Pipeline cable assembly

Abstract

A method and apparatus for simultaneous transmission of electrical power and delivery of at least one fluid, and a method of manufacturing a ducted power cable assembly, an offshore energy center, and a method of installing a ducted member and an elongate flexible element at desired locations are disclosed. The apparatus includes a conduit member including a fluid retaining liner defining an aperture of the conduit member; and at least one elongate flexible element, the at least one elongate flexible element comprising an outer sleeve and at least one conductive element disposed within the outer sleeve; wherein the elongate flexible element is wound on the outer surface along at least a portion of the conduit member.

Description

[0001] The present invention relates to a method and apparatus for conveying fluid and simultaneously transmitting power. In particular, but not exclusively, the present invention relates to a pipe-cable assembly comprising a fluid pipe and a cable wound around the pipe member. Optionally, the pipe-cable assembly is suitable for use onshore or offshore.

[0002] There is a demand for environmentally friendly and sustainable energy production. Therefore, renewable energy technologies are being implemented, wherever possible, to reduce pollution and other abnormal environmental side effects associated with energy production and to provide consumers with usable energy without depleting limited global resources (such as fossil fuels). In particular, offshore wind farms are becoming increasingly attractive due to the abundance of wind energy, the ability to build farms in remote areas, and the low environmental-related costs in operation.

[0003] An offshore wind farm comprises one or more wind turbines located at an offshore location. The energy produced by such wind turbines is now sometimes also used to produce hydrogen from water via electrolysis. Hydrogen is a valuable energy source and can be used in fuel cells or to power vehicles, etc. However, most conventional hydrogen generation methods are harmful to the environment. Therefore, it is desirable to produce so-called "green" hydrogen from offshore wind farms, thereby significantly reducing the environmental costs associated with hydrogen production.

[0004] After production, it is usually necessary to transport hydrogen to and from various locations of an offshore wind farm, or to first convert hydrogen into ammonia for transportation, and then transport it. Typically, pipelines arranged on the seabed can be used to transport hydrogen and / or other fluids in and around an offshore wind farm. However, it is well known that hydrogen causes embrittlement of metallic materials. Therefore, if used for hydrogen transmission, pipelines containing metals are prone to failure. Therefore, metal pipes are generally not used to transport hydrogen. Sometimes pipelines comprising composite materials are used instead.

[0005] However, some fluid transport pipelines that may include composite materials tend to have significant buoyancy, especially during hydrogen (or other gas) transport. Therefore, during use, the pipeline needs to be weighted and / or attached to the seafloor. In an offshore environment, this can be a time-consuming, complex, and potentially dangerous operation. In addition, attaching the pipeline to the seafloor can be costly and reduces the reusability of such pipelines.

[0006] In addition, it is often necessary to transmit electricity between different locations. These locations may be onshore and / or offshore locations. An example of an offshore location is an offshore wind farm. The electricity generated by the wind turbines needs to be transmitted from the wind turbines. Similarly, other components of the offshore wind farm (e.g., an electrolysis station for hydrogen generation) require electricity to operate, and therefore a mechanism for power transmission is required. This power transmission is usually achieved through submarine cables. However, independently laying submarine cables and fluid pipelines can be very time-consuming and lead to complex underwater configurations and architectures.

[0007] It is an object of the present invention to at least partially alleviate one or more of the above problems.

[0008] It is an object of certain embodiments of the present invention to provide a conduit cable assembly that can be installed as a single unit in a desired area.

[0009] It is an object of certain embodiments of the present invention to provide a pipe cable assembly for conveying fluids in offshore areas that are non-buoyant in use.

[0010] It is an object of certain embodiments of the present invention to provide a pipe-cable assembly including a low-cost composite reinforced fluid transmission pipe that is free of metallic materials.

[0011] It is an object of certain embodiments of the present invention to provide a pipe-cable assembly in which a subsea power cable is self-supporting on a fluid pipe and does not need to be secured to the fluid pipe by connectors or the like.

[0012] It is an object of certain embodiments of the present invention to provide apparatus for simultaneously conveying fluid and transmitting electrical power to and / or from at least one element of an energy center.

[0013] It is an object of certain embodiments of the present invention to provide a method for simultaneously conveying fluid and transmitting electrical power through a conduit-cable assembly.

[0014] It is an object of certain embodiments of the present invention to provide a method of manufacturing a conduit-cable assembly for simultaneously conveying fluids and transmitting electrical power.

[0015] According to a first aspect of the present invention, there is provided an apparatus for simultaneously transmitting electricity and conveying at least one fluid, the apparatus comprising: a conduit member comprising a fluid retaining liner defining a hole in the conduit member; and at least one elongated flexible element comprising an outer sleeve and at least one conductive element disposed within the outer sleeve; wherein the elongated flexible element is wrapped around an outer surface along at least a portion of the conduit member.

[0016] Suitably, the fluid retaining liner is a fluid retaining polymer liner.

[0017] Suitably, the duct member comprises a composite material.

[0018] Suitably, the circular radius of a first imaginary circle associated with the radially innermost surface of the outer sleeve of the wound elongate flexible element is substantially equal to the circular radius of another imaginary circle associated with the outer surface.

[0019] Suitably, the pitch between adjacent corresponding points of the wound elongate flexible element is in the range between two times the diameter of the cross-section of the outer surface and 50 times the diameter of the cross-section of the outer surface.

[0020] Suitably, the pitch between adjacent corresponding points of the wound elongate flexible element is in the range between two times the outer diameter of the conduit member and 50 times the outer diameter of the conduit member.

[0021] Suitably, the elongate flexible element is self-supporting on at least a portion of the conduit member, being wrapped around the outer surface, the elongate flexible element optionally being helically wrapped around the outer surface.

[0022] Suitably, the elongate flexible element is helically wrapped about the outer surface.

[0023] Suitably, the elongate flexible element has a non-circular cross-section, optionally substantially elliptical.

[0024] Suitably, the non-circular cross-section is substantially elliptical.

[0025] Suitably, the non-circular cross-section has an aspect ratio of no less than 1:2.

[0026] Suitably, the non-circular cross-section is stadium-shaped and comprises two substantially flat sides each connected by a curved side.

[0027] Suitably, the duct member comprises a composite material, optionally comprising a thermoplastic matrix and fibres of a non-metallic material.

[0028] Suitably, the weight of the elongate flexible element is equal to or greater than the buoyancy of the duct member when the duct member is filled with gas.

[0029] Suitably, the weight of the elongate flexible element is equal to or greater than the buoyancy of the duct member.

[0030] Suitably, the weight of the elongate flexible element is equal to or greater than the buoyancy of the conduit member when the transport fluid is disposed in the bore of the conduit member.

[0031] Suitably, in the stored configuration the duct member and the elongate flexible element wrapped around the outer surface are wound together on the spool and can be unwound as a common unit.

[0032] Suitably, the apparatus further comprises at least one armour layer disposed radially about the inner liner, the armour layer optionally comprising a composite material.

[0033] Suitably, the ducting member and the elongate flexible element wrapped around the outer surface are provided between two structures, optionally offshore structures.

[0034] Suitably, the conduit member comprises a permeation barrier.

