Apparatus for transferring fluids to and / or from a vessel and method for using same

Abstract

A fluid transfer device and a method for using the same. In some embodiments, the device can include a mooring structure, a fluid swivel disposed on the mooring structure, and first and second subsea conduits configured to provide fluid communication between first and second pipelines and the first and second flow paths defined by the swivels, respectively. The device can also include first and second offshore conduits capable of providing fluid communication between a vessel storage tank and the first and second flow paths defined by the swivels, respectively. The device can also include a crossover conduit configured to provide fluid communication between (i) the first and second offshore conduits, (ii) the first and second subsea conduits, or (iii) between the first subsea conduit and an optional third pipeline. The device can transfer a fluid having a boiling point below ambient temperature at atmospheric pressure to or from the storage tank.

Description

[Technical Field]

[0001] CROSS-REFERENCE TO RELATED APPLICATIONS This application claims priority to U.S. Provisional Patent Application No. 63 / 391,151, filed July 21, 2022, which is incorporated herein by reference.

[0002] The described embodiments relate generally to an apparatus for transferring fluid to and / or from a vessel and methods for using the same. More particularly, such embodiments relate to a fluid transfer apparatus located or fixed at an offshore location, where the apparatus may be configured to moor a vessel thereto and transfer fluid to and / or from the vessel. [Background technology]

[0003] In the offshore renewable industry, it is becoming increasingly necessary or desirable to moor vessels and transfer fluids to and / or from vessels. Certain equipment, such as cryogenic transfer equipment, is available, including equipment for transferring liquefied natural gas (LNG). However, these equipment operate at very low temperatures and require specialized materials that can be very expensive.

[0004] Therefore, there is a need for improved devices for transferring fluids to and / or from vessels and methods for using the same. Summary of the Invention

[0005] An apparatus for transferring fluid to and / or from a vessel and a method for using the same are presented. In some embodiments, the fluid transfer apparatus can include a mooring structure, a fluid swivel, a first subsea conduit, a second subsea conduit, a first offshore conduit, a second offshore conduit, and a crossing conduit. The mooring structure can be configured to be disposed within a body of water. The mooring structure can include a fixed portion rotatably coupled to a rotating portion. The fluid swivel can be configured to be disposed on the mooring structure. The fluid swivel can include a fixed portion rotatably coupled to the rotating portion. The fixed and rotating portions of the fluid swivel can define first and second fluid flow paths therethrough, which can be isolated from one another. The fixed portion of the fluid swivel can be coupled to the fixed portion of the mooring structure. The first subsea conduit can be configured to provide fluid communication between a first pipeline disposed on the seabed and the first fluid flow path defined by the fluid swivel. The second subsea conduit can be configured to provide fluid communication between a second pipeline located on the seabed and a second fluid flow path defined by the fluid swivel. The first offshore conduit can be configured to fluidly connect a fluid storage tank located on the vessel and the first fluid flow path defined by the fluid swivel. The first offshore conduit can include a valve. The second offshore conduit can be configured to fluidly connect the fluid storage tank and the second fluid flow path defined by the fluid swivel. The second offshore conduit can include a valve. The crossover conduit can include a crossover valve. The crossover conduit can be configured to provide fluid communication (i) between the first offshore conduit and the second offshore conduit, (ii) between the first subsea conduit and the second subsea conduit, or (iii) between the first subsea conduit and any third pipeline located on the seabed. The fixed portion of the fluid swivel and the rotating portion of the fluid swivel can be configured to maintain fluid communication between the first subsea conduit and the first offshore conduit via a first fluid flow path, and the fixed portion of the fluid swivel and the rotating portion of the fluid swivel can be configured to maintain fluid communication between the second subsea conduit and the second offshore conduit via a second fluid flow path.In some embodiments, the device can be configured to transfer a fluid having a boiling point below ambient temperature at atmospheric pressure to or from a fluid storage tank.

[0006] In other embodiments, the fluid transfer device can include a mooring structure, a fluid swivel, a subsea conduit, an offshore conduit, and a crossover conduit. The mooring structure can be configured to be disposed within a body of water. The mooring structure can include a fixed portion rotatably coupled to a rotating portion. The fluid swivel can be configured to be disposed on the mooring structure. The fluid swivel can include a fixed portion rotatably coupled to the rotating portion. The fixed and rotating portions of the fluid swivel can define a fluid flow path therethrough. The fixed portion of the fluid swivel can be coupled to a fixed portion of the mooring structure. The subsea conduit can be configured to provide fluid communication between a first pipeline disposed on the seabed and the fluid flow path defined by the fixed and rotating portions of the fluid swivel. The offshore conduit can be configured to fluidly connect a fluid storage tank disposed on the vessel to the fluid flow path defined by the fixed and rotating portions of the fluid swivel. The offshore conduit can include a valve. The crossover conduit can include a crossover valve. The crossover conduit can be configured to provide fluid communication between the subsea conduit and a second pipeline located on the seabed. The fixed portion of the fluid swivel and the rotating portion of the fluid swivel can be configured to maintain fluid communication between the subsea conduit and the offshore conduit. In some embodiments, the apparatus can be configured to transfer a fluid having a boiling point below ambient temperature at atmospheric pressure to or from a fluid storage tank.

[0007] In some embodiments, a method for transferring fluids can include mooring a vessel to a mooring structure disposed in a body of water. The mooring structure can include a fluid swivel, a first subsea conduit, a second subsea conduit, a first offshore conduit, a second offshore conduit, and a cross conduit. The fluid swivel can be disposed on the mooring structure. The fluid swivel can include a fixed portion rotatably coupled to a rotating portion. The fixed and rotating portions of the fluid swivel can define first and second fluid flow paths therethrough, which can be isolated from one another. The first subsea conduit can be in fluid communication with a first pipeline disposed on the seabed and a first fluid path defined by the fluid swivel. The second subsea conduit can be in fluid communication with a second pipeline disposed on the seabed and a second fluid flow path defined by the fluid swivel. The first offshore conduit can be in fluid communication with the first fluid flow path defined by the fluid swivel. The first marine conduit can be configured to fluidly connect to a fluid storage tank disposed on the vessel. The first marine conduit can include a valve. The second marine conduit can be in fluid communication with a second fluid flow path defined by a fluid swivel. The second marine conduit can be configured to fluidly connect to the fluid storage tank. The second marine conduit can include a valve. The crossover conduit can include a crossover valve. The crossover conduit can be in fluid communication with the first marine conduit and the second marine conduit. The fixed portion of the fluid swivel can be coupled to a mooring structure. The fixed portion of the fluid swivel and the rotating portion of the fluid swivel can maintain fluid communication between the first subsea conduit and the first marine conduit via the first fluid flow path. The fixed portion of the fluid swivel and the rotating portion of the fluid swivel can maintain fluid communication between the second subsea conduit and the second marine conduit via the second fluid flow path. The method may also include connecting the first offshore conduit to a fluid storage tank disposed on the vessel. The method may also include closing a valve on the first offshore conduit. The method may also include opening a crossover valve.The method may also include flowing a fluid from the first subsea pipeline through the first subsea conduit, the first fluid flow path defined by the fluid swivel, at least a portion of the first offshore conduit, the crossover conduit, at least a portion of the second offshore conduit, the second fluid flow path defined by the fluid swivel, and the second subsea conduit to the second subsea pipeline. In some embodiments, the fluid may have a boiling point below ambient temperature at atmospheric pressure. The method may also include closing the crossover valve. The method may also include opening the valve of the first offshore conduit. The method may also include flowing the fluid from the first subsea pipeline through the first subsea conduit, through the first fluid flow path defined by the fluid swivel, through the first offshore conduit, and to a fluid storage tank disposed on the vessel. The method may also include closing the valve of the first offshore conduit. The method may also include opening the crossover valve.

[0008] Various aspects and advantages of preferred embodiments of the present invention will become apparent to those skilled in the art upon understanding the following detailed description of the invention, when read in light of the accompanying drawings, which form a part hereof. [Brief explanation of the drawings]

[0009] [Figure 1] FIG. 1 illustrates a flow diagram of an exemplary apparatus for transferring fluid to and / or from a fluid storage tank located on a marine vessel, the apparatus including a fluid swivel defining at least two fluid flow paths therethrough, and at least two offshore conduits that can be placed in fluid communication with one another via a crossover conduit, according to one or more embodiments described. [Figure 2] FIG. 1 illustrates a flow diagram of another exemplary apparatus for transferring fluid to and / or from a fluid storage tank located on a marine vessel, including a fluid swivel defining a fluid flow path therethrough, and a marine conduit, according to one or more embodiments described. [Figure 3]FIG. 1 illustrates a flow diagram of another exemplary apparatus for transferring fluid to and / or from a fluid storage tank located on a vessel, including a fluid swivel defining at least two fluid flow paths therethrough, at least two offshore conduits, and an optional subsea pipeline end manifold, according to one or more embodiments described. [Figure 4] 1 illustrates a flow diagram of another exemplary apparatus for transferring fluid to and / or from a fluid storage tank disposed on a vessel, the apparatus including a fluid swivel, at least two offshore conduits, and at least two subsea conduits defining at least two fluid flow paths therethrough, according to one or more embodiments described, wherein the offshore conduits and / or the subsea conduits may be disposed in fluid communication with one another via one or more intersecting conduits. [Figure 5] FIG. 1 illustrates a flow diagram of another exemplary apparatus for transferring fluid to and / or from a fluid storage tank located on a vessel, the apparatus including a fluid swivel defining at least two flow paths therethrough, at least two offshore conduits, and a dedicated recirculating subsea pipeline line, according to one or more embodiments described. [Figure 6] FIG. 1 illustrates an elevation view of an exemplary fluid transfer apparatus including a catenary anchor leg mooring buoy configured to transfer fluid to and / or from a fluid storage tank located on a vessel moored to the buoy, according to one or more embodiments described. [Figure 7] 7 illustrates a plan view of the exemplary fluid transfer device and vessel shown in FIG. 6. [Figure 8] FIG. 1 illustrates a detailed plan view of an exemplary catenary anchor leg mooring buoy configured to moor a vessel thereto and transfer fluid to and / or from a fluid storage tank located on the vessel, according to one or more embodiments described. [Figure 9] FIG. 9 shows an elevation view of the catenary anchor leg mooring buoy shown in FIG. [Figure 10]FIG. 1 illustrates a plan view of an exemplary pipeline end manifold including a crossover conduit that can be configured to fluidly connect a first subsea pipeline and a second subsea pipeline located on the seabed, according to one or more embodiments described. [Figure 11] FIG. 1 illustrates a plan view of another example pipeline end manifold that can be configured to connect to a first subsea pipeline, a second subsea pipeline, and a third subsea pipeline located on the seabed, according to one or more embodiments described. [Figure 12] FIG. 1 illustrates an elevation view of an exemplary fluid transfer apparatus including a marine loading tower configured to transfer fluid to and / or from a fluid storage tank that may be located on a vessel that may be moored to the fluid transfer apparatus, according to one or more embodiments described. [Figure 13] 13 shows a plan view of the fluid transfer device shown in FIG. 12. [Figure 14] 14 shows an enlarged partial plan view of the fluid transfer device shown in FIGS. 12 and 13. FIG. DETAILED DESCRIPTION OF THE INVENTION

[0010] The following detailed description is provided. Each of the appended claims defines a separate invention, which for infringement purposes is recognized as including equivalents to the various elements or limitations specified in the claim. Depending on the context, all references to the "invention" may, in some cases, refer only to certain specific or preferred embodiments. In other cases, references to the "invention" may refer to the subject matter recited in one or more (but not necessarily all) of the claims. It should be understood that the following disclosure describes several exemplary embodiments for implementing various features, structures, or functions of the present invention. Below, exemplary embodiments of components, arrangements, and configurations are described to simplify the disclosure. However, these exemplary embodiments are presented by way of example only and are not intended to limit the scope of the present invention. Furthermore, the present disclosure may repeat reference numerals and / or characters in various exemplary embodiments and among the figures presented herein. This repetition is for the purposes of brevity and clarity and does not, in itself, affect the relationship between the various exemplary embodiments and / or configurations described in the figures. Furthermore, in the following description, the formation of a first feature relative to or based on a second feature includes embodiments in which the first feature and the second feature are formed in a direct connection, and also includes embodiments in which an additional feature is formed interposed between the first feature and the second feature such that the first feature and the second feature are not directly connected. The exemplary embodiments presented below may be combined in any combination, i.e., any element from one exemplary embodiment may be used in any other exemplary embodiment without departing from the scope of the present disclosure. The figures are not necessarily drawn to scale, and certain features and certain views of the figures may be shown exaggerated or schematic in scale for clarity and / or conciseness.

[0011] Furthermore, certain terms are used throughout the following description and claims to refer to particular components. As will be appreciated by those skilled in the art, various entities may refer to the same component by different names, and as such, the naming conventions for components described herein are not intended to limit the scope of the present invention, unless specifically defined otherwise herein. Furthermore, the naming conventions used herein are not intended to distinguish between components that differ in name but not function. Furthermore, in the following description and claims, the terms "including" and "comprising" are used in an open-ended manner and should therefore be interpreted to mean "including but not limited to."

[0012] All numerical values in this disclosure are either exactly that value or approximately ("about") unless specifically stated otherwise. Thus, various embodiments of the present disclosure can deviate from the numbers, values, and ranges disclosed herein without departing from the intended purpose.

[0013] Furthermore, the word "or" is intended to encompass both the exclusive and inclusive cases, i.e., "A or B" is intended to be synonymous with "at least one of A and B," unless expressly specified otherwise herein. The indefinite articles "a" and "an" refer to both singular (i.e., "one") and plural referents (i.e., one or more), unless the context clearly dictates otherwise. Because the device and methods of using it may be equally effective at various angles or orientations, the words "up" and "down," "upward" and "downward," "upper" and "lower," "upwardly" and "downwardly," "above" and "below," and other similar words used herein refer to relative positions with respect to each other and are not intended to indicate a specific spatial direction.

[0014] FIG. 1 illustrates a flow diagram of an exemplary apparatus 100 for transferring fluid to and / or from a fluid storage tank 165 located on a vessel 160, according to one or more embodiments. The apparatus 100 may include a fluid swivel 120 that may define at least two fluid flow paths therethrough (two shown, 123, 124), and at least two offshore conduits (two shown, 131, 132). The offshore conduits 131, 132 may be configured to be placed in fluid communication with one another via a crossover conduit 133. In some embodiments, the fluid may be a liquid that may have a boiling point below ambient temperature at atmospheric pressure, e.g., about 101.3 kPa—absolute pressure. In some embodiments, the fluid may be ammonia, petroleum gas, or carbon dioxide. In some embodiments, maintaining the fluid at high pressure may maintain or substantially maintain the fluid in a liquid state at ambient temperature.

