Patent ID: 12240566

DETAILED DESCRIPTION OF THE INVENTION

The present disclosure describes scalable and interchangeable offshore floating platform systems. Embodiments described herein include a detachable floating buoy tethered to a seafloor with a plurality of mooring lines and coupled to a subsea production system via one or more communication lines. A plurality of floating surface facilities may each be able to mate with the detachable floating buoy via a standardized bottom interface without the need to use turrets or swivel systems. Rather, in contrast to turret-based systems incorporating swivels, the embodiments disclosed herein are able to deploy larger and more numerous risers, and are not constrained by the temperature and pressure limitations of swivels. Moreover, as the floating surface facilities individually mate with the detachable floating buoy, each floating surface facility may be placed in communication with the subsea production system via the communication lines. The systems described herein enables an operator to replace, swap out, or re-deploy floating surface facilities as needed to match the desired capacity through the field service life and/or reservoir depletion profile. Moreover, the systems described herein facilitate relatively quick, simple, and easy deployment and demobilization of offshore floating platform facilities to various locations, as needed. Consequently, an operator can maximize value from the deployed asset by using a correctly-sized floating platform facility that matches varying reservoir profiles through field service.

FIG.1is a schematic diagram of an example modular floating platform system100, according to one or more embodiments. As illustrated, the modular floating platform system100(hereafter “the system100”) includes a detachable floating buoy102configured to mate with a plurality of floating surface facilities, shown inFIG.1as a first floating surface facility104a, a second floating surface facility104b, and a third floating surface facility104c. The system100may be deployed or used in any body of water106, such as the ocean or any body of freshwater (e.g., lakes, inlets, etc.). In the illustrated embodiment, the system100is deployed in an offshore oceanic environment, and portions of the system100may be secured to a seafloor108at the bottom of the ocean.

As described in more detail below, the floating surface facilities104a-cmay each be matable with the detachable floating buoy102via a standardized bottom interface, but may be provided (manufactured) in varying sizes and exhibiting corresponding varying capabilities and capacities. The varying capabilities and capacities of the floating surface facilities104a-cmay prove advantageous in allowing an operator to use an appropriately sized floating surface facility104a-cbased on the current production profile of an offshore hydrocarbon field. As a result, operators are able to maximize capital value by using the most efficient (appropriate) floating surface facility104a-cthat matches a varying reservoir profile through field service.

The detachable floating buoy102may comprise a generally annular body110having a top112aand a bottom112b. A central aperture114is defined or provided by the body110and sized to mate with a standardized bottom interface136of each floating surface facility104a-c. In some embodiments, the central aperture114extends entirely through the body110between the top and the bottom112a,b, but could alternatively extend from the top112apast the bottom112b, without departing from the scope of the disclosure.

The detachable floating buoy102may be tethered to an anchoring system (not shown) at the seafloor108with a plurality of mooring lines116attached to the body110. In some embodiments, the buoy102is “spread moored” using mooring lines116that extend from several sides or locations about the outer periphery of the body110. This spread-moored arrangement helps to stabilize the system100when the detachable floating buoy102is mated with one of the floating surface facilities104a-cand also helps maintain the system100in place in the water106during use.

The detachable floating buoy102may also be in communication with a subsea production system118arranged at the seafloor108. The production system118may be configured to collect production fluids (e.g., liquid or gaseous hydrocarbons, water, etc.) from one or more hydrocarbon-bearing reservoirs. More specifically, the subsea production system118may include one or more subsea trees120(two shown) and the detachable floating buoy102may be communicably coupled to the subsea trees(s)120via one or more communication lines122. The communication lines122can include one or more riser conduits (e.g., pipes, hoses, etc.) for transferring production fluids (oil, gas, water, etc.) from the subsea tree(s)120to the detachable floating buoy102. The communication lines122can also include one or more umbilicals that facilitate the transfer of power, hydraulics, and/or communication signals to the subsea tree(s)120. Each umbilical may comprise, for example, a single conduit that includes a plurality of pipes, tubes, cables, fiber optics, or other channels used to convey utilities and communications within the conduit. Once the detachable floating buoy102successfully mates with one of the floating surface facilities104a-c, power, communication signals, and hydraulics may be transferred between the floating surface facility104a-cand the subsea production system118via the communication lines122to enable remote operation of the subsea production system118.

