Submarine hose configuration for transferring a gas from a buoy

Systems and processes for transferring a gas from a buoy. In one embodiment, the system can include a buoy floating in water. A fluid swivel assembly can be coupled to the buoy. The system can also include a gas submarine conduit and a pipeline end manifold located at a subsea location. The gas submarine conduit can be configured to transfer a gas between the fluid swivel assembly and the pipeline end manifold. The gas submarine conduit can include one or more negatively buoyant members coupled thereto. The one or more negatively buoyant members coupled to the gas submarine conduit can urge the gas submarine conduit toward a seafloor to maintain the gas submarine conduit in a Chinese lantern configuration.

BACKGROUND

Field

Embodiments described generally relate to offshore single point mooring marine terminals. More particularly, such embodiments relate to offshore mooring buoys configured to transfer fluids to and from a vessel moored thereto and processes for using same.

Description of the Related Art

In the drilling, production, and transportation of offshore liquid hydrocarbons, mooring buoys have been used to connect floating vessels to loading/unloading capabilities away from shore. A single point mooring (SPM) marine terminal includes a loading/unloading buoy anchored offshore that serves as a mooring link between geostatic subsea pipeline end manifold (PLEM) connections and the floating vessels. The buoy includes a material transfer system that transports liquid hydrocarbons between the pipeline end manifold and the vessel, for example from the pipeline end manifold into a vessel storage tank. The buoy connects to the pipeline end manifold using one or more submarine conduits, riser lines, or hoses. The pipeline end manifolds connect to pipelines that carry liquid hydrocarbons to and from near-shore or on-shore facilities or locations for distribution and/or processing.

During loading operations, a vessel is moored to a conventional single point mooring marine terminal. One or more floating transport lines or hoses are placed in fluid communication with the vessel storage tank and the single point mooring marine terminal. Liquid hydrocarbons are then conveyed from the pipeline, through the submarine lines, through the buoy, through the floating transport lines, and into the vessel storage tank(s). Conventional liquid hydrocarbon carrying vessel storage tanks are designed to safely operate within specified pressure ranges. As the liquid hydrocarbon is introduced into the vessel storage tank gas within the tank is displaced such that a pressure within the vessel storage tank can be maintained within the specified ranges. Current processes for controlling the pressure within the tank include venting, displacing, or discharging the vapors/gases directly to the atmosphere.

There is a need, therefore, for improved systems and processes for capturing gas displaced from vessel storage tanks during loading operations that avoid or substantially reduce gases from being introduced into the atmosphere.

SUMMARY

Systems and processes for transferring a gas from a buoy are provided. In one embodiment, the system can include a buoy floating in water. A fluid swivel assembly can be coupled to the buoy. The system can also include a gas submarine conduit and a pipeline end manifold located at a subsea location. The gas submarine conduit can be configured to transfer a gas between the fluid swivel assembly and the pipeline end manifold. The gas submarine conduit can include one or more negatively buoyant members coupled thereto. The one or more negatively buoyant members coupled to the gas submarine conduit can urge the gas submarine conduit toward a seafloor to maintain the gas submarine conduit in a Chinese lantern configuration.

In one embodiment, the process can include displacing a gas from a vessel storage tank by flowing a liquid into the vessel storage tank. The gas can flow from the vessel storage tank through a floating buoy to a gas pipeline end manifold located subsea. The gas can flow through a gas transfer conduit that can be in fluid communication with the vessel storage tank and the floating buoy, through the floating buoy, and through a gas submarine conduit that can be in fluid communication with the floating buoy and the gas pipeline end manifold. The gas submarine conduit can be configured in a Chinese lantern configuration between the floating buoy and the gas pipeline end manifold.

In one embodiment, the process can include displacing a gas from a vessel storage tank by flowing a liquid into the vessel storage tank. The gas can flow from the vessel storage tank through a floating buoy to a gas pipeline end manifold located subsea. The floating buoy can include a rotatable turntable. The rotatable turntable can include a fluid swivel assembly coupled thereto. The displaced gas can flow through a gas transfer conduit that is in fluid communication with the vessel storage tank and the fluid swivel assembly. The displaced gas can flow through the fluid swivel assembly and through a gas submarine conduit that is in fluid communication with the fluid swivel assembly and the gas pipeline end manifold. The gas submarine conduit can be configured in a Chinese lantern configuration between the floating buoy and the gas pipeline end manifold. The liquid can flow from a liquid pipeline end manifold located subsea, through a liquid submarine conduit that is in fluid communication with the liquid pipeline end manifold and the fluid swivel assembly, through the fluid swivel assembly, and through a liquid transfer conduit that is in fluid communication with the fluid swivel assembly and the vessel storage tank. The liquid submarine conduit can be configured in a Chinese lantern configuration, a steep-S configuration, or a lazy-S configuration between the buoy and the second subsea location.

