redundancy reasons, with at least one reserve micro inert gas generation system.

[0087] In addition, the offshore hydrogen production system 100 can, for example, comprise a medium interconnection network 118. The medium interconnection network 118 can comprise at least one water pipe network 120, for example formed by at least one fluid line in the form of a water pipe (e.g., a pipe, hose, or the like). As can be seen from Figure 1, the medium interconnection network 118 can be laid at least between the offshore hydrogen production wind turbines 102 and the central processing structure 108. In other words, the offshore hydrogen production wind turbines 102 are connected in this case via the medium interconnection network 118 at least to the first central processing structure 108.

[0088] The treated water is conveyed or pumped from the water treatment plant 110 via the water supply network 120 to the respective micro-electrolysis plants 104. The treated water can be conveyed, for example, under pressure.

[0089] The medium network 118 can, in particular, comprise an inert gas line network 122, for example, formed by at least one inert gas line (e.g., a pipe, hose, or the like). The generated inert gas can, in this case, be conducted or conveyed from the inert gas generation system 114 via the inert gas line network 122 to the respective micro-electrolysis systems 104. In this case, the generated inert gas can, for example, be conducted under pressure.

[0090] Preferably, the medium interconnected network 118 can comprise an electrical power cable network 132 arranged at least between the plurality of offshore hydrogen production wind turbines 102 and the first central offshore processing structure 108. In particular, the power cable network 132 can be a medium-voltage network, for example, formed from at least one electrical line in the form of a medium-voltage cable. Electrical energy can preferably be exchanged bidirectionally via the electrical power cable network 132. Preferably, the electrical power cable network 132 makes it possible to dispense with a separate energy supply in the form of another wind turbine on the central processing structure 108. In particular, the electrical systems 110, 114 of the first central processing structure 108 can be supplied with electrical energy by the wind turbines 106.In variants of the invention, a central processing structure can also comprise a wind turbine. Furthermore, the central processing structure 108 can comprise a substation 116, in particular in the form of at least one (electrical) transformer device. In particular, the substation 116 can form a grid connection point to an onshore electrical grid (not shown), in particular with the interposition of an onshore substation (not shown) of the offshore hydrogen production system 100. A second electrical power cable network 124 can be configured to exchange electrical energy with the onshore electrical grid. For example, excess electrical energy can be fed into the onshore electrical grid or electrical energy can be drawn from the onshore electrical grid (for example, to start or power up the wind turbines 106).

[0091] In variants of the invention, the central offshore processing structure shown can have at least one additional processing plant, such as a hydrogen processing plant. In this exemplary embodiment, this plant can also be installed as a decentralized micro-hydrogen processing plant on the offshore hydrogen production wind turbines. Produced hydrogen can, for example, be transported to the coast via appropriate transport vessels and / or pipelines (e.g., made of steel).

[0092] Preferably, two central offshore processing structures can be provided, with only systems that cannot create explosive atmospheres being installed on a first central offshore processing structure 108.

[0093] In a preferred embodiment, the offshore hydrogen production system comprises a further (not shown) central offshore processing structure with systems where explosive atmospheres can arise. The further central offshore processing structure can comprise a hydrogen processing plant configured to process the (pre-dried) hydrogen produced by the micro-electrolysis plants. For example, the produced hydrogen can be cooled to approximately 3 to 5°C by a (not shown) pre-cooling module (or a corresponding refrigeration machine) of a micro-electrolysis plant. On its way through a (not shown) hydrogen pipeline network to the central processing structure, essentially no further water condenses (therefore no risk of water hammer).

[0094] In particular, a hydrogen processing plant may comprise a hydrogen drying plant (TSA) configured to dry the obtained (pre-dried) hydrogen, in particular to -40°C. Furthermore, the hydrogen processing plant may comprise a hydrogen compression plant configured to compress the processed hydrogen, in particular the hydrogen dried by the hydrogen drying plant.

[0095] The hydrogen processing plant can preferably be formed from at least three micro-water processing plants or three water processing modules. The capacity of the at least three micro-hydrogen processing plants can be designed such that two of the three micro-hydrogen processing plants already have sufficient capacity to process the hydrogen produced by all micro-electrolysis plants. In particular, at least one reserve micro-hydrogen processing plant can be arranged, which (fully) compensates for the failure of another micro-hydrogen processing plant in the event of this failure. A micro-hydrogen processing plant can preferably be integrated into a 20-foot container.