In some embodiments, the detachable floating buoy102may further include a ballast system124operable to adjust the buoyancy of the detachable floating buoy102and thereby adjust its depth within the water106and relative to the water surface126. The ballast system124may include one or more buoyancy connections128in fluid communication with one or more variable ballast tanks or compartments (not shown) provided within the body110. The ballast tanks may be flooded or evacuated either using gravity (e.g., passively) or using a pumping system (e.g., actively) to alter the buoyancy of the detachable floating buoy102and thereby adjust its depth.

In some embodiments, for example, the ballast system124may include one or more active pumps operable to pump water in or out of the ballast tanks and thereby adjust buoyancy. In such embodiments, an underwater vehicle130, such as a remotely operated vehicle (ROV) or an autonomous underwater vehicle (AUV), may connect to the detachable floating buoy102at the buoyancy connections128; e.g., via a hot stab connection. Once connected at the buoyancy connections128, the underwater vehicle130may operate the pumps included in the ballast system124and thereby flood or evacuate the variable ballast compartments, as desired. Alternatively, a combination of a support vessel (not shown) and a diver (not shown) may be able to accomplish the same operation by manually connecting the support vessel to the detachable floating buoy102at the buoyancy connections128.

In other embodiments, however, the underwater vehicle130or a diver may be able to open the ballast compartments at the buoyancy connections128and thereby flooding the variable ballast compartments and allow gravity to adjust the buoyancy (depth) of the detachable floating buoy102. Accordingly, the depth of the detachable floating buoy102may be adjusted independent of the floating surface facilities104a-cusing any combination of underwater vehicles130, divers, and support vessels.

In some embodiments, the ballast system124may be designed to achieve fixed buoyancy by using low density fixed buoyant materials, such as syntactic foam within the buoy structure. Such fixed buoyant materials may be arranged in specific fixed ballast compartments for managing buoy weight, buoyancy, and stability.

Each floating surface facility104a-cincludes a main floater body or hull134that allows the facilities104a-cto float on the water106at the water surface126. Each floating surface facility104a-calso carries with it or otherwise houses one or more topside modules132, also referred to as the “superstructure” of the floating surface facility104a-c. Example topside modules132can include, but are not limited to, accommodation, local equipment control rooms, subsea control, power generation and utilities, oil processing, gas processing, water processing, chemical handling, flare, metering skids, any combination thereof, and other modules or equipment common to offshore floating platforms.

Depending on which topside modules132are included, each floating surface facility104a-cmay be operated as a vessel or platform commonly employed in the oil and gas industry, including, but not limited to, a floating production storage and offloading (FPSO) vessel, a floating storage and offloading (FSO) vessel, a floating production unit (FPU) vessel, a floating liquefied natural gas (FLNG) platform, a floating storage regasification unit (FSRU) vessel, a floating storage regasification unit-power and water (FSRUPW) platform, a floating control station (FCS) vessel, or a ‘Floatel (Accommodation Vessel)’.

In other embodiments, however, the floating surface facilities104a-cmay be customized with topside modules132directed to other offshore operations, such as a floating desalination plant. In such embodiments, the topside modules132might include accommodation, power generation, water treatment, electrical transmission, etc. Accordingly, the presently disclosed system100is not limited to use in the oil and gas industry but is equally applicable to other industries outside of the oil and gas industry and that may require an offshore floating platform. Other applicable industries include, but are not limited to, (1) low-carbon and renewables industry applications, such as floating wind energy, wave energy, solar energy, carbon sequestration, etc., (2) space and aviation industry to aid launch and recovery of aircrafts or spacecraft and, (3) food industry applications, such as floating farms and food processing facilities. As will be appreciated, the topsides modules132and superstructure can be customized depending on the intended application.

As indicated above, each floating surface facility104a-cmay further include a standardized bottom interface designed to mate and connect with the detachable floating buoy102. More specifically, each floating surface facility104a-cmay include a plug portion136arranged at or near the bottom of the hull134and otherwise extending downward (deeper into the water106) therefrom. The plug portion136may be sized and shaped to be received within the central aperture114of the detachable floating buoy102.

Once the plug portion136is properly received within the central aperture114, the detachable floating buoy102may be mechanically coupled to the particular floating surface facility104a-cusing a latching mechanism138. The latching mechanism138may comprise any type of mechanical locking device including, but not limited to, latches, dogs, wedges, jacks, hooks, connectors, chains, ropes, electromagnets utilizing mechanical, hydraulic, pneumatic, electrical interfaces, or any combination thereof. In the illustrated embodiment, the latching mechanism138is shown as being arranged on the plug portion136, but could alternatively be arranged on the detachable floating buoy102. In other embodiments, corresponding portions of the latching mechanism138may be included on both the plug portion136and the detachable floating buoy102, without departing from the scope of the disclosure. Moreover, the latching system138may include multiple components included at multiple locations at the interface between the plug portion136and the central aperture114.