DETAILED DESCRIPTION

A detailed description will now be 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 claims. Depending on the context, all references to the “invention”, in some cases, refer to certain specific or preferred embodiments only. In other cases, references to the “invention” refer to subject matter recited in one or more, but not necessarily all, of the claims. It is to be understood that the following disclosure describes several exemplary embodiments for implementing different features, structures, or functions of the invention. Exemplary embodiments of components, arrangements, and configurations are described below to simplify the present disclosure; however, these exemplary embodiments are provided merely as examples and are not intended to limit the scope of the invention. Additionally, the present disclosure may repeat reference numerals and/or letters in the various exemplary embodiments and across the Figures provided herein. This repetition is for the purpose of simplicity and clarity and does not in itself dictate a relationship between the various exemplary embodiments and/or configurations discussed in the Figures. Moreover, the formation of a first feature over or on a second feature in the description that follows includes embodiments in which the first and second features are formed in direct contact and also includes embodiments in which additional features are formed interposing the first and second features, such that the first and second features are not in direct contact. The exemplary embodiments presented below may be combined in any combination of ways, i.e., any element from one exemplary embodiment may be used in any other exemplary embodiment, without departing from the scope of the disclosure. The figures are not necessarily drawn to scale and certain features and certain views of the figures can be shown exaggerated in scale or in schematic for clarity and/or conciseness.

Additionally, certain terms are used throughout the following description and claims to refer to particular components. As one skilled in the art will appreciate, various entities may refer to the same component by different names, and as such, the naming convention for the elements described herein is not intended to limit the scope of the invention, unless otherwise specifically defined herein. Also, the naming convention used herein is not intended to distinguish between components that differ in name but not function. Furthermore, in the following discussion and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to.” Also, as used herein the indefinite articles ‘a’ and ‘an’ should be interpreted to mean “at least one” or “one or more.”

All numerical values in this disclosure are exact or approximate values (“about”) unless otherwise specifically stated. Accordingly, various embodiments of the disclosure may deviate from the numbers, values, and ranges disclosed herein without departing from the intended scope.

Further, the term “or” is intended to encompass both exclusive and inclusive cases, i.e., “A or B” is intended to be synonymous with “at least one of A and B,” unless otherwise expressly specified herein. The indefinite articles “a” and “an” refer to both singular forms (i.e., “one”) and plural referents (i.e., one or more) unless the context clearly dictates otherwise. The terms “up” and “down”; “upward” and “downward”; “upper” and “lower”; “upwardly” and “downwardly”; “above” and “below”; and other like terms used herein refer to relative positions to one another and are not intended to denote a particular spatial orientation since the apparatus and methods of using the same may be equally effective at various angles or orientations.

FIG. 1depicts a schematic elevation view of an illustrative single point mooring marine terminal101that includes a buoy115, for conveying a gas from a floating vessel104to a subsea location139, according to one or more embodiments. The buoy115can float in a body of water126. The buoy115can be coupled or otherwise secured to a seafloor108by one or more anchor legs103. The buoy115can be held in a relatively geostationary condition by the one or more anchor legs103. A floating vessel104can be moored to the buoy115. In some examples, the vessel104can be moored to the buoy115via a hawser arrangement141.

The hawser arrangement141can be or can include nylon rope that can be shackled to a mooring uni-joint107on the buoy115. A load pin150can be applied to the hawser arrangement141to measure hawser loads. The hawser arrangement141can be adapted or configured with one or more ropes depending, at least in part, on the tonnage of the floating vessel104. The ropes can be single-leg or grommet leg type ropes. By “vessel” it can be meant any type of floating structure including but not limited to tankers, boats, ships, and the like.

The buoy115can be a catenary anchor leg mooring (CALM) type buoy, as depicted, or a single anchor leg mooring (SALM) type buoy as described below. In some examples, the buoy115can be or can include the turntable116rotatably coupled to the buoy115, as depicted, which is typically referred to as a “turntable buoy”. In other examples, the buoy115can be or can include a rotatable floating buoy coupled to a relatively geostationary turret, which is typically referred to as a “turret buoy”. On a turret buoy, the turret can be suspended from a rotatable floating buoy and the turret can be coupled to the seafloor108. A fluid swivel assembly117can be coupled to the turntable116or the rotatable floating buoy. As such, the buoy115can be what is typically called a turret buoy, a turntable buoy, or a single anchor leg mooring type buoy. The floating vessel104can be moored to the turntable116or the rotatable floating buoy and can weathervane about or with the turntable116or the rotatable floating buoy, respectively.

The fluid swivel assembly117can include a first swivel section rotatably coupled to a second swivel section. A first gas transfer conduit120can be in fluid communication with the first swivel section and a second gas transfer conduit125can be in fluid communication with the second swivel section. The first gas transfer conduit120and the second gas transfer conduit125can be in fluid communication with a first flow path defined by the fluid swivel assembly117. The fluid swivel assembly117can be adapted or configured to maintain fluid communication between the first gas transfer conduit120and the second gas transfer conduit125during rotation therebetween and when there is no rotation therebetween.

In some embodiments, the fluid swivel assembly117can also include a first liquid transfer conduit160and a second liquid transfer conduit105. The first liquid transfer conduit160can be in fluid communication with the second swivel section and the second liquid transfer conduit105can be in fluid communication with the first swivel section. The first liquid transfer conduit160and the second liquid transfer conduit105can be in fluid communication with a second flow path defined by the fluid swivel assembly117. The fluid swivel assembly117can be adapted or configured to maintain fluid communication between the first liquid transfer conduit160and the second liquid transfer conduit105during rotation therebetween and when there is no rotation therebetween.