[0096] As further indicated in Figure 1, the first end of a fluid line can be connected to a fluid connection of the first offshore structure, the fluid line can then be led to the underwater bed and along this (e.g. buried) to the further offshore structure. There the line can lead upwards and the other end of the line can be connected to another fluid connection of the further offshore structure. A line can be buried, laid on the underwater bed and / or arranged in a suspended manner, for example with further suspension points for fastening, which could be floating PV systems or buoys. A line can be fixed to the underwater bed at intervals (e.g. by means of point-based fill or concrete mats). A variant is also conceivable in which a line with positive buoyancy (if necessary) is arranged.achieved by attaching suitable buoyancy bodies at the required intervals) is kept suspended by sufficiently heavy ballast bodies at a defined distance above the seabed.

[0097] The reference numeral 130 denotes in particular the ambient water or sea water.

[0098] Figure 2 shows a schematic view of an embodiment of a ship landing device 250 according to the present invention. The ship landing device 250 can, for example, be arranged on a foundation of an offshore structure of the offshore hydrogen production system according to Figure 1.

[0099] The ship landing device 250 comprises a ladder structure 252 and an impact body protection structure 254. The ladder structure 252 has, for example, two parallel spars 238, 240, which extend vertically when installed or fastened. A plurality of mutually parallel rungs 242 are arranged between the spars 238, 240. The rungs 242 can, in particular, extend horizontally. The ladder structure 252 can be formed from metal, in particular steel. A spar 238, 240 can, in particular, be formed as a hollow cylinder.

[0100] The impact body protection structure 254 comprises, for example, two parallel, elongated impact bodies 244, 246, which extend vertically when installed or fastened. An elongated impact body 244, 246 can be formed, in particular, as a hollow cylinder, for example, made of steel. For example, the conductor structure 252 and the impact body protection structure 254 can be connected to one another via a plurality of connecting pieces 248.

[0101] As can be seen, the cross-sectional area of ​​an elongated impact body 244, 246 can be larger than the cross-sectional area of ​​a spar 238, 240.

[0102] According to the invention, the ship landing device 250 further comprises at least one fluid line 256, 258 (e.g., a water line for conducting treated water, a cooling water line, a hydrogen line, an inert gas line, etc.) integrated into the conductor structure 252 and / or the impact body protection structure 254, which can be connected to a hydrogen processing device (not shown). Two fluid lines 256, 258 are shown here by way of example.

[0103] A first fluid line 256 is, in particular, integrated into the impact body protection structure 254 such that it leads from a lower end region 260 of an elongate impact body 244 through the cavity of the elongate impact body 244 to an upper end region 262 of the elongate impact body 244. In particular, the fluid line enters the elongate impact body 244 in the lower end region 260 and is led out again in the upper end region 262, for example to a fluid connection (not shown). In variants of the invention, leading the fluid line out comprises directly connecting the fluid line to a fluid connection (not shown). Furthermore, in variants of the invention, the fluid line can be formed at least in sections by the cavity of the elongate impact body 244.

[0104] A second fluid line 258 is, in particular, integrated into the conductor structure 252 such that it leads from a lower end region 264 of a beam 238 through the hollow space of the beam 238 to an upper end region 266 of the beam 238. In particular, the fluid line 258 enters the beam 238 in the lower end region 264 and is led out again in the upper end region 266, for example to a fluid connection (not shown). In variants of the invention, leading the fluid line out comprises directly connecting the fluid line to a fluid connection (not shown). Furthermore, in variants of the invention, the fluid line can be formed at least in sections by the hollow space of the beam 238.

[0105] Figures 3a and 3b show schematic views of an embodiment of a foundation set 370 according to the present invention with a further embodiment of a ship landing device 350 according to the present invention. To avoid repetition, only the differences from the previous embodiment according to Figure 2 are described below (particularly with regard to the ship landing device 350).

[0106] The foundation set 370 comprises a foundation 326 (e.g., a monopile), for example, with a platform 372. The platform 372 or a device installed thereon (see, for example, Fig. 1) can, for example, have at least one fluid connection (not shown) and / or at least one electrical connection (not shown). Furthermore, the foundation set 370 further comprises at least one ship landing device 350 that can be attached to the foundation 326. In the illustrated embodiment, the ship landing device 350 is attached to the foundation 326, in particular by means of a plurality of connecting pieces 348. In other words, the ship landing device 350 is in an installed state or a fastened state.

[0107] In the manner described above, at least one fluid line 356 can be integrated, for example, in an elongated impact body 344 of the impact body protection structure 354.