Each floating surface facility104a-cmay further include one or more communication couplings140configured to place the corresponding floating surface facility104a-cin communication with the communication lines122once the floating surface facility104a-cmates with the detachable floating buoy102. As illustrated, the communication coupling(s)140may be arranged on the plug portion136, and may configured to mate with the communication lines122terminating on the inner surface of the central aperture114. In other embodiments, however, the communication coupling(s)140may be arranged on the inner surface of the central aperture114, or corresponding portions of the communication coupling(s)140may be included on both the plug portion136and the detachable floating buoy102, without departing from the scope of the disclosure.

The communication couplings140may comprise any type of device or mechanism suitable for operatively and communicably coupling the corresponding floating surface facility104a-cto the communication lines122. In at least one embodiment, for example, the communication couplings140may comprise quick-stab type riser connectors or piping couplers to provide necessary latching and sealing for communication of fluids, power and controls, without the need for turrets or swivels.

Once the communication lines122are properly mated with the communication couplings140, the contents within the riser conduits (e.g., oil, gas, water, etc.) may be transferred from the subsea production system118to the corresponding mated floating surface facility104a-c. Moreover, once the communication lines122are properly mated with the communication couplings140, power, electrical signals, and hydraulics, may be transferred within the umbilicals between the floating surface facility104a-cand the subsea production system118in either direction.

As illustrated, the floating surface facilities104a-cmay be manufactured in varying sizes and are thereby able to accommodate topside modules132appropriate for varying applications. In the illustrated embodiment, the first floating surface facility104ais larger than the second floating surface facility104b, which is larger than the third floating surface facility104c. As mentioned above, the varying sizes of the floating surface facilities104a-cmay prove advantageous in allowing an operator to employ an appropriately sized floating surface facility104a-cbased on the current production profile of the offshore hydrocarbon field.

For example, in the first five years of operation, the production profile of a given offshore hydrocarbon field may exhibit maximum production, which would necessitate using the first floating surface facility104ato accommodate the elevated (maximum) production capacity. In the next ten years, however, the production profile may diminish and exhibit medium production based on reservoir depletion trends, which can be accommodated using the second floating surface facility104b. At that time, an operator may decide to decouple the first floating surface facility104afrom the detachable floating buoy102and replace it with the second floating surface facility104b. The first floating surface facility104amay then be moved to another location where its enlarged capacity and capabilities can be best utilized.

Furthermore, in the last five to ten years, the production profile of the hydrocarbon field may diminish even further based on reservoir depletion trends and exhibit minimal production, which can be accommodated using the third (and smallest) floating surface facility104c. At that time, the second floating surface facility104bmay be decoupled from the detachable floating buoy102and replaced with the third floating surface facility104c. The second floating surface facility104bmay then be moved to another location where its capacity and capabilities can be best utilized. As will be appreciated, the ‘plug-and-play’ capability of the presently described system100maximizes the value of each floating surface facility104a-cby avoiding underutilization beyond peak production. The system100facilitates relatively quick, simple, and easy deployment and demobilization of the floating surface facilities104a-cto various locations, thus enabling an operator to maximize value by using the most efficient (appropriate) asset that matches varying reservoir profile through field service.

FIG.2is a top view of the detachable floating buoy102, according to one or more embodiments. In the illustrated embodiment, the annular body110exhibits a generally circular or round cross-sectional shape, and the central aperture114defined by the body110is similarly circular or round. Consequently, an outer periphery (circumference)202of the body110is circular, and an inner surface204of the central aperture114is likewise circular. As discussed herein, however, the body110may exhibit other cross-sectional shapes, without departing from the scope of the disclosure.

In some embodiments, as illustrated, the shape of the body110may be axisymmetric, which may prove advantageous in use at locations with omnidirectional metocean extreme environments, where resulting environmental loads on and the hydrodynamic response of the ‘modular offshore floating platform system’ from all directions remain similar. Moreover, in the illustrated embodiment, the annular body110comprises a monolithic, annular structure, but could alternatively be made up of two or more mechanically coupled arcuate sections, without departing from the scope of the disclosure.

