Ship landing device

Abstract

The invention relates to a ship landing device for an offshore structure, wherein the offshore structure comprises at least one hydrogen processing device, wherein the ship landing device comprises at least one ladder structure, at least one shock body protection structure, and at least one fluid line integrated in the ladder structure and / or the shock body protection structure, and / or at least one electrical line integrated in the ladder structure and / or the shock body protection structure with a voltage of at least 1 kV.

Description

[0001] 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), and wherein the ship landing device comprises at least one ladder structure and at least one impact protection structure. Furthermore, the invention relates to a foundation set, an offshore hydrogen production system, and a method.

[0002] Hydrogen, especially hydrogen gas, is increasingly used as an energy carrier today. For example, hydrogen can be produced from water through electrolysis. In electrolysis, a redox reaction is forced using electrical energy or power, thereby generating hydrogen.

[0003] 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) for supplying the at least one electrolysis plant of the hydrogen production system. A renewable or regenerative energy source is understood to be, in particular, an energy source that is practically inexhaustible and / or regenerates relatively quickly.

[0004] Wind energy is among the most important renewable energy sources, where a wind turbine converts the kinetic energy of the wind into electrical energy. Wind farms and wind energy systems are increasingly being built at offshore locations. Compared to onshore locations, wind conditions, especially average wind speeds and frequency, are better at offshore sites.

[0005] An offshore wind farm typically consists of multiple offshore wind turbines, which are connected to at least one offshore substation via a power cable network, primarily consisting of multiple submarine cables. The offshore substation may, in turn, be connected to an onshore substation via another power cable network, typically using at least one submarine cable (usually at least two parallel submarine cables). The generated electrical energy can then be fed into a (public) distribution network via the onshore substation.

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

[0007] However, this approach has several disadvantages: 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. Submarine cables, however, are significantly more expensive than a hydrogen pipeline. Furthermore, energy losses during the transmission of electrical energy are greater compared to the transport of hydrogen. Finally, a hydrogen pipeline typically allows for a significantly larger energy transmission capacity compared to a conventional power cable network.

[0008] For these reasons, there is increasing consideration of constructing hydrogen production systems at offshore locations. In principle, two approaches to offshore hydrogen production systems are known from the state of the art. In the first, so-called centralized approach, the offshore hydrogen production system, including all production facilities (e.g., electrolysis plant, water treatment plant, nitrogen plant, cooling water plant, hydrogen upgrading plant, including a hydrogen drying plant, hydrogen compression plant, etc.), is 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.

[0009] 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 a multitude of decentralized micro-hydrogen production systems, each of which comprises 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 purification 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 construction space of an offshore wind turbine is used and the respective micro-hydrogen production system is directly supplied with electrical energy by the respective wind turbine.

[0010] Compared to the centralized approach, the decentralized approach involves increased maintenance. Regular maintenance of the individual micro-hydrogen production systems at each offshore wind turbine is required. Such maintenance necessitates landing at the respective wind turbine. Consequently, numerous landings are required, resulting in significant effort. Furthermore, landings are only possible under specific weather and / or sea conditions, which can lead to considerable delays in maintenance. This, in turn, can reduce yield. Another disadvantage is that each micro-hydrogen production system must meet stringent safety requirements, particularly regarding explosion protection. This is primarily due to the risk of explosive atmospheres.

[0011] To reduce the described disadvantages, it is known from the prior art to carry out hydrogen production decentrally using individual micro-electrolysis plants on each offshore hydrogen production wind turbine, and, for example, to carry out water treatment for decentralized hydrogen production centrally using a water treatment plant located on a central offshore processing structure, and / or hydrogen treatment centrally using a hydrogen treatment plant located on a central offshore processing structure, and / or inert gas generation using an inert gas generation plant located on a central offshore processing structure. This combined approach, in particular, combines the advantages of both the decentralized and the centralized approaches.

[0012] However, such an offshore hydrogen production system requires the installation of fluid pipelines, for example in the form of a network of interconnected media, between the at least two offshore structures to transport flowable media or fluids between these structures. For instance, the (wet) hydrogen produced decentrally at an offshore hydrogen production wind turbine can be conveyed via a first fluid pipeline to another offshore structure, namely a central offshore processing facility with a hydrogen upgrading plant, and / or the water treated by a central water treatment plant can be conveyed via a second fluid pipeline from a central offshore processing facility to the at least one decentralized offshore hydrogen production wind turbine.

[0013] Laying at least one fluid line to transport a fluid between two offshore structures is very complex. It requires connecting one end of the fluid line to a fluid connection on the first offshore structure, then routing the line, for example, to the underwater seabed and along it (e.g., buried) to the second offshore structure, bringing the fluid line upwards, and connecting the other end to another fluid connection on the second offshore structure. Besides the considerable effort involved in such a route, the stringent safety standards, particularly those required for hydrogen pipelines, pose a significant challenge. Furthermore, the wave load on the foundation increases if additional fluid lines, especially in the form of steel pipes, are used on the outer wall of the foundation of an offshore structure.

[0014] Therefore, the invention is based on the objective of providing a method 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, while at the same time high safety standards are maintained and wave loading is reduced.

[0015] The problem is solved 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 ladder structure. The ship landing device comprises at least one shock absorber protection structure. The ship landing device comprises at least one fluid line integrated in the ladder structure and / or the shock absorber protection structure, which is, in particular, connectable to the hydrogen processing device. Alternatively or additionally, the ship landing device comprises at least one electrical line integrated in the ladder structure and / or in the shock absorber protection structure, operable at a voltage of at least 1 kV.