[0035] According to a second aspect of the present invention, an offshore energy center is provided, which comprises: a pipeline component, which includes a fluid retaining liner that defines a hole in the pipeline component; and at least one slender flexible element, which includes an outer sleeve and at least one conductive element arranged in the outer sleeve; wherein the slender flexible element is wrapped around the outer surface along at least a portion of the pipeline component, and the slender flexible element is arranged between at least two of the following items: an energy generating element; an energy storage element; a fluid production element; a fluid storage element; and an unloading element.

[0036] Suitably, the duct member comprises a composite material.

[0037] Suitably, the circular radius of a first imaginary circle associated with the radially innermost surface of the outer sleeve of the wound elongate flexible element is substantially equal to the circular radius of another imaginary circle associated with the outer surface.

[0038] Suitably, the pitch between adjacent corresponding points of the wound elongate flexible element is in the range between two times the diameter of the cross-section of the outer surface and 50 times the diameter of the cross-section of the outer surface.

[0039] Suitably, the pitch between adjacent corresponding points of the wound elongate flexible element is in the range between two times the outer diameter of the conduit member and 50 times the outer diameter of the conduit member.

[0040] Suitably, the elongate flexible element is self-supporting on at least a portion of the conduit member, being wrapped around the outer surface, the elongate flexible element optionally being helically wrapped around the outer surface.

[0041] Suitably, the elongate flexible element is helically wrapped about the outer surface.

[0042] Suitably, the elongate flexible element has a non-circular cross-section, optionally substantially elliptical.

[0043] Suitably, the non-circular cross-section is substantially elliptical.

[0044] Suitably, the non-circular cross-section has an aspect ratio of no less than 1:2.

[0045] Suitably, the non-circular cross-section is stadium-shaped and comprises two substantially flat sides each connected by a curved side.

[0046] Suitably, the duct member comprises a composite material, optionally comprising a thermoplastic matrix and fibres of a non-metallic material.

[0047] Suitably, the weight of the elongate flexible element is equal to or greater than the buoyancy of the duct member when the duct member is filled with gas.

[0048] Suitably, the weight of the elongate flexible element is equal to or greater than the buoyancy of the duct member.

[0049] Suitably, the weight of the elongate flexible element is equal to or greater than the buoyancy of the conduit member when the transport fluid is disposed in the bore of the conduit member.

[0050] Suitably, in the stored configuration the duct member and the elongate flexible element wrapped around the outer surface are wound together on the spool and can be unwound as a common unit.

[0051] Suitably, the energy generating element comprises a wind turbine or a subsea turbine.

[0052] Suitably, the fluid production element comprises at least one electrolysis system for generating hydrogen and / or at least one compression system for liquefying hydrogen.

[0053] Suitably, the fluid storage element comprises a geological reservoir.

[0054] Suitably, the energy storage element comprises a battery.

[0055] Suitably, the energy generating element is an energy generating structure.

[0056] Suitably, the energy storage element is an energy storage system.

[0057] Suitably, the fluid production element is a fluid production structure.

[0058] Suitably, the fluid storage element is a fluid storage or unloading structure.

[0059] Suitably, the unloading element is a unloading structure.

[0060] Suitably, the apparatus further comprises at least one armour layer disposed radially about the inner liner, the armour layer optionally comprising a composite material.

[0061] Suitably, the ducting member and the elongate flexible element wrapped around the outer surface are provided between two structures, optionally offshore structures.

[0062] Suitably, the conduit member comprises a permeation barrier.

[0063] According to a third aspect of the invention, there is provided a method for installing a pipe member and an elongated flexible element at a desired location, the method comprising: unfolding a pipe member comprising a fluid retaining liner defining a hole in the pipe member; and at least one elongated flexible element comprising an outer sleeve and at least one conductive element disposed within the outer sleeve; wherein the elongated flexible element is wound around an outer surface along at least a portion of the pipe member, and wherein in a storage configuration, the pipe member and the elongated flexible element wound around the outer surface are wound together on a reel and are capable of being unfolded from the reel as a common unit at a desired location, which desired location is optionally an offshore location.

[0064] Suitably, the elongate flexible element is a power cable.

[0065] Suitably, the desired location is a desired area.

[0066] Suitably the offshore location is an offshore area.

[0067] Suitably, the desired location is an offshore location.

[0068] Suitably, the offshore location is one that is intended to serve as an energy center.

[0069] Suitably, the offshore location is an area intended to be a center of energy.

[0070] Suitably, the duct member comprises a composite material.

[0071] Suitably, the circular radius of a first imaginary circle associated with the radially innermost surface of the outer sleeve of the wound elongate flexible element is substantially equal to the circular radius of another imaginary circle associated with the outer surface.

[0072] Suitably, the pitch between adjacent corresponding points of the wound elongate flexible element is in the range between two times the diameter of the cross-section of the outer surface and 50 times the diameter of the cross-section of the outer surface.

[0073] Suitably, the pitch between adjacent corresponding points of the wound elongate flexible element is in the range between two times the outer diameter of the conduit member and 50 times the outer diameter of the conduit member.

[0074] Suitably, the elongate flexible element is self-supporting on at least a portion of the conduit member, being wrapped around the outer surface, the elongate flexible element optionally being helically wrapped around the outer surface.

[0075] Suitably, the elongate flexible element is helically wrapped about the outer surface.

[0076] Suitably, the elongate flexible element has a non-circular cross-section, optionally substantially elliptical.

[0077] Suitably, the non-circular cross-section is substantially elliptical.

[0078] Suitably, the non-circular cross-section has an aspect ratio of no less than 1:2.

[0079] Suitably, the non-circular cross-section is stadium-shaped and comprises two substantially flat sides each connected by a curved side.

[0080] Suitably, the duct member comprises a composite material, optionally comprising a thermoplastic matrix and fibres of a non-metallic material.

[0081] Suitably, the weight of the elongate flexible element is equal to or greater than the buoyancy of the duct member when the duct member is filled with gas.

[0082] Suitably, the weight of the elongate flexible element is equal to or greater than the buoyancy of the duct member.

[0083] Suitably, the weight of the elongate flexible element is equal to or greater than the buoyancy of the conduit member when the transport fluid is disposed in the bore of the conduit member.

[0084] Suitably, the apparatus further comprises at least one armour layer disposed radially about the inner liner, the armour layer optionally comprising a composite material.

[0085] Suitably, the ducting member and the elongate flexible element wrapped around the outer surface are provided between two structures, optionally offshore structures.

[0086] Suitably, the method further comprises laying the pipe member and the elongate flexible element wrapped around the outer surface along a region of the sea floor between the two offshore structures.

[0087] Suitably, the conduit member comprises a permeation barrier.

[0088] According to a fourth aspect of the present invention, a method for simultaneously transmitting power and conveying at least one fluid is provided, the method comprising: providing at least one fluid at a first position of a hole defined by a fluid-retaining inner lining of a pipe member; providing power via at least one conductive element disposed within an outer sleeve of an elongated flexible element, the elongated flexible element being wrapped around an outer surface of the pipe member along at least a portion of the pipe member; and conveying the fluid from a first position in a first direction along the hole of the pipe member to a second position spaced apart from the first position along the hole of the pipe member; and providing power through the conductive element at least partially during or throughout the fluid conveyance.

[0089] Suitably, the duct member comprises a composite material.

[0090] Suitably, the method further comprises providing electrical power in a transfer direction opposite to or aligned with the direction of fluid delivery.

[0091] Suitably, the fluid comprises hydrogen.

[0092] Suitably, the fluid comprises ammonia or CO2, or a fluid solution in which CO2 is dissolved or captured.