[0015] In some embodiments, the fluid can be ammonia, and by maintaining the ammonia at a pressure of up to about 2,100 kPa-absolute, the ammonia can be maintained or substantially maintained in a liquid state at a temperature of about 50°C. In some embodiments, by maintaining the ammonia at a pressure of up to about 1,650 kPa-absolute, the ammonia can be maintained or substantially maintained in a liquid state at a temperature of 40°C. In some embodiments, the ammonia can be cooled so that the fluid remains in a liquid state at ambient pressure. In some embodiments, the ammonia can be at a temperature of about -30°C, about -35°C, about -40°C, about -45°C, or about -50°C to -55°C, -60°C, -65°C, or -70°C. In some embodiments, the fluid can be cooled ammonia in a liquid state. In some embodiments, the ammonia can be green ammonia and / or blue ammonia produced by reacting nitrogen separated from air with green hydrogen and / or blue hydrogen, respectively, using electricity generated from renewable sources, e.g., electricity obtained from wind, water, and / or sunlight.

[0016] In other embodiments, the fluid may be liquid petroleum gas. In some embodiments, the liquid petroleum gas may be or may include, but is not limited to, ethane, ethylene, propane, propylene, butane, butene, pentane, or any mixture thereof. In some embodiments, the liquid petroleum gas may also include one or more mercaptans as odorants. In some embodiments, the liquid petroleum gas may be maintained or substantially maintained in a liquid state at a temperature of about 45° C. by maintaining the liquid petroleum gas at about 1,090 kPa-absolute pressure, about 1,410 kPa-absolute pressure, or about 2,000 kPa-absolute to about 4,000 kPa-absolute pressure, about 6,240 kPa-absolute pressure, about 6,420 kPa-absolute pressure, or about 8,120 kPa-absolute pressure. In some embodiments, the liquid petroleum gas can be maintained in a liquid state at a temperature of about 32°C by maintaining the liquid petroleum gas at about 1,040 kPa absolute, about 2,070 kPa absolute, or about 3,000 kPa absolute to about 4,550 kPa absolute, about 6,070 kPa absolute, or about 7,870 kPa absolute. In some embodiments, the liquid petroleum gas can have a boiling point of about −45°C, about −35°C, or about −30°C to about −20°C, about −10°C, or about 0°C at atmospheric pressure, e.g., about 101.3 kPa absolute. In some embodiments, the liquid petroleum gas can be cooled to a temperature of about −35°C, about −40°C, about −45°C, or about −50°C to about −55°C, −60°C, −65°C, or −70°C. In some embodiments, the fluid may be refrigerated liquefied petroleum gas in a liquid state.

[0017] In some embodiments, the fluid can be carbon dioxide. In some embodiments, the carbon dioxide can be at a temperature of about -56.6 C, about -40 C, or about -30 C to about 0 C, about 15 C, or about 31.1 C, and at a pressure of greater than 517 kPa absolute, greater than 618 kPa absolute, greater than 700 kPa absolute, or greater than 800 kPa absolute to about 1,000 kPa absolute, about 1,500 kPa absolute, about 3,000 kPa absolute, or about 5,000 kPa absolute. In some embodiments, the fluid can be cooled carbon dioxide in a liquid state.

[0018] The apparatus 100 may also include a mooring structure 150. The mooring structure 150 may be a fixed structure, such as a marine loading tower, or a floating or conformable structure, such as a catenary anchor leg mooring buoy (CALM buoy) or a single point anchor leg mooring buoy (SALM buoy). In some embodiments, the catenary anchor leg mooring buoy may be a turntable buoy or a turret buoy. In some embodiments, the mooring structure 150 may include a fixed portion 151 rotatably coupled to a rotating portion 152. The fixed portion 151 of the mooring structure 150 may be configured to be fixed with respect to the Earth / stationary with respect to the Earth or relatively fixed with respect to the Earth, meaning that the fixed portion 151 of the mooring structure 150 may be configured not to substantially rotate about an axis perpendicular to the Earth. In some embodiments, the fixed portion 151 of the mooring structure 150 may rotate about an axis perpendicular to the Earth by about + / - 20 degrees or less, about + / - 15 degrees or less, or about + / - 10 degrees or less. The mooring structure 150 may be configured to moor a vessel 160 to the rotating portion 152 of the mooring structure 150.

[0019] The fluidic swivel 120 can be disposed on the mooring structure 150. The fluidic swivel 120 can include a fixed portion 121 rotatably coupled to a rotating portion 122. The fixed portion 121 of the fluidic swivel 120 can be coupled to the fixed portion 151 of the mooring structure 150. In some embodiments, the rotating portion 122 of the fluidic swivel 120 can be coupled to the rotating portion 152 of the mooring structure 150. The fluidic swivel 120 can be configured to provide fluid communication between the fixed portion 121 and the rotating portion 122 of the fluidic swivel 120, while the rotating portion 122 of the fluidic swivel 120 rotates relative to the fixed portion 121 of the fluidic swivel 120. As described above, in some embodiments, the fluidic swivel 120 can define one or more fluid flow paths therethrough, e.g., a first fluid flow path 123 and a second fluid flow path 124. In some embodiments, the fluidic swivel 120 can define one or more fluid flow paths therethrough. The fluidic swivel 120 can be configured to maintain a first fluid flow path 123 separated or otherwise isolated from a second fluid path 124, while the rotating portion 122 of the fluidic swivel 120 rotates relative to a fixed portion 121 of the fluidic swivel 120. The fluidic swivel 120 can be configured to maintain a first fluid flow path 123 separated or otherwise isolated from a second fluid flow path 124, while simultaneously maintaining fluid communication through the first and second fluid flow paths 123, 124 of the fluidic swivel 120, while simultaneously maintaining fluid communication through the first and second fluid flow paths 123, 124 of the fluidic swivel 120, while the rotating portion 122 of the fluidic swivel 120 rotates relative to a fixed portion 121 of the fluidic swivel 120.

[0020] The apparatus 100 may also include a first subsea conduit 105 that may be configured to provide fluid communication between a first pipeline 101 located on the seabed and a first fluid flow path 123 defined by a fluid swivel 120, and a second subsea conduit 106 that may be configured to provide fluid communication between a second subsea pipeline 102 located on the seabed and a second fluid flow path 124 defined by the fluid swivel 120. In some embodiments, the first subsea conduit 105 and the second subsea conduit 106 may each be configured as a rigid conduit, a flexible conduit, or a combination of one or more rigid conduits and one or more flexible conduits.

[0021] In some embodiments, the first subsea conduit 105 may include a first rigid subsea conduit 111 in fluid communication with a first flexible subsea conduit 113 that may be in fluid communication with a swivel inlet conduit 115 that may be in fluid communication with a first fluid flow path 123 defined by the fluid swivel 120. In some embodiments, the second subsea conduit 106 may include a second rigid subsea conduit 112 in fluid communication with a second flexible subsea conduit 114 that may be in fluid communication with a swivel outlet conduit 116 that may be in fluid communication with a second fluid flow path 124 defined by the fluid swivel 120. The swivel inlet conduit 115 and the swivel outlet conduit 116 may be disposed on a fixed portion 151 of the mooring structure 150 and / or the fixed portion 121 of the fluid swivel 120. In some embodiments, the fluid swivel inlet conduit 115 and the fluid swivel outlet conduit 116 may be rigid conduits.

[0022] In some embodiments, first subsea conduit 105 and / or second subsea conduit 106 may each optionally include one or more valves. In some embodiments, first rigid subsea conduit 111 and / or second rigid subsea conduit 114 may each include at least one valve 103, 104. In some embodiments, swivel inlet conduit 115 and / or swivel outlet conduit 116 may each include at least one valve 107, 108.

[0023] The apparatus 100 may also include a first offshore conduit 131, a second offshore conduit 132, and a crossover conduit 133, as described above. The first offshore conduit 131 may be configured to provide fluid communication between a first fluid flow path 123 defined by the fluid swivel 120 and a loading pipe 161 disposed on the vessel 160. The loading pipe 161 disposed on the vessel 160 may include a boarding valve 162 and may be in fluid communication with a storage tank 165 disposed on the vessel 160. The first offshore conduit 131 may include at least one valve 136. In some embodiments, the valve 136 may be disposed on the rotating portion 152 of the mooring structure 150 and / or the rotating portion 122 of the fluid swivel 120. In some embodiments, the first offshore conduit 131 can include a rigid conduit 135 that can be in fluid communication with a first flexible conduit or a first floating conduit 140 disposed in the rotating portion 152 of the mooring structure 150 and / or the rotating portion 122 of the fluid swivel 120. In some embodiments, the first flexible conduit 140 can be configured to float on or near the surface of the body of water. When the conduit is configured to float near the surface of the body of water, at least a portion of the upper portion of the conduit between its first and second ends can be located just below the surface of the body of water or at a depth of about 0.1 m, about 1 m, about 2 m, about 3 m, about 4 m, about 5 m, about 6 m, about 7 m, or more below the surface of the body of water. In some embodiments, the first flexible conduit 140 can include a valve 141. The second marine conduit 132 can be configured to be in fluid communication with the second fluid pathway 124 defined by the fluid swivel 120. In some embodiments, the second marine conduit 132 can be disposed in the rotating portion 152 of the mooring structure 150 and / or the rotating portion 122 of the fluid swivel 120. The crossover conduit 133 can be configured to fluidly connect the first marine conduit 131 and the second marine conduit 132. In some embodiments, the crossover conduit 133 can include a crossover valve 134 such that fluid communication between the first marine conduit 131 and the second marine conduit 132 via the crossover conduit 133 can be enabled or disabled by the crossover valve 134.In some embodiments, the crossover valve 134 can be a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve.

[0024] In some embodiments, the apparatus 100 can be configured to flow a fluid, such as ammonia, LPG, or carbon dioxide, from a first pipeline 101 located on the seabed, through a first subsea conduit 105, through a first fluid flow path 123 defined by a fluid swivel 120, through a first offshore conduit 131, through a loading pipe 161 located on the vessel 160, to a storage tank 165 located on the vessel 160. In other embodiments, the apparatus 100 may be configured to flow fluid from a first pipeline 101 located on the seabed, through a first subsea conduit 105, through a first fluid flow path 123 defined by the fluid swivel 120, through a portion of a first offshore conduit 131, through a crossover conduit 133, through a second offshore conduit 132, through a second fluid flow path 124 defined by the fluid swivel 120, and through a second subsea conduit 106 to a second pipeline 102 located on the seabed.

[0025] In other embodiments, the apparatus 100 may be configured to flow a fluid, such as ammonia, LPG, or carbon dioxide, from a first pipeline 101 located on the seabed, through a first subsea conduit 105, through a first fluid flow path 123 defined by a fluid swivel 120, through a first offshore conduit 131, through a loading pipe 161 located on the vessel 160, to a storage tank 165 located on the vessel 160, and once the fluid storage tank 165 is filled to a desired height, the valve 136 may be closed and the crossover valve 134 may be opened to allow the fluid to flow therethrough into a second offshore conduit 132 and ultimately into a second pipeline 102 located on the seabed. In yet another embodiment, the apparatus 100 may be configured to flow fluid from a first pipeline 101 located on the seabed, through a first subsea conduit 105, through a first fluid flow path 123 defined by the fluid swivel 120, through a portion of a first offshore conduit 131, through a crossover conduit 133, through a second offshore conduit 132, through a second fluid flow path 124 defined by the fluid swivel 120, through a second subsea conduit 106 to a second pipeline 102 located on the seabed, subsequently closing the crossover valve 134 and opening valves 136, 141, 162, and then flowing the fluid through the first offshore conduit 131, through a loading pipe 161 located on a vessel 160, to a storage tank 165 located on the vessel 160.

[0026] In some embodiments, the apparatus 100 can be configured to flow an inert gas from a first pipeline 101 located on the seabed, through a first subsea conduit 105, through a first fluid flow path 123 defined by the fluid swivel 120, through a first marine conduit 131, and to a loading pipe 161 located on the vessel 160 to remove moisture or water content from the apparatus 100 prior to flowing the fluid. In some embodiments, the inert gas can be a non-flammable gas. In some embodiments, the inert gas can be or can include, but is not limited to, nitrogen, carbon dioxide, argon, or mixtures thereof. In some embodiments, the inert gas can be exhaust gas or dry exhaust gas, for example, exhaust gas or dry exhaust gas generated by the vessel 160. In some embodiments, the apparatus 100 may be configured to flow an inert gas, such as nitrogen, from a first pipeline 101 located on the seabed, through a first subsea conduit 105, through a first fluid flow path 123 defined by the fluid swivel 120, through a first offshore conduit 131, and into a loading pipe 161 located on the vessel 160 to purge or otherwise remove at least a portion of any residual fluid from at least a portion of the apparatus 100 after the fluid has been transferred to a storage tank 165 located on the vessel 160.

[0027] In some embodiments, the apparatus 100 may be configured to flow inert gas from a first pipeline 101 located on the seabed, through a first subsea conduit 105, through a first fluid flow path 123 defined by the fluid swivel 120, through a portion of the first offshore conduit 131, through a crossover conduit 133, through a second offshore conduit 132, through a second fluid flow path 124 defined by the fluid swivel 120, and through a second subsea conduit 106 to a second pipeline 102 located on the seabed to remove or reduce moisture or water content from at least a portion of the apparatus 100 prior to flowing the fluid therethrough. In some embodiments, the apparatus 100 may be configured to flow inert gas from a first pipeline 101 located on the seabed, through a first subsea conduit 105, through a first fluid flow path 123 defined by the fluid swivel 120, through a portion of the first offshore conduit 131, through a crossover conduit 133, through a second offshore conduit 132, through a second fluid flow path 124 defined by the fluid swivel 120, and through a second subsea conduit 106 to a second pipeline 102 located on the seabed to purge or otherwise remove at least a portion of the fluid from at least a portion of the apparatus 100 after transferring the fluid to a storage tank 165 located on the vessel 160.

[0028] In other embodiments, the apparatus 100 may be configured to flow inert gas from the vessel 160 through the loading pipe 161, through the first offshore conduit 131, through the crossover conduit 133, through the second offshore conduit 132, through the fluid swivel 120, through the second subsea conduit 106, and to the second pipeline 102 located on the seabed to remove or reduce moisture or water content from at least a portion of the apparatus 100 prior to flowing the fluid therethrough. In yet another embodiment, the apparatus 100 may be configured to flow inert gas from the vessel 160 through the loading pipe 161, through the first offshore conduit 131, through the crossover conduit 133, through the second offshore conduit 132, through the fluid swivel 120, through the second subsea conduit 106, and to the second pipeline 102 located on the seabed to remove or reduce the concentrated portion of the fluid from the apparatus 100 after transferring the fluid to a storage tank 165 located on the vessel 160.

[0029] In some embodiments, the apparatus 100 can include a nitrogen cylinder or nitrogen generator (not shown) disposed on the mooring structure 150, which can include a regulator or control valve in fluid communication with the first offshore conduit 131, the second offshore conduit 132, the crossover conduit 133, or the fluid swivel 120, to purge the gaseous and / or liquid medium from at least a portion of the apparatus 100. In some embodiments, the apparatus 100 can include a vent conduit (not shown) in fluid communication with the first offshore conduit 131, the second offshore conduit 132, and / or the crossover conduit 133. In some embodiments, the vent conduit can provide an outlet to the atmosphere for the gaseous and / or liquid medium. In some embodiments, the fluid can be diluted within the vessel or tank (not shown) to a concentration suitable or otherwise acceptable for release of the fluid to the atmosphere in accordance with local regulations. In some embodiments, the vent conduit can include a valve. In other embodiments, the gaseous and / or liquid medium may be treated on the vessel 160 or on land to remove impurities.