[0108] Furthermore, in the present exemplary embodiment, at least one electrical line 376, operable with a voltage of 1 kV, is integrated into the conductor structure 352, in particular in a spar 340. In variants of the invention, an electrical line can also be integrated into the impact body protection structure. The at least one electrical line 376 is in particular a medium-voltage cable and / or a high-voltage cable. For example, the electrical line 376 can comprise a data line. Alternatively, a (separate and not shown) data line can also be integrated into the conductor structure and / or the impact body protection structure.

[0109] Furthermore, at least one seawater reservoir 374 can optionally be integrated into the impact body protection structure 354, in particular in an elongated impact body 346. The seawater reservoir is particularly configured to store and provide seawater for at least one component of the offshore structure. For example, the seawater can be made available to a previously described water treatment plant or the seawater can be used as cooling water for a component of the offshore structure that is to be cooled.

[0110] A pump 378 can be arranged at a lower end region 360 of the elongated impact body 346 of the impact body protection structure 354, configured to suck in ambient water (in particular seawater or ocean water) and to pump the sucked-in ambient water toward the upper end region 362 of the elongated impact body 346, in particular toward a fluid connection. In variants of the invention, a seawater reservoir can also be integrated into the conductor structure, with or without a pump.

[0111] Figure 4 shows a schematic view, in particular a top view, of another embodiment of a foundation set 470 according to the present invention with another embodiment of a ship landing device 450 according to the present invention. To avoid repetition, only the differences from the previous embodiments according to Figures 2 and 3 are described below.

[0112] The foundation set 470 with the foundation 426 and the ship landing device 450 is shown in particular in the installed state of the ship landing device 450. A first fluid line 456 (e.g., a hydrogen line) can be integrated into a first spar 438 of the conductor structure 452, in particular, at least partially formed by the cavity of the spar 438. A further fluid line 458 (e.g., an inert gas line) can be integrated into a second spar 440, in particular, at least partially formed by the cavity of the spar 440.

[0113] A seawater reservoir 474 (or a cooling water line, in particular in the form of a forward channel) can be integrated into a first elongated impact body 446 of the impact body protection structure 454, in particular formed by the cavity of the spar 438. A previously described pump is not shown here. An electrical line 476 (in particular a medium-voltage cable) and a fluid line 480 in the form of a return channel of a cooling circuit can be integrated into the second elongated impact body 444 of the impact body protection structure 454. As can be seen, the return channel is routed along the electrical line 476, so that the electrical line 476 is cooled by the cooling fluid, which is, for example, returned to the sea. The forward and return channels can, in particular, be part of the same cooling circuit.

[0114] Optionally, the ship landing device 450 may further comprise at least one additional elongated hollow body 482, 488, for example, for accommodating at least one further fluid line 484 (e.g., a water line for treated water) and / or at least one electrical line 492 (e.g., a low-voltage line). The additional elongated hollow body 482, 488 may be attached to the conductor structure 452 and / or to the impact body protection structure 454, for example, by screwing or welding.

[0115] In addition, the ship landing device 450 comprises in particular a collar 486 (also referred to as collar or cage) configured to fasten the ship landing device 450 to the foundation 426. In addition, the ship landing device 450 can in particular have a plurality of anchoring points 490 (e.g. in the form of eyelets).

[0116] Figure 5 shows a schematic view of another embodiment of a foundation set 670 according to the present invention with another embodiment of a ship landing device 650 according to the present invention. To avoid repetition, only the differences from the previous embodiments according to Figures 2, 3, and 4 are described below.

[0117] In this example, the ship landing device 650 is attached to the foundation 626 by means of two collars 686. Optionally, connecting pieces 648 can be used for fastening. For example, a connecting piece 648 can be welded to the ladder structure 652 and / or the impact body protection structure 654 and / or the foundation 626.

[0118] As can be seen from Figure 5, in the illustrated installed state of the ship landing device 650, a lower end 697 of at least one spar 638 of the ladder structure 652 can extend substantially to the underwater floor 695. Preferably, all spars 638 can extend substantially to the underwater floor 695. In particular, in addition, in the installed state of the ship landing device 650, a lower end 693 of at least one elongated impact body 644 of the impact body protection structure 654 can extend substantially to the underwater floor 695. Preferably, all elongated impact bodies 644 can extend substantially to the underwater floor 695.