[0016] In contrast to the prior art, the invention provides a ship landing device for an offshore structure in which at least one line (fluid line for conveying a fluid or line operable with a voltage of at least 1 kV) is integrated or routed through the conductor structure and / or the hydrogen processing device, thus reducing the disadvantages of the prior art and, in particular, simplifying the laying of a fluid line at an offshore structure, while simultaneously maintaining high safety standards and reducing wave loading.

[0017] According to the invention, it has been found that a structure already present on the offshore structure, particularly its foundation, and which is at least partially hollow, can be additionally used to accommodate a conduit and guide it safely along an outer foundation wall to a fluid connection of the offshore structure or its foundation. In particular, due to the impact protection structure of the ship landing device, a further protective device for the at least one fluid conduit can be omitted. A further advantage is that material consumption can be reduced, especially by using at least one cavity present in the conductor structure and / or impact protection structure as a fluid conduit. Furthermore, wave load is reduced, and at least the number of additional structures on the foundation can be reduced.

[0018] A ship landing device according to the invention serves to land a vessel (e.g., a crew transfer vessel (CTV)) at an offshore structure. A ship landing device can be attached to an outer wall of the offshore structure, in particular to the outer foundation wall of the offshore structure's foundation.

[0019] A ship landing device according to the invention comprises at least one (generally exactly one) ladder structure and at least one (generally exactly one) impact protection structure. Optionally, a ladder structure (or an impact protection structure) can be manufactured and assembled in a plurality of segments (e.g., arranged vertically one above the other), particularly if the foundation structure is also constructed from several segments (e.g., a monopile with a transition piece (TP)). In this case, a tight connection between the segments can be provided for conveying liquid or gaseous media, or a continuous inner tube can be inserted into the cavities.

[0020] A ladder structure is used in particular for ascending and descending, for example, between a vessel (landed at the ship landing device) and a platform or component of the offshore structure, which is supported by the foundation of the offshore structure. A ladder structure can, in particular, have a plurality of rungs arranged parallel to each other, which are arranged on two parallel stiles. It is understood that other forms of ladder structures are also conceivable in other embodiments of the invention, such as a single-stile ladder, a ladder with three stiles, interrupted and / or offset / twisted ladder segments, and / or the like.

[0021] 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 beams can lie, in particular, in a substantially vertical plane and, in particular, extend substantially vertically upwards from the direction of the underwater seabed. A beam can, in particular, be cylindrical, preferably hollow cylindrical. It is understood that a beam can also have a different cross-sectional shape, such as oval, rectangular, etc.

[0022] A conductor structure can be made at least partially of metal (especially steel) and / or a composite material (e.g. carbon fiber composite, glass fiber composite, etc.).

[0023] A shock 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 elongated shock bodies extending (parallel to each other). In the installed state of the ship landing device, the preferably at least two elongated shock bodies can lie, in particular, in a substantially vertical plane and, in particular, extend substantially vertically upwards from the direction of the underwater seabed. 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.

[0024] The impact protection structure and the ladder structure are connected to each other, for example, via at least one connecting piece, which is welded or bolted on. In particular, an elongated impact body is located on the outer side of each ladder structure beam. This allows a vessel to collide with the two elongated impact bodies or push against them using engine power (and maintain this landing position), so that at least one user can use the ladder structure located between the elongated impact bodies to ascend and descend between the landed vessel and a platform or device of the offshore structure.

[0025] The impact protection structure can be made at least partially of metal (especially steel) and / or a composite material (e.g. carbon fiber composite, glass fiber composite, etc.).

[0026] According to the invention, it has been discovered 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, operating at 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 in the conductor structure and / or a cavity in the impact protection structure. Particularly preferably, the at least one fluid line can be formed through a cavity or the inner wall of an elongated (and especially vertically extending) cavity in the conductor structure and / or the impact protection structure. In particular, the at least one integrated line can run in a substantially vertical direction.

[0027] In the present case, a conductor integrated into the ladder structure and / or the impact protection structure includes, in particular, that a section of a total conductor is arranged within the ladder structure and / or in the impact protection structure, and in particular is guided.

[0028] 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 convey hydrogen, in particular wet or pre-dried hydrogen. The hydrogen line can, in particular, be 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 convey the hydrogen produced by a micro-electrolysis unit of an offshore hydrogen production wind turbine to a central offshore processing structure with a hydrogen processing plant. The (central) hydrogen processing plant can be configured to process the (produced) hydrogen.

[0029] A particular advantage of routing a hydrogen pipeline along the outer wall of the offshore structure, especially the foundation, is that, unlike a hydrogen pipeline routed inside the foundation, adequate explosion protection can be provided more easily. While inside the foundation or the offshore structure there is a risk of an explosive mixture forming in areas where sparks could occur, this danger does not exist on the outer wall or in the open air, provided there is sufficient distance from spark-generating components.

[0030] In both scenarios, an explosive atmosphere can form, which is always the case when there is more than 4% hydrogen in the air. However, the main problem inside is the presence of numerous spark sources (e.g., switchgear, the internal wiring system, the generator in the nacelle), which are practically unavoidable. Outside, the components can be positioned so that sparking is not expected in areas where explosive atmospheres may be present. This could, for example, be a 1-meter zone around the top of the ship landing device. A hydrogen line leak would create an explosive atmosphere in this area and within the ship landing device itself. Sparking can then be easily prevented in these areas by not placing any spark-generating components, such as lights, and by ensuring that all metal parts are properly grounded (due to potential electrostatic charging).