[0093] Suitably, the method further comprises conveying fluid from the first structure to the other structure via the aperture and simultaneously transmitting electricity from the first structure to the other structure or from the other structure to the first structure via the conductive element, the first structure and the other structure each optionally being a respective offshore structure.

[0094] According to a fifth aspect of the present invention, there is provided a method of manufacturing a conduit power cable assembly, the method comprising: providing a conduit member comprising a fluid retaining inner lining defining a bore of the conduit member; providing an elongated flexible element comprising an outer sleeve and at least one electrical conductor element arranged within the outer sleeve; and wrapping the elongated flexible element around an outer surface along at least a portion of the conduit member.

[0095] Suitably, the duct member comprises a composite material.

[0096] Suitably, the method further comprises, after winding the elongate flexible element onto the outer surface, simultaneously winding the tubing member together with the elongate flexible element wrapped onto the outer surface of the tubing member onto the storage reel member.

[0097] Certain embodiments of the present invention provide a conduit cable assembly that can be installed as a common unit at a desired location.

[0098] Certain embodiments of the present invention provide devices that facilitate the simultaneous transport of fluids and transmission of electrical power.

[0099] Certain embodiments of the present invention provide a method for simultaneously conveying fluid and transmitting power through a pipe-cable assembly. Optionally, the power and fluid can be transmitted in the same or opposite directions.

[0100] Certain embodiments of the present invention reduce the need to compensate for buoyancy of fluid pipelines installed in offshore areas.

[0101] Certain embodiments of the present invention provide a method of simultaneously delivering fluid and transmitting electrical power to and / or from at least one element of an energy center.

[0102] Certain embodiments of the present invention provide a method of self-supporting an elongated flexible element on a conduit member without the need for connecting elements or the like.

[0103] Certain embodiments of the present invention provide a transportable hybrid piping system comprising a subsea power cable and a fluid piping wound together on a reel.

[0104] Embodiments of the present invention will now be described hereinafter, by way of example only, with reference to the accompanying drawings, in which:

[0105] Figure 1 A hybrid piping system located at an offshore energy center is shown;

[0106] Figure 2 shows a perspective view of a hybrid duct cable system;

[0107] Figure 3 The fluid conduits are shown in greater detail;

[0108] Figure 4 The submarine cable is shown in more detail;

[0109] Figure 5 shows a cross-sectional view of an alternative submarine cable;

[0110] Figure 6 A cross-sectional view of a pipe cable assembly is shown;

[0111] Figure 7 A hybrid conduit cable system arranged in a storage configuration is shown; and

[0112] Figure 8 An installation of a hybrid piping system at an offshore area is shown.

[0113] In the drawings, like reference numerals refer to like parts.

[0114] Figure 1 A first hybrid piping system 102 is shown disposed between two structures in an offshore area 104. It should be appreciated that the hybrid piping system 102 is an example of a pipe-cable assembly. It should be appreciated that the offshore area 104 is an example of an offshore environment. Figure 1 The offshore area 104 is an offshore wind farm and includes a plurality of offshore structures 106, 108, 110, 112 arranged on the seabed 114. These structures 106, 108, 110, 112 are partially or completely immersed in seawater. It should be understood that the offshore wind farm (i.e., an example of the offshore area 104) is an example of an energy center. It should also be understood that the structures 106, 108, 110, 112 are examples of energy center elements. It should also be understood that the hybrid piping system 102 can be connected between structures that are not part of the energy center instead.

[0115] It should be understood that the hybrid piping system 102 can be used in an onshore environment or to connect an onshore location to an offshore location. It should be understood that the hybrid piping system 102 can be used in an onshore energy center instead. It should also be understood that the hybrid piping system 102 can be connected between structures that are not part of an energy center instead.

[0116] Figure 1 The offshore energy center includes two offshore wind turbines 106. It should be understood that a single wind turbine 106 may be used instead. Alternatively, it should be understood that more than two wind turbines 106 may be used. Wind turbines 106 are examples of energy generating elements. Alternatively, different energy generating elements may be utilized. For example, a subsea turbine, tidal energy, or wave energy generation system may be used instead.

[0117] The offshore wind turbines 106 each include a monopile 116 and a tower 118 mounted on top of the monopile 116. The monopile 116 is at least partially submerged in the seawater and extends into the seabed 114. Thus, each monopile 116 anchors the corresponding offshore wind turbine 106 to the seabed 114 and serves as a base for the tower 118. A turbine 120 is attached to the top of the tower 118. The rotor 122 of the turbine attachment 120 is attached to three turbine blades 124. Any other suitable number of turbine blades 124 may be used as appropriate. In use, the wind provides a force on the turbine blades 124 that rotates the rotor 122. The rotor is connected to a generator, which is turned by the rotating rotor 122 and generates electricity. It should be understood that the force can be measured in Newtons and can be obtained by measuring the wind speed, which can be measured using an anemometer. It should also be understood that the wind turbine can be of a floating type rather than being fixed directly to the seabed.

[0118] Figure 1 The offshore wind farm also includes two power storage structures 108. It should be understood that the power storage structures 108 are examples of energy storage elements. Figure 1 The power storage structure 108 includes a battery to store the energy generated by the offshore wind turbine 106 as chemical potential energy. Other energy storage devices, such as capacitors, flywheels, etc., may be used as appropriate.

[0119] Figure 1The offshore wind farm shown also includes an electrolysis structure 110. It should be understood that, optionally, the electrolysis structure is not included. The electrolysis structure 110 is an example of a fluid production element. For example, an alternative fluid production element may include an ammonia production system. The electrolysis structure 110 produces hydrogen from water by electrolysis. Therefore, the electrolysis structure 110 uses direct current to decompose water into oxygen and hydrogen by introducing an anode and a cathode into a certain volume of water, and then pumps the hydrogen into a gas storage structure 112, or converts it into ammonia for subsequent storage in, for example, a gas storage structure.

[0120] Figure 1 The offshore wind farm also includes a gas storage structure 112. It should be understood that the gas storage structure 112 is an example of a fluid storage element. Figure 1 The gas storage structure 112 is a reservoir into which the produced hydrogen can be transported for storage. Figure 1 The gas storage structure 112 is a reservoir for storing hydrogen or ammonia, from which hydrogen or ammonia can be supplied to other structures 106, 108, 110 of the offshore wind farm, or transported from the offshore wind farm to other energy systems, such as onshore energy systems, or offshore fuel delivery systems for transportation. Suitably, the gas storage structure 112 is a natural reservoir, such as a cavity in the seabed.

[0121] Figure 1 The offshore wind farm also includes a gas input / output element 126. It should be understood that the gas input / output element 126 is convenient for introducing hydrogen or ammonia or O2 into the Figure 1 The invention relates to an offshore wind farm or an installation removed therefrom. Other suitable fluids may be used as appropriate.