As shown inFIG.2, the mooring lines116may be attached to the outer periphery202of the body110to secure the detachable floating buoy102to the seafloor108(FIG.1). Moreover, the mooring lines116can be attached to and extend from multiple sides or locations about the outer periphery202, thus resulting in a “spread-moored” configuration, as briefly discussed above. The communication lines122are also attached to the outer periphery202of the body110and extend to the detachable floating buoy102from the subsea production system118(FIG.1). In some embodiments, as illustrated, attachment of the mooring lines116and the communication lines122may alternate about the outer periphery202, but could alternatively be arranged in any other order or configuration, without departing from the scope of the disclosure.

In the illustrated embodiment, the communication lines122are depicted as a first set of communication lines122a, a second set of communication lines122b, a third set of communication lines122c, and a fourth set of communication lines122d. In some embodiments, the first set of communication lines122amay be configured to convey a first fluid type (e.g., oil) to the detachable floating buoy102, the second set of communication lines122bmay be configured to convey a second fluid type (e.g., gas) to the detachable floating buoy102, and the third set of communication lines122cmay be configured to convey a third fluid type (e.g., water) to the detachable floating buoy102. The fourth set of communication lines122dmay be configured to convey power, command signals, hydraulics, etc. between the subsea production system118(FIG.1) and the detachable floating buoy102.

In the illustrated embodiment, each set of communication lines122a-dterminates at a corresponding communication coupling, shown as a first communication coupling206a, a second communication coupling206b, a third communication coupling206c, and a fourth communication coupling206d. The communication couplings206a-dmay be configured to mate with the communication couplings140(FIG.1) provided on the floating surface facilities104a-c(FIG.1) when any of the floating surface facilities104a-care mated to the detachable floating buoy102. Accordingly, the communication couplings140,206a-dmay cooperatively form a coupling assembly configured to place the floating surface facilities104a-cin communication with the subsea production system118. In some embodiments, some or all of the communication couplings140,206a-dmay comprise fluid manifolds used to route riser fluids (oil, gas, water, etc.) to appropriate destinations. Fluid manifolds may be utilized to facilitate communication from the communication couplings206a-dto the appropriate topsides modules132.

In some embodiments, as illustrated, the detachable floating buoy102may also include the latching mechanism138(or a portion thereof), shown as four separate latching components spread about the inner surface204of the central aperture114. As described above, the latching mechanism138may be used to mechanically couple the floating surface facility104a-c(FIG.1) to the detachable floating buoy102.

Lastly,FIG.2also shows the buoyancy connections128arranged about the outer periphery202of the body110. As described above, the buoyancy connections128may provide access to one or more variable ballast tanks (not shown) provided within the body110to alter the buoyancy of the detachable floating buoy102and thereby adjust its depth within the water106(FIG.1).

FIGS.3A-3Care side views of various examples of the system100ofFIG.1depicting the second floating surface facility104bmated with the detachable floating buoy102, according to one or more embodiments. While the following discussion is directed to mating the second floating surface facility104bwith the detachable floating buoy102, the discussion is equally applicable to mating the first or third floating surface facility104a,cwith the detachable floating buoy102.

The process of mating the second floating surface facility104bwith the detachable floating buoy102may first entail vertically aligning the plug portion136of the hull134with the central aperture114of the detachable floating buoy102. Once aligned, the vertical distance between the second floating surface facility104band the detachable floating buoy102may be closed to enable the plug portion136to be received within the central aperture114. This may be accomplished by 1) operating an internal ballast system302included in the second floating surface facility104band thereby causing the second floating surface facility104bto descend toward the detachable floating buoy102) operating the ballast system124of the detachable floating buoy102and thereby causing the detachable floating buoy102to ascend toward the second floating surface facility104b, or 3) a combination of the foregoing. Accordingly, the draft of the second floating surface facility104band the depth of the detachable floating buoy102may be adjusted independently of each other.

In at least one embodiment, the second floating surface facility104bmay include a winching system304operable to help close the distance between the second floating surface facility104band the detachable floating buoy102. The winching system304may also be useful in helping during disconnection of the second floating surface facility104bfrom the detachable floating buoy102. The winching system304could consist of a single or multiple loadbearing lines from the floating surface facility104bwith corresponding attachment points on detachable floating buoy102. Alternatively, the operation to help manage the distance between the second floating surface facility104band the detachable floating buoy102could be facilitated by using winch lines of field support vessels. Moreover, in some embodiments, the system100may further include one or more orientation mechanisms configured to help properly angularly orient the detachable floating buoy102with respect to the hull134. Properly orienting the detachable floating buoy102may be required to enable the communication lines122to properly align with corresponding manifolds, etc. within the second floating surface facility104b. Example orientation mechanisms can include, but are not limited to, dogs, keys, slots, any combination thereof, or other types of guides or guiding mechanisms capable of helping to achieve the correct angular orientation (azimuth).