[0030] FIG. 2 shows a flow diagram of another exemplary apparatus 200 for transferring fluid to and / or from a storage tank 265 located on a vessel 260, including a fluid swivel 220 defining a fluid flow path 223 therethrough and an offshore conduit 231, according to one or more embodiments. In some embodiments, the fluid can be a liquid that may have a boiling point below ambient temperature at atmospheric pressure, e.g., about 101.3 kPa absolute. In some embodiments, the fluid can be ammonia, liquid petroleum gas, or carbon dioxide, as described above with reference to FIG. 1 . The apparatus 200 can also include a mooring structure 250. The mooring structure 250 can be a fixed structure, such as a marine loading tower, or a floating or conformable structure, such as a catenary anchor leg mooring buoy or a single-point anchor leg mooring buoy. In some embodiments, the mooring structure 250 can include a fixed portion 251 rotatably coupled to a rotating portion 252. In some embodiments, the tethering structure 250 may be the tethering structure 150 described above with reference to FIG.

[0031] The fluidic swivel 220 can be disposed on the mooring structure 250. The fluidic swivel 220 can include a fixed portion 221 rotatably coupled to a rotating portion 222. The fluidic swivel 220 can define at least one fluid flow path 223 therethrough. The fixed portion 221 of the fluidic swivel 220 can be coupled to the fixed portion 252 of the mooring structure 250. In some embodiments, the rotating portion 222 of the fluidic swivel 220 can be coupled to the rotating portion 251 of the mooring structure 250. In some embodiments, the fluidic swivel 220 can be a linear swivel. The fluidic swivel 220 can maintain fluid communication between the fixed portion 221 and the rotating portion 222 of the fluidic swivel 220 via the at least one flow path 223, while the rotating portion 222 of the fluidic swivel 220 rotates relative to the fixed portion 221 of the fluidic swivel 220.

[0032] The apparatus 200 may include a first subsea conduit 205 configured to provide fluid communication between a first pipeline 201 located on the seabed and a first fluid flow path 223 defined by a fluid swivel 220, and a second subsea conduit 206 that may be configured to provide fluid communication with a second pipeline 202 located on the seabed. In some embodiments, the first subsea conduit 205 and the second subsea conduit 206 may be individually configured as rigid conduits, as flexible conduits, or as a combination of rigid and flexible conduits.

[0033] In some embodiments, the first subsea conduit 205 may include a first rigid subsea conduit 211 in fluid communication with a first flexible subsea conduit 213, which may be in fluid communication with a swivel inlet conduit 215, which may be in fluid communication with a first fluid flow path 223 defined by the fluid swivel 220. In some embodiments, the second subsea conduit 206 may be a second rigid subsea conduit. The swivel inlet conduit 215 may be disposed in the fixed portion 252 of the mooring structure 250. In some embodiments, the fluid swivel inlet conduit 215 may be a rigid conduit.

[0034] In some embodiments, the first subsea conduit 205 and / or the second subsea conduit 206 can each include one or more valves. In some embodiments, the first rigid subsea conduit 211 and / or the second subsea conduit 206 can each include at least one valve 203, 204. In some embodiments, the swivel inlet conduit 215 can include at least one valve 207. The apparatus 200 can include a subsea crossover conduit 270 configured to provide fluid communication between the first subsea conduit 205 and the second subsea conduit 206. In some embodiments, the subsea crossover conduit 270 can be configured as a rigid conduit. In some embodiments, the subsea crossover conduit 270 can provide fluid communication between the first rigid subsea conduit 211 and the second subsea conduit 206. In some embodiments, the subsea crossover conduit 270 can include a subsea crossover valve 271 that can enable or prevent fluid communication between the first subsea conduit 205 and the second subsea conduit 206 via the crossover conduit 270. In some embodiments, the crossover valve 271 can be configured as a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve.

[0035] The apparatus 200 may also include an offshore conduit 231. The offshore conduit 231 may be configured to provide fluid communication between the fluid flow path 223 defined by the fluid swivel 220 and a loading pipe 261 disposed on the vessel 260. The loading pipe 261 disposed on the vessel 260 may include a boarding valve 262 and may be in fluid communication with a storage tank 265 disposed on the vessel 260. The offshore conduit 231 may include at least one valve 236. In some embodiments, the valve 236 may be disposed on the rotating portion 252 of the mooring structure 250. In some embodiments, the offshore conduit 231 may include a rigid conduit 235 that may be in fluid communication with a flexible or floating conduit 240 disposed on the rotating portion 252 of the mooring structure 250 and / or the rotating portion 222 of the fluid swivel 220. In some embodiments, the flexible conduit 240 may include a valve 241. In some embodiments, the flexible conduit 240 can be configured to float on or near the surface of the body of water.

[0036] In some embodiments, the apparatus 200 can be configured to flow a fluid, such as ammonia, liquid petroleum gas, or carbon dioxide, from a first pipeline 201 located on the seabed, through a first subsea conduit 205, through a subsea crossover conduit 270, through a second subsea conduit 206, to a second pipeline 202 located on the seabed. In some embodiments, the apparatus 200 can be configured to flow a fluid, such as ammonia, liquid petroleum gas, or carbon dioxide, from a first pipeline 201 located on the seabed, through the first subsea conduit 205, through a fluid flow path 223 of a fluid swivel 220, through an offshore conduit 231, through a loading pipe 261 located on the vessel 260, to a storage tank 165 located on the vessel 160.

[0037] In some embodiments, apparatus 200 can be configured to flow an inert gas from first pipeline 201 located on the seabed, through first subsea conduit 205, through fluid flow path 223 of fluid swivel 220, through offshore conduit 231, to loading pipe 261 located on vessel 260 to remove moisture or water from at least a portion of apparatus 200 prior to flowing fluid through apparatus 200. In some embodiments, apparatus 200 can be configured to flow an inert gas, such as nitrogen, from first pipeline 201 located on the seabed, through first subsea conduit 205, through fluid flow path 223 of fluid swivel 220, through offshore conduit 231, to loading pipe 261 located on vessel 260 to purge or otherwise remove at least a portion of fluid from apparatus 200 after flowing fluid through the apparatus. In some embodiments, apparatus 200 can include a nitrogen cylinder or nitrogen generator (not shown) disposed on mooring structure 250, which can include a regulator or control valve in fluid communication with first offshore conduit 231 or fluid swivel 220, to purge fluid from at least a portion of apparatus 200. In some embodiments, apparatus 200 can include a vent conduit (not shown) in fluid communication with first offshore conduit 231. In some embodiments, the vent conduit can provide an outlet for the fluid to the atmosphere. In some embodiments, the fluid can be diluted within the vessel or tank (not shown) to a concentration suitable or otherwise acceptable for release to the atmosphere in accordance with local regulations. In some embodiments, the vent conduit can include a valve.

[0038] FIG. 3 shows a flow diagram of another exemplary apparatus 300 for transferring fluid to and / or from a fluid storage tank 365 located on a vessel 360, including a fluid swivel 320 defining at least two fluid flow paths therethrough (two shown, 323, 324), at least two offshore conduits (two shown, 331, 332), and an optional subsea pipeline end manifold 380, according to one or more embodiments. In some embodiments, the fluid can be a liquid that may have a boiling point below ambient temperature at atmospheric pressure, e.g., about 101.3 kPa absolute. In some embodiments, the fluid can be ammonia, liquid petroleum gas, or carbon dioxide, as described above with reference to FIG. 1. The apparatus 300 can also include a mooring structure 350. The mooring structure 350 can be a fixed structure, such as a fixed mooring tower, or a floating or conformable structure, such as a catenary anchor leg mooring buoy or a single-point anchor leg mooring buoy. The tether structure 350 can include a fixed portion 352 rotatably coupled to a rotating portion 351. In some embodiments, the tether structure 350 can be the tether structure 150 described above with reference to FIG.

[0039] The fluidic swivel 320 can be disposed on a mooring structure 350. The fluidic swivel 320 can include a fixed portion 321 rotatably coupled to a rotating portion 322. The fixed portion 321 of the fluidic swivel 320 can be coupled to the fixed portion 352 of the mooring structure 350. In some embodiments, the rotating portion 322 of the fluidic swivel 320 can be coupled to the rotating portion 351 of the mooring structure 350. The fluidic swivel 320 can be configured to provide fluid communication between the fixed portion 321 and the rotating portion 322 of the fluidic swivel 320, while the rotating portion 322 of the fluidic swivel 320 rotates relative to the fixed portion 321 of the fluidic swivel 320.

[0040] In some embodiments, the fluidic swivel 320 can define a first fluid flow path 323 and a second fluid flow path 324 therethrough. In other embodiments, the fluidic swivel 320 can define three or more fluid flow paths therethrough. The fluidic swivel 320 can be configured to provide a first fluid flow path 323 that is separate or otherwise isolated from a second fluid path 324, while the rotating portion 322 of the fluidic swivel 320 rotates relative to a fixed portion 321 of the fluidic swivel 320. The fluidic swivel 320 can be configured to provide a first fluid flow path 323 that is separate or otherwise isolated from a second fluid flow path 324, while simultaneously maintaining fluid communication through the first fluid flow path 323 of the fluidic swivel 320 and maintaining fluid communication through the second fluid flow path 324 of the fluidic swivel 320, while simultaneously maintaining fluid communication through the first fluid flow path 323 of the fluidic swivel 320.

[0041] The apparatus 300 may include a first subsea conduit 305 that may be configured to provide fluid communication between a first pipeline 301 located on the seabed and a first fluid flow path 323 defined by a fluid swivel 320, and a second subsea conduit 306 that may be configured to provide fluid communication between a second subsea pipeline 302 located on the seabed and a second fluid flow path 324 defined by the fluid swivel 320. In some embodiments, the first subsea conduit 305 and the second subsea conduit 306 may be individually configured as rigid conduits, as flexible conduits, or as a combination of rigid and flexible conduits.

[0042] In some embodiments, the first subsea conduit 305 may include a first rigid subsea conduit 311 in fluid communication with a first flexible subsea conduit 313, which may be in fluid communication with a swivel inlet conduit 315, which may be in fluid communication with a first fluid flow path 323 defined by the fluid swivel 320. In some embodiments, the second subsea conduit 306 may include a second rigid subsea conduit 312 in fluid communication with a second flexible subsea conduit 314, which may be in fluid communication with a swivel outlet conduit 316, which may be in fluid communication with a second fluid flow path 324 defined by the fluid swivel 320. The swivel inlet conduit 315 and the swivel outlet conduit 316 may be disposed in a fixed portion 351 of the mooring structure 350. In some embodiments, the fluid swivel inlet conduit 315 and the fluid swivel outlet conduit 316 may be rigid conduits.

[0043] In some embodiments, first subsea conduit 305 and / or second subsea conduit 306 may each optionally include one or more valves. In some embodiments, first rigid subsea conduit 311 and / or second rigid subsea conduit 312 may each include at least one valve 303, 304. In some embodiments, swivel inlet conduit 315 and / or swivel outlet conduit 316 may each include at least one valve 307, 308. In some embodiments, apparatus 300 may include a subsea crossover conduit 370 configured to provide fluid communication between first subsea conduit 305 and second subsea conduit 306. In some embodiments, subsea crossover conduit 370 may be configured as a rigid conduit disposed in any pipeline end manifold 380. In some embodiments, subsea crossover conduit 370 may provide fluid communication between first rigid subsea conduit 311 and second rigid subsea conduit 312. In some embodiments, the subsea crossover conduit 370 can include a subsea crossover valve 371 such that fluid communication between the first subsea conduit 305 and the second offshore conduit 306 through the crossover conduit can be enabled or prevented by the crossover valve 371. In some embodiments, the crossover valve 371 can be configured as a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve.

[0044] The apparatus 300 may also include a first marine conduit 331 and a second marine conduit 332, as described above. The apparatus 300 may also include a crossover conduit 333. The first marine conduit 331 may be configured to provide fluid communication between a first fluid flow path 323 defined by the fluid swivel 320 and a loading pipe 363 disposed on the vessel 360. The loading pipe 363 disposed on the vessel 360 may include a boarding valve 362 and may be in fluid communication with a storage tank 365 disposed on the vessel 360. The first marine conduit 331 may include at least one valve 336. In some embodiments, the valve 336 may be disposed on the rotating portion 352 of the mooring structure 350. In some embodiments, first offshore conduit 331 may include a rigid offshore conduit 335 that may be in fluid communication with a flexible conduit or offshore conduit 340 disposed in rotating portion 352 of mooring structure 350 and / or rotating portion 322 of fluid swivel 320. In some embodiments, flexible conduit 340 may include a valve 341. In some embodiments, flexible conduit 340 may be a flexible hose or flexible pipe. In some embodiments, flexible conduit 340 may be configured to float on or near the surface of the body of water. Second offshore conduit 332 may be configured to provide fluid communication with second fluid pathway 324 defined by fluid swivel 320. In some embodiments, second offshore conduit 332 may be disposed in rotating portion 352 of mooring structure 350. The crossover conduit 333 can be configured to fluidly connect the first offshore conduit 331 and the second offshore conduit 332. In some embodiments, the crossover conduit 333 can include a crossover valve 334, such that the crossover valve 334 can enable or prevent fluid communication between the first offshore conduit 331 and the second offshore conduit 332 via the crossover conduit 333. In some embodiments, the crossover valve 334 can be a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve.

[0045] In some embodiments, the apparatus 300 can be configured to flow a fluid, such as ammonia, liquid petroleum gas, or carbon dioxide, from a first pipeline 301 located on the seabed, through a first subsea conduit 305, through a first fluid flow path 323 defined by a fluid swivel 320, through a first offshore conduit 331, through a loading pipe 361 located on the vessel 360, and to a storage tank 365 located on the vessel 360. In other embodiments, the apparatus 300 may be configured to flow fluid from a first pipeline 301 located on the seabed, through a first subsea conduit 305, through a first fluid flow path 323 defined by the fluid swivel 320, through a portion of a first offshore conduit 331, through a crossover conduit 333, through a second offshore conduit 332, through a second fluid flow path 324 defined by the fluid swivel 320, and through a second subsea conduit 306 to a second pipeline 302 located on the seabed. In other embodiments, the apparatus 300 may be configured to flow fluid from a first pipeline 301 located on the seabed, through a portion of a first subsea conduit 305, through a subsea crossover conduit 370, and through a portion of a second subsea conduit 306 to a second pipeline 302 located on the seabed.