A first floating conduit110can be in fluid communication with the first gas transfer conduit120. For example, an end of the first gas transfer conduit120can be coupled to an end of the first floating conduit110. As further described below, the first floating conduit110can be adapted or configured to convey a gas from the vessel104and into the first gas transfer conduit120. In some embodiments, a second floating conduit111can be in fluid communication with the second liquid transfer conduit105. As further described below, the second floating conduit111can be adapted or configured to convey a liquid to the vessel104. An end of the second liquid transfer conduit105can be coupled to an end of the second floating conduit111.

The second gas transfer conduit125can be in fluid communication with a gas submarine conduit140, a pipeline end manifold133, and a gas pipeline134located at the subsea location139. The gas submarine conduit140can be adapted or configured to transfer the gas from the second gas transfer conduit in fluid communication with the fluid swivel assembly117to the pipeline end manifold133. As such, in some embodiments, the first floating conduit110, the first gas transfer conduit120, the fluid assembly117, the second gas transfer conduit125, and the gas submarine conduit140can be adapted or configured to convey the gas from the vessel104to the subsea location139, e.g., the pipeline end manifold133. In some embodiments, the first liquid transfer conduit160can be in fluid communication with a liquid submarine conduit145, the pipeline end manifold133, and a liquid pipeline128. The liquid submarine conduit145can be adapted or configured to transfer a liquid, e.g., a liquid hydrocarbon, from the pipeline end manifold133to the fluid swivel assembly117. As such, in some embodiments, the second floating conduit111, the first liquid transfer conduit160, the fluid swivel assembly117, the second liquid transfer conduit105, and the liquid submarine conduit145can be adapted or configured to convey the liquid from the subsea location139, e.g., the pipeline end manifold133, to the vessel104.

In some examples, the gas submarine conduit140can be configured in a Chinese lantern configuration between the buoy115and the subsea location139. The gas submarine conduit140can include one or more negatively buoyant members162coupled thereto between the pipeline end manifold133and the second gas transfer conduit125. In some examples, the one or more negatively buoyant members162can be coupled to the gas submarine conduit140between the pipeline end manifold133and a midpoint of the gas submarine conduit140. In other examples, one or more negatively buoyant members162can be coupled to the gas submarine conduit140between the pipeline end manifold133and the midpoint of the gas submarine conduit140and one or more negatively buoyant members162can be coupled to the gas submarine conduit140between the midpoint and the second gas transfer conduit125. In still other examples, the gas submarine conduit140can include one or more negatively buoyant members162and one or more positively buoyant members164coupled thereto between the pipeline end manifold133and the second gas transfer conduit125. In some embodiments, the positively buoyant member(s), if present, can be located between the midpoint and the second gas transfer conduit125, between the pipeline end manifold133and the midpoint, or a combination thereof. As such, in some embodiments, one or more negatively buoyant members162and, optionally, one or more positively buoyant members164can be distributed along the gas submarine conduit125to maintain the gas submarine conduit140in the Chinese lantern configuration.

The one or more negatively buoyant members162can urge the gas submarine conduit140toward a seafloor108to maintain the gas submarine conduit140in the Chinese lantern configuration. Similarly, the one or more negatively buoyant members162and the optional one or more positively buoyant members164can urge the gas submarine conduit140toward a seafloor108and away from the seafloor108, respectively, to maintain the gas submarine conduit140in the Chinese lantern configuration. In other examples, the gas submarine conduit140can be adapted or configured in a steep-S configuration or a lazy-S configuration between the buoy115and the subsea location139. The gas submarine conduit140can be adapted or configured to convey the gas from the fluid swivel assembly117to the subsea location139, e.g., the pipeline end manifold133. The one or more negatively buoyant members162can be made from any suitable material that can sink in water, including sea water. For example, the one or more negatively buoyant members162can be made from or include metal chains, cement, lead, natural stone, metal alloy, or other suitable materials. The one or more optional positively buoyant members164can be made from or include syntactic foams, foamed thermoset or thermoplastic materials, thermoset or thermoplastic materials filled with particles (such as glass, plastic, micro-spheres, and/or ceramics), rubber, nylon, composites of these materials, any other material buoyant in water, e.g., sea water, or any combination thereof.

The liquid submarine conduit145can be coupled between the pipeline end manifold133and the first liquid transfer conduit160. The liquid submarine conduit145can be adapted or configured in a Chinese lantern configuration, a steep-S configuration, or a lazy-S configuration between the buoy115and the subsea location139. For example, one or more negatively buoyant members162and one or more positively buoyant members164can be distributed along the liquid submarine conduit145to maintain the liquid submarine conduit145in the Chinese lantern configuration, the steep-S configuration, or the lazy-S configuration. The liquid submarine conduit145can be adapted or configured to convey the liquid from the subsea location139, e.g., the pipeline end manifold133, to the fluid swivel assembly117.

The gas submarine conduit140and the liquid submarine conduit145can be adapted or configured to compensate for motions of the buoy115. The gas submarine conduit140and liquid submarine conduit145can be flexible and can be any type of elongated conduit. The first floating conduit110, the second floating conduit111, the gas submarine conduit140, and the liquid submarine conduit145can be made from any suitable material. For example, the first floating conduit110, the second floating conduit111, the gas submarine conduit140, and the liquid submarine conduit145can be made from a synthetic fiber such as polyester or nylon filament, rubber, synthetic rubbers, metal alloys, or other suitable materials. It should be understood that any of the conduits, e.g., the first floating conduit110, the second floating conduit111, the gas submarine conduit140, the liquid submarine conduit145, etc., can each be or can each include a plurality of conduit segments connected together.