[0031] 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 convey an inert gas, in particular 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 include an inert gas generation plant. The inert gas generation plant can be configured to generate an inert gas. The inert gas pipeline network can, in particular, be configured to supply the respective micro-electrolysis plants 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 include a gas storage facility, particularly in the form of a pressure storage tank, designed for the (intermediate) storage of the generated inert gas.

[0032] The generated inert gas, supplied via the inert gas pipeline network, is used in a micro-electrolysis plant, for example, to purge all gas-contaminated system components of the product gases hydrogen and oxygen. The generated inert gas can also replace the instrument air or compressed air required, for example, for valve actuation.

[0033] Preferably, a nitrogen generation plant configured to generate nitrogen can be provided as the inert gas generation plant. It is understood that in variants of the invention, other inert gas generation plants can also be provided alternatively or additionally. By centralizing inert gas generation, the maintenance effort of the offshore hydrogen production system can be reduced.

[0034] 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 convey treated water. In particular, the water line can 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.

[0035] Preferably, the water treatment plant can be a seawater desalination plant with membrane-based pressure filtration. Such a seawater desalination plant can be equipped with reverse osmosis, ultrafiltration, and / or electrodialysis (also called electrodeionization (EDI)) to treat the water, or to process the seawater accordingly. This treatment allows seawater to be purified, particularly in an energy-efficient manner, for use in the water electrolysis of a micro-electrolysis plant. The purified water can also be referred to as ultrapure water or "demin water." To supply the decentralized micro-water treatment plants of the offshore hydrogen production system with the purified water, and in particular the ultrapure water, the offshore hydrogen production system can include at least one water distribution network.

[0036] According to a further embodiment of the ship landing device, the at least one fluid line can be a further water line, configured for conveying ambient water, in particular seawater. Specifically, the water line can be a cooling water line for conveying ambient water to a component of the offshore structure that requires cooling. For example, a micro-electrolysis plant can include a pre-cooling module configured for cooling the produced hydrogen (e.g., to as low as 3°C). In particular, the cooling process can include the partial condensation and separation of the condensed water.

[0037] As already described, at least one of the aforementioned fluid lines is integrated into the ladder structure and / or the impact protection structure; preferably at least two of the described fluid lines. In particular, all of the aforementioned fluid lines can be integrated into the ladder structure and / or the impact protection structure.

[0038] 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 beam of the ladder structure. As already described, a longitudinal axis of a beam of a ladder structure, in the installed state of the ship landing device, runs at least substantially in a vertical direction. Furthermore, a beam is, in particular, a hollow cylinder or a similar hollow body. The elongated cavity of a beam can therefore be used particularly advantageously as a fluid line or for routing a line (fluid line and / or electrical line operable with a voltage of at least 1 kV) through said cavity.

[0039] Alternatively, preferably in addition to the at least one beam, the at least one conduit (fluid conduit and / or electrical conduit capable of operating at a voltage of at least 1 kV) can be integrated into at least one elongated impact body of the impact protection structure. As already described, a longitudinal axis of an elongated impact body of an impact protection structure, in the installed state of the ship landing device, runs at least substantially in a vertical direction. Furthermore, 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 particularly advantageously used as a fluid conduit or for routing a conduit (fluid conduit and / or electrical conduit capable of operating at a voltage of at least 1 kV) through said cavity.

[0040] According to a further embodiment of the ship landing device, the at least one electrical conductor can be integrated into the conductor structure and / or into the shock absorber protection structure. The at least one electrical conductor can, in particular, be 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 conductor can be a power cable and preferably be part of a medium-voltage or high-voltage network of an offshore hydrogen production system according to the invention.

[0041] Preferably, an additional electrical conductor in the form of a low-voltage cable can be integrated into the conductor structure and / or the impact protection structure. In other words, two separate first electrical power 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, in particular, between two offshore structures or between an offshore structure and an onshore structure by means of an electrical conductor.

[0042] Alternatively or additionally, at least one data line can be integrated into the conductor structure and / or into the impact 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.

[0043] Furthermore, according to another embodiment of the ship landing device according to the invention, at least one seawater reservoir can be integrated into the ladder structure and / or the impact protection structure. The seawater reservoir (also referred to as a caisson) can be formed directly by a (previously described) cavity or by a seawater pipe that can be inserted into such a cavity and, in particular, removed. A water storage tank can be provided in a simple manner, for example, for a cooling circuit and / or as a water storage tank for a water treatment plant. The warmer seawater pipe can be part of the cooling system by transferring heat to the colder ambient air and / or the colder surrounding seawater.

[0044] 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 beam (which can, in particular, form the seawater reservoir) of the ladder structure. The pump can be configured to draw in ambient water and, in particular, to pump the drawn-in ambient water towards the upper end region of the beam. 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 draw in ambient water and, in particular, to pump the drawn-in ambient water towards the upper end region of the elongated impact body. A water storage tank can be provided in a particularly simple manner, for example, for a cooling circuit and / or as a water storage tank for a water treatment plant.

[0045] Preferably, the at least one pump can be removed from the corresponding lower end area by means of a rope and / or wire and / or rod and / or shaft attached to the pump, for example for inspection and / or maintenance of the pump.