[0122] Where appropriate, various other suitable structures may be used instead. Figure 1 offshore wind farms. It should be understood that Figure 1 Any of the structures 106, 108, 110, 112 of the offshore wind farm may include a pumping system to facilitate gas transfer between the structures 106, 108, 110, 112 of the offshore wind farm (or transfer out of the offshore wind farm). For example, the electrolysis structure 110 may include a pumping system. Alternatively, the offshore wind farm may include a pumping structure that may be a pumping station. Suitably, Figure 1 Any of the structures 106, 108, 110, 112 of the offshore wind farm may include a compression system for liquefying the produced hydrogen, or a system for producing liquid ammonia, or a system for combining the CO2 with a solvent medium to prepare the CO2 for storage or sequestration in a reservoir. For example, Figure 1The electrolysis structure 110 may include a compression system. Alternatively, the offshore wind farm may include a compression system, which may be a compression station. Alternatively, the offshore wind farm may include or be connected to a refueling station for transport to provide hydrogen or ammonia to ships to power, for example, their electrical systems and / or their propulsion systems. Alternatively or in addition, the offshore wind farm may include or be connected to an unloading station for transport to be able to discharge, for example, CO2, or a fluid solution in which CO2 is dissolved or trapped.

[0123] Figure 1 The first hybrid piping system 102 is arranged on the seabed 114 of the offshore area 104 where the offshore wind farm is located. The first hybrid piping system 102 is therefore immersed in seawater. It should be understood that the first hybrid piping system 102 is an example of a pipe cable assembly, which is a pipe power cable assembly. Figure 1 As shown, the first hybrid piping system 102 is connected between the electrolysis structure 110 and the gas storage structure 112. Therefore, the first hybrid piping system facilitates the transportation of the produced hydrogen to the storage, and the transportation of the stored hydrogen to other structures of the offshore wind farm. It should be understood that the first hybrid piping system 102 can be connected to the electrolysis structure 110 and the gas storage structure 112 instead. Figure 1 between any suitable structures of an offshore wind farm. Figure 1 Also shown is a second mixing conduit system 128 connected between the electrolysis structure 110 and the gas output / input element. Thus, the second mixing conduit system 126 facilitates the transport of hydrogen to and from the offshore wind farm.

[0124] Figure 2 A perspective view of a hybrid duct system 200 is shown. Figure 2 The hybrid piping system can be used with Figure 1 The first hybrid piping system 102 and the other hybrid piping system 128 are substantially the same. The hybrid piping system 200 includes a fluid pipeline 205 and a submarine cable 210. It should be understood that the fluid pipeline 205 is an example of a pipeline component. It should be understood that the submarine cable 210 is an example of a slender flexible element. It should be understood that the submarine cable 210 can be changed to a different type of cable, such as a cable suitable for an onshore environment. It should be understood that the submarine cable 210 can be an umbilical cable including a plurality of cables and / or a control cable system. Suitably, the cable 210 can be an umbilical cable including any other suitable element and / or system.

[0125] like Figure 2As shown, the submarine cable 210 is wound around the outer surface 215 of the fluid pipe 205. The wound submarine cable 210 extends along the length 220 of the fluid pipe 205. Suitably, the submarine cable 210 may extend along only a portion of the length 220 of the fluid pipe 202. It should be understood that the length 220 of the fluid pipe refers to the extension of the fluid pipe 205 along the major axis 222 of the fluid pipe 205. The submarine cable 210 wound around the outer surface 215 of the fluid pipe 205 is self-supporting on the fluid pipe 205. That is, the submarine cable 210 is basically tightly wound around the fluid pipe 205, so that the submarine cable 210 is effectively attached to the fluid pipe 215 without any additional attachment elements. Of course, one or two (or more) additional attachment elements or fixing elements may be included as required. It should be understood that the length 220 may be measured in meters and may be measured using a tape measure.

[0126] The submarine cable 210 comprises an outer casing 230 covering the submarine cable and providing an outer surface 232 of the submarine cable 210. Suitably, the outer casing comprises a polymer material. Suitably, the outer casing is watertight. Suitably, the cable comprises an armoring element, such as an armoring wire. Suitably, the cable comprises a conductive element, such as a copper wire or an aluminum wire. The submarine cable 210 is tightly wound on the outer surface 215 such that a radius 230 of a first imaginary circle 235 defined by a radially innermost surface 240 of the wound submarine cable 210 (that is, the first imaginary circle 235 is a two-dimensional representation of the winding of the wound submarine cable 210, which is equal in size to the radially innermost surface 240 of the winding) is substantially the same as a radius 245 of another imaginary circle 250 defined by the outer surface 215 of the fluid conduit. That is, the wound submarine cable tightly hugs the outer surface of the fluid conduit.

[0127] It should be understood that the first virtual circle 235 and the further virtual circle 250 are circles that do not exist physically but are used to represent the innermost radial dimension of the wound submarine power cable 210 and the outermost radial dimension of the outer surface 215 of the fluid conduit 205 , respectively.

[0128] It should be appreciated that the radii 230, 245 may be measured in meters and may be measured using a tape measure.

[0129] It should be understood that the radially innermost surface 240 of the wound submarine cable 210 is the surface arranged inside the winding when the submarine cable 210 is wound around the outer surface 215 of the fluid pipe 205, that is, the physical limit of the outside of the cable 210, and is therefore the part of the submarine cable closest to the fluid pipe 205.

[0130] like Figure 2As shown, the submarine cable 210 is wound on the outer surface 215 of the fluid pipe 205 such that the windings of the submarine cable 210 have a defined pitch 260. It should be understood that the pitch of the wound submarine cable 210 is the distance between two corresponding points on adjacent windings of the wound submarine cable 210. Suitably, the pitch of the wound submarine cable 210 is in the range between two and fifty times the outer diameter 265 of the fluid pipe 205, which is the diameter 265 of the outer surface 215 of the fluid pipe 205. It should be understood that the outer diameter 265 of the fluid pipe is the diameter of another imaginary circle 272 of a size equal to the outer surface 215 of the fluid pipe 205. The spacing of the cable assembly along the pipe may be constant, or may be larger or smaller in desired areas.

[0131] like Figure 2 As shown in the hybrid piping system 200, the submarine cable 210 is wound on the outer surface 215 of the fluid pipe 205 in a substantially spiral arrangement. That is, the winding of the submarine cable 210 around the fluid pipe 205 defines a substantially spiral shape. Suitably, the submarine cable 210 may be wound unevenly so that the winding does not have a spiral shape. Suitably, the submarine cable 210 may be loosely wound on the outer surface of the fluid pipe 205.

[0132] It will be appreciated that the fluid conduit 205 is configured to transport a fluid during use. That is, the fluid conduit 205 is a conduit through which a fluid can pass. It will be appreciated that transporting a fluid includes moving a fluid from a first location to another location. Thus, Figure 2 The hybrid piping system 200 facilitates the flow of fluid from a first end of the hybrid piping system 200 to another end of the hybrid piping system 200. It should be understood that in use and when connected between at least two elements of an energy center such as an offshore wind farm, the hybrid piping facilitates the transport of fluid between the two energy center elements.

[0133] The fluid configured to be transported via the fluid conduit 205 is optionally a gas. The gas is optionally hydrogen. Alternatively, it will be appreciated that the fluid conduit 205 can be configured to transport different gases, such as carbon dioxide, oxygen, helium, methane, etc. Alternatively, the fluid conduit can be configured to transport liquids. Suitably, the liquid is liquid hydrogen. Optionally, the fluid conduit 205 can be configured to transport different liquids, such as liquid ammonia. Optionally, the liquid is a fluid solution in which CO2 is dissolved or trapped. Liquid hydrogen can be produced by compressing hydrogen produced by electrolysis at an offshore wind farm. Optionally, the fluid conduit can be configured to transport any other suitable fluid, such as a liquid. It is also possible to transport a gas or a liquid or a combination of a gas and a liquid.