The first floating conduit110and the gas submarine conduit140can convey fluids such as the gas discharged from the floating vessel104. In some examples, the gas can be or can include an exhaust gas, air, an inert gas such as nitrogen or carbon dioxide, hydrocarbon gas, or any mixture thereof. In some examples, the exhaust gas can be from the vessel104and can include one or more contaminants. Such contaminants can be or can include, but are not limited to, oxides of sulfur (SOx), oxides of nitrogen (NOx), carbon monoxide, carbon dioxide, hydrocarbons, and carbon particles suspended in the gas, or any mixture thereof. The second floating conduit111and the liquid submarine conduit145can also convey fluids such as the liquid. The liquid can be or can include, but is not limited to, water, raw hydrocarbons such as crude oil or a fraction thereof, refined hydrocarbons such as, but not limited to, diesel fuel, jet fuel, kerosene, and/or gasoline, or any mixture thereof.

In some embodiments, electric power for safety lights and other equipment can be provided by a solar panel and power storage assembly142disposed on the buoy115, for example on an upper surface of the buoy115. In other examples, the electrical power can be provided via a power cable from an alternate location, for example, on-shore or the near-by platform.

FIG. 2depicts a schematic elevation view of another illustrative buoy215, according to one or more embodiments.FIG. 3depicts a schematic plan view of the buoy215shown inFIG. 2. The buoy215can be substantially similar to buoy115. The buoy215can include a fluid swivel assembly217coupled thereto. The fluid swivel assembly217can include a first swivel section218rotatably coupled to a second swivel section219. A first gas transfer conduit220can be in fluid communication with the first swivel section218and a second gas transfer conduit225can be in fluid communication with the second swivel section219. The first gas transfer conduit220can be in fluid communication with a first flow path defined by the first swivel section218and the second gas transfer conduit225can be in fluid communication with a first flow path defined by the second swivel section219. In some examples, the second gas transfer conduit225can extend from the second swivel section219and transition into two or more second gas transfer conduits228(two are shown). The first swivel section218and the second swivel section219can be adapted or configured to maintain fluid communication between the first gas transfer conduit220and the second gas transfer conduit225during rotation therebetween and when there is no rotation therebetween.

A first liquid transfer conduit260(two are shown) and a second liquid transfer conduit205(two are shown) can also be coupled to the fluid swivel assembly217as discussed above with regard toFIG. 1. The first liquid transfer conduit260can be in fluid communication with the second swivel section219and the second liquid transfer conduit205can be in fluid communication with the first swivel section218. The first liquid transfer conduit260can be in fluid communication with a second flow path defined by the second swivel section219and the second liquid transfer conduit205can be in fluid communication with a second flow path defined by the first swivel section218. The first swivel section218and the second swivel section219can be adapted or configured to maintain fluid communication between the first liquid transfer conduit260and the second liquid transfer conduit205during rotation therebetween and when there is no rotation therebetween.

Two or more second floating conduits111(two are shown) can be in fluid communication with the two or more second liquid transfer conduits205(two are shown). The end of the first gas transfer conduit220and the end of the second liquid transfer conduit205can have a declination angle ∂ relative to a local horizontal252of the buoy215. Accordingly, a portion of the first floating conduit110can have the declination angle ∂. In some embodiments, the declination angle ∂ can be from about five degrees to about forty degrees from the local horizontal252. It should be noted that the local horizontal252may stay static with regard to the buoy215while a declination angle relative to a surface of a body of water126may change with wave action and other perturbations of the buoy215.

In some embodiments, electric power for safety lights and other equipment can be produced by a solar panel and power storage assembly142disposed on the buoy215, for example on an upper surface of the buoy215. In other examples, the electrical power can be provided via a power cable from an alternate location, for example, on-shore or a near-by platform.

FIG. 4depicts a schematic elevation view of another illustrative single point mooring marine terminal401, according to one or more embodiments.FIG. 5depicts a schematic plan view of the single point mooring marine terminal401shown inFIG. 4. The floating vessel104can include a vessel storage tank410that can include the gas. For example, the floating vessel104can be a floating production, storage, and offloading (FPSO) vessel, a floating storage and offloading (FSO) vessel, or a conventional liquid carrying tanker which may be a very large crude carriers (VLCC), and ultra large crude carriers (ULCCs) or any other size liquid carrying tanker.

Referring now toFIGS. 2, 4, and 5, in some examples, the second gas transfer conduit225can be in fluid communication with the gas submarine conduit140(two are shown) and a first pipeline end manifold415located at a first subsea location420. The gas submarine conduit140can be coupled between the first pipeline end manifold415and the second gas transfer conduit225for fluid communication therebetween. As shown, the gas submarine conduit140can include a first submarine conduit441and a second submarine conduit442. The gas submarine conduit140can be coupled between the first pipeline end manifold415and the two or more second gas transfer conduits228for fluid communication therebetween.