[0046] In some embodiments, the apparatus 300 can be configured to flow an inert gas, such as nitrogen, from the first pipeline 101 located on the seabed, through the first subsea conduit 305, through the first fluid flow path 323 defined by the fluid swivel 320, through the first offshore conduit 331, to the loading pipe 361 located on the vessel 360, to remove moisture or water from the apparatus 300 before flowing the fluid. In some embodiments, the apparatus 300 can be configured to flow an inert gas, such as nitrogen, from the first pipeline 101 located on the seabed, through the first subsea conduit 305, through the first fluid flow path 323 defined by the fluid swivel 320, through the first offshore conduit 331, to the loading pipe 361 located on the vessel 360, to purge or otherwise remove at least a portion of the fluid from at least a portion of the apparatus 300, after flowing the fluid. In some embodiments, the apparatus 300 may be configured to flow an inert gas, such as nitrogen, from a first pipeline 301 located on the seabed, through a first subsea conduit 305, through a first fluid flow path 323 defined by the fluid swivel 320, through a portion of the first offshore conduit 331, through a crossover conduit 333, through a second offshore conduit 332, through a second fluid flow path 324 defined by the fluid swivel 320, and through a second subsea conduit 306 to a second pipeline 302 located on the seabed to remove moisture or water from at least a portion of the apparatus 300 prior to flowing the fluid. In some embodiments, the apparatus 300 may be configured to flow an inert gas, such as nitrogen, from a first pipeline 301 located on the seabed, through a first subsea conduit 305, through a first fluid flow path 323 defined by the fluid swivel 320, through a portion of the first offshore conduit 331, through the crossover conduit 333, through a second offshore conduit 332, through a second fluid flow path 324 defined by the fluid swivel 320, and through a second subsea conduit 306 to a second pipeline 302 located on the seabed to purge or otherwise remove at least a portion of the fluid from at least a portion of the apparatus 300, to remove moisture or water from at least a portion of the apparatus 300 after the fluid has been flowed.

[0047] In some embodiments, apparatus 300 can include a nitrogen cylinder or nitrogen generator 320 (not shown) disposed on mooring structure 350, which can include a regulator or control valve in fluid communication with first offshore conduit 331, second offshore conduit 332, crossover conduit 333, or swivel 320, to purge at least a portion of the liquid from at least a portion of apparatus 300. In some embodiments, apparatus 300 can include a vent conduit (not shown) in fluid communication with first offshore conduit 331, second offshore conduit 332, and / or crossover conduit 333. In some embodiments, the vent conduit can provide an outlet for the fluid to the atmosphere. In some embodiments, the vent conduit can include a valve.

[0048] FIG. 4 shows a flow diagram of another exemplary apparatus 400 for transferring fluid to and / or from a storage tank 465 disposed on a vessel 460, according to one or more embodiments. The apparatus 400 may include a fluid swivel 420 defining at least two fluid flow paths therethrough (two shown, 423, 424), at least two offshore conduits (two shown, 431, 432), and at least two subsea conduits (two shown, 405, 406). In some embodiments, the offshore conduits 431, 432 may be disposed in fluid communication with one another via a crossover conduit 433 and / or a crossover conduit 442. In some embodiments, the subsea conduits 405, 406 may be disposed in fluid communication with one another via a crossover conduit 470. In some embodiments, the fluid may be ammonia, liquid petroleum gas, or carbon dioxide, as described above with reference to FIG. 1. The apparatus 400 may include a mooring structure 450. Mooring structure 450 can be a fixed structure, such as a fixed mooring tower, or a floating or conformable structure, such as a catenary anchor leg mooring buoy or a single point anchor leg mooring buoy. Mooring structure 450 can include a rotating portion 451 rotatably coupled to a fixed portion 452. In some embodiments, mooring structure 450 can be mooring structure 150 described above with reference to FIG. 1.

[0049] The fluidic swivel 420 can be disposed on a mooring structure 450. The fluidic swivel 420 can include a fixed portion 421 rotatably coupled to a rotating portion 422. The fixed portion 421 of the fluidic swivel 420 can be coupled to the fixed portion 452 of the mooring structure 450. In some embodiments, the rotating portion 422 of the fluidic swivel 420 can be coupled to the rotating portion 451 of the mooring structure 450. The fluidic swivel 420 can be configured to maintain fluid communication between the fixed portion 421 and the rotating portion 422 of the fluidic swivel 420, while the rotating portion 422 of the fluidic swivel 420 rotates relative to the fixed portion 421 of the fluidic swivel 420.

[0050] In some embodiments, the fluidic swivel 420 can define a first fluid flow path 423 and a second fluid flow path 424 therethrough, as described above. In other embodiments, the fluidic swivel 420 can define three or more fluid flow paths therethrough. The fluidic swivel 420 can be configured to maintain the first fluid flow path 423 separated or otherwise isolated from the second fluid path 424, while the rotating portion 422 of the fluidic swivel 420 rotates relative to the fixed portion 421 of the fluidic swivel 420. The fluid swivel 420 can be configured to maintain the first fluid flow path 423 separated or otherwise isolated from the second fluid flow path 424, while simultaneously maintaining fluid communication through the first fluid flow path 423 of the fluid swivel 420 and maintaining fluid communication through the second fluid flow path 424 of the fluid swivel 420, and simultaneously allowing the rotating portion 422 of the fluid swivel 420 to rotate relative to the fixed portion 421 of the fluid swivel 420.

[0051] The apparatus 400 may also include a first subsea conduit 405, which may be configured to provide fluid communication between a first pipeline 401 located on the seabed and a first fluid flow path 423 defined by a fluid swivel 420, as described above, and a second subsea conduit 406, which may be configured to provide fluid communication between a second subsea pipeline 402 located on the seabed and a second fluid flow path 424 defined by the fluid swivel 420. In some embodiments, the first subsea conduit 405 and the second subsea conduit 406 may each be configured as a rigid conduit, a flexible conduit, or a combination of rigid and flexible conduits.

[0052] In some embodiments, the first subsea conduit 405 may include a first rigid subsea conduit 411 in fluid communication with a first flexible subsea conduit 413 that may be in fluid communication with a swivel inlet conduit 415 that may be in fluid communication with a first fluid flow path 423 defined by the fluid swivel 420. In some embodiments, the second subsea conduit 406 may include a second rigid subsea conduit 412 in fluid communication with a second flexible subsea conduit 414 that may be in fluid communication with a swivel outlet conduit 416 that may be in fluid communication with a second fluid flow path 424 defined by the fluid swivel 420. The swivel inlet conduit 415 and the swivel outlet conduit 416 may be disposed on a fixed portion 451 of the mooring structure 450. In some embodiments, the fluid swivel inlet conduit 415 and the fluid swivel outlet conduit 416 may be rigid conduits.

[0053] In some embodiments, the first subsea conduit 405 and / or the second subsea conduit 406 may each optionally include one or more valves. In some embodiments, the first rigid subsea conduit 411 and / or the second rigid subsea conduit 414 may each include at least one valve 403, 404. In some embodiments, the swivel inlet conduit 415 and / or the swivel outlet conduit 416 may each include at least one valve 407, 408. In some embodiments, the apparatus 400 may include a subsea crossover conduit 470 configured to provide fluid communication between the first subsea conduit 405 and the second subsea conduit 406, as described above. In some embodiments, the subsea crossover conduit 470 may be configured as a rigid conduit disposed in any pipeline end manifold 480. In some embodiments, the subsea crossover conduit 470 may provide fluid communication between the first rigid subsea conduit 411 and the second rigid subsea conduit 412. In some embodiments, the subsea crossover conduit 470 can include a subsea crossover valve 471, whereby fluid communication between the first subsea conduit 405 and the second offshore conduit 406 via the crossover conduit 470 can be allowed or prevented by opening or closing the crossover valve 471. In some embodiments, the crossover valve 471 can be configured as a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve.

[0054] The apparatus 400 may also include a first offshore conduit 431 and a second offshore conduit 432, as described above. In some embodiments, the apparatus 400 may optionally include at least one of a first crossover conduit 433 and a second crossover conduit 442. The first offshore conduit 431 may be configured to provide fluid communication between a first fluid flow path 423 defined by the fluid swivel 420 and a loading pipe 461 disposed on the vessel 460. The loading pipe 461 disposed on the vessel 460 may include a boarding valve 462 and may be in fluid communication with a storage tank 465 disposed on the vessel 460. The first offshore conduit 431 may include at least one valve 436. In some embodiments, the valve 436 may be disposed on a rotating portion 452 of the mooring structure 450. In some embodiments, the first marine conduit 431 may include a first rigid marine conduit 435 that may be in fluid communication with a first flexible or floating conduit 440 disposed on the rotating portion 452 of the mooring structure 450. In some embodiments, the first flexible conduit 440 may include a valve 441. In some embodiments, the first flexible conduit 440 may be configured to float on or near the surface of the body of water. The second marine conduit 432 may be configured to provide fluid communication between the second fluid flow path 424 defined by the fluid swivel 420 and a discharge pipe 463 disposed on the vessel 460. The discharge pipe 463 disposed on the vessel 460 may include a valve 462 and may be in fluid communication with a storage tank 465 disposed on the vessel 460. The second marine conduit 432 may include at least one valve 438. In some embodiments, the valve 438 can be disposed on the rotating portion 452 of the mooring structure 450. In some embodiments, the second offshore conduit 432 can include a second rigid offshore conduit 437 that can be in fluid communication with a second flexible or floating conduit 445 disposed on the rotating portion 452 of the mooring structure 450. In some embodiments, the second flexible conduit 445 can include a valve 444.In some embodiments, the second flexible conduit 445 can be configured to float on or near the surface of the body of water. The first crossover conduit 433 can be configured to fluidly connect the first offshore conduit 431 and the second offshore conduit 432. In some embodiments, the first crossover conduit 433 can be configured to fluidly connect the first rigid offshore conduit 435 and the second rigid offshore conduit 437. In some embodiments, the first crossover conduit 433 can include a first crossover valve 434, whereby fluid communication between the first offshore conduit 431 and the second offshore conduit 432 via the crossover conduit 433 can be enabled or prevented by opening or closing the crossover valve 434. In some embodiments, the crossover valve 434 can be a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve.

[0055] In some embodiments, the second crossover conduit 442 can be configured to fluidly connect the first offshore conduit 431 and the second offshore conduit 432. In some embodiments, the second crossover conduit 433 can be configured to fluidly connect the first flexible offshore conduit 435 and the second rigid offshore conduit 437. In other embodiments, the second crossover conduit 433 can be configured to fluidly connect the loading pipe 461 and the discharge pipe 463. In some embodiments, the second crossover conduit 442 can include a second crossover valve 443, such that fluid communication between the first offshore conduit 431 and the second offshore conduit 432 via the second crossover conduit 442 can be enabled or disabled by the crossover valve 443. In some embodiments, the crossover valve 443 can be a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve.

[0056] In some embodiments, the apparatus 400 can be configured to flow a fluid, such as ammonia, liquid petroleum gas, or carbon dioxide, from a first pipeline 401 located on the seabed, through a first subsea conduit 405, through a first fluid flow path 423 defined by a fluid swivel 420, through a first offshore conduit 431, through a loading pipe 461 located on a vessel 460, to a storage tank 465 located on a vessel 460. In other embodiments, the apparatus 400 can be configured to flow a gaseous fluid, such as ammonia, liquid petroleum gas, or carbon dioxide, from a storage tank located on a vessel, through a discharge pipe 463 located on the vessel 460, through a second offshore conduit 432, through a second fluid flow path 424 defined by a fluid swivel 420, and through a second subsea conduit 406 to a second subsea pipeline 402 located on the seabed.

[0057] In other embodiments, the apparatus 400 may be configured to flow fluid from a first pipeline 401 located on the seabed, through a first subsea conduit 405, through a first fluid flow path 423 defined by the fluid swivel 420, through a portion of a first offshore conduit 431, through a first crossover conduit 433, through a portion of a second offshore conduit 432, through a second fluid flow path 424 defined by the fluid swivel 420, and through a second subsea conduit 406 to a second pipeline 402 located on the seabed. In other embodiments, the apparatus 400 may be configured to flow fluid from a first pipeline 401 located on the seabed, through a first subsea conduit 405, through a first fluid flow path 423 defined by the fluid swivel 420, through at least a portion of a first offshore conduit 431, through a second crossover conduit 442, through at least a portion of a second offshore conduit 432, through a second fluid flow path 424 defined by the fluid swivel 420, and through a second subsea conduit 406 to a second pipeline 402 located on the seabed.

[0058] In other embodiments, when the second crossover conduit 442 is configured to provide fluid communication between the loading conduit 461 and the discharge conduit 463, the apparatus 400 can be configured to flow fluid from the first pipeline 401 located on the seabed, through the first subsea conduit 405, through the first fluid flow path 423 defined by the fluid swivel 420, through the first offshore conduit 431, through the second crossover conduit 442, through the second offshore conduit 432, through the second fluid flow path 424 defined by the fluid swivel 420, and through the second subsea conduit 406 to the second pipeline 402 located on the seabed. In other embodiments, the apparatus 400 may be configured to flow fluid from a first pipeline 401 located on the seabed, through a portion of a first subsea conduit 405, through a subsea crossover conduit 470, through a portion of a second subsea conduit 406, and to a second pipeline 402 located on the seabed.

[0059] In some embodiments, the apparatus 400 can be configured to flow an inert gas, such as nitrogen, from a first pipeline 401 located on the seabed, through a first subsea conduit 405, through a first fluid flow path 423 defined by the fluid swivel 420, and through a first offshore conduit 431 to a loading pipe 461 located on the vessel 460 to remove moisture or water content from the fluid prior to flow therethrough. In other embodiments, the apparatus 400 can be configured to flow an inert gas, such as nitrogen, from a first pipeline 401 located on the seabed, through a first subsea conduit 405, through a first fluid flow path 423 defined by the fluid swivel 420, and through a first offshore conduit 431 to a loading pipe 461 located on the vessel 460 to remove at least a portion of residual fluid therefrom after the fluid has flowed therethrough.

[0060] In other embodiments, the apparatus 400 may be configured to flow an inert gas, such as nitrogen, from a first pipeline 401 located on the seabed, through the first subsea conduit 405, through the first fluid flow path 423 defined by the fluid swivel 420, through at least a portion of the first offshore conduit 431, through the first crossover conduit 433 and / or the second crossover conduit 442, through at least a portion of the second offshore conduit 432, through the second fluid flow path 424 defined by the fluid swivel 420, and through the second subsea conduit 406 to a second pipeline 402 located on the seabed to remove at least a portion of the moisture or water from the fluid before it is flowed to the fluid storage tank 465. In other embodiments, the apparatus 400 may be configured to flow an inert gas, such as nitrogen, from a first pipeline 401 located on the seabed, through the first subsea conduit 405, through the first fluid flow path 423 defined by the fluid swivel 420, through at least a portion of the first offshore conduit 431, through the first crossover conduit 433 and / or the second crossover conduit 442, through at least a portion of the second offshore conduit 432, through the second fluid flow path 424 defined by the fluid swivel 420, and through the second subsea conduit 406 to a second pipeline 402 located on the seabed to remove at least a portion of the residual fluid therefrom after the fluid has flowed therethrough.