[0134] It should be understood that in use, the fluid conduit 205 will have an associated buoyancy. For example, when disposed in an offshore environment where the fluid conduit 205 may be on the seafloor, the fluid conduit 205 may be buoyant. In particular, when a fluid such as a gas is present in the fluid conduit 205, the fluid conduit may be buoyant. The submarine cable 210 includes one or more heavy elements, such as wires, etc. The submarine cable 210 may include one or more wires, which are power conductors. The submarine cable 210 may also include one or more reinforcing wires. Such wires are optionally metal elements. That is, the wires may include metal materials such as copper, steel, or aluminum. The submarine cable 210 has an associated weight. When a fluid is present in the fluid conduit 205, the weight of the submarine cable 210 is greater than the buoyancy of the fluid conduit 205. Therefore, when the fluid is located in the fluid conduit 205, the submarine cable 210 acts as a counterweight and offsets the buoyancy of the fluid conduit 205. Therefore, the weight of the submarine cable 210 prevents the fluid conduit 205 from floating during use and allows the hybrid conduit system 200 to remain stable on the sea floor during use. Therefore, no additional weight is required to counteract the buoyancy of the fluid conduit 205 when used in an offshore environment.

[0135] It will be appreciated that the buoyancy of a given volume of fluid conduit 205 may be measured in Newtons and may be obtained by measuring the density of the ambient fluid (eg, seawater), which may be measured using a hydrometer.

[0136] It should be understood that the weight of the submarine cable 210 may be measured in Newtons and may be measured by weighing.

[0137] It should be understood that the fluid conduit 205 of the hybrid conduit system 200 used in an offshore wind farm is connected to at least one element of the offshore wind farm. These elements may be Figure 1 Any of the structures 106, 108, 110, 112 shown. Suitably, the offshore wind farm may include any other suitable element that may be an offshore structure. The fluid conduit 205 may be connected between two or more elements of the offshore wind farm. As previously described, the hybrid piping system 200 facilitates the transport of fluids from and / or to the elements of the offshore wind farm via the fluid conduit 205. For example, the hybrid piping system may facilitate the transport of fluids from a fluid production element to a fluid storage element, the fluid production element may be an electrolysis structure 110, and the fluid storage element may be a gas reservoir 112. It should be understood that the fluid production element may include one electrolysis system or multiple electrolysis systems for hydrogen production. For example, the fluid storage element may be a natural reservoir or an artificial storage unit. Suitably, the reservoir may be a geological reservoir, such as a cavity under the seabed 114. It should be understood that the fluid production element and / or the fluid storage element may include one or more compression systems, such as for the liquefaction of hydrogen.

[0138] It should be understood that the submarine cable 210 used in the offshore wind farm is connected to at least one element of the offshore wind farm. The submarine cable 210 can be connected between two or more elements of the offshore wind farm. The submarine cable 210 can be connected to one or more of the same elements of the offshore wind farm as the fluid pipeline 205. Alternatively, the submarine cable 210 can be connected to different elements of the offshore wind farm, or connected between different elements of the offshore wind farm, instead of the fluid pipeline 205. It should be understood that the submarine cable 210 is conducive to transmitting electricity to and / or from the elements of the offshore wind farm. For example, the submarine cable 210 can be conducive to transmitting electricity from an energy generating element (e.g., at least one wind turbine) to an energy storage element (e.g., at least one battery). Suitably, the submarine cable 210 can provide the power required for operation of various elements of the offshore wind farm. For example, the submarine cable 210 can provide the energy required for electrolysis to the fluid production element to generate hydrogen from water. Similarly, a subsea cable may provide the necessary power to a pump to transport fluid from a first location of an offshore wind farm to another location of an offshore wind farm via fluid conduit 205 .

[0139] It will be appreciated that power transmission involves providing an electric current through an electrical conductor due to a potential difference between a voltage at a first circuit location and a voltage at a second circuit location. Power transmission from a power source to a power receiving element occurs via one or more power conductors of the submarine cable 210. It will be appreciated that the power conductors of the submarine power cable are examples of conductive elements.

[0140] The hybrid piping system 200 allows for simultaneous transmission of power via the submarine cable 210 and delivery of fluid via the fluid pipeline. That is, fluid can be delivered while power is being delivered via the hybrid piping system 200. Thus, the hybrid piping system 200 facilitates simultaneous delivery of fluid via the fluid pipeline 205 and delivery of power via the submarine cable 210. It should be understood that the transmission of power via the submarine cable 210 may only partially occur while fluid is being delivered via the fluid pipeline 205. Alternatively, the transmission of power via the submarine cable 210 may occur continuously while fluid is being delivered via the fluid pipeline 205. That is, power may be delivered during the entire time period during which the delivery of fluid occurs, or power may be delivered intermittently and, therefore, only partially delivered during the entire time period during which the delivery of fluid occurs.

[0141] It should be understood that power can be transmitted in the same or opposite direction as the direction in which fluid is transported through the hybrid piping system 200. That is, the net / average direction of power transmission through the submarine cable 210 can be the same or opposite to the direction of fluid transport through the fluid pipeline 205. It should be understood that the direction of fluid transport through the fluid pipeline 205 will be a direction parallel to the pipeline axis 222. It should be understood that power is transmitted through the submarine cable 210 through the windings of the submarine cable 210 that are wrapped around the fluid pipeline 205. Therefore, the instantaneous transmission of power through the submarine cable 210 through the windings will be at an oblique angle to the axis 222 of the hybrid piping system 200. However, it should be understood that the net direction of power transmission through the submarine cable 210, i.e., the power transmission direction, will be along the pipeline axis 222, and therefore will be the same or opposite to the direction of fluid transport through the fluid pipeline 205.

[0142] Figure 3 The fluid conduit 300 is shown in greater detail. It should be appreciated that Figure 3 The fluid conduit 300 can be connected with Figure 2 The fluid conduit 200 shown is the same. Figure 1 and Figure 2 As discussed, fluid conduit 300 is an example of a conduit component. Figure 3 The fluid conduit 300 shown is generally cylindrical. That is, Figure 3 The fluid conduit 300 is generally tubular. The fluid conduit has a length 310 extending along a main axis 320 of the fluid conduit 300. Figure 3 As shown, the fluid conduit 300 includes a fluid retaining liner 330 that defines a hole 340 of the fluid conduit 300. That is, the fluid retaining liner 330 surrounds an internal cavity, which is the hole 340 of the fluid conduit 300. It should be understood that the hole 340 of the fluid conduit receives the fluid in use during fluid transport. Suitably, the fluid comprises a gas. Suitably, the fluid comprises hydrogen. Suitably, the fluid comprises ammonia. Suitably, the fluid comprises carbon dioxide. Suitably, the fluid is a fluid solution in which CO2 is dissolved or trapped. Suitably, the fluid comprises a liquid. The fluid moves through the hole 340 of the fluid conduit during transport.