Receiving the plug portion136within the central aperture114may also simultaneously facilitate operative connection at the communication couplings140,206a-d, thus placing the second floating surface facility104bin communication (e.g., production fluids, power, communication signals, hydraulics, etc.) with the subsea production system118(FIG.1) via the communication lines122. Moreover, once properly mated, the second floating surface facility104bmay be mechanically coupled to the detachable floating buoy102with the latching mechanism138, as generally described above. Once mechanically mated, the mooring lines116help stabilize the entire system100within the water106and help maintain the system100in place during use.

InFIG.3A, the length (depth) of the plug portion136is sized such that it does not protrude past the bottom112bof the detachable floating buoy102. In at least one embodiment, the bottom of the plug portion136may reside flush or substantially flush with the bottom112bof the detachable floating buoy102.

InFIG.3B, in contrast, the length (depth) of the plug portion136is sized such that it protrudes past the bottom112bof the detachable floating buoy102. The increased length (depth) of the plug portion136may prove advantageous for a few reasons. First, a larger plug portion136allows for more storage space within the hull for produced fluids. Second, the longer/larger plug portion136can result in enhanced hydrodynamic stability. Lastly, the longer plug portion136allows the latching mechanism138to be located outside of the central aperture114and otherwise beneath the detachable floating buoy102. This allows an operator to be able to visually inspect the latching mechanism138(e.g., by using a diver or ROV) and ensure that it is properly latched and secured.

InFIG.3C, the plug portion136is conical or frustoconical in shape, and the inner surface204of the central aperture114may be correspondingly angled to accommodate the frustoconical shape. The frustoconical plug portion136may prove advantageous in allowing the plug portion136to more easily locate and mate with the central aperture114, thus making the mating process easier.

FIGS.4A-4Care top views of various examples of the detachable floating buoy102, according to the present disclosure. InFIG.4A, the annular body110exhibits a polygonal cross-sectional shape, and the inner surface204of the central aperture114defined by the body110is similarly polygonal in shape. In the illustrated embodiment, the body110and the central aperture114each form an octagon. In other embodiments, however, the body110and or the central aperture114may exhibit other polygonal cross-sectional shapes including, but not limited to, a triangle, a rectangle (including a square), a pentagon, a hexagon, and so forth.

InFIG.4B, the annular body110exhibits a generally circular cross-sectional shape, while the inner surface204of the central aperture114exhibits a polygonal cross-sectional shape. In particular, and similar to the embodiment ofFIG.4A, the central aperture114forms an octagon, but could alternatively exhibit other polygonal cross-sectional shapes, without departing from the scope of the disclosure.

InFIG.4C, the annular body110exhibits a polygonal cross-sectional shape, while the inner surface204of the central aperture114exhibits a generally circular cross-sectional shape. In particular, and similar to the embodiment ofFIG.4A, the annular body110forms an octagon, but could alternatively exhibit other polygonal cross-sectional shapes, without departing from the scope of the disclosure.

FIGS.5A-5Care side views of various embodiments of another modular floating platform system500, according to one or more embodiments. The modular floating platform system500(hereafter “the system500”) may be similar in some respects to the system100ofFIG.1and, therefore, may be best understood with reference thereto, where like numerals represent like components not described again in detail. As illustrated, the system500includes a detachable floating buoy502and a floating surface facility504. The floating surface facility504may be the same as or similar to any of the floating surface facilities104a-cofFIG.1. InFIG.5A, the floating surface facility504comprises a “wet tow” offshore platform that is towed in the water106to the location of the detachable floating buoy502. InFIG.5B, however, the floating surface facility504comprises a “dry tow” offshore platform that is carried to the location of the detachable floating buoy502on a transportation barge506.

The detachable floating buoy502may be similar in some respects to the detachable floating buoy102ofFIG.1. More specifically, the detachable floating buoy502may be tethered to the seafloor108(FIG.1) with the plurality of mooring lines116, and may also be in communication with the subsea production system118(FIG.1) via the communication lines122(only one shown). The detachable floating buoy502may also provide or otherwise define a central aperture508.