[0046] Furthermore, according to another 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 protection structure.

[0047] In particular, a plurality of anchoring points (eyelets) can be arranged on the ship landing device, especially on the ladder structure and / or the shock protection structure and / or a first connecting piece between the ladder structure and the shock protection structure or a second connecting piece between the shock protection structure or the ladder structure and the foundation. In other words, the ship landing device (also referred to as a boat landing) 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.

[0048] According to a further embodiment of the ship landing device according to the invention, the ship landing device may further comprise: - at least one additional elongated hollow body for accommodating at least one further fluid line and / or at least one electrical line, - wherein the additional elongated hollow body is attached to the ladder structure and / or to the impact protection structure.

[0049] In particular, if at least one more fluid line and / or at least one more electrical line needs to be installed than can be integrated into the conductor structure and / or the impact 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 attached to the conductor structure and / or the impact protection structure, for example, by bolting or welding. An additional elongated hollow body for accommodating at least one further fluid line includes, in particular, an additional elongated hollow body that forms the further fluid line.

[0050] 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 stile of the ladder structure can extend substantially to the underwater seabed. Alternatively or additionally, in an installed state of the ship landing device, a lower end of at least one elongated shock absorber of the shock absorber protection structure can extend substantially to the underwater seabed. In other words, compared to a conventional ladder structure and / or shock absorber protection structure, at least one of these structures can be extended in the vertical direction (although this is not necessary for the actual landing process).

[0051] By extending at least one spar (preferably at least two spars) and / or at least one elongated shock absorber (preferably at least two spars) to at least substantially the underwater seabed, a (safe) guide can be provided for the at least one conduit (preferably a plurality of fluid conduits and, in particular, the at least one electrical conduit) to the underwater seabed. While this extension requires additional material, the overall need for secondary steel or composite material is reduced. Furthermore, the overall shaft load can be lower than with a solution using separate external fluid conduits.

[0052] According to a further embodiment of the ship landing device according to the invention, the cross-sectional area of ​​the at least one beam can taper (continuously and / or in steps) from an upper end of the beam to the lower end. Alternatively or additionally, the cross-sectional area of ​​the at least one elongated impact body can taper (continuously and / or in steps) from an upper end of the elongated impact body to the lower end. This can, in particular, reduce the amount of material required to manufacture a beam and / or an elongated impact body.

[0053] According to a particularly preferred embodiment of the ship landing device according to the invention, the at least one beam can be formed from at least two telescopic beam elements. In variants of the invention, three or more telescopic beam 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 beam or a telescopic impact body can be formed, in particular, from two or more coaxially nested cylindrical or prismatic, and in some cases slightly conical, partial tubes. Other cross-sectional shapes are conceivable. Preferably, each of the inner telescopic elements (e.g., telescopic beam elements and / or telescopic impact body elements) can be extended axially from the next larger element that directly surrounds it.

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

[0056] In addition to providing watertightness at the 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 shock absorber elements relative to each other, thereby preventing movement caused by waves or currents. This can particularly prevent excessive wear. Furthermore, the sealed telescopic spar elements or telescopic shock absorber elements can also provide vertical support / fixation of the telescopic tube elements.

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

[0058] According to a further embodiment of the ship landing device according to the invention, at least one kink protection element can be arranged at the lower end of at least one stile of the ladder structure. Alternatively or additionally, at least one kink protection element can be arranged at the lower end of at least one elongated impact body of the impact protection structure. A kink protection element is, in particular, a cable guide designed to prevent bending of a fluid line or electrical cable beyond the permissible bending radius of the fluid line or electrical cable. The risk of damage to the fluid line or electrical cable can be reduced. In particular, a kink protection element can be provided if a stile or impact body extends substantially to the underwater bottom (in particular, the seabed).Preferably, a kink protection 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 pole or a telescopic locking body and tightened, for example, from a main working platform once all telescopic elements have been lowered into place and, in particular, secured.

[0059] 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. It has been found, in particular, that the cooling water used to cool a component of the offshore structure 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 line can reach a permissible temperature of preferably up to 105 °C (e.g., 95 °C), the heated cooling water has a maximum temperature of between approximately 50 °C and 60 °C.

[0060] For example, the return channel can be directly adjacent to the electrical conductor. For instance, the electrical conductor and the return channel can each be integrated as independent conductors (and, in particular, lying side by side) within the same beam or elongated impact body. The electrical conductor can also pass at least partially through the return channel. For example, an elongated cavity in a beam or the elongated cavity in an elongated impact body can be designed as a fluid channel, and the electrical conductor can be routed through this elongated cavity. The cooling water flows directly past the electrical conductor being cooled. Reliable and efficient operation of the electrical conductor, especially in geographically hot locations, can be ensured, particularly without the need for additional cooling.In some cases, a smaller cable cross-section may prove sufficient due to the cooling effect, which reduces the procurement costs of the cable and allows for easier installation.

[0061] Alternatively or additionally, a first fluid line and a second fluid line can be provided in the form of a return channel for a cooling circuit and, in particular, integrated into the ladder structure or the impact protection structure. The return channel can run alongside 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 be integrated into the same beam or the same elongated impact body, each as an independent line (and, in particular, lying side by side). For example, an elongated cavity in a beam or the elongated cavity in 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 frost protection, especially in geographical locations with low temperatures, can be provided.