The first floating conduit110can be in fluid communication with the vessel storage tank410. The second gas transfer conduit225can be in fluid communication with the first pipeline end manifold415, e.g., via the gas submarine conduit140. In some examples, the two or more second gas transfer conduits228can be in fluid communication with the first pipeline end manifold415. The first floating conduit110, the first gas transfer conduit220, the second gas transfer conduit225, and the gas submarine conduit140can be adapted or configured to transfer or convey the gas displaced or otherwise conveyed from the floating vessel104, for example from the vessel storage tank410, to the first pipeline end manifold415located at the first subsea location420. The gas can be displaced from the vessel storage tank410to keep a pressure within the vessel storage tank410within specified ranges when introducing the liquid into the vessel storage tank410.

The gas pipeline430can be in fluid communication with and span from the first pipeline end manifold415to another location, such as a near-shore or on-shore facility or location. The first floating conduit110, the first gas transfer conduit220, the second gas transfer conduit225, the gas submarine conduit140, the first pipeline end manifold415, and the gas pipeline430can be adapted or configured to transfer or convey the gas from the floating vessel104and/or the vessel storage tank410to the near-shore or on-shore location.

The first liquid transfer conduit260can be in fluid communication with the liquid submarine conduit145(two are shown) and a second pipeline end manifold425located at a second subsea location427. The second pipeline end manifold425can be in fluid communication with a liquid pipeline428. The liquid pipeline428can be in fluid communication with and span from the second pipeline end manifold425to another location, such as the near-shore or on-shore facility or location. The second floating conduit111can be in fluid communication with the floating vessel104and/or the vessel storage tank410. The liquid pipeline428, the second pipeline end manifold425, the liquid submarine conduit145, the first liquid transfer conduit260, the second liquid transfer conduit205, and the second floating conduit111can be adapted or configured to convey the liquid, for example the liquid hydrocarbon, from the near-shore or on-shore location to the floating vessel104and/or the vessel storage tank410. The gas in the vessel storage tank410can be displaced from the vessel storage tank410simultaneously with the introduction of the liquid into the vessel storage tank410.

In some examples, the gas submarine conduit140can be configured in the Chinese lantern configuration between the buoy215and the first subsea location420. For example, the first and second submarine conduits441,442can each include one or more negatively buoyant members162coupled thereto between the first pipeline end manifold415and a midpoint of each of the first and second submarine conduits441,442. The one or more negatively buoyant members162can urge each of the first and second submarine conduits441,442toward the seafloor108to maintain the first and second submarine conduits441,442in the Chinese lantern configuration. In other examples, the gas submarine conduit140can be adapted or configured in a steep-S configuration or a lazy-S configuration between the buoy215and the first subsea location420.

As shown, the liquid submarine conduit145can include a third submarine conduit446and a fourth submarine conduit447. The third and fourth submarine conduits446,447can independently be configured in the Chinese lantern configuration, the steep-S configuration, or the lazy-S configuration between the buoy215and the second subsea location427. For example, one or more negatively buoyant members162and one or more positively buoyant members164can be distributed along each of the third and fourth submarine conduits446,447to maintain the third and fourth submarine conduits446,447in the Chinese lantern configuration, the steep-S configuration, or the lazy-S configuration.

In some examples, the pressure developed within the vessel storage tank410during liquid loading may not be sufficient to push the gas all the way through the gas pipeline430. Accordingly, one or more blowers435(three are shown) can be used to maintain the pressure within the vessel storage tank410within specified design ranges and/or can be used to move or otherwise urge the gas from the vessel storage tank410through the pipeline430. In some examples the blower435can be located at the first subsea location420, on the buoy215, floating adjacent the buoy215, on the floating vessel104, an adjacent platform, and/or on shore in fluid communication with the gas pipeline430. The blower435can be adapted or configured to provide a propulsive force within the conduits to assist the gas conveyance through the pipeline430. For example, the blower435can increase a mass flow of the gas that can be conveyed from the vessel storage tank410through the pipeline430to another location, such as the near-shore or on-shore facility or location. The blower435can induce or otherwise produce a partial vacuum and/or increase a pressure within the gas pipeline430, the first pipeline end manifold415, the gas submarine conduit140, the second gas transfer conduit225, the first gas transfer conduit220and/or the first floating conduit110, to draw or otherwise urge the gas from the vessel104such that the gas can be conveyed to another location, such as the near-shore or on-shore facility or location. The gas, once conveyed to the near-shore or on-shore facility or location, can be processed to reduce or remove at least a portion of one or more contaminants therefrom. In some examples, the gas can be an exhaust gas from the vessel that can include one or more contaminants.

FIGS. 6 and 7depict a schematic plan view and a schematic elevation view of the first pipeline end manifold415, according to one or more embodiments. The first pipeline end manifold415can include a first pipeline end conduit505disposed on a skid510. The skid510can be secured to the seafloor108by one or more piles515(four are shown) and/or ballast. The first pipeline end conduit505can include one or more valves540for fluid isolation within one or more portions of the first pipeline end conduit505. One or more first interface connectors520(two are shown) can provide fluid communication from the first interface connectors520to the gas pipeline430. The first pipeline end conduit505can have a U-shape or other curved shape to accommodate a pipeline pig for maintenance activities, for example for removal of a condensate from the first pipeline end manifold415and/or the gas pipeline430. A protective cage can surround the first pipeline end conduit505and/or the first pipeline end manifold415for protection from various environmental hazards.