In contrast to the detachable floating buoy102, however, the detachable floating buoy502may include a bottom or “pontoon”510such that the central aperture508could extend all the way through the detachable floating buoy502. Moreover, the detachable floating buoy502may also include one or more vertical supports or columns512extending from the bottom510. In some embodiments, the buoyancy of the detachable floating buoy502can be adjusted such that the vertical supports512may be submerged below the water to enable mating with the floating surface facility504. After the mating is successfully achieved, the buoyancy of the detachable floating buoy502can be adjusted such that the vertical supports512can extend above the water line such that the connection point to the floating surface facility504is above water. In the illustrated embodiments, the detachable floating buoy502is depicted as having four vertical supports512, which can be reduced to at least three vertical supports512. In at least one embodiment, however, the detachable floating buoy502may include a single vertical support512in the form of a cylinder (e.g., circular, polygonal, etc.), as generally shown inFIG.6A, without departing from the scope of the disclosure.

In further contrast to the system100ofFIG.1, the system500may include vertically mounted latching mechanisms514and communication ‘stab-in’ type couplings516with compatible mating receptors518on the floating surface facility504. In the system100, the latching mechanism138(FIGS.1-3C) and the communication couplings104,202a-d(FIGS.1-3C) are all arranged radially for radial interaction at the interface between the floating surface facilities104a-c(FIG.1) and the detachable floating buoy102(FIG.1). In contrast, the latching mechanisms514and the communication couplings516of the system500may be arranged at a vertical interface between the floating surface facility504and the detachable floating buoy502. In the illustrated embodiment, for example, the latching mechanisms514and the communication couplings516are arranged at the top of the vertical support(s)512and configured to mate with a standardized bottom interface provided on the bottom of the floating surface facility504. The standardized bottom interface of the floating surface facility504may comprise, for example, one or more receptacles configured to receive and otherwise mate with the latching mechanisms514and the communication couplings516. In other embodiments, however, the latching mechanisms514and the communication couplings516may alternatively be arranged at the bottom of the floating surface facility504and configured to mate with the top of the vertical support(s)512. In yet other embodiments, portions of the latching mechanisms514and the communication couplings516may be arranged on both the top of the vertical support(s)512and the bottom of the floating surface facility504, without departing from the scope of the disclosure.

Once the latching mechanisms514and the communication couplings516are properly connected at the interface between the floating surface facility504and the detachable floating buoy502, as shown inFIG.5C, production fluids, power, command signals, and hydraulics may then be transferred between the subsea production system118(FIG.1) and the floating surface facility504.

FIGS.6A-6Care top views of example embodiments of the detachable floating buoy502, according to the present disclosure. As illustrated, the detachable floating buoy502includes a body602that defines the central aperture508. A plurality of latching mechanisms514and communication couplings516, as generally described above, may be mounted to the body602in each embodiment. Moreover, the detachable floating buoy502can exhibit a variety of different cross-sectional shapes.

InFIG.6A, for example, the body602exhibits a generally circular or round cross-sectional shape, and the central aperture508defined by the body602is similarly circular or round. Consequently, an outer periphery (circumference)604of the body602is circular, and an inner surface606of the central aperture508is similarly circular. In other embodiments, however, the central aperture508may be used as a ‘moonpool’ or ‘central-well’ and can alternatively exhibit other cross-sectional shapes, such as a polygonal shape, without departing from the scope of the disclosure.

InFIG.6B, the body602exhibits a polygonal cross-sectional shape, and the central aperture508is similarly polygonal in shape. In the illustrated embodiment, both the body602and the aperture exhibit a triangular cross-sectional shape. Consequently, the outer periphery (circumference)604of the body602is in the shape of a triangle, and the inner surface606of the central aperture508is similarly in the shape of a triangle. In other embodiments, however, the central aperture508may alternatively exhibit other cross-sectional shapes, such as another polygonal shape or circular, without departing from the scope of the disclosure.

InFIG.6C, the body602again exhibits a polygonal cross-sectional shape, and the central aperture508is similarly polygonal in shape. In the illustrated embodiment, both the body602and the aperture exhibit a rectangular (including square) cross-sectional shape. Consequently, the outer periphery (circumference)604of the body602is in the shape of a rectangle, and the inner surface606of the central aperture508is similarly in the shape of a rectangle. In other embodiments, however, the central aperture508may alternatively exhibit other cross-sectional shapes, such as another polygonal shape or circular, without departing from the scope of the disclosure.