[0062] As described, on its way back to the sea, the heated cooling water return can be routed through a return channel (e.g., a steel pipe) and thus serve, in particular, as frost protection for at least one other fluid line. Simultaneously, the warm cooling water flow can also serve as a cooling medium for at least one (even warmer) medium- or high-voltage cable, in order to prevent potential hotspots and / or allow for smaller cable diameters.

[0063] For extended shutdowns during winter, the above-ground portion of the water pipeline carrying the treated water can be emptied by injecting pressurized inert gas from the foundation platform, primarily to prevent freezing. Alternatively or additionally, a shut-off and venting valve and / or an electric heater can be used.

[0064] In the case of internal cooling of a foundation, the heat from the fluid line in the form of the return channel (e.g. steel pipe) can be directly connected to the foundation via the thermally conductive coupling of the fluid lines, acting as frost protection for the inside of the fluid lines.

[0065] A line and / or pipe and / or cable can be fastened with cable ties, heat shrink tubing, composite clamps (half shells), insert plates, hinged door, or similar.

[0066] Another aspect of the invention is a foundation set. The foundation set comprises at least one foundation for an offshore structure. The offshore structure comprises at least one hydrogen processing unit. The foundation set also includes at least one ship landing device, as previously described, which can be attached to the foundation. Furthermore, the foundation set can include at least one fluid line and / or at least one electrical line.

[0067] In its installed state, the foundation set (or 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 include, but are not limited to, micro-electrolysis plants, micro-water treatment plants, micro-nitrogen plants, micro-cooling water plants, micro-hydrogen processing plants (such as micro-hydrogen drying plants), and / or micro-hydrogen compression plants, and / or a central electrolysis plant, central water treatment plant, central nitrogen plant, central cooling water plant, central hydrogen processing plant (such as a central hydrogen drying plant), and / or a central hydrogen compression plant, and / or similar devices.It goes without saying that other equipment can be supported by the foundation, such as a wind turbine, a photovoltaic system, a transformer, etc.

[0068] As described, further processing of hydrogen can involve drying, compression, measurement and / or a chemical reaction (e.g. to NH3).

[0069] Examples of offshore structures, though not exhaustive, include offshore hydrogen production wind turbines and central offshore processing facilities.

[0070] The foundation can be a floating foundation (e.g., barge foundation, semi-submersible foundation, Spar foundation, and / or tension leg platform (TLP) foundation). Alternatively, the foundation can be a non-floating foundation (e.g., monopile, tripod, triplele, or jacket foundation).

[0071] The foundation may include at least one pre-installed eyelet (or the like), designed to receive and, in particular, guide the ship landing device, especially the ladder structure and / or the impact protection structure, along an outer wall of the foundation. The ship landing device may be inserted from above into the at least one pre-installed eyelet, or in particular, a plurality of eyelets. Optionally, the ship landing device may be secured or locked in place (e.g., by a screwable or weldable collar). A ship landing device can be easily mounted to a foundation.

[0072] Another 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 as previously described.

[0073] Another 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 1kV) within a conductor structure of the ship landing device and / or within a shock body protection structure of the ship landing device.

[0074] There are now numerous possibilities for designing and further developing the ship landing devices, the foundation set, the hydrogen production system, the method, and the use according to the invention. Reference is made, on the one hand, to the claims subordinate to the independent claims, and on the other hand, to the description of exemplary embodiments in conjunction with the drawing. The drawing shows: Fig. 1 a schematic view of an embodiment of an offshore hydrogen production system according to the present invention, Fig. 2 a schematic view of an embodiment of a ship landing device according to the present invention, Fig. 3a 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, Fig. 3b another schematic view of the embodiment according to Fig. 3a, Fig. 4 a schematic view of a further embodiment of a foundation set according to the present invention with a further embodiment of a ship landing device according to the present invention, and Fig. 5 a schematic view of a further 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] In the following, similar reference symbols are used for similar elements. Furthermore, z denotes a vertical direction or a vertical axis, and y a horizontal direction or a horizontal axis.

[0076] The Fig. 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 following has been changed in the Fig. 1 The at least one ship landing device according to the present invention is not explicitly shown. It is understood that at least one foundation 126, 128, preferably all foundations 126, 128, can be provided with a ship landing device.

[0077] The depicted 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.

[0078] Furthermore, each offshore hydrogen production wind turbine 102 can preferably be essentially identical. In particular, each offshore hydrogen production wind turbine 102 comprises a wind turbine 106 and, as a hydrogen processing device, a micro-electrolysis plant 104 or a micro-electrolysis module.

[0079] A wind turbine 106 can comprise a tower, a nacelle, a rotor, rotor blades, a generator, etc. A wind turbine 106 is specifically designed to generate electrical energy by converting the kinetic energy of the wind into electrical energy. The electrical energy generated by each wind turbine 106 is specifically supplied to the respective micro-electrolysis plant 104.

[0080] As can be seen, each micro-electrolysis plant 104 can be arranged on a respective foundation 126 of a respective offshore hydrogen production wind turbine 102. A micro-electrolysis plant 104 (e.g., a PEM electrolyzer with multiple stacks) is set up to produce or generate hydrogen.

[0081] In particular, the respective offshore hydrogen production wind turbines 102 in the present preferred embodiment do not have any processing plants that are implemented on the at least one central offshore processing structure 108 or a central offshore structure.