[0061] In other embodiments, the apparatus 400 may be configured to flow an inert gas, such as nitrogen, from a first pipeline 401 located on the seabed, through a first subsea conduit 405, through a first fluid flow path 423 defined by the fluid swivel 420, through at least a portion of the first offshore conduit 431, through a second crossover conduit 442, through at least a portion of the second offshore conduit 432, through a second fluid flow path 424 defined by the fluid swivel 420, and through a second subsea conduit 406 to a second pipeline 402 located on the seabed to remove at least a portion of the moisture or water therefrom before flowing the fluid therethrough. In other embodiments, the apparatus 400 may be configured to flow an inert gas, such as nitrogen, from a first pipeline 401 located on the seabed, through a first subsea conduit 405, through a first fluid flow path 423 defined by the fluid swivel 420, through at least a portion of a first offshore conduit 431, through a second crossover conduit 442, through at least a portion of a second offshore conduit 432, through a second fluid flow path 424 defined by the fluid swivel 420, and through a second subsea conduit 406 to a second pipeline 402 located on the seabed to remove at least a portion of the residual fluid therefrom after the fluid has flowed therethrough.

[0062] In some embodiments, the apparatus 400 can include a nitrogen cylinder or nitrogen generator 420 (not shown) disposed on the mooring structure 450, which can include a regulator or control valve in fluid communication with the first offshore conduit 431, the second offshore conduit 432, the first crossover conduit 433, the second crossover conduit 442, or the swivel 420, for purging at least a portion of the moisture and / or fluid therefrom. In some embodiments, the apparatus 400 can include a vent conduit (not shown) in fluid communication with the first offshore conduit 431, the second offshore conduit 432, the first crossover conduit 433, and / or the second crossover conduit 442. In some embodiments, the vent conduit can provide an outlet for the fluid to the atmosphere. In other embodiments, the fluid can be diluted aboard the vessel or in a tank (not shown) to a concentration suitable or otherwise acceptable for release to the atmosphere in accordance with local regulations. In some embodiments, the vent conduit can include a valve.

[0063] 5 shows a flow diagram of another exemplary apparatus 500 for transferring fluid to and / or from a storage tank 565 located on a vessel 560, including a fluid swivel 520 defining at least two flow paths therethrough (two shown, 523, 524), at least two offshore conduits (two shown, 531, 532), and a dedicated recirculation subsea pipeline line 590, according to one or more embodiments. The apparatus 500 may also include a mooring structure 550. The mooring structure 550 may be a fixed structure, such as, for example, a fixed mooring tower, or a floating or conformable structure, such as, for example, a catenary anchor leg mooring buoy or a single-point anchor leg mooring buoy. In some embodiments, the mooring structure 550 may be the mooring structure 150 described above with reference to FIG. 1.

[0064] The fluidic swivel 520 can be disposed on a mooring structure 550. The fluidic swivel 520 can include a fixed portion 521 rotatably coupled to a rotating portion 522. The fixed portion 521 of the fluidic swivel 520 can be coupled to the fixed portion 551 of the mooring structure 550. The rotating portion 522 of the fluidic swivel 520 can be coupled to the rotating portion 552 of the mooring structure 550. The fluidic swivel 520 can be configured to maintain fluid communication between the fixed portion 521 and the rotating portion 522 of the fluidic swivel 520, while the rotating portion 522 of the fluidic swivel 520 rotates relative to the fixed portion 521 of the fluidic swivel 520.

[0065] In some embodiments, the fluidic swivel 520 can define a first fluid flow path 523 and a second fluid flow path 524 therethrough, as described above. In other embodiments, the fluidic swivel 520 can define three or more fluid flow paths therethrough. The fluidic swivel 520 can be configured to maintain the first fluid flow path 523 separated or otherwise isolated from the second fluid path 524, while the rotating portion 522 of the fluidic swivel 520 rotates relative to the fixed portion 521 of the fluidic swivel 520. The fluid swivel 520 can be configured to maintain a first fluid flow path 523 separated or otherwise isolated from a second fluid flow path 524, while simultaneously maintaining fluid communication through the first fluid flow path 523 of the fluid swivel 520 and maintaining fluid communication through the second fluid flow path 524 of the fluid swivel 520, and simultaneously allowing the rotating portion 522 of the fluid swivel 520 to rotate relative to the fixed portion 521 of the fluid swivel 520.

[0066] The apparatus 500 may also include a first subsea conduit 505 that may be configured to provide fluid communication between a first pipeline 501 located on the seabed and a first fluid flow path 523 defined by a fluid swivel 520, and a second subsea conduit 506 that may be configured to provide fluid communication between a second subsea pipeline 502 located on the seabed and a second fluid flow path 524 defined by the fluid swivel 520. In some embodiments, the first subsea conduit 505 and the second subsea conduit 506 may be individually configured as rigid conduits, as flexible conduits, or as a combination of rigid and flexible conduits.

[0067] In some embodiments, the first subsea conduit 505 may include a first rigid subsea conduit 511 in fluid communication with a first flexible subsea conduit 513 that may be in fluid communication with a swivel inlet conduit 515 that may be in fluid communication with a first fluid flow path 523 defined by the fluid swivel 520. In some embodiments, the second subsea conduit 506 may include a second rigid subsea conduit 512 in fluid communication with a second flexible subsea conduit 514 that may be in fluid communication with a swivel outlet conduit 516 that may be in fluid communication with a second fluid flow path 524 defined by the fluid swivel 520. In some embodiments, the swivel inlet conduit 515 and the swivel outlet conduit 516 may be disposed on a fixed portion 551 of the mooring structure 550. In some embodiments, the swivel inlet conduit 515 and the swivel outlet conduit 516 may be rigid conduits.

[0068] In some embodiments, first subsea conduit 505 and / or second subsea conduit 506 may each optionally include one or more valves. In some embodiments, first rigid subsea conduit 511 and / or second rigid subsea conduit 514 may each include at least one valve 503, 504. In some embodiments, swivel inlet conduit 515 and / or swivel outlet conduit 516 may each include at least one valve 507, 508. In some embodiments, apparatus 500 may include a third subsea conduit 591 configured to provide fluid communication between first subsea conduit 505 and a third pipeline or dedicated recirculation subsea pipeline 590 located on the seabed. In some embodiments, third subsea conduit 591 may be configured as a rigid conduit located at any pipeline end manifold 580. In some embodiments, the third subsea conduit 591 can provide fluid communication between the first rigid subsea conduit 511 and a third pipeline 590 located on the seabed. In some embodiments, the third subsea conduit 591 can include a subsea valve 592 that can enable or prevent fluid communication between the first subsea conduit 505 and the third pipeline 590 located on the seabed via the third subsea conduit 591. The valve 592 can be configured as a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve.

[0069] Apparatus 500 may also include first offshore conduit 531 and second offshore conduit 532, as described above. In some embodiments, apparatus 500 may also include offshore crossing conduit or first offshore crossing conduit 533 and / or offshore crossing conduit or second offshore crossing conduit 542. First offshore conduit 531 may be configured to provide fluid communication between first fluid flow path 523 defined by fluid swivel 520 and loading pipe 561 disposed on vessel 560. Loading pipe 561 disposed on vessel 560 may include boarding valve 562 and may be in fluid communication with fluid storage tank 565 disposed on vessel 560. In some embodiments, first offshore conduit 531 may include at least one valve 536. In some embodiments, valve 536 may be disposed on rotating portion 552 of mooring structure 550. In some embodiments, the first offshore conduit 531 may include a first rigid offshore conduit 535 disposed on the rotating portion 552 of the mooring structure 550 and may be in fluid communication with a first flexible conduit 540. In some embodiments, the first flexible or floating conduit 540 may include at least one valve 541. In some embodiments, the first flexible conduit 540 may be configured to float on or near the surface of the body of water. The second offshore conduit 532 may be configured to provide fluid communication between the second fluid flow path 524 defined by the fluid swivel 520 and a discharge pipe 563 disposed on the vessel 560. The discharge pipe 563 disposed on the vessel 560 may include a valve 564 and may be in fluid communication with a storage tank 565 disposed on the vessel 560. The second offshore conduit 532 may include at least one valve 538. In some embodiments, the valve 538 can be disposed on the rotating portion 552 of the mooring structure 550. In some embodiments, the second offshore conduit 532 can include a second rigid offshore conduit 537 that can be in fluid communication with a second flexible or floating conduit 545 that is disposed on the rotating portion 552 of the mooring structure 550. In some embodiments, the second flexible conduit 545 can include a valve 544.In some embodiments, the second flexible conduit 545 can be configured to float on or near the surface of the body of water. The crossover conduit 533 can be configured to fluidly connect the first offshore conduit 531 and the second offshore conduit 532. In some embodiments, the crossover conduit 533 can be configured to fluidly connect the first rigid offshore conduit 535 and the second rigid offshore conduit 537. In some embodiments, the crossover conduit 533 can include a crossover valve 534, such that fluid communication between the first offshore conduit 531 and the second offshore conduit 532 through the crossover conduit 533 can be enabled or disabled by the crossover valve 534. In some embodiments, the crossover valve 534 can be a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve. The second crossover conduit 542 can be configured to fluidly connect the first offshore conduit 531 and the second offshore conduit 532. In some embodiments, the second crossover conduit 542 can be configured to fluidly connect the first flexible offshore conduit 535 and the second flexible offshore conduit 545. In other embodiments, the second crossover conduit 542 can be configured to fluidly connect the loading conduit 561 and the discharge conduit 562. In some embodiments, the second crossover conduit 542 can include a crossover valve 543 such that fluid communication between the first offshore conduit 531 and the second offshore conduit 532, or between the loading conduit 561 and the discharge conduit 563, via the crossover conduit 542 can be allowed or prevented by opening or closing the crossover valve 543. In some embodiments, the crossover valve 543 can be a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve.

[0070] In some embodiments, apparatus 500 can be configured to flow a fluid, such as ammonia, liquid petroleum gas, or carbon dioxide, from a first pipeline 501 located on the seabed, through a first subsea conduit 505, through a first fluid flow path 523 defined by a fluid swivel 520, through a first offshore conduit 531, through a loading pipe 561 located on a vessel 560, to a storage tank 565 located on a vessel 560. In some embodiments, apparatus 500 can be configured to flow a gaseous fluid, such as ammonia, liquid petroleum gas, or carbon dioxide, from a storage tank 565 located on a vessel 560, through a discharge pipe 563 located on the vessel 560, through a second offshore conduit 532, through a second fluid flow path 524 defined by a fluid swivel 520, and through a second subsea conduit 506 to a second subsea pipeline 502 located on the seabed.

[0071] In other embodiments, the apparatus 500 may be configured to flow fluid from a first pipeline 501 located on the seabed, through a first subsea conduit 505, through a first fluid flow path 523 defined by a fluid swivel 520, through a portion of a first offshore conduit 531, through a first crossover conduit 533, through a portion of a second offshore conduit 532, through a second fluid flow path 524 defined by a fluid swivel 520, and through a second subsea conduit 506 to a second pipeline 502 located on the seabed. In other embodiments, the apparatus 500 can be configured to flow fluid from a first pipeline 501 located on the seabed, through a first subsea conduit 505, through a first fluid flow path 523 defined by a fluid swivel 520, through at least a portion of a first offshore conduit 531, through a second crossover conduit 542, through at least a portion of a second offshore conduit 532, through a second fluid flow path 524 defined by a fluid swivel 520, through a second subsea conduit 506, to a second pipeline 502 located on the seabed. In other embodiments, the apparatus 500 can be configured to flow fluid from a first pipeline 501 located on the seabed, through a portion of the first subsea conduit 505, through a third subsea conduit 591, to a third pipeline 590 located on the seabed.

[0072] In some embodiments, the apparatus 500 can be configured to flow an inert gas, such as nitrogen, from a first pipeline 501 located on the seabed, through a first subsea conduit 505, through a first fluid flow path 523 defined by a fluid swivel 520, and through a first offshore conduit 531 to a loading pipe 561 located on the vessel 560 to remove at least a portion of the moisture or water content therefrom prior to flowing the fluid therethrough. In some embodiments, the apparatus 500 can be configured to flow an inert gas, such as nitrogen, from a first pipeline 501 located on the seabed, through a first subsea conduit 505, through a first fluid flow path 523 defined by a fluid swivel 520, and through a first offshore conduit 531 to a loading pipe 561 located on the vessel 560 to remove at least a portion of the residual fluid therefrom after the fluid has flowed therethrough.

[0073] In some embodiments, the apparatus may be configured to flow an inert gas, such as nitrogen, from a first pipeline 501 located on the seabed, through a first subsea conduit 505, through a first fluid flow path 523 defined by a fluid swivel 520, through at least a portion of a first offshore conduit 531, through a first crossover conduit 533 and / or a second crossover conduit 542, through at least a portion of a second offshore conduit 532, through a second fluid flow path 524 defined by a fluid swivel 520, and through a second subsea conduit 506 to a second pipeline 502 located on the seabed to remove at least a portion of the moisture or water therefrom prior to flowing the fluid through at least a portion thereof. In some embodiments, the apparatus 500 may be configured to flow an inert gas, such as nitrogen, from a first pipeline 501 located on the seabed, through a first subsea conduit 505, through a first fluid flow path 523 defined by the fluid swivel 520, through at least a portion of the first offshore conduit 531, through a first crossover conduit 533 and / or a second crossover conduit 542, through at least a portion of the second offshore conduit 532, through a second fluid flow path 524 defined by the fluid swivel 520, and through a second subsea conduit 506 to a second pipeline 502 located on the seabed to purge or otherwise remove at least a portion of the fluid therefrom after the fluid has flowed therethrough.

[0074] In some embodiments, apparatus 500 can include a nitrogen cylinder or nitrogen generator (not shown) disposed on mooring structure 550, which can include a regulator or control valve in fluid communication with first offshore conduit 531, second fluid conduit 532, crossover conduit 533, or fluid swivel 520, to purge moisture / water and / or residual fluid therefrom. In some embodiments, apparatus 500 can include a vent conduit (not shown) in fluid communication with first offshore conduit 531, second offshore conduit 532, first crossover conduit 533, and / or second crossover conduit 542. In some embodiments, the vent conduit can provide an outlet for the fluid to the atmosphere. In other embodiments, the fluid can be diluted within the vessel or tank (not shown) to a concentration suitable or otherwise acceptable for release to the atmosphere in accordance with local regulations. In some embodiments, the vent conduit can include a valve.

[0075] In some embodiments, as will be appreciated by those skilled in the art, after a desired amount of fluid, e.g., liquid ammonia, has been transferred from first pipelines 101, 102, 103, 104, and 105, respectively, through units 100, 200, 300, 400, and / or 500, to fluid storage tanks 165, 265, 365, 465, and 565, crossover valves 134 (unit 100), 271 (unit 200), 334 and / or 371 (unit 300), 434 and / or 443 and / or 471 (unit 400), and 534 and / or 543 and / or 592 (unit 500) can be opened to allow at least a portion of the boil-off steam to enter pipelines 102, 202, 304, 402, and 502 and / or any pipeline 590. In some embodiments, the boil-off vapor can be returned to a facility, for example, an onshore facility, where it can be recondensed into a liquid phase.