FIG.7is an isometric view of the system500ofFIGS.5A-5C, according to one or more embodiments. As illustrated, the system500includes the detachable floating buoy502shown mated with the floating surface facility504. The detachable floating buoy502is tethered to the seafloor108(FIG.1) with a plurality of mooring lines116, and communicates with the subsea production system118(FIG.1) via the communication lines122.

In the illustrated embodiment, the detachable floating buoy502exhibits a generally rectangular shape, similar to the embodiment shown inFIG.6C. In this embodiment, the vertical supports512extend from each geometric corner of the detachable floating buoy502to be coupled to bottom of the standardized bottom interface of the floating surface facility504at four locations. The latching mechanisms514and the communication couplings516of the system500are arranged at the corners to operatively and communicably couple the floating surface facility504to the detachable floating buoy502. Moreover, in the illustrated embodiment, the central aperture508is open and thereby provides a ‘moonpool’ or ‘central-well’, but could alternatively be closed, without departing from the scope of the disclosure.

FIG.8is an isometric view of the system500ofFIGS.5A-5C, according to one or more additional embodiments. As illustrated, the system500includes the detachable floating buoy502shown mated with the floating surface facility504. The detachable floating buoy502is tethered to the seafloor108(FIG.1) with a plurality of mooring lines116, and communicates with the subsea production system118(FIG.1) via the communication lines122.

In the illustrated embodiment, the detachable floating buoy502exhibits a generally circular cylindrical shape, similar to the embodiment shown inFIG.6A. In this embodiment, the vertical support512comprises a single, columnar structure. While shown exhibiting a generally circular cross-sectional shape, the vertical support512may alternatively exhibit other cross-sectional shapes, including any polygonal shape, without departing from the scope of the disclosure. Moreover, the latching mechanisms514and the communication couplings516of the system500are arranged at the interface between the floating surface facility504and the detachable floating buoy502to facilitate communication therebetween of production fluids, electrical signals, hydraulics, etc.

One or more illustrative incarnations incorporating one or more invention elements are presented herein. Not all features of a physical implementation are described or shown in this application for the sake of clarity. It is understood that in the development of a physical embodiment incorporating one or more elements of the present invention, numerous implementation-specific decisions must be made to achieve the developer's goals, such as compliance with system-related, business-related, government-related and other constraints, which vary by implementation and from time to time. While a developer's efforts might be time-consuming, such efforts would be, nevertheless, a routine undertaking for those of ordinary skill in the art and having benefit of this disclosure.

While systems and methods are described herein in terms of “comprising” various components or steps, the systems and methods can also “consist essentially of” or “consist of” the various components and steps.

Embodiments Listing

Clause 1: A modular floating platform system includes a detachable floating buoy communicably coupled to a subsea production system via one or more communication lines, a plurality of floating surface facilities individually matable with the detachable floating buoy at a standardized bottom interface provided on each floating surface facility, a latching mechanism that individually couples each floating surface facility to the detachable floating buoy when each floating surface facility is individually mated to the detachable floating buoy, and one or more communication couplings that place each floating surface facility in communication with the subsea production system via the one or more communication lines when each floating surface facility is individually mated to the detachable floating buoy.

Clause 2: The system of Clause 1, wherein the standardized bottom interface of each floating surface facility comprises a plug portion sized to be received within a central aperture defined by the detachable floating buoy.

Clause 3: The system of Clause 2, wherein the plug portion extends into the central aperture but does not protrude past a bottom of the detachable floating buoy.

Clause 4: The system of Clause 2, wherein the plug portion extends into the central aperture and past a bottom of the detachable floating buoy.

Clause 5: The system of Clause 2, wherein the plug portion exhibits a conical shape and an inner surface of the central aperture is angled to accommodate the conical shape.

Clause 6: The system of any of the preceding Clauses, wherein the detachable floating buoy is spread-moored to a seafloor with a plurality of mooring lines.

Clause 7: The system of any of the preceding Clauses, wherein the one or more communication lines comprise one or more riser conduits for transferring production fluids, and one or more umbilicals that facilitate transfer of electrical power, communication signals, and hydraulics.

Clause 8: The system of any of the preceding Clauses, wherein the detachable floating buoy further includes a ballast system operable to adjust a buoyancy of the detachable floating buoy.