[0082] The depicted central offshore processing structure 108 includes, for example, a (central) water treatment plant 110 as a hydrogen processing device. The water treatment plant 110 is arranged on a foundation 128 of the central offshore processing structure 108. The water treatment plant 110 is specifically designed for processing water for hydrogen production by the micro-electrolysis plants 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 treated or processed water is then used for hydrogen production by the micro-electrolysis plants 104 of the offshore hydrogen production wind turbines 102.In particular, treated water is made available to all micro-electrolysis plants 104 for hydrogen production.

[0083] Preferably, as in the Fig. As shown in Figure 1, the water treatment plant 110 is composed of at least three micro water treatment plants 112 or three water treatment modules. The capacity of the at least three micro water treatment plants 112 can be designed such that two of the three micro water treatment plants 112 already have sufficient capacity to supply all micro electrolysis plants 104 with (sufficiently) treated water. In particular, at least one reserve micro water treatment plant 112 can be provided, which can (completely) compensate for the failure of another micro water treatment plant 112. In particular, a micro water treatment plant 112 can be integrated into a 20-foot container.

[0084] Optionally and preferably, the central processing structure 108 can include a (central) inert gas generation plant 114. For example, the inert gas generation plant 114 can generate nitrogen as the inert gas. The inert gas generation plant 114 can be arranged on the foundation 128. Preferably, the inert gas generation plant 114 can be integrated into a 20-foot container. In variants of the application, for redundancy reasons, at least two micro-inert gas generation plants can also be provided, with at least one reserve micro-inert gas generation plant.

[0085] Furthermore, the offshore hydrogen production system 100 can, for example, comprise a media network 118. The media network 118 can comprise at least one water supply network 120, for example formed by at least one fluid line in the form of a water line (e.g., a pipe, hose, or the like). As can be seen from the Fig. As can be seen in Figure 1, the medium 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 to at least the first central processing structure 108 via the medium network 118.

[0086] The treated water is conveyed 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 under pressure, for example.

[0087] The medium network 118 can, in particular, comprise an inert gas pipeline network 122, for example, formed by at least one inert gas pipeline (e.g., a pipe, hose, or the like). The generated inert gas can, in this case, be conveyed or pumped from the inert gas generation plant 114 via the inert gas pipeline network 122 to the respective micro-electrolysis plants 104. The generated inert gas can, for example, be conveyed under pressure.

[0088] Preferably, the interconnected network 118 can comprise an electrical power cable network 132 arranged between at least the majority 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. Preferably, electrical energy can be exchanged bidirectionally via the electrical power cable network 132. Preferably, the electrical power cable network 132 enables the central processing structure 108 to forgo its own power supply in the form of another wind turbine. In particular, the electrical installations 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 include a wind turbine.

[0089] Furthermore, the central processing structure 108 can include a substation 116, in particular in the form of at least one (electrical) transformer. Specifically, the substation 116 can form a grid connection point to an (not shown) onshore electrical grid, particularly via an (not shown) onshore substation of the offshore hydrogen production system 100. A second electrical power cable network 124 can be provided for exchanging 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 ramp up the wind turbines 106).

[0090] In variants of the invention, the depicted central offshore processing structure can include at least one further processing unit, such as a hydrogen processing unit. In this exemplary embodiment, this can also be installed decentrally as a separate micro-hydrogen processing unit on the offshore hydrogen production wind turbines. The produced hydrogen can, for example, be transported to suitable vessels and / or pipelines (e.g., made of steel) towards the coast.

[0091] Preferably, two central offshore processing structures can be provided, wherein on a first central offshore processing structure 108 only equipment is installed in which no explosive atmospheres can arise.

[0092] In a preferred embodiment, the offshore hydrogen production system comprises a further (not shown) central offshore processing structure with facilities where explosive atmospheres can occur. This further central offshore processing structure can include a hydrogen processing plant configured to process the (pre-dried) hydrogen produced by the micro-electrolysis plants.

[0093] For example, a pre-cooling module (or a corresponding chiller) in a micro-electrolysis plant (not shown) can cool the produced hydrogen down to approximately 3 to 5°C. On its way through a hydrogen pipeline network (not shown) to the central processing structure, essentially no further water condenses (therefore no risk of water hammer).

[0094] In particular, a hydrogen processing plant may include a hydrogen drying plant (TSA) equipped for drying the obtained (pre-dried) hydrogen, especially to -40°C. Furthermore, the hydrogen processing plant may include a hydrogen compression plant equipped for compressing the processed hydrogen, especially the hydrogen dried by the hydrogen drying plant.

[0095] Preferably, the hydrogen upgrading plant can be composed of at least three micro-water upgrading plants or three water upgrading modules. The capacity of the at least three micro-hydrogen upgrading plants can be designed such that any two of the three micro-hydrogen upgrading plants have sufficient capacity to process the hydrogen produced by all micro-electrolysis plants. In particular, at least one reserve micro-hydrogen upgrading plant can be provided, which (completely) compensates for the failure of another micro-hydrogen upgrading plant. Preferably, a micro-hydrogen upgrading plant can be integrated into a 20-foot container.

[0096] As further in the Fig. As 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 routed to the underwater seabed and along it (e.g., buried) to the next offshore structure. There, the line can ascend and the other end of the line can be connected to another fluid connection of the next offshore structure. A line can be buried, run along the underwater seabed, and / or suspended, for example, with additional anchor points such as floating PV systems or buoys. A line can be fixed to the underwater seabed at intervals (e.g., by localized embankments or concrete mats). A variant is also conceivable in which a line with positive buoyancy (possibly...) is used.(achieved by attaching suitable buoyancy bodies at the required intervals) and being kept suspended at a defined distance above the seabed by sufficiently heavy ballast bodies.