[0143] The fluid retaining liner 330 is generally cylindrical. That is, the fluid retaining liner 330 is generally tubular. The fluid retaining liner 330 is substantially impermeable to the fluid intended to be transported through the holes 340 of the fluid conduit 300. Therefore, the fluid retaining liner 330 substantially prevents the fluid from leaking from the holes 340 of the fluid conduit 300 to the surrounding environment. Suitably, the fluid retaining layer 330 comprises a polymer material. Suitably, the fluid retaining liner 330 comprises a composite material. Suitably, the fluid retaining liner 330 comprises a thermoplastic composite material. Examples of suitable polymer materials include polyolefins, polyamides, polyketones, fluoropolymers (such as PVDF, PEEK or PEKK) or TV resins. Suitably, the fluid retaining liner 330 is reinforced with non-metallic fibers. Examples of suitable non-metallic fibers include glass, basalt, carbon and stretched polymers. Optionally, a permeation barrier layer may be included outside the fluid retaining liner. The permeation barrier layer may include a film or foil of a low permeability material, such as aluminum or a metallized polymer tape.

[0144] Figure 3 The fluid conduit of the invention comprises an outer layer 350. Suitably, the outer layer 350 comprises a polymer material. Suitably, the outer layer 350 comprises a composite material. Suitably, the fluid outer layer comprises a thermoplastic composite material. Suitably, the outer layer 350 is reinforced with non-metallic fibers. Figure 3 The outer layer 350 is a reinforcing layer of the tubular structure supporting the fluid conduit 300. Suitably, the fluid conduit 300 includes only a single layer, namely the fluid retaining liner 330, which is optionally reinforced with non-metallic fibers for structural stability. Optionally, the fluid conduit 300 may include more than two layers. For example, the fluid conduit 300 may include one or more armor layers radially arranged around the fluid retaining liner 330. The armor layer may be made of a composite material. Suitably, the armor layer may be made of a metallic material. The armor layer may include a tensile armor layer and / or a pressure armor layer. The armor layer may include a plurality of interlocking spirally wound tapes. The armor layer may alternatively include at least one spirally wound non-interlocking tape. The fluid conduit 300 may also include a skeleton layer arranged in a hole of the fluid conduit. The skeleton layer may include a spirally wound tape with interlocking adjacent windings. The multilayer fluid conduit 300 may optionally include an impermeable outer sheath. Suitably, the fluid conduit includes more than two concentrically arranged composite material layers. Suitably, the submarine cable 400 may include electrical insulation material disposed between the power conductors 410 to help isolate each power conductor.

[0145] Fluid conduit 300 may be made of a variety of suitable materials depending on the fluid to be transported. Figure 3 The fluid conduit is a hydrogen transport fluid conduit 300, and the hydrogen transport fluid conduit includes a composite material and / or a non-metallic material. Figure 3The fluid conduit 300 will not become embrittled during use due to exposure to hydrogen. For example, a fluid conduit 300 configured to transport other gases such as carbon dioxide may instead include a metal layer for structural support.

[0146] Figure 4 The submarine cable 400 is shown in more detail. Figure 4 The submarine cable 400 includes three power conductors 410. It should be understood that the power conductors 410 are examples of conductive elements. Figure 4 The power conductor 410 is made of copper. Alternatively, the power conductor may be made of any other suitable conductive material. Suitably, the power conductor comprises a conductive metal material. It should be understood that the power conductor 410 extends from a first terminal of the submarine cable 400 to the remaining terminal of the submarine cable 400, and is used to transmit power from the first terminal of the submarine cable 400 to the other end of the submarine cable 400, or vice versa. The submarine cable 400 also includes a plurality of reinforcing wires 420. The reinforcing wires 420 protect the power conductor 410 from damage when the submarine power cable 400 is bent or wrapped around another object such as a fluid pipeline. Figure 4 The submarine power cable 400 includes 24 reinforcing wires 420. Alternatively, the submarine power cable 400 may include any other suitable number of reinforcing wires 420. Figure 4 As shown, the reinforcing wires 420 are radially arranged in an elliptical ring around the power conductor 410 . Figure 4 The submarine cable 400 includes a reinforcement wire 420 forming two elliptical loops. Figure 3 The reinforcing wire 420 is made of steel. Suitably, the reinforcing wire 420 is made of any other suitable metal material. Suitably, the reinforcing wire 420 is made of an alloy material. Suitably, the reinforcing wire 420 is made of a non-metallic material (e.g., a composite material) instead. Figure 4 As shown, the reinforcing wire 420 is twisted relative to the long axis 430 of the submarine cable 400, which extends through the length 440 of the submarine cable 400. That is, the inner ring 440 of the reinforcing wire 420 is spirally wound on the power conductor 410. The outer ring 450 of the reinforcing wire 420 is wound around the inner ring 440 of the reinforcing wire 420 and is spirally wound relative to the long axis 430 of the submarine cable 400.

[0147] The submarine power cable also includes an outer casing 460. It should be understood that the outer casing 460 is substantially watertight. Therefore, the outer casing 460 is used to prevent water from leaking into the submarine cable 400, which may damage the internal components of the cable 400. For example, when deployed in an offshore environment, seawater may cause corrosion of the reinforcement wire 420 and / or the power conductor 410. Figure 4The outer sleeve 460 is made of a polymer material. Appropriately, the outer sleeve 460 can be made of a thermoplastic material. The outer sleeve 460 radially surrounds the reinforcing wire 420 and the power conductor 410. That is, the reinforcing wire 420 and the power conductor 410 are arranged in the outer sleeve 460.

[0148] Figure 5 A cross-sectional view of an alternative submarine cable 500 is shown. Figure 5 The submarine cable 500 includes two power conductors 510 . Figure 5 The submarine cable also includes 28 reinforcing wires 520. The reinforcing wires 520 are arranged in two elliptical rings radially surrounding the power conductor 510. The outer sleeve 530 radially surrounds the outer ring 540 of the reinforcing wires 520. Figure 5 As shown, the cross-section of the submarine cable 500 is substantially elliptical. That is, the horizontal axis 550 of the cross-section of the submarine cable 500 is longer than the vertical axis 560 of the submarine cable 500 (e.g., Figure 5 500). The submarine power cable 500 thus has a substantially non-circular cross-section. The cross-section of the submarine cable 500 includes two relatively long curved edges 565, 570 (each having a relatively large radius of curvature), each of which is adjacent to two relatively short curved edges 575, 580 (each having a relatively small radius of curvature). It should be understood that in use, when the submarine cable 500 is wound on the fluid pipe, the elliptical cross-section of the submarine cable 500 increases the contact area between the submarine cable 500 and the outer surface of the fluid pipe. It should be understood that this is because the longer edge 570 of the elliptical cross-section of the submarine cable 500 contacts the outer surface of the fluid pipe. Therefore, the elliptical cross-section of the submarine cable 500 facilitates the submarine cable 500 to be wound on the outer surface of the fluid pipe. The increased contact area between the outer sleeve 530 of the submarine cable 500 and the outer surface of the fluid pipe also helps to self-support the submarine cable 500 on the fluid pipe by increasing the friction between the submarine cable 500 and the fluid pipe. It should be understood that the friction can be measured in Newtons.

[0149] The oval cross-section of the submarine cable 500 also allows for the inclusion of Figure 5 The hybrid conduit assembly of the submarine cable 500 lies flush on the seabed in use, wherein the submarine cable is wound on the outer surface of the fluid conduit. The oval cross section of the submarine cable 500 wound on the outer surface of the fluid conduit provides a slightly flat surface for the hybrid conduit assembly to contact the seabed, namely one of the long curved edges of the cross section 565 of the cable 500. That is, when the submarine cable 500 is wound on the fluid conduit, the substantially flat surface is provided by the radial outer edge of the oval cross section of the submarine cable 500, which includes the long curved edge of the cross section 565 of the cable 500.