[0119] Preferably, the cross-sectional area of ​​the at least one beam 638 can taper from an upper end of the beam 638 to the lower end 697, for example, in a step-like manner. In particular, the cross-sectional area of ​​the at least one elongated impact body 644 can additionally taper from an upper end of the elongated impact body 644 to the lower end 693.

[0120] The at least one spar 638 can preferably be formed from at least two telescopic spar elements 691, 689. In a pre-installation state of the spar 638, the second spar element 689 can be arranged at least partially (preferably at least almost completely) in the first spar element 691. Figure 6 shows the installed state in which the second spar element 689 is extended from the first spar element 691.

[0121] The at least one elongate impact body 644 can be formed from at least two telescopic impact body elements 687, 685. In a pre-installation state of the elongate impact body 644, the second impact body element 685 can be arranged at least partially (preferably at least almost completely) within the first impact body element 687. Figure 6 shows the installed state in which the second impact body element 685 is extended from the first impact body element 687. This provides a simple, secure guidance of the at least one line 656, 676 down to the underwater floor 695.

[0122] Optionally, at least one anti-kink element (not shown) can be arranged at a lower end 697 of at least one spar 638 of the conductor structure 652, in particular to guide a line 676, such as an electrical line 676, to the underwater floor 695 without the line 676 being bent in an impermissible manner.

[0123] Optionally, at least one anti-kink element (not shown) can be arranged at a lower end 693 of at least one elongated impact body 644 of the impact body protection structure 654, in particular to guide a line 656, such as a fluid line 656, to the underwater floor 695 without the line 656 being bent in an impermissible manner. In particular, the lowest connecting piece or the lowest strut can serve as a dual entry and anchoring point for the anti-kink element.

[0124]

[0125] 100 Offshore Hydrogen Production System

[0126] 102 Offshore hydrogen production wind turbines

[0127] 104 Micro-electrolysis plant

[0128] 106 wind turbines

[0129] 108 central processing structure

[0130] 110 Water treatment plant

[0131] 112 Micro water treatment plant

[0132] 114 inert gas generation system

[0133] 116 substation

[0134] 118 Medium interconnected network

[0135] 120 water supply network

[0136] 122 Inert gas pipeline network

[0137] 124 Energy cable network

[0138] 126 Founding

[0139] 128 Founding

[0140] 130 Sea

[0141] 132 Energy cable network

[0142] 238 Holm

[0143] 242 rungs

[0144] 244 elongated impact body

[0145] 248 connecting piece

[0146] 250 ship landing device

[0147] 252 ladder structure

[0148] 254 Impact body protection structure

[0149] 256 Fluid line

[0150] 258 Fluid line

[0151] 260 end area

[0152] 262 End area - 2 -

[0153] 264 End area

[0154] 266 End area

[0155] 326 Founding

[0156] 340 Holm

[0157] 344 elongated impact body

[0158] 346 elongated impact body

[0159] 348 connecting piece

[0160] 350 ship landing device

[0161] 352 ladder structure

[0162] 354 impact body protection structure

[0163] 356 Fluid line

[0164] 360 end area

[0165] 362 End area

[0166] 370 Founding Set

[0167] 372 Platform

[0168] 374 Seawater reservoir

[0169] 376 Line

[0170] 378 Pump

[0171] 426 Founding

[0172] 438 Holm

[0173] 440 Holm

[0174] 442 rungs

[0175] 444 elongated impact body

[0176] 446 elongated impact body

[0177] 448 connecting piece

[0178] 450 ship landing device

[0179] 452 ladder structure

[0180] 454 Impact body protection structure

[0181] 456 Fluid line

[0182] 458 Fluid line

[0183] 470 Founding Set - 3 -

[0184] 474 Seawater reservoir

[0185] 476 electrical cable

[0186] 480 fluid line

[0187] 482 hollow bodies

[0188] 484 additional fluid line

[0189] 486 collar

[0190] 488 additional fluid line

[0191] 490 anchor point

[0192] 492 electrical cable

[0193] 626 Founding

[0194] 638 Holm

[0195] 644 impact bodies

[0196] 648 connecting piece

[0197] 650 ship landing device

[0198] 652 ladder structure

[0199] 654 Impact body protection structure

[0200] 656 Fluid line

[0201] 670 Founding Set

[0202] 676 electrical cable

[0203] 685 Impact body element

[0204] 686 collar

[0205] 687 Impact body element

[0206] 689 Beam element

[0207] 691 Beam element

[0208] 693 End

[0209] 695 Underwater floor

[0210] 697 End

Claims

Patent claims 1. A ship landing device for an offshore structure, wherein the offshore structure in particular comprises at least one hydrogen processing device, wherein the ship landing device comprises: at least one conductor structure, and at least one impact body protection structure, characterized in that the ship landing device further comprises: at least one fluid line integrated in the conductor structure and / or in the impact body protection structure, and / or at least one electrical line with a voltage of at least 1 kV integrated in the conductor structure and / or in the impact body protection structure.