FIGS. 8 and 9depict a schematic plan view and a schematic elevation view of the second pipeline end manifold425, according to one or more embodiments. The second pipeline end manifold425can include a second pipeline end conduit705disposed on a skid712. The skid712can be secured to the seafloor108by the one or more piles515(four are shown) and/or ballast. The second pipeline end conduit705can include one or more valves720for fluid isolation within one or more portions of the second pipeline end conduit705. One or more second interface connectors710(two are shown) can provide fluid communication from the second interface connectors710to the liquid pipeline428. A protective cage can surround the second pipeline end conduit705and/or the second pipeline end manifold425for protection from various environmental hazards.

It should be understood that although the first pipeline end manifold415and the second pipeline end manifold425are depicted as being located at two locations420,427on two different skids510,712at some distance from one another, the first and second pipeline end manifolds415,425can be located adjacent each other and/or formed or assembled on a single skid adapted or configured to accommodate the first pipeline end conduit505and the second pipeline end conduit705.

FIG. 10depicts a schematic of another illustrative single point mooring marine terminal1001that includes a single anchor leg mooring (SALM) type buoy315, according to one or more embodiments. The buoy315can be anchored to the seabed by a single anchor leg905. The single anchor leg905can be connected to a base910which can be ballasted and/or piled to a subsea location915. The single anchor leg905can be attached to the base910by either a chain or by an elongated conduit. One or more universal joints920(two are shown) can allow the buoy315and the floating vessel104to rotate about the anchor leg905and/or the base910. The first floating conduit110can be coupled to and in fluid communication with the gas submarine conduit140. The second floating conduit111can be coupled to and in fluid communication with the liquid submarine conduit145. Although described as separate conduits, the first floating conduit110and the gas submarine conduit140can be combined into a single gas conveyance conduit and the second floating conduit111and the liquid submarine conduit145can be combined into single liquid conveyance conduit.

The gas submarine conduit140can be in fluid communication with a first swivel section318and the gas pipeline430. The liquid submarine conduit145can be in fluid communication with the the first swivel section318and the liquid pipeline428. The first swivel section318and a second swivel section319can be adapted or configured to maintain fluid communication between the gas submarine conduit140and the gas pipeline430during rotation therebetween and when there is no rotation therebetween. The first swivel section318and the second swivel section319can be adapted or configured to maintain fluid communication between the liquid submarine conduit145and the liquid pipeline428during rotation therebetween and when there is no rotation therebetween. The liquid can be conveyed from the liquid pipeline428, through the liquid submarine conduit145, through the second floating conduit111and to the floating vessel104and/or the vessel storage tank410. Gas discharged from the floating vessel104and/or the vessel storage tank410can be conveyed through the first floating conduit110, through the gas submarine conduit140, through the gas pipeline430to another location, such as the near-shore or on-shore facility or location.

FIG. 11depicts a schematic elevation view of yet another illustrative single point mooring terminal1101, including another illustrative buoy1015, according to one or more embodiments.FIG. 12depicts a schematic plan view of another pipeline end manifold1115, according to one or more embodiments. The pipeline end manifold1115can be located at a subsea location1120and can include the first pipeline end conduit505and the second pipeline end conduit705disposed on a dual skid1110. The gas pipeline430can be in fluid communication with and span from the pipeline end manifold1115to another location, such as a near-shore or on-shore facility or location. The first floating conduit110, the gas submarine conduit140(one is shown), the first pipeline end conduit505, and the gas pipeline430can be adapted or configured to transfer or convey the gas from the floating vessel104and/or the vessel storage tank410to the near-shore or on-shore location.

The liquid pipeline428can be in fluid communication with and span from the pipeline end manifold1115to another location, such as the near-shore or on-shore facility or location. The liquid pipeline428, the second pipeline end conduit705, the liquid submarine conduit145(two are shown), and the second floating conduit111can be adapted or configured to convey the liquid, for example liquid hydrocarbons, from the near-shore or on-shore location to the floating vessel104and/or the vessel storage tank410. The gas in the vessel storage tank410can be displaced from the vessel storage tank410simultaneously with the introduction of the liquid into the vessel storage tank410.

In some examples, the gas submarine conduit140can be configured in a Chinese lantern configuration between the buoy1015and the subsea location1120. The gas submarine conduit140can include one or more negatively buoyant members162coupled thereto (ten are shown) between the pipeline end manifold1115and the buoy1015. In some examples, the one or more negatively buoyant members162can be coupled thereto between the pipeline end manifold1115and a midpoint of the gas submarine conduit140. In other examples, one or more negatively buoyant members162can be coupled to the gas submarine conduit140between the pipeline end manifold1115and the midpoint of the gas submarine conduit140and one or more negatively buoyant members162can be coupled to the gas submarine conduit140between the midpoint and the buoy1015.

The liquid submarine conduit145can be adapted or configured in a Chinese lantern configuration. For example, one or more positively buoyant members164can be distributed along the third submarine conduit446and the fourth submarine conduit447to maintain the liquid submarine conduit145in the Chinese lantern configuration. One or more positively buoyant members164and one or more negatively buoyant members162can be distributed along the third submarine conduit446and the fourth submarine conduit447to maintain the liquid submarine conduit145in the Chinese lantern configuration. The liquid submarine conduit145can be adapted or configured to convey the liquid from the subsea location1120, e.g., the pipeline end manifold1115, to the fluid swivel assembly117.