[0076] Figure 6 shows an elevation view of an example fluid transfer apparatus 600 including a catenary anchor leg mooring buoy, or simply CALM buoy or buoy 650, configured to transfer fluid to and / or from a fluid storage tank 665 located on a vessel 660 moored to a buoy 650, according to one or more embodiments. Figure 7 shows a plan view of the example fluid transfer apparatus 600 and vessel 660 shown in Figure 6. The apparatus 600 may include a first subsea conduit 605, a second subsea conduit 606, a first floating conduit 640, a second floating conduit 645, a buoy 650, one or more mooring hawsers 603 (two shown), one or more mooring legs 601 (several shown) connected to anchor points 602 located on the seabed 699, and an optional pipeline end manifold 680. In some embodiments, the catenary anchor leg mooring buoy 650 may be configured with the apparatus 100, 200, 300, 400, or 500 described above with reference to Figures 1-5. In some embodiments, the apparatus 100, 200, 300, 400, and / or 500 may be configured to transfer liquid ammonia while limiting the pressure within the apparatus to less than 2,100 kPa absolute.

[0077] In some embodiments, first floating conduit 640 and second floating conduit 645 can be configured as flexible hoses or flexible pipes, respectively. In some embodiments, first floating conduit 640 and second floating conduit 645 can be configured to float on or near the surface of a body of water. In some embodiments, first subsea conduit 605 can include first flexible subsea conduit 613 and second subsea conduit 606 can include second flexible subsea conduit 614. In some embodiments, first flexible subsea conduit 613 and / or second flexible subsea conduit 614 can be configured in a lantern shape, as shown. In such embodiments, pipeline end manifold 680 can be generally located directly below or below buoy 650.

[0078] In other embodiments, the first flexible subsea conduit 613 and / or the second flexible subsea conduit 614 can be configured in a steep S-shape. In such embodiments, the structure of the apparatus 600 can include a submersible float (not shown) that can be tethered to the seabed. In such embodiments, the first flexible subsea conduit 613 and / or the second flexible subsea conduit 614 can be draped or otherwise positioned on the float so that the first flexible subsea conduit 613 and / or the second flexible subsea conduit 614 can be configured to form a steep or sharp "S" shape. In such embodiments, the pipeline end manifold 680 can typically be offset relative to the buoy 650. In such embodiments, the first flexible subsea conduit 613 and / or the second flexible subsea conduit 614 can approach the seabed 699 at an approach angle or tilt angle that is greater than zero. In some embodiments, the approach or tilt angle can be about 40 degrees, about 50 degrees, about 60 degrees, or about 65 degrees to about 70 degrees, about 75 degrees, about 80 degrees, about 85 degrees, or about 90 degrees from horizontal.

[0079] In other embodiments, the first flexible subsea conduit 613 and / or the second flexible subsea conduit 614 may be configured with a steep corrugation. In such embodiments, the apparatus 600 may include a plurality of buoyant elements (not shown) distributed along at least a portion of the first flexible subsea conduit 613 and / or the second flexible subsea conduit 614 such that the first flexible subsea conduit 613 and / or the second flexible subsea conduit 614 are configured in a gentle or gradual "S" shape. In such embodiments, the pipeline end manifold 680 may typically be offset from the buoy 650. In such embodiments, the first flexible subsea conduit 613 and / or the second flexible subsea conduit 614 may approach the seabed 699 at an approach angle or tilt angle greater than zero. In some embodiments, the approach or tilt angle can be about 40 degrees, about 50 degrees, about 60 degrees, or about 65 degrees to about 70 degrees, about 75 degrees, about 80 degrees, about 85 degrees, or about 90 degrees from horizontal.

[0080] In other embodiments, first flexible subsea conduit 613 and / or second flexible subsea conduit 614 can be configured in a loose S-shape. In such embodiments, the structure of apparatus 600 can include a submersible float that can be tethered to the seabed 699. In such embodiments, first flexible subsea conduit 613 and / or second flexible subsea conduit 614 can be draped or otherwise positioned over the float to cause the first flexible subsea conduit and / or second flexible subsea conduit to be in a loose "S" shape. In such embodiments, pipeline end manifold 680 can typically be offset from CALM buoy 650. In such embodiments, first flexible subsea conduit 613 and / or second flexible subsea conduit 614 can approach the seabed and / or pipeline end manifold 680 at a tangent or substantially horizontal approach or oblique angle.

[0081] In other embodiments, the first flexible subsea conduit 613 and / or the second flexible subsea conduit 614 may be configured with a gentle corrugation. In such embodiments, the apparatus 600 may include a plurality of buoyant elements distributed along at least a portion of the first flexible subsea conduit 613 and / or the second flexible subsea conduit 614 such that the first flexible subsea conduit 613 and / or the second flexible subsea conduit 614 are configured with a gentle "S" shape. In such embodiments, the pipeline end manifold 680 may typically be offset from the CALM buoy 650. In such embodiments, the first flexible subsea conduit 613 and / or the second flexible subsea conduit 614 may approach the seabed and / or the pipeline end manifold at a tangential or substantially horizontal approach or oblique angle. Lantern, steep S, steep wave, gentle S, and gentle wave shapes are all well known to those skilled in the art of subsea riser engineering.

[0082] FIG. 8 shows a detailed plan view of an exemplary catenary anchor leg mooring buoy, or simply CALM buoy 850, configured to moor a vessel and transfer fluid to and / or from a fluid storage tank located on the vessel, according to one or more embodiments. FIG. 9 shows an elevation view of the catenary anchor leg mooring buoy 850 shown in FIG. 8. In some embodiments, the fluid can be a liquid that may have a boiling point below ambient temperature at atmospheric pressure, e.g., about 101.3 kPa absolute. In some embodiments, the fluid can be ammonia, liquid petroleum gas, or carbon dioxide, as described above with reference to FIG. 1. In some embodiments, the CALM buoy 850 can be configured with the apparatus 100, 200, 300, 400, or 500 described above with reference to FIGS. 1-5.

[0083] The CALM buoy 850 can include a fixed portion 852 rotatably coupled to a rotating portion 851. The fixed portion 852 of the CALM buoy 850 can be configured to be fixed with respect to the Earth / stationary with respect to the Earth or relatively fixed / stationary with respect to the Earth, meaning that the fixed portion 852 of the CALM buoy 850 can be configured not to rotate substantially about an axis perpendicular to the Earth. In some embodiments, the fixed portion 852 of the CALM buoy 850 can rotate about an axis perpendicular to the Earth by about + / - 20 degrees or less, about + / - 15 degrees or less, or about + / - 10 degrees or less. The CALM buoy 850 can be configured to moor a vessel (not shown, but similar or the same as the vessel 660 shown in Figures 6 and 7) to the rotating portion 851 of the CALM buoy 850. The CALM buoy 850 can include mooring hawsers 803, two of which are shown, that can be configured to moor the vessel to the CALM buoy 850. CALM buoy 850 may have mooring legs 801, six of which are shown. Mooring legs 801 may be configured such that a first end thereof is anchored to the seabed and a second end thereof is coupled to a fixed portion 852 of CALM buoy 850.

[0084] CALM buoy 850 can include a fluidic swivel 820. In some embodiments, the fluidic swivel can define a first fluid flow path 823 and a second fluid flow path 824 therethrough. In other embodiments, the fluidic swivel 820 can define three or more fluid flow paths therethrough. The fluidic swivel 820 can include a fixed portion 821 rotatably coupled to a rotating portion 822. The fixed portion 821 of the fluidic swivel 820 can be coupled to a fixed portion 851 of the CALM buoy 850. In some embodiments, the rotating portion 822 of the fluidic swivel 820 can be coupled to a rotating portion 852 of the CALM buoy 850. The fluidic swivel 820 can be configured to maintain the first fluid flow path 823 separated or otherwise isolated from the second fluid path 824 while the rotating portion 822 of the fluidic swivel 820 rotates relative to the fixed portion 821 of the fluidic swivel 820. The fluid swivel 120 can be configured to maintain the first fluid flow path 823 separated or otherwise isolated from the second fluid flow path 824, while simultaneously maintaining fluid communication through the first fluid flow path 823 of the fluid swivel 820 and maintaining fluid communication through the second fluid flow path 824 of the fluid swivel 820, and simultaneously allowing the rotating portion 822 of the fluid swivel 820 to rotate relative to the fixed portion 821 of the fluid swivel 820.

[0085] CALM buoy 850 may also include a first offshore conduit 831, a crossover conduit 833, and a second offshore conduit 837. First offshore conduit 831 may be configured to provide fluid communication between a first fluid flow path 823 defined by fluid swivel 820 and a loading pipe (not shown, but similar to or the same as loading pipe 161 described above with reference to FIG. 1 ) disposed on the vessel. First offshore conduit 831 may include at least one valve 836. In some embodiments, valve 836 may be disposed on a rotating portion 852 of CALM buoy 850. In some embodiments, valve 836 may be a butterfly valve, a ball valve, or a gate valve. In some embodiments, first offshore conduit 831 may include a first rigid conduit 835 disposed on the rotating portion 852 of CALM buoy 850, which may be in fluid communication with first floating conduit 840. In some embodiments, the first floating conduit 840 can include a valve (not shown). In some embodiments, the valve of the first floating conduit 840, if present, can be a butterfly valve, a ball valve, or a gate valve. In some embodiments, the first floating conduit 840 can be configured to float on or near the surface of the body of water.

[0086] Second marine conduit 837 can be configured to provide fluid communication with second fluid pathway 823 defined by fluid swivel 820. In some embodiments, second marine conduit 837 can be a rigid conduit. In some embodiments, second marine conduit 837 can be disposed on rotating portion 852 of CALM buoy 850. In some embodiments not shown, second marine conduit 837 can include a second rigid conduit that can be in fluid communication with a second floating conduit disposed on rotating portion 852 of CALM buoy 850. In such embodiments, the second floating conduit can include a valve. In such embodiments, the second floating conduit can be configured to float on or near the surface of the body of water.

[0087] The crossover conduit 833 can be configured to fluidly connect the first offshore conduit 831 and the second offshore conduit 837. In some embodiments, the crossover conduit 833 can be configured to fluidly connect the first rigid conduit 835 with the second offshore conduit 837. In some embodiments, the crossover conduit 833 can include a crossover valve 834 such that fluid communication between the first rigid conduit 835 and the second offshore conduit 837 via the crossover conduit 8133 can be enabled or prevented by the crossover valve 834. The crossover valve 834 can be a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve.

[0088] In some embodiments, the CALM buoy 850 may include a swivel inlet conduit 815 disposed on the fixed portion 552 of the CALM buoy 850. The swivel inlet conduit 815 may be configured to fluidly connect a first fluid flow path 823 of the fluid swivel 820 to the first flexible subsea conduit 813. In some embodiments, the CALM buoy 850 may include a swivel outlet conduit 816 disposed on the fixed portion 552 of the CALM buoy 850. The swivel outlet conduit 816 may be configured to fluidly connect a second fluid flow path 824 of the fluid swivel 820 to the second flexible subsea conduit 814. In some embodiments, the inlet conduit 815 and the outlet conduit 816 may be configured with valves 807, 808, respectively. In some embodiments, the valves 807, 808 may be butterfly valves, ball valves, or gate valves.

[0089] 10 shows a plan view of an exemplary pipeline end manifold 1080 including a crossover conduit 1071 that can be configured to fluidly connect a first subsea pipeline 1001 and a second subsea pipeline 1002 disposed on the seabed 1099, according to one or more embodiments. In some embodiments, the pipeline end manifold 1080 can include a structural frame 1181 and can be secured to the seabed 1099 with at least one piling 1082, four of which are shown. In other embodiments, the pipeline end manifold 1080 can be secured to the seabed with a gravity block (not shown).

[0090] In some embodiments, the pipeline end manifold 1080 can include a first rigid subsea conduit 1011, a second rigid subsea conduit 1012, and a crossover conduit 1070. In some embodiments, the first rigid subsea conduit 1011 and the second rigid subsea conduit 1012 can be configured with valves 1003 and 1004, respectively. Each valve 1003 and 1004 can be a diver-operated valve, a valve controlled via a remotely operated transmission, or a remotely controlled valve. In some embodiments, the valves 1003 and 1004 can individually be butterfly valves, ball valves, or gate valves. In some embodiments, the crossover valve 1071 can be a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve.

[0091] 11 shows a plan view of another exemplary pipeline end manifold 1180 that can be configured to connect to a first subsea pipeline 1101, a second subsea pipeline 1102, and a third subsea pipeline 1190 disposed on the seabed 1199, according to one or more embodiments. In some embodiments, the pipeline end manifold 1180 can include a structural frame 1181 and can be configured to be anchored to the seabed 1199 with at least one piling 1181, of which four are shown. In other embodiments, the pipeline end manifold 1180 can be anchored to the seabed with a gravity block (not shown).

[0092] In some embodiments, the pipeline end manifold 1180 can include a first rigid subsea conduit 1111, a second rigid subsea conduit 1112, and a third subsea conduit 1191. In some embodiments, the first rigid subsea conduit 1111, the second rigid subsea conduit 1112, and the third rigid conduit 1191 can be configured with valves 1103, 1104, and 1192, respectively. In some embodiments, the valves 1103, 1104, and 1192 can individually be diver-operated valves, valves operated via remotely operated transmission means, or remotely controlled valves. In some embodiments, the valves 1103, 1104, and 1192 can individually be butterfly valves, ball valves, or gate valves.

[0093] FIG. 12 shows an elevation view of an exemplary fluid transfer apparatus 1200 including a marine loading tower 1250 configured to transfer fluid to and / or from a fluid storage tank 1265 that may be located on a vessel 1260 that may be moored to the fluid transfer apparatus 1200, according to one or more embodiments. FIG. 13 shows a plan view of the fluid transfer apparatus 1200 shown in FIG. 12. FIG. 14 shows an enlarged partial plan view of the fluid transfer apparatus 1200 shown in FIGS. 12 and 13. The apparatus 1200 may include a first subsea conduit 1205, a second subsea conduit 1206, a first offshore conduit 1231, a second offshore conduit 1232, a crossover conduit 1233, the marine loading tower 1250 that may be secured to the seabed 1299, and mooring hawsers 1256. In some embodiments, the first subsea conduit 1205 and the second subsea conduit 1206 may be rigid conduits. In some embodiments, the first subsea conduit 1205 and the second subsea conduit 1206 may include valves 1203, 1204, respectively.

[0094] Marine loading tower 1250 can include a base 1251 rotatably coupled to a turntable 1252. In some embodiments, base 1251 can include a first end 1253 fixedly attached to the seabed 1299 and a second end 1254 disposed above the surface 1298 of the body of water. First end 1253 of base 1251 can be configured to be anchored to the seabed 1299. In some embodiments, first end 1253 of base 1251 can include three pegs 1259, shown, configured to secure first end 1253 of base 1251 to the seabed 1299. In other embodiments, not shown, first end 1253 of base 1251 can be anchored to the seabed 1299 by a gravity block or gravity weight.

[0095] A turntable 1252 of the marine loading tower 1250 can be rotatably coupled to a second end 1254 of the base 1251. A loading arm 1255 can be disposed on the turntable 1252. The marine loading tower 1250 can be configured to moor the vessel 1260 to the turntable 1252 and / or the loading arm 1255. The marine loading tower 1250 can include a mooring hawser 1256 that can be configured to moor the vessel 1260 to the marine loading terminal 1250.