2. Ship landing device according to claim 1, characterized in that the at least one fluid line is a hydrogen line, designed to conduct hydrogen, in particular wet hydrogen.

3. Ship landing device according to claim 1 or 2, characterized in that the at least one fluid line is an inert gas line, designed to conduct an inert gas, in particular to conduct nitrogen, and / or the at least one fluid line is a water line, designed to conduct treated water, and / or the at least one fluid line is a water line, arranged to conduct ambient water, in particular to conduct sea water.

4. Ship landing device according to one of the preceding claims, characterized in that the at least one fluid line and / or the at least one electrical line is integrated in at least one spar of the ladder structure, and / or the at least one fluid line and / or the at least one electrical line in at least one elongate impact body of the Impact body protection structure is integrated.

5. Ship landing device according to one of the preceding claims, characterized in that the at least one electrical line is a medium-voltage cable and / or a high-voltage cable.

6. Ship landing device according to one of the preceding claims, characterized in that at least one seawater reservoir is integrated in the ladder structure and / or in the impact body protection structure.

7. Ship landing device according to one of the preceding claims, characterized in that a pump is arranged at a lower end region of a spar of the ladder structure, designed to suck in ambient water and to pump the sucked ambient water towards the upper end region of the spar, and / or a pump is arranged at a lower end region of the elongated impact body of the impact body protection structure, designed to Suction of ambient water and pumping of the sucked ambient water towards the upper end region of the elongated impact body.

8. Ship landing device according to one of the preceding claims, characterized in that the ship landing device further comprises: at least one additional elongated hollow body for receiving at least one further fluid line and / or at least one further electrical line, wherein the additional elongated hollow body is attached to the conductor structure and / or to the impact body protection structure.

9. Ship landing device according to one of the preceding claims, characterized in that in an installed state of the ship landing device, a lower end of at least one spar of the ladder structure extends substantially to the underwater floor, and / or in an installed state of the ship landing device, a lower end of at least one elongate impact body of the impact body protection structure extends substantially to the underwater floor.

10. Ship landing device according to claim 9, characterized in that the cross-sectional area of ​​the at least one spar tapers from an upper end of the spar to the lower end, and / or the cross-sectional area of ​​the at least one elongate impact body tapers from an upper end of the elongate impact body to the lower end.

11. Ship landing device according to claim 9 or 10, characterized in that the at least one spar is formed from at least two telescopic spar elements, and / or the at least one elongate impact body is formed from at least two telescopic impact body elements.

12. Ship landing device according to one of the preceding claims, characterized in that at least one anti-kink element is arranged at a lower end of at least one spar of the ladder structure, and / or at least one anti-kink element is arranged at a lower end of at least one elongate impact body of the impact body protection structure.

13. Ship landing device according to one of the preceding claims, characterized in that the at least one fluid line is a return channel of a cooling circuit, wherein the return channel is guided along the electrical line for cooling the electrical line, and / or a first fluid line and a second fluid line are integrated in the form of a return channel in the conductor structure or the impact body protection structure, wherein the return channel is guided along the at least the first fluid line for heating the first fluid line.

14. A foundation kit comprising: at least one foundation of an offshore structure, wherein the offshore structure comprises at least one hydrogen processing device, characterized in that the foundation kit further comprises: at least one ship landing device according to one of the preceding claims which can be attached to the foundation.

15. Foundation set according to claim 14, characterized in that at least one first line end of the at least one line leading out of an upper end region of the conductor structure is connected to a connection of the foundation, and / or at least one first line end of the at least one line leading out of an upper end region of the impact body protection structure is connected to a connection of the foundation.

16. An offshore hydrogen production system comprising: at least one offshore structure having at least one hydrogen production device and a ship landing device according to any one of the preceding claims 1 to 13, attached to a foundation of the offshore structure.

17. Use of a ship landing device for guiding at least one fluid line or one electrical line operable with a voltage of at least 1 kV within a conductor structure of the ship landing device and / or within an impact body protection structure of the ship landing device.

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