It should be understood that rather than a single point mooring marine terminal, other types of mooring systems can be used to moor the floating vessel during transfer or conveyance of the gas from the vessel to the subsea location. In some examples, the vessel can be moored via a spread mooring system during conveyance of the gas from the vessel to the subsea location. A suitable spread mooring system can include the disconnectable spread mooring and riser tower system disclosed in U.S. patent application Ser. No. 16/527,345. In other examples, the vessel can be moored via anstabilized mooring system such as the stabilized mooring system disclosed in U.S. Patent Application No. 62/888,940. In other examples, the vessel can be moored via a disconnectable tower yoke mooring system such as those disclosed in U.S. Pat. No. 9,650,110 and Patent Application Nos. 62/830,082; and 62/830,088.

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

1. A single point mooring marine terminal, comprising: a buoy floating in water; a fluid swivel assembly coupled to the buoy; a gas submarine conduit; and a pipeline end manifold located at a subsea location, wherein: the gas submarine conduit is configured to transfer a gas between the fluid swivel assembly and the pipeline end manifold, the gas submarine conduit comprises one or more negatively buoyant members coupled thereto, and the one or more negatively buoyant members coupled to the gas submarine conduit urge the gas submarine conduit toward a seafloor to maintain the gas submarine conduit in a Chinese lantern configuration.

2. The marine terminal of paragraph 1, wherein the gas submarine conduit is configured to transfer the gas from the fluid swivel assembly to the pipeline end manifold.

3. The marine terminal of paragraphs 1 or 2, further comprising: a liquid submarine conduit, wherein: the liquid submarine conduit is configured to transfer a liquid from the pipeline end manifold to the fluid swivel assembly, the liquid submarine conduit comprises one or more positively buoyant members coupled thereto between the pipeline end manifold and the fluid swivel assembly, and the one or more positively buoyant members urge the liquid submarine conduit away from the seafloor.

4. The marine terminal according to any of paragraphs 1 to 3, wherein: the gas submarine conduit is a first submarine conduit, the marine terminal further comprising: a second submarine conduit, wherein: the first and second submarine conduits are each configured to transfer a portion of the gas between the fluid swivel assembly and the pipeline end manifold, the second submarine conduits comprises one or more negatively buoyant members coupled thereto, and the one or more negatively buoyant members coupled to the second submarine conduit urge the second submarine conduit toward a seafloor to maintain the first and second submarine conduits in a Chinese lantern configuration.

5. The marine terminal according to any of paragraphs 1 to 4, wherein the gas comprises an exhaust gas.

6. The marine terminal according to any of paragraphs 1 to 5, wherein the pipeline end manifold located at the subsea location is a first pipeline end manifold located at a first subsea location, the marine terminal further comprising: a third submarine conduit; a fourth submarine conduit; and a second pipeline end manifold located at a second subsea location, wherein: the third and fourth submarine conduits are each configured to transfer a liquid from the second pipeline end manifold to the fluid swivel assembly, the third and fourth submarine conduits each comprise one or more positively buoyant members coupled thereto between the second pipeline end manifold and the fluid swivel assembly, and the one or more positively buoyant members urge each submarine conduit away from the seafloor.

7. The marine terminal according to any of paragraphs 1 to 6, further comprising: a rotatable turntable coupled to the buoy, wherein: the fluid swivel assembly is coupled to the rotatable turntable, and the fluid swivel assembly comprises a first swivel section rotatably coupled to a second swivel section; a first liquid transfer conduit; a second liquid transfer conduit; and a gas transfer conduit; wherein: the third and fourth submarine conduits are in fluid communication with a first flow path defined by the second swivel section, the first and second submarine conduits are in fluid communication with a second flow path defined by the second swivel section, the first swivel section and the second swivel section are configured to maintain fluid communication between the first and second liquid transfer conduits and the third and fourth submarine conduits, respectively, during rotation therebetween, the first swivel section and the second swivel section are configured to maintain fluid communication between the gas transfer conduit and the first and second submarine conduits during rotation therebetween, and the gas transfer conduit, the fluid swivel assembly, and the first and second submarine conduits are configured to transfer the gas from a vessel storage tank to the first pipeline end manifold.

8. The marine terminal according to any of paragraphs 1 to 7, wherein the third and fourth submarine conduits are independently configured in a Chinese lantern configuration, a steep-S configuration, or a lazy-S configuration between the buoy and the second subsea location.

9. The marine terminal according to any of paragraphs 1 to 8, wherein the third and fourth submarine conduits are each configured in a steep-S configuration or a lazy-S configuration between the buoy and the second subsea location.

10. The marine terminal according to any of paragraphs 1 to 9, wherein the first pipeline end manifold is configured to receive the gas from the first and second submarine conduits, and wherein the second pipeline end manifold is configured to introduce a liquid into the third and fourth submarine conduits.

11. The marine terminal according to any of paragraphs 1 to 10, wherein the third submarine conduit and the fourth submarine conduit are each in fluid communication at a first end with the second pipeline end manifold and are each in fluid communication at a second end with the vessel storage tank.