[0096] The marine loading tower 1250 may include a fluid swivel 1220. In some embodiments, the fluid swivel may define a first fluid flow path 1223 and a second fluid flow path 1224 therethrough. In other embodiments, the fluid swivel 1220 may define three or more fluid flow paths therethrough. The fluid swivel 1220 may include a fixed portion 1221 rotatably coupled to a rotating portion 1222. The fixed portion 1221 of the fluid swivel 1220 may be coupled to a second end 1254 of the base 1251. The rotating portion 1222 of the fluid swivel 1220 may be coupled to a turntable 1252. The fluidic swivel 1220 can be configured to maintain the first fluid flow path 1223 separated or otherwise isolated from the second fluid path 1224, while the rotating portion 1222 of the fluidic swivel 1220 rotates relative to the fixed portion 1221 of the fluidic swivel 1220. The fluidic swivel 1220 can be configured to maintain the first fluid flow path 1223 separated or otherwise isolated from the second fluid flow path 1224, while simultaneously maintaining fluid communication through the first fluid flow path 1223 of the fluidic swivel 1220 and maintaining fluid communication through the second fluid flow path 1224 of the fluidic swivel 1220, while simultaneously maintaining the rotating portion 1222 of the fluidic swivel 1220 rotates relative to the fixed portion 1221 of the fluidic swivel 1220.

[0097] In some embodiments, the first offshore conduit 1231 can be configured to provide fluid communication between a first fluid flow path 1223 defined by the fluid swivel 1220 and a loading pipe 1261 disposed on the vessel 1260 and in fluid communication with a fluid storage tank 1265. The first offshore conduit 1231 can include at least one valve 1236. In some embodiments, the valve 1236 can be disposed on the turntable 1252 or, as shown, on the loading arm 1255. In some embodiments, the valve 1236 can be a butterfly valve, a ball valve, or a gate valve. In some embodiments, the first offshore conduit 1231 can include a first rigid conduit 1235 disposed on the turntable 1252 and, optionally, on the loading arm 1255, that can be in fluid communication with a first flexible conduit 1240. In some embodiments, the first flexible conduit 1240 can be suspended from the loading arm 1255 when not fluidly connected to a loading pipe 1261 disposed on the vessel 1265 by a wire, rope, cable, or other elongated object 1257, which can be connected to a winch 1270. In some embodiments, the first flexible conduit 1240 and the loading pipe 1261 can include one or more valves 1262 therebetween. The valves 1262, if present, can be butterfly valves, ball valves, or gate valves. In other embodiments, the first flexible conduit 1240 can be configured to float on or near the surface 1298 of the body of water.

[0098] In some embodiments, the second marine conduit 1232 can be configured to provide fluid communication between the second fluid pathway 1224 defined by the fluid swivel 1220 and a discharge pipe 1263 disposed on the vessel 1260 and in fluid communication with a fluid storage tank 1265. In some embodiments, the second marine conduit 1232 can be a rigid conduit. In some embodiments, the second marine conduit 1232 can be disposed on the turntable 1252. In some embodiments, the second marine conduit 1232 can include a second rigid conduit 1237 that can be in fluid communication with a second flexible conduit 1245 disposed on the turntable 1252 and, optionally, on the loading arm 1255. In some embodiments, the second flexible conduit 1245 and the loading pipe 1263 can include one or more valves 1264 therebetween. In some embodiments, the second flexible conduit 1245 can be suspended from the loading arm 1255 when not fluidly connected to the loading pipe 1263 located on the vessel 1265 by a wire, rope, cable, or other elongated object 1258 connected to a winch 1270. In other embodiments, the second flexible conduit 1245 can be configured to float on or near the surface 1298 of the body of water.

[0099] The crossover conduit 1233 can be configured to fluidly connect the first offshore conduit 1231 and the second offshore conduit 1232. In some embodiments, the crossover conduit 1233 can be configured to fluidly connect the first rigid conduit 1235 with the second offshore conduit 1232. In some embodiments, the crossover conduit 1233 can include a crossover valve 1234 such that fluid communication between the first rigid conduit 1235 and the second offshore conduit 1232 via the crossover conduit 1233 can be enabled or disabled by the crossover valve 1234. In some embodiments, the crossover valve 1234 can be a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve.

[0100] In some embodiments, the marine loading tower 1250 can include a swivel inlet conduit 1215 disposed at the second end 1254 of the base 1251. The swivel inlet conduit 1215 can be configured to fluidly connect the first fluid flow path 1223 of the fluid swivel 1220 to the first subsea conduit 1205. In some embodiments, the marine loading tower 1250 can include a swivel outlet conduit 1216 disposed at the second end 1254 of the base 1251. The swivel outlet conduit 1216 can be configured to fluidly connect the second fluid flow path 1224 of the fluid swivel 1220 to the second subsea conduit 1206. In some embodiments, the inlet conduit 1215 and the outlet conduit 1216 can be configured with valves 1203, 1204, respectively. In some embodiments, the valves 1203, 1204 can be butterfly valves, ball valves, or gate valves.

[0101] The present disclosure further relates to any one or more of the following numbered embodiments:

[0102] A1. A fluid transfer device, the device comprising: a mooring structure configured to be disposed within a body of water; a fluid swivel configured to be disposed on the mooring structure, the fluid swivel having a fixed portion rotatably coupled to a rotating portion, the fixed portion and rotating portion of the fluid swivel defining isolated first and second fluid flow paths therethrough; a first subsea conduit configured to provide fluid communication between a first pipeline disposed on the seabed and the first fluid flow path defined by the fluid swivel; a second subsea conduit configured to provide fluid communication between a second pipeline disposed on the seabed and the second fluid flow path defined by the fluid swivel; a first subsea conduit configured to fluidly connect a fluid storage tank disposed on a vessel with the first fluid flow path defined by the fluid swivel; a first offshore conduit comprising a valve; a second offshore conduit in fluid communication with a second fluid flow path defined by a fluid swivel, the second offshore conduit comprising a valve; and a crossover conduit comprising a crossover valve configured to provide fluid communication between the first offshore conduit and the second offshore conduit, wherein a fixed portion of the fluid swivel and a rotating portion of the fluid swivel are configured to maintain fluid communication between the first subsea conduit and the first offshore conduit via the first fluid flow path, and wherein the fixed portion of the fluid swivel and the rotating portion of the fluid swivel are configured to maintain fluid communication between the second subsea conduit and the second offshore conduit via the second fluid flow path, and the apparatus is configured to transfer a fluid having a boiling point below ambient temperature at atmospheric pressure to or from a fluid storage tank.

[0103] A2. The apparatus of A1, wherein the mooring structure comprises a fixed portion rotatably connected to the rotating portion, and the fixed portion of the fluid swivel is connected to the fixed portion of the mooring structure.

[0104] A3. The apparatus of A1 or A2, wherein the apparatus is configured to transfer ammonia or liquid petroleum gas.

[0105] A4. The apparatus of any one of A1 to A3, wherein the apparatus is configured to limit pressure within the first subsea conduit, the second subsea conduit, the first offshore conduit, the crossing conduit, the second offshore conduit, the first fluid flow path defined by the fluid swivel, and the second fluid flow path defined by the fluid swivel to less than 2,100 kPa absolute.

[0106] A5. The apparatus of any one of A2 to A4, wherein the mooring structure is a catenary anchor leg mooring buoy configured to float on the surface of the body of water, the catenary anchor leg mooring buoy further comprising a mooring leg having a first end configured to be coupled to a fixed portion of the mooring structure and a second end configured to be coupled to the seabed, and the catenary anchor leg mooring buoy is configured to moor the vessel to the rotating portion of the mooring structure.

[0107] A6. The apparatus of A5, wherein the first offshore conduit comprises a first rigid conduit configured to be disposed on a rotating portion of a mooring structure and a first floating conduit configured to be in fluid communication with each other and to float on the surface of the body of water, the first floating conduit configured to be fluidly connected to a fluid storage tank.

[0108] A7. The apparatus of A5 or A6, wherein the second marine conduit comprises a second rigid conduit configured to be disposed on a rotating portion of the catenary anchor leg mooring buoy and a second floating conduit configured to float on or near the surface of the body of water in fluid communication with each other, the second floating conduit configured to fluidly connect to a fluid storage tank.

[0109] A8. The apparatus of A7, wherein a first end of the first floating conduit is configured to be connected to the first rigid conduit, a second end of the first floating conduit is configured to float on or near the surface of the body of water, and a first end of the second floating conduit is configured to be connected to the second rigid conduit, and a second end of the second floating conduit is configured to float on or near the surface of the body of water.

[0110] A9. The apparatus of A8, wherein the crossover conduit is configured to be connected to the first rigid conduit and the second rigid conduit, the crossover conduit being configured to be disposed on the rotating portion of the buoy.

[0111] A10. The apparatus of A9, wherein the crossover conduit is a first crossover conduit, the crossover valve is a first crossover valve, and further comprising a second crossover conduit comprising a second crossover valve, the second crossover conduit being connected to second ends of the first floating conduit and the second floating conduit and configured to provide fluid communication between the first floating conduit and the second floating conduit.

[0112] A11. The apparatus of A8, wherein the crossover conduit is configured to be connected to the second end of the first floating conduit and to the second end of the second floating conduit.

[0113] A12. The apparatus of any one of A9 to A11, further comprising a subsea crossover conduit comprising a subsea crossover valve, the subsea crossover conduit configured to provide fluid communication between the first subsea conduit and the second subsea conduit.

[0114] A13. The apparatus of any one of A5 to A12, wherein the first subsea conduit is arranged in a steep S-shape, a shallow S-shape, or a lantern shape.

[0115] A14. The apparatus of any one of A5 to A13, wherein the second subsea conduit is configured in a steep S-shape, a shallow S-shape, or a lantern shape.

[0116] A15. The apparatus of any one of A5 to A14, wherein the catenary anchor leg mooring buoy is a turntable buoy or a turret buoy.

[0117] A16. The apparatus of any one of A5 to A15, wherein the crossover valve, if present, the second crossover valve, or the subsea crossover valve, if present, is individually configured as a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve.

[0118] A17. The apparatus of any one of A1 to A16, wherein the apparatus is configured to convey a fluid, such as a liquid, a boil-off gas, or a combination thereof.

[0119] A18. The apparatus of any one of A1 to A17, wherein the apparatus is configured to convey fluid through the first subsea conduit, the fluid swivel, the first offshore conduit, and to a fluid storage tank located on the vessel.

[0120] A19. The apparatus of any one of A1 to A17, wherein the apparatus is configured to convey fluid through the first subsea conduit, the first fluid flow path defined by the fluid swivel, a portion of the first offshore conduit, the crossing conduit, at least a portion of the second offshore conduit, the second fluid flow path defined by the fluid swivel, and the second subsea conduit to a second subsea pipeline.

[0121] A20. The apparatus of any one of A2 to A4, wherein the mooring structure is a marine loading tower, the fixed portion of the mooring structure is a base having a first end fixed to the seabed and a second end disposed above the water surface of the body of water, the rotating portion of the mooring structure comprises a turntable, and the marine loading tower further comprises a loading arm disposed on the turntable, and the marine loading tower is configured to moor the vessel to the rotating portion of the turntable, the loading arm, or a combination thereof.

[0122] A21. The apparatus of A20, wherein the first marine conduit comprises a first rigid marine conduit configured to be disposed on the turntable and loading arm, and a first flexible conduit configured to be suspended from the loading arm in fluid communication with each other, the first flexible conduit configured to be fluidly connected to a fluid storage tank.

[0123] A22. The apparatus of A20 or A21, wherein the second offshore conduit comprises a second rigid offshore conduit configured to be disposed on the turntable and loading arm, and a second flexible conduit configured to be suspended from the loading arm in fluid communication with each other, the second flexible conduit configured to be fluidly connected to the fluid storage tank.

[0124] A23. The apparatus of A22, wherein a first end of the first flexible conduit is configured to be connected to a first rigid conduit, a second end of the first flexible conduit is configured to be suspended from a loading arm, a first end of the second flexible conduit is configured to be connected to a second rigid conduit, and a second end of the second flexible conduit is configured to be suspended from a loading arm.

[0125] A24. The apparatus of A22 or A23, wherein the crossover conduit is configured to be connected to the first rigid offshore conduit and the second rigid offshore conduit, and the crossover conduit is configured to be positioned on the turntable and / or loading arm.

[0126] A25. The apparatus of A24, wherein the crossover conduit is a first crossover conduit, the crossover valve is a first crossover valve, and further comprising a second crossover conduit comprising a second crossover valve, the second crossover conduit being connected to second ends of the first flexible conduit and the second flexible conduit and configured to provide fluid communication between the first flexible conduit and the second flexible conduit.

[0127] A26. The apparatus of A23, wherein the crossover conduit is configured to connect to the second end of the first flexible conduit and to the second end of the second flexible conduit.

[0128] A27. The apparatus of any one of A20 to A26, wherein the crossover valve, the first crossover valve, and / or the second crossover valve, if present, are individually configured as a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve, respectively.

[0129] A28. The apparatus of any one of A20 to A27, wherein the apparatus is configured to convey a fluid, such as a liquid, a boil-off gas, or a combination thereof.

[0130] A29. The apparatus of any one of A20 to A27, wherein the apparatus is configured to convey fluid through the first subsea conduit, the fluid swivel, the first offshore conduit, and to a fluid storage tank located on the vessel.

[0131] A30. The apparatus of any one of A20 to A27, wherein the apparatus is configured to convey fluid through the first subsea conduit, the first fluid flow path defined by the fluid swivel, a portion of the first offshore conduit, the crossing conduit, at least a portion of the second offshore conduit, the second fluid flow path defined by the fluid swivel, and the second subsea conduit to a second subsea pipeline.

[0132] B1. A fluid transfer device, the device comprising: a mooring structure configured to be disposed within a body of water; a fluid swivel configured to be disposed on the mooring structure, the fluid swivel having a fixed portion rotatably coupled to a rotating portion, the fixed portion and rotating portion of the fluid swivel defining a fluid flow path therethrough; a first subsea conduit configured to provide fluid communication between a first pipeline disposed on the seabed and the fluid flow path defined by the fluid swivel; a second subsea conduit configured to fluidly communicate with a second pipeline disposed on the seabed; a fluid storage tank disposed on a vessel; an offshore conduit configured to fluidly connect a storage tank and a fluid flow path defined by a fluid swivel, the offshore conduit comprising a valve and a crossover conduit comprising a crossover valve, wherein a fixed portion of the fluid swivel is coupled to a mooring structure, the crossover conduit is configured to provide fluid communication between a first subsea conduit and a second subsea conduit, and the flow path defined by the fluid swivel is configured to maintain fluid communication between the first subsea conduit and the offshore conduit, and the apparatus is configured to transfer a fluid having a boiling point below ambient temperature at atmospheric pressure to or from the fluid storage tank.

[0133] B2. The apparatus of B1, wherein the mooring structure comprises a fixed portion rotatably connected to the rotating portion, and the fixed portion of the fluid swivel is connected to the fixed portion of the mooring structure.