[0150] Suitably, the cross-section of the submarine cable 500 may be any other suitable shape. Optionally, the cross-section of the submarine cable 500 is substantially circular. Optionally, the cross-section of the submarine cable 500 is stadium-shaped. That is, the cross-section of the submarine cable 500 may have two substantially flat edges arranged parallel to each other, each flat edge being adjoined by a curved edge.

[0151] Figure 6 A cross-sectional view of a hybrid piping system 600 is shown. Figure 6 The hybrid piping system can be basically similar to Figure 2 Hybrid piping system. Figure 6 It is shown how the hole 610 of the fluid conduit 620 of the hybrid conduit system 600 is surrounded by an inner liner 630. The inner liner 630 has a substantially circular cross-section. Therefore, the cross-section of the hole 610 is substantially circular. Figure 6 The fluid conduit 620 has four further composite material layers 635, 640, 645, 650. Each of these layers 635, 640, 645, 650 has a circular cross-section. The layers 635, 640, 645, 650 are arranged radially concentrically relative to each other. That is, each of the layers 635, 640, 645, 650 has a different cross-sectional radius, with the layers of smaller cross-sectional radius arranged within the layers of larger cross-sectional radius. Suitably, the composite layers 635, 640, 645, 650 comprise thermoplastic composite materials. Suitably, the composite layers 635, 640, 645, 650 are reinforced with non-metallic fibers.

[0152] Figure 6 It is also shown how the hybrid piping system 600 further includes a submarine cable 660 tightly wound on the outer surface 665 of the fluid pipe 620. The cable 660 is tightly wound so that the radius 670 (i.e., the circle radius) of the imaginary circle 675 provided by the radially innermost surface of the windings of the outer sleeve 680 of the submarine cable 660 is substantially the same as the radius 685 (i.e., the circle radius) of the imaginary circle 690 provided by the outer surface 695 of the cross section of the fluid pipe 620. Since the cable 660 is wound on the fluid pipe 620, the submarine cable 660 is thus self-supporting on the fluid pipe 620.

[0153] Figure 7 A hybrid tubing system 700 is shown arranged in a storage configuration 710. It should be understood that the hybrid tubing system is a tubing cable assembly. Figure 7As shown, in the storage configuration 710, the hybrid tubing system 700 is wound on a reel 720. That is, the fluid tubing 730 is wound on the reel 720 together with the submarine cable 740 wound on the outer surface 750 of the fluid tubing 730. It should be understood that the reel 720 is an example of a storage reel element.

[0154] It should be understood that Figure 7 The fluid conduit 730 is a flexible fluid conduit and can therefore be wound around the reel 720. However, it should be understood that an alternative hybrid conduit system 700 may not include a flexible fluid conduit, and the alternative hybrid conduit system is not configured to be arranged in the storage configuration 710 in which the hybrid conduit system 700 is wound around the reel 720. For example, the fluid conduit in this alternative hybrid conduit system may instead be rigid.

[0155] It should be understood that Figure 7 The hybrid piping system 700 can be wound into the storage configuration 710 around the storage reel 720 when manufactured for storage. Alternatively, the hybrid piping system 700 can be wound into the storage configuration 710 around the reel 720 after manufacturing, or even after the hybrid piping system 700 is used. For example, the hybrid piping system 700 can be removed from a first use area (which can be, for example, an offshore energy center) and can be transported to another use area (which can be, for example, a different offshore energy center). Alternatively, the hybrid piping system 700 can be stored in the storage configuration 710 after manufacturing or after initial (or subsequent) use of the hybrid piping system 700.

[0156] It should be understood that the hybrid piping system 700 arranged in the storage configuration 710 can be conveniently transported to the desired area. The desired area can be an area where the hybrid piping system 700 will be used and / or installed in an energy center. For example, this can be an offshore energy center. The hybrid piping system 700 can therefore be intended to be connected to at least one element of this offshore energy center. The hybrid piping system 700 can be intended to be connected between two or more elements of the offshore energy center. It should be understood that once at the desired area, the hybrid piping system 700 can be deployed for installation. That is, the fluid pipeline 730 of the hybrid piping system 700 and the submarine cable 740 wound on the outer surface 750 of the fluid pipeline 730 can be deployed as a common unit. That is, the hybrid piping system 700 can be deployed as a single entity. Therefore, during the installation of the hybrid piping system 700, after the fluid pipeline 730 is installed at the desired area, the submarine cable 740 does not need to be independently connected to the fluid pipeline 730. In particular, the submarine cable 740 does not need to be connected to the fluid pipeline 730 that is set in the offshore environment and can be immersed in water.

[0157] It should be understood that the interwinding of the two elements of the hybrid piping system can be performed offshore during delivery and installation. In this way, the fluid pipe 730 and the submarine cable 740 can be provided on reels separately, and then during installation, when the pipe is wound from the storage reel 720, a separate cable reel can be circulated around the fluid pipe to basically spirally wind the submarine cable 740 around the fluid pipe 730.

[0158] Figure 8 The deployment and installation of the hybrid piping system 800 at an offshore wind farm 810 is shown, which is an offshore area. The offshore wind farm 810 (i.e., the offshore area) is an example of an offshore energy center, which is an example of a desired area. It should be understood that the hybrid piping system can be deployed and installed at any other suitable desired area.

[0159] The offshore wind farm 810 includes an offshore wind turbine 815. The offshore wind turbine 815 includes a monopile 820 extending into the sea floor 822. The monopile is partially submerged in sea water 824. The offshore wind turbine 815 also includes three turbine blades 824 and a rotor 826 connected to a turbine head 827. The turbine head 827 is mounted on a tower 828 of the wind turbine 815.

[0160] The offshore wind farm 810 also includes an electrolysis structure 830 for producing "green" (environmentally friendly) hydrogen using electricity generated by the offshore wind turbines 815. The electrolysis structure 830 is an example of a fluid production element. Also included in the offshore wind farm 810 is a gas storage structure 835. It should be understood that the gas storage structure 835 is an example of a fluid storage element. The gas storage structure is configured to store hydrogen produced at the electrolysis structure 830.

[0161] It should be understood that both the electrolysis structure 830 and the gas storage structure 835 require electricity to operate. For example, operating the pumps for gas delivery, operating the valves for gas storage, and producing hydrogen from water via electrolysis, etc., as well as all examples of operations that require electricity. Similarly, the hydrogen produced at the electrolysis structure 830 must be transported to the gas storage structure 835 for storage. Therefore, Figure 8 A hybrid piping system 800 is shown installed between the electrolysis structure 830 and the gas storage structure 835 for simultaneously transporting fluids between the electrolysis structure 830 and the gas storage structure 835 (in Figure 8 of hydrogen) and transmit electricity.

[0162] The hybrid piping system 800 includes a fluid conduit 840 and a subsea power cable 845 wound on an outer surface 850 of the fluid conduit 840. It should be appreciated that the fluid conduit 840 facilitates hydrogen transport between the electrolysis structure 830 and the gas storage structure 835. It should be appreciated that the subsea power cable facilitates power transmission between the electrolysis structure 830 and the gas storage structure 835. Optionally, power generated by the offshore wind turbine 815 is initially transmitted to the electrolysis structure 830 (via a suitable cable, etc.) and subsequently transmitted to the gas storage structure 835 via the subsea power cable 845.