12. The marine terminal according to any of paragraphs 1 to 11, wherein the first and second submarine conduits are free of any positive buoyancy members configured to increase a buoyancy of the first and second submarine conduits between the buoy and the midpoint of each submarine conduit.

13. The marine terminal according to any of paragraphs 1 to 12, wherein the first and second submarine conduits are each in fluid communication at a first end with the pipeline end manifold and are each in fluid communication at a second end with the vessel storage tank.

14. The marine terminal according to any of paragraphs 1 to 13, further comprising a gas transfer conduit, wherein the gas transfer conduit is in fluid communication at a first end with the fluid swivel assembly and in fluid communication at a second end with the gas submarine conduit.

15. The marine terminal according to any of paragraphs 1 to 14, wherein the gas transfer conduit is configured to provide a pressure drop across a transition between the gas transfer conduit and the gas submarine conduit.

16. The marine terminal according to any of paragraphs 1 to 15, wherein the one or more negatively buoyant members are coupled to the gas submarine conduit between the pipeline end manifold and a midpoint of the gas submarine conduit.

17. A process for transferring a fluid through a single point mooring marine terminal, comprising: displacing a gas from a vessel storage tank by flowing a liquid into the vessel storage tank; and flowing the gas from the vessel storage tank through a floating buoy to a gas pipeline end manifold located subsea, wherein: the gas flows through a gas transfer conduit that is in fluid communication with the vessel storage tank and the floating buoy, through the buoy, and through a gas submarine conduit that is in fluid communication with the floating buoy and the gas pipeline end manifold, and the gas submarine conduit is configured in a Chinese lantern configuration between the floating buoy and the gas pipeline end manifold.

18. The process of paragraph 17, wherein the floating buoy comprises a rotatable turntable, wherein the rotatable turntable comprises a fluid swivel assembly coupled thereto, and wherein the fluid swivel assembly comprises a first swivel section rotatably coupled to a second swivel section.

19. The process of paragraph 17 or 18, wherein the liquid flows from a liquid pipeline end manifold located subsea, through the floating buoy, and into the vessel storage tank.

20. The process according to any of paragraphs 17 to 19, wherein the liquid from the second pipeline end manifold flows through a liquid submarine conduit that is in fluid communication with the liquid pipeline end manifold and the floating buoy, through the buoy, and through a liquid transfer conduit that is in fluid communication with the floating buoy and the vessel storage tank.

21. The process according to any of paragraphs 17 to 20, wherein the liquid submarine conduit is configured in a Chinese lantern configuration, a steep-S configuration, or a lazy-S configuration between the buoy and the second subsea location.

22. The process according to any of paragraphs 17 to 21, wherein the liquid submarine conduit is configured in a steep-S configuration or a lazy-S configuration between the buoy and the second subsea location.

23. The process according to any of paragraphs 17 to 22, wherein: the floating buoy comprises a rotatable turntable, the rotatable turntable comprises a fluid swivel assembly coupled thereto, the fluid swivel assembly comprises a first swivel section rotatably coupled to a second swivel section, the first swivel section and the second swivel section are configured to maintain fluid communication between the liquid transfer conduit and the liquid submarine conduit during rotation therebetween, and the first swivel section and the second swivel section are configured to maintain fluid communication between the gas transfer conduit and the gas submarine conduit during rotation therebetween.

24. The system or process according to any of paragraphs 1 to 23, wherein the gas comprises an exhaust gas, air, an inert gas, a hydrocarbon gas, or any mixture thereof.

25. The system or process according to any of paragraphs 1 to 24, the liquid comprises raw hydrocarbons such as crude oil or a fraction thereof, refined hydrocarbons such as, but not limited to, diesel fuel, jet fuel, kerosene, and/or gasoline, water, or any mixture thereof.

26. The system or process according to any of paragraphs 1 to 25, wherein the buoy is a single point mooring marine terminal.

27. A process for transferring a fluid through a single point mooring marine terminal, comprising: displacing a gas from a vessel storage tank by flowing a liquid into the vessel storage tank; and flowing the gas from the vessel storage tank through a floating buoy to a gas pipeline end manifold located subsea, wherein: the floating buoy comprises a rotatable turntable comprising a fluid swivel assembly coupled thereto, the displaced gas flows through a gas transfer conduit that is in fluid communication with the vessel storage tank and the fluid swivel assembly, through the fluid swivel assembly, and through a gas submarine conduit that is in fluid communication with the fluid swivel assembly and the gas pipeline end manifold, the gas submarine conduit is configured in a Chinese lantern configuration between the floating buoy and the gas pipeline end manifold, the liquid flows from a liquid pipeline end manifold located subsea, through a liquid submarine conduit that is in fluid communication with the liquid pipeline end manifold and the fluid swivel assembly, through the fluid swivel assembly, and through a liquid transfer conduit that is in fluid communication with the fluid swivel assembly and the vessel storage tank, and the liquid submarine conduit is configured in a Chinese lantern configuration, a steep-S configuration, or a lazy-S configuration between the buoy and the second subsea location.

While certain preferred embodiments of the present invention have been illustrated and described in detail above, it can be apparent that modifications and adaptations thereof will occur to those having ordinary skill in the art. It should be, therefore, expressly understood that such modifications and adaptations may be devised without departing from the basic scope thereof, and the scope thereof can be determined by the claims that follow.