[0097] Reference numeral 130 refers in particular to ambient water or seawater.

[0098] The Fig. Figure 2 showed 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 attached to a foundation of an offshore structure of the offshore hydrogen production system according to Fig. 1 be arranged.

[0099] The ship landing device 250 comprises a ladder structure 252 and a shock-absorbing structure 254. The ladder structure 252 has, by way of example, two parallel stiles 238, 240, which extend vertically in the installed or fastened state. A plurality of rungs 242, extending parallel to each other, are arranged between the stiles 238, 240. The rungs 242 can, in particular, extend horizontally. The ladder structure 252 can be made of metal, in particular steel. One stile 238, 240 can, in particular, be formed as a hollow cylinder.

[0100] The impact protection structure 254 has, by way of example, two parallel elongated impact bodies 244, 246 which, in the installed or fastened state, extend in a vertical direction. An elongated impact body 244, 246 can, in particular, be formed as a hollow cylinder, for example made of steel. The ladder structure 252 and the impact protection structure 254 can be connected to each other, for example, by 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., water line for conveying treated water, cooling water line, hydrogen line, inert gas line, etc.) integrated in the ladder structure 252 and / or the shock absorber 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 integrated into the impact protection structure 254 such that it leads from a lower end region 260 of an elongated impact body 244 through the cavity of the elongated impact body 244 to an upper end region 262 of the elongated impact body 244. In particular, the fluid line enters the elongated impact body 244 at the lower end region 260 and exits at the upper end region 262, for example to a fluid connection (not shown). In embodiments of the invention, exiting the fluid line includes directly connecting the fluid line to a fluid connection (not shown). Furthermore, in embodiments of the invention, the fluid line can be formed at least partially through the cavity of the elongated impact body 244.

[0104] A second fluid line 258 is integrated into the ladder structure 252 such that it leads from a lower end region 264 of a spar 238 through the cavity of the spar 238 to an upper end region 266 of the spar 238. Specifically, the fluid line 258 enters the spar 238 at the lower end region 264 and exits at the upper end region 266, for example, to a fluid connection (not shown). In embodiments of the invention, exiting the fluid line includes directly connecting the fluid line to a fluid connection (not shown). Furthermore, in embodiments of the invention, the fluid line can be formed at least partially through the cavity of the spar 238.

[0105] The Fig. 3a and Fig. Figure 3b shows 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 are described below (especially with regard to the ship landing device 350). Fig. 2 described.

[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 on it (see, e.g., Fig. 1) may, for example, have at least one fluid connection (not shown) and / or at least one electrical connection (not shown). Furthermore, the foundation set 370 also includes 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 fixed state.

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

[0108] Furthermore, in the present embodiment, at least one electrical conductor 376, operable at a voltage of 1 kV, is integrated into the conductor structure 352, in particular into a spar 340. In variants of the invention, an electrical conductor can also be integrated into the impact protection structure. The at least one electrical conductor 376 is in particular a medium-voltage cable and / or a high-voltage cable. For example, the electrical conductor 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 protection structure.

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

[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 draw in ambient water (in particular seawater) and to pump the drawn-in ambient water towards the upper end region 362 of the elongated impact body 346, in particular to a fluid connection. In variants of the invention, a seawater reservoir can also be integrated into the ladder structure, with or without a pump.

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

[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.

[0113] A first fluid line 456 (e.g., a hydrogen line) can be integrated into a first spar 438 of the ladder structure 452, in particular being 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 being at least partially formed by the cavity of the spar 440.

[0114] In a first elongated impact body 446 of the impact protection structure 454, a seawater reservoir 474 (or a cooling water line, in particular in the form of a supply channel) can be integrated, especially formed by the cavity of the spar 438. A pump as previously described is not shown here. In the second elongated impact body 444 of the impact protection structure 454, 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. 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 supply and return channels can, in particular, be part of the same cooling circuit.

[0115] Optionally, the ship landing device 450 can further comprise at least one additional elongated hollow body 482, 488, for example, to accommodate at least one additional 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 can be attached to the ladder structure 452 and / or to the impact protection structure 454, for example, by bolting or welding.

[0116] Furthermore, the ship landing device 450 includes in particular a collar 486 (also referred to as a collar or cage), designed for attaching the ship landing device 450 to the foundation 426. In addition, the ship landing device 450 may in particular have a plurality of anchoring points 490 (e.g. in the form of eyelets).

[0117] The Fig. Figure 5 shows a schematic view of a further embodiment of a foundation set 670 according to the present invention, together with a further embodiment of a ship landing device 650 according to the present invention. To avoid repetition, only the differences from the previous embodiments are essentially described below. Fig. 2, Fig. 3, and Fig. 4 described.

[0118] The ship landing device 650 is shown here, by way of example, 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 shock protection structure 654 and / or the foundation 626.

[0119] As from the Fig. As can be seen in Figure 5, in the depicted installed state of the ship landing device 650, a lower end 697 of at least one beam 638 of the ladder structure 652 can extend substantially to the underwater bottom 695. Preferably, all beams 638 can extend substantially to the underwater bottom 695. In particular, 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 also extend substantially to the underwater bottom 695. Preferably, all elongated impact bodies 644 can extend substantially to the underwater bottom 695.