[0134] B3. An apparatus as in B1 or B2 where the fluid contains ammonia or one or more hydrocarbons.

[0135] B4. The apparatus of any one of B1 to B3, wherein the apparatus is configured to limit pressure within a flow path defined by the first subsea conduit, the second subsea conduit, the first offshore conduit, the crossing conduit, the second offshore conduit, and the fluid swivel to less than 2,100 kPa absolute.

[0136] B5. The apparatus of any one of B2 to B4, wherein the mooring structure is a catenary anchor leg mooring buoy floating on the surface of the body of water, the catenary anchor leg mooring buoy further comprising a mooring leg having a first end configured to be coupled to a fixed portion of the mooring structure and a second end configured to be coupled to the seabed, and the catenary anchor leg mooring buoy is configured to moor the vessel to the rotating portion of the mooring structure.

[0137] B6. The apparatus of B5, wherein the offshore conduit comprises a rigid conduit disposed on a rotating portion of the catenary anchor leg mooring buoy and a floating conduit in fluid communication with each other and configured to float on or near the surface of the body of water.

[0138] B7. The apparatus of B5 or B6, wherein the first subsea conduit is arranged in a steep s-shape, a gentle s-shape, or a lantern shape.

[0139] B8. The apparatus of any one of B5 to B7, wherein the catenary anchor leg mooring buoy is a turntable buoy or a turret buoy.

[0140] B9. The apparatus of any one of B1 to B8, wherein the apparatus is configured to convey a fluid, such as a liquid, a boil-off gas, or a combination thereof.

[0141] B10. The apparatus of any one of B2 to B4, wherein the mooring structure is a marine loading tower, the fixed portion of the mooring structure comprises a base having a first end fixed to the seabed and a second end disposed above the surface of the body of water, the rotating portion of the mooring structure comprises a turntable, and the marine loading tower further comprises a loading arm disposed on the turntable, and the marine loading tower is configured to moor the vessel to the rotating portion of the turntable, the loading arm, or a combination thereof.

[0142] B11. The apparatus of B10, wherein the offshore conduit comprises a rigid offshore conduit configured to be disposed on the turntable and loading arm and a flexible conduit configured to be suspended from the loading arm in fluid communication with each other, the flexible conduit configured to be fluidly connected to a fluid storage tank.

[0143] B12. The apparatus of B11, wherein a first end of the flexible conduit is configured to be connected to the rigid offshore conduit and a second end of the flexible conduit is configured to be suspended from the loading arm.

[0144] B13. The apparatus of B12, wherein the crossover conduit is configured to be disposed with respect to its first end on the base.

[0145] B14. The apparatus of any one of B10 to B13, wherein the crossover valve is configured as a pressure relief valve, a pressure control valve, a remotely operated valve, or a manually operated valve.

[0146] B15. The apparatus of any one of B10 to B14, wherein the apparatus is configured to convey a fluid, such as a liquid, a boil-off gas, or a combination thereof.

[0147] B16. The apparatus of any one of B10 to B14, wherein the apparatus is configured to convey fluid through the first subsea conduit, the fluid flow path defined by the fluid swivel, and the offshore conduit to a fluid storage tank located on the vessel.

[0148] B17. The apparatus of any one of B10 to B14, wherein the apparatus is configured to convey fluid through a portion of the first subsea conduit, the crossover conduit, a portion of the second subsea conduit, and to a second pipeline.

[0149] C1. A method for transferring a fluid, the method comprising mooring a vessel to a mooring structure disposed within a body of water, the mooring structure comprising: a fluid swivel disposed on the mooring structure, the fluid swivel having a fixed portion rotatably coupled to a rotating portion, the fixed portion and rotating portion of the fluid swivel defining isolated first and second fluid flow paths therethrough; a first pipeline disposed on the seabed and a first subsea conduit in fluid communication with the first fluid path defined by the fluid swivel; a second pipeline disposed on the seabed and a second subsea conduit in fluid communication with the second fluid flow path defined by the fluid swivel, a first offshore conduit in fluid communication with the first fluid flow path defined by the fluid swivel, the first offshore conduit configured to fluidly connect to a fluid storage tank located on the vessel, the first offshore conduit comprising a valve, a second offshore conduit in fluid communication with the second fluid flow path defined by the fluid swivel, the second offshore conduit configured to fluidly connect to the fluid storage tank, the second offshore conduit comprising a valve, and a crossover conduit comprising a crossover valve, the crossover conduit configured to fluidly connect to the first offshore conduit. a cross-conduit in fluid communication with the conduit and a second offshore conduit, wherein a fixed portion of the fluid swivel is coupled to the mooring structure, the fixed portion of the fluid swivel and the rotating portion of the fluid swivel maintaining fluid communication between the first subsea conduit and the first offshore conduit via a first fluid flow path, and the fixed portion of the fluid swivel and the rotating portion of the fluid swivel maintaining fluid communication between the second subsea conduit and the second offshore conduit via a second fluid flow path, and the method includes connecting the first offshore conduit to a fluid storage tank located on the vessel, closing a valve of the first offshore conduit, and opening a cross-conduit. and flowing a fluid from the first subsea pipeline through the first subsea conduit, the first fluid flow path defined by the fluid swivel, at least a portion of the first subsea conduit, the crossover conduit, at least a portion of the second subsea conduit, the second fluid flow path defined by the fluid swivel, and the second subsea conduit to the second subsea pipeline, wherein the fluid has a boiling point at atmospheric pressure that is lower than ambient temperature; closing the crossover valve; opening the valve of the first subsea conduit; and flowing a fluid from the first subsea pipeline through the first subsea conduit and through the first fluid flow path defined by the fluid swivel;A method comprising: flowing a fluid through a first offshore conduit to a fluid storage tank located on a vessel; closing a valve on the first offshore conduit; and opening a crossover valve.

[0150] C2. The method of C1, further comprising, prior to flowing the fluid, flowing an inert gas from the first subsea pipeline, through the first subsea conduit, through a first fluid flow path defined by the fluid swivel, through at least a portion of the first offshore conduit, through the crossover conduit, through at least a portion of the second offshore conduit, through a second fluid flow path defined by the fluid swivel, and through the second subsea conduit to the second subsea pipeline, and stopping the flow of the inert gas.

[0151] C3. The method of C1 or C2, wherein reopening the crossover valve after the valve of the first offshore conduit is closed allows at least a portion of the boil-off steam to flow into the second subsea pipeline.

[0152] C4. The method of any one of C1 to C3, wherein the mooring structure is a marine loading tower or a catenary anchor leg mooring buoy.

[0153] D1. A method for transferring a fluid, the method comprising mooring a vessel to a mooring structure disposed within a body of water, the mooring structure comprising: a fluid swivel disposed on the mooring structure, the fluid swivel having a fixed portion rotatably coupled to a rotating portion, the fixed and rotating portions of the fluid swivel defining a fluid flow path therethrough; a first pipeline disposed on the seabed and a first subsea conduit in fluid communication with the fluid flow path defined by the fluid swivel, the first subsea conduit comprising a valve; a second subsea conduit in fluid communication with a second pipeline disposed on the seabed; a fluid storage tank disposed on the vessel and an offshore conduit in fluid communication with the flow path defined by the fluid swivel, the offshore conduit comprising a valve; and a crossover conduit comprising a crossover valve; the crossover conduit is in fluid communication with the first subsea conduit and the second subsea conduit, and a fluid flow path defined by the fluid swivel is configured to maintain fluid communication between the first subsea conduit and the offshore conduit, the method comprising: closing a valve of the first subsea conduit; opening the crossover valve; flowing a fluid from the first subsea pipeline, through at least a portion of the first subsea conduit, through the crossover valve, through the second subsea conduit, and through the second subsea conduit to the second pipeline; closing the crossover valve; opening the valve of the first subsea conduit and the valve of the offshore conduit; flowing a fluid from the first subsea pipeline, through the first subsea conduit, through the flow path defined by the fluid swivel, and through the first offshore conduit to a storage tank disposed on the vessel; closing the valve of the first offshore conduit; and reopening the crossover valve.

[0154] D2. The method of D1, further comprising, prior to flowing the fluid, flowing an inert gas from the first subsea pipeline, through at least a portion of the first subsea conduit, through the crossover conduit, through the second subsea conduit, and to the second subsea pipeline, and stopping the flow of the inert gas.

[0155] D3. The method of D1 or D2, wherein reopening the crossover valve after the valve of the first offshore conduit is closed allows at least a portion of the boil-off steam to flow through the second subsea conduit to the second subsea pipeline.

[0156] D4. The method of any one of D1 to D3, wherein the mooring structure is a marine loading tower or a catenary anchor leg mooring buoy.

[0157] E1. A fluid transfer device, the device comprising: a mooring structure configured to be disposed within a body of water, the mooring structure comprising a fixed portion rotatably coupled to a rotating portion; a fluid swivel configured to be disposed on the mooring structure, the fluid swivel comprising a fixed portion rotatably coupled to a rotating portion, the fixed and rotating portions of the fluid swivel defining isolated first and second fluid flow paths therethrough, the fixed portion of the fluid swivel being connected to the fixed portion of the mooring structure; a first subsea conduit configured to provide fluid communication between a first pipeline disposed on the seabed and the first fluid flow path defined by the fluid swivel; a second subsea conduit configured to provide fluid communication between a second pipeline disposed on the seabed and the second fluid flow path defined by the fluid swivel; a first offshore conduit configured to fluidly connect a fluid storage tank disposed on a vessel with the first fluid flow path defined by the fluid swivel, the first offshore conduit having a valve a first offshore conduit comprising: a first offshore conduit configured to fluidly connect a fluid storage tank and a second fluid flow path defined by a fluid swivel, the second offshore conduit comprising a valve; and a crossover conduit comprising a crossover valve configured to provide fluid communication between (i) the first offshore conduit and the second offshore conduit; (ii) the first subsea conduit and the second subsea conduit; or (iii) between the first subsea conduit and any seabed-located third pipeline. wherein the fixed portion of the fluid swivel and the rotating portion of the fluid swivel are configured to maintain fluid communication between a first subsea conduit and a first offshore conduit via a first fluid flow path, and the fixed portion of the fluid swivel and the rotating portion of the fluid swivel are configured to maintain fluid communication between a second subsea conduit and a second offshore conduit via a second fluid flow path, and the apparatus is configured to transfer a fluid having a boiling point below ambient temperature at atmospheric pressure to or from a fluid storage tank.

[0158] E2. The apparatus of E1, wherein the first marine conduit is configured to fluidly connect to a loading pipe located on the vessel and configured to be in fluid communication with a fluid storage tank, the second marine conduit is configured to fluidly connect to a discharge pipe located on the vessel and configured to be in fluid communication with the fluid storage tank, and the crossover conduit is located on the vessel and configured to be in fluid communication with the loading pipe and the discharge pipe to provide fluid communication between the first marine conduit and the second marine conduit when the crossover valve is in an open position.

[0159] E3. The apparatus of E2, wherein the loading pipe and the discharge pipe each include at least one valve between the fluid storage tank and the crossover conduit.

[0160] E4. The apparatus of E3, wherein at least one valve of the loading pipe and at least one valve of the discharge pipe are configured to be in a closed position when the crossover valve is in an open position to provide fluid communication between the first offshore conduit and the second offshore conduit.

[0161] E5. The device of any one of E1 to E4, wherein the mooring structure is a catenary anchor leg mooring buoy configured to float on the surface of the body of water, and the device further comprises a mooring leg having a first end configured to be coupled to a fixed portion of the mooring structure and a second end configured to be coupled to the seabed, and wherein the catenary anchor leg mooring buoy is configured to moor the vessel to the rotating portion of the mooring structure.

[0162] E6. The apparatus of any one of E1 to E4, wherein the mooring structure is a marine loading tower, the fixed portion of the mooring structure comprises a base having a first end fixed to the seabed and a second end disposed above the surface of the body of water, the rotating portion of the mooring structure comprises a turntable, and the marine loading tower further comprises a loading arm disposed on the turntable, and the marine loading tower is configured to moor a vessel to the rotating portion of the turntable or the loading arm.

[0163] E7. The apparatus of any one of E1 to E6, wherein the apparatus is configured to transfer ammonia or liquid petroleum gas.

[0164] E8. The apparatus of any one of E1 to E7, wherein the apparatus is configured to limit pressure in the first subsea conduit, the second subsea conduit, the first offshore conduit, the crossing conduit, the second offshore conduit, the first fluid flow path defined by the fluid swivel, and the second fluid flow path defined by the fluid swivel to less than 2,100 kPa absolute.

[0165] E9. The apparatus of any one of E1 to E8, wherein the crossover conduit is configured to provide fluid communication between the first offshore conduit and the second offshore conduit.

[0166] E10. The apparatus of any one of E1 to E8, wherein the crossover conduit is configured to provide fluid communication between the first subsea conduit and the second subsea conduit.

[0167] E11. The apparatus of any one of E1 to E8, wherein an optional third pipeline is present and the crossover conduit is configured to provide fluid communication between the first subsea conduit and the third pipeline.

[0168] E12. The apparatus of any one of E1 to E8, wherein the crossover conduit is a first crossover conduit comprising a first crossover valve, and the apparatus further comprises a second crossover conduit comprising a second crossover valve, the first crossover conduit configured to provide fluid communication between the first offshore conduit and the second offshore conduit, and the second crossover conduit configured to provide fluid communication between the first subsea conduit and the second subsea conduit or between the first subsea conduit and any third pipeline located on the seabed.

[0169] E13. The apparatus of any one of E1 to E8, wherein the crossover conduit is a first crossover conduit comprising a first crossover valve, a third pipeline is present, and the apparatus further comprises a second crossover conduit comprising a second crossover valve and a third crossover conduit comprising a third crossover valve, wherein the first crossover conduit is configured to provide fluid communication between the first offshore conduit and the second offshore conduit, the second crossover conduit is configured to provide fluid communication between the first subsea conduit and the second subsea conduit, and the third crossover conduit is configured to provide fluid communication between the first subsea conduit and the third pipeline.

[0170] Certain embodiments and features are described using a set of upper numerical limits and a set of lower numerical limits. Unless otherwise stated, it is understood that ranges including any combination of two values are contemplated, for example, any lower limit with any upper limit, any two lower limits, and / or any two upper limits. Specific lower limits, upper limits, and ranges are set forth in one or more claims below. All numerical values are expressed as "about" or "approximately" and take into account experimental error and variations that would be expected by one of ordinary skill in the art.

[0171] Various terms are defined above. If a term used in the claims cannot be defined above, it should be given the broadest definition given to that term by one of ordinary skill in the art, as set forth in at least one printed publication or issued patent. Furthermore, all patents, test procedures, and other documents cited in this application are incorporated by reference in their entirety to the extent such disclosure is not inconsistent with this application and to the full extent such incorporation is permissible.

[0172] While certain preferred embodiments of the present invention have been illustrated and described in detail above, it will be apparent that modifications and alterations thereof will occur to those skilled in the art. It is therefore to be clearly understood that such modifications and alterations can be devised without departing from the basic scope thereof, which scope is defined by the following claims.

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