Clause 9: The system of Clause 8, wherein the ballast system includes one or more buoyancy connections in fluid communication with one or more ballast tanks, and wherein the ballast tanks are capable of being flooded or evacuated via the one or more buoyancy connections.

Clause 10: The system of any of the preceding Clauses, wherein the detachable floating buoy exhibits a circular or polygonal cross-section.

Clause 11: The system of Clause 10, wherein the detachable floating buoy defines a central aperture that exhibits a circular or polygonal cross-section.

Clause 12: The system of Clause 10, wherein a body of the detachable floating buoy is axisymmetric.

Clause 13: The system of any of the preceding Clauses, wherein the detachable floating buoy includes one or more vertical supports arranged to mate and connect with the standardized bottom interface provided on a bottom of each floating surface facility.

Clause 14: The system of Clause 13, wherein the latching mechanism and the one or more communication couplings are arranged at an interface between the one or more vertical supports and the standardized bottom interface.

Clause 15: The system of Clause 13, wherein the standardized bottom interface of each floating surface facility comprises one or more receptacles configured mate with the one or more vertical supports.

Clause 16: A method of operating a modular floating platform system includes the steps of communicably coupling a detachable floating buoy to a subsea production system at an offshore location via one or more communication lines, the detachable floating buoy providing a central aperture, mating a floating surface facility to the detachable floating buoy, the floating surface facility including a standardized bottom interface comprising a plug portion matable with the central aperture, placing the floating surface facility in communication with the subsea production system via the one or more communication lines as the plug portion mates with the central aperture, and securing the floating surface facility to the detachable floating buoy with a latching mechanism.

Clause 17: The method of Clause 16, wherein mating the floating surface facility to the detachable floating buoy comprises vertically aligning the plug portion with the central aperture, closing a vertical distance between the floating surface facility and the detachable floating buoy, and receiving the plug portion within the central aperture.

Clause 18: The method of Clause 17, wherein closing the vertical distance comprises operating a ballast system included in the floating surface facility and thereby causing the floating surface facility to descend toward the detachable floating buoy.

Clause 19: The method of Clause 17, wherein closing the vertical distance comprises operating a ballast system included in the detachable floating buoy and thereby causing the detachable floating buoy to ascend toward the floating surface facility.

Clause 20: The method of any of Clauses 16 through 19, wherein one or more communication couplings are arranged at an interface between the detachable floating buoy and the floating surface facility, and wherein placing the floating surface facility in communication with the subsea production system comprises mating the one or more communication couplings as the plug portion mates with the central aperture, and facilitating communication between the floating surface facility and the subsea production system via the one or more communication lines once the one or more communication couplings are mated.

Clause 21: The method of any of Clauses 16 through 20, further comprising tethering the detachable floating buoy to the seafloor with a plurality of mooring lines.

Clause 22: The method of any of Clauses 16 through 21, wherein the floating surface facility is a first floating surface facility and the method further comprises decoupling the first floating surface facility from the detachable floating buoy, mating a second floating surface facility to the detachable floating buoy, the second floating surface facility including the standardized bottom interface comprising the plug portion matable with the central aperture, placing the second floating surface facility in communication with the subsea production system via the one or more communication lines as the plug portion of the second floating surface facility mates with the central aperture, placing the second floating surface facility in communication with the subsea production system via the one or more communication lines as the plug portion of the second floating surface facility mates with the central aperture, and securing the second floating surface facility to the detachable floating buoy with the latching mechanism.

Therefore, the present invention is well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. The particular examples and configurations disclosed above are illustrative only, as the present invention may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular illustrative examples disclosed above may be altered, combined, or modified and all such variations are considered within the scope and spirit of the present invention. The invention illustratively disclosed herein suitably may be practiced in the absence of any element that is not specifically disclosed herein and/or any optional element disclosed herein. While compositions and methods are described in terms of “comprising,” “containing,” or “including” various components or steps, the compositions and methods can also “consist essentially of” or “consist of” the various components and steps. All numbers and ranges disclosed above may vary by some amount. Whenever a numerical range with a lower limit and an upper limit is disclosed, any number and any included range falling within the range is specifically disclosed. In particular, every range of values (of the form, “from about a to about b,” or, equivalently, “from approximately a to b,” or, equivalently, “from approximately a-b”) disclosed herein is to be understood to set forth every number and range encompassed within the broader range of values. Also, the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee. Moreover, the indefinite articles “a” or “an,” as used in the claims, are defined herein to mean one or more than one of the element that it introduces.