[0163] Storage reel 852 is arranged on ship 854, which is a boat. Ship 854 is an example of a deployment element. It should be understood that hybrid tubing system 800 is initially loaded onto ship 854 in a storage configuration in which the hybrid tubing system is wound on reel 852. Figure 8 The storage configuration of the hybrid pipeline system 800 is similar to Figure 7 Storage configuration shown.

[0164] Figure 8 The hybrid piping system 800 is shown partially unrolled from a storage reel 852. The first terminal 856 of the hybrid piping system 800 is connected to the electrolysis structure 830. It should be understood that the first terminal of the subsea power cable 845 will be connected to a suitable electrical connector of the electrolysis structure 830. It should be understood that the first terminal of the fluid conduit 840 will be connected to a suitable conduit terminal connector of the electrolysis structure 830.

[0165] When the hybrid piping system 800 is deployed at the offshore wind farm 810, the hybrid piping system is unrolled from the reel 852 as a single unit. That is, the fluid pipeline 840 and the submarine cable 845 wound on the outer surface 850 of the fluid pipeline 840 can be unrolled from the reel together as a common unit. The submarine cable 845 and the fluid pipeline 840 do not need to be deployed independently. The hybrid piping system 800 is deployed to be laid across the seabed 822. That is, the hybrid piping system 800 is deployed so that the hybrid piping system 800 is submerged and extends along the area of ​​the seabed 822 located between the electrolysis structure 830 and the gas storage structure 835. Optionally, the hybrid piping structure 800 is deployed so that it extends below the seabed 822.

[0166] It will be appreciated that once the hybrid piping system 800 is unwound from the reel 852, the remaining terminals of the hybrid piping system are connected to the gas storage structure 835. It will be appreciated that the remaining terminals of the subsea power cable 845 will be connected to suitable electrical connectors of the gas storage structure 835. It will be appreciated that the remaining terminals of the fluid piping 840 will be connected to suitable piping terminal connectors of the gas storage structure 835.

[0167] Throughout the detailed description and claims of this specification, the words "comprise" and "contain" and their variations mean "including but not limited to", and they are not intended to (and do not) exclude other parts, additives, components, integral bodies or steps. Throughout the detailed description and claims of this specification, the singular encompasses the plural unless the context requires otherwise. In particular, where the indefinite article is used, the specification should be understood as contemplating plural as well as singularity unless the context requires otherwise.

[0168] Features, integers, features or groups described in conjunction with a particular aspect, embodiment or example of the invention are to be understood to be applicable to any other aspect, embodiment or example described herein unless incompatible therewith. All features disclosed in this specification (including any appended claims, abstract and drawings) and / or all steps of any method or process so disclosed may be combined in any combination, except that at least some of the features and / or steps are mutually exclusive combinations. The invention is not limited to any details of any of the foregoing embodiments. The invention extends to any novel feature or novel combination of features disclosed in this specification (including any appended claims, abstract and drawings), or to any novel step or novel combination of steps of any method or process so disclosed.

[0169] The reader's attention is directed to all papers and documents filed in connection with this patent application concurrently with or before this specification and which disclose public inspection of the present specification, and the contents of all these papers and documents are incorporated herein by reference.

Claims

1. A device for simultaneously transmitting power and conveying at least one fluid, the device comprising: a pipe member including a fluid retaining liner defining a bore of the pipe member; and at least one elongated flexible member, the at least one elongated flexible member comprising an outer sleeve and at least one conductive member disposed within the outer sleeve; in The elongated flexible element is wrapped around an outer surface along at least a portion of the conduit member.

2. The apparatus according to claim 1, wherein: A first imaginary circle associated with a radially innermost surface of the outer sleeve around which the elongated flexible element is wrapped has a circle radius substantially equal to a circle radius of another imaginary circle associated with the outer surface.

3. The apparatus according to claim 1 or claim 2, wherein: The pitch between adjacent corresponding points of the wound elongated flexible element is in the range between twice the diameter of the cross-section of the outer surface and 50 times the diameter of the cross-section of the outer surface.

4. Apparatus according to any preceding claim, wherein: The elongate flexible element wrapped around the outer surface is self-supporting on at least a portion of the conduit member, the elongate flexible element optionally being helically wrapped around the outer surface.

5. Apparatus according to any preceding claim, wherein: The elongated flexible element has a non-circular cross-section, which is optionally substantially elliptical.

6. Apparatus according to any preceding claim, wherein: The duct member comprises a composite material optionally including a thermoplastic matrix and fibers of a non-metallic material.

7. Apparatus according to any preceding claim, wherein: When the conduit member is filled with gas, the weight of the elongated flexible element is equal to or greater than the buoyancy of the conduit member.

8. Apparatus according to any preceding claim, wherein: In the stored configuration, the tubing member and the elongated flexible element wrapped around the outer surface are wound together on a reel and can be unwound as a common unit.

9. An offshore energy center, comprising: The device according to any one of claims 1 to 9, wherein the device is arranged between at least two of the following items: Energy generating elements; Energy storage components; Fluid production elements; Fluid storage elements; and Uninstall the component.

10. The offshore energy center according to claim 9, wherein: The energy generating element comprises a wind turbine or a subsea turbine.

11. An offshore energy center according to claim 9 or claim 10, wherein: The fluid production elements comprise at least one electrolysis system for generating hydrogen and / or at least one compression system for liquefying hydrogen.

12. An offshore energy center according to any one of claims 9 to 11, wherein: The fluid storage element includes a geological reservoir.

13. An offshore energy center according to any one of claims 9 to 12, wherein: The energy storage element comprises a battery.

14. A method of installing a duct member and an elongated flexible element at a desired location, the method comprising: The apparatus according to claim 10 is unrolled from the reel at a desired location, optionally an offshore location.

15. A method for simultaneously transmitting power and conveying at least one fluid, the method comprising: providing at least one fluid at a first location of a bore defined by a fluid retaining interior liner of a pipe member; providing electrical power via at least one conductive element disposed within an outer sleeve of an elongated flexible element wrapped around an outer surface of the conduit member along at least a portion of the conduit member; as well as conveying the fluid in a first direction from the first location along the aperture of the conduit member to a second location spaced from the first location along the aperture of the conduit member; as well as Power is provided through the conductive element at least partially during or throughout the fluid delivery.

16. The method according to claim 15, further comprising: Power is provided in a transmission direction opposite to or aligned with the direction of fluid delivery.

17. The method according to claim 15 or 16, wherein: The fluid includes hydrogen.

18. The method according to any one of claims 15 to 17, further comprising: The fluid is transported from a first structure to another structure via the holes and simultaneously power is transmitted from the first structure to another structure or from the other structure to the first structure via the conductive element, the first structure and the other structure each optionally being a respective offshore structure.

19. A method of manufacturing a conduit power cable assembly, the method comprising: providing a duct member including a fluid retaining inner liner defining a bore of the duct member; providing an elongated flexible element comprising an outer sleeve and at least one electrical conductor element disposed within the outer sleeve; as well as The elongated flexible element is wrapped around the outer surface along at least a portion of the conduit member.

20. The method according to claim 19, further comprising: After the elongated flexible element is wound on the outer surface, the tube member is simultaneously wound together with the elongated flexible element wound on the outer surface of the tube member on a storage reel element.

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