[0120] Preferably, the cross-sectional area of ​​the at least one spar 638 can taper from an upper end of the spar 638 to the lower end 697, for example in a stepped 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.

[0121] 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) within the first spar element 691. Fig. Figure 6 shows the installed state in which the second spar element 689 is extended from the first spar element 691.

[0122] The at least one elongated impact body 644 can be formed from at least two telescopic impact body elements 687, 685. In a pre-installation state of the elongated 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. Fig. Figure 6 shows the installed state in which the second shock element 685 is extended from the first shock element 687. This provides a simple and secure guide for at least one line 656, 676 down to the underwater bottom 695.

[0123] Optionally, at least one (not shown) kink protection element can be arranged at a lower end 697 of at least one spar 638 of the ladder structure 652, in particular to guide a line 676, such as an electrical line 676, to the underwater bottom 695 without the line 676 being bent in an impermissible manner.

[0124] Optionally, at least one (not shown) anti-kink element 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 bottom 695 without the line 656 being bent in an impermissible manner.

[0125] In particular, the lowest connecting piece or the lowest strut can serve doubly as an entry point and anchoring point for the buckling protection element. Reference symbol list: 100 Offshore Hydrogen Production Systems 102 Offshore hydrogen production wind turbines 104 Micro-electrolysis plant 106 Wind turbines 108 central processing structure 110 Water treatment plant 112 Micro water treatment plant 114 inert gas generation system 116 Substation 118 Medium network 120 Water supply network 122 Inert gas pipeline network 124 Energy cable network 126 Founding 128 Founding 130 Sea 132 Energy cable network 238 Holm 242 rungs 244 elongated impact body 248 Connecting piece 250 ship landing device 252 ladder structure 254 Impact protection structure 256 Fluid line 258 Fluid line 260 end range 262 End range 264 End range 266 End range 326 Founding 340 Holm 344 elongated impact body 346 elongated impact body 348 Connecting piece 350 ship landing device 352 ladder structure 354 Impact protection structure 356 Fluid line 360 end range 362 End range 370 Founding Kit 372 platform 374 Seawater reservoir 376 Line 378 Pump 426 Founding 438 Holm 440 Holm 442 rungs 444 elongated impact body 446 elongated impact body 448 Connecting piece 450 Ship landing device 452 ladder structure 454 Impact protection structure 456 Fluid line 458 Fluid line 470 Founding Kit 474 Seawater reservoir 476 electrical line 480 Fluid line 482 Hollow bodies 484 additional fluid lines 486 collars 488 additional fluid lines 490 Anchor point 492 electrical line 626 Founding 638 Holm 644 impact bodies 648 Connecting piece 650 Ship landing device 652 ladder structure 654 Impact protection structure 656 Fluid line 670 Founding Kit 676 electrical line 685 Shock body element 686 collars 687 Impact element 689 Holm element 691 Holm element 693 End 695 Underwater floor 697 End

Claims

[1] A ship landing device for an offshore structure, the offshore structure comprising in particular at least one hydrogen processing device, the ship landing device comprising: - at least one ladder structure, and - at least one impact body protection structure, characterized by 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 into the conductor structure and / or the impact body protection structure. [2] Ship landing device according to claim 1, characterized by , that - the at least one fluid line is a hydrogen line, configured to conduct hydrogen, in particular wet hydrogen. [3] Ship landing device according to claim 1 or 2, characterized by , 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 convey treated water, and / or - the at least one fluid line is a water line, designed to conduct ambient water, in particular to conduct sea water. [4] Ship landing device according to one of the preceding claims, characterized by , that - the at least one fluid line and / or the at least one electrical line is integrated in at least one spar of the conductor structure, and / or - the at least one fluid line and / or the at least one electrical line is integrated into at least one elongated impact body of the impact body protection structure. [5] Ship landing device according to one of the preceding claims, characterized by , that - at least one electrical cable is a medium-voltage cable and / or a high-voltage cable. [6] Ship landing device according to one of the preceding claims, characterized by , that - at least one seawater reservoir is integrated into the ladder structure and / or the impact body protection structure. [7] Ship landing device according to one of the preceding claims, characterized by , 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, configured to suck in ambient water and to pump the sucked in ambient water towards the upper end region of the elongated impact body. [8] Ship landing device according to one of the preceding claims, characterized by 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 ladder structure and / or to the impact body protection structure. [9] Ship landing device according to one of the preceding claims, characterized by , 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 bottom, and / or - 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 extends substantially to the underwater bottom. [10] Ship landing device according to claim 9, characterized by , 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 by , that - the at least one spar is formed from at least two telescopic spar elements, and / or - the at least one elongated impact body is formed from at least two telescopic impact body elements. [12] Ship landing device according to one of the preceding claims, characterized by , 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 elongated impact body of the impact body protection structure. [13] Ship landing device according to one of the preceding claims, characterized by , 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 in the form of a return channel are integrated in the conductor structure or the impact body protection structure, wherein the return channel is guided along at least the first fluid line for heating the first fluid line. [14] Founding set, including: - at least one foundation of an offshore structure, the offshore structure comprising at least one hydrogen processing device, characterized by that the start-up set also includes: - 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 by , 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] Offshore hydrogen production system comprising: - at least one offshore structure with at least one hydrogen production device and a ship landing device according to one of the preceding claims 1 to 13, which is 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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