BUOYANT SYSTEM AND METHOD WITH BUOYANT EXTENSION AND GUIDE TUBE

Abstract

The present invention provides a buoyant system and method for a hydrocarbon offshore floating platform to be coupled and decoupled from a subsea buoyant extension with risers slidably coupled thereto. The buoyant system can allow rigid risers to be coupled and decoupled and alternatively move between a first elevation below the offshore floating platform, such as at the buoyant extension, and a higher second elevation at the offshore floating platform independent of a spool piece, arch support, and flexible joint for the risers. The buoyant system can reduce riser stress by reducing bending required for the riser to form a catenary or other curved shape even as a rigid riser.

Claims

1. A buoyant system configured to be detachable from an offshore floating platform, comprising: a buoyant extension having a buoyancy and configured to be detachably coupled with the offshore floating platform; and a first guide tube coupled to the buoyant extension and configured to allow a rigid portion of a riser to pass through the guide tube alternatively between a first elevation below the offshore floating platform and a higher second elevation at the offshore floating platform.

2. The system of claim 1, wherein the buoyant extension comprises an extension upper portion.

3. The system of claim 2, wherein the extension upper portion is configured to provide a buoyancy to the buoyant extension.

4. The system of claim 1, wherein the buoyant extension comprises members having buoyancy.

5. The system of claim 1, wherein the buoyant extension comprises a truss configured to allow water to laterally flow through the buoyant extension.

6. The system of claim 1, wherein the buoyant extension is configured to guide the rigid portion of the riser at a nonvertical angle independently of a spool piece, arch support, and flexible joint for the riser.

7. The system of claim 1, wherein the system further comprises the riser, and wherein the riser is a rigid riser from a subsea production equipment to be coupled to the offshore floating platform.

8. The system of claim 1, further comprising a second guide tube coupled to the buoyant extension at a different angle than the first guide tube.

9. The system of claim 1, further comprising a buoyancy module configured to be coupled to the riser at an elevation below the buoyant extension.

10. The system of claim 1, further comprising a plurality of mooring lines coupled to the buoyant extension and configured to moor the floating platform when the floating platform is coupled with the buoyant extension.

11. The system of claim 1, wherein the system further comprises the riser, and wherein the riser comprises at least a flexible portion below the buoyant extension.

12. The system of claim 1, wherein the buoyant extension comprises a riser guide structure configured to guide a plurality of risers.

13. A floating platform coupled with the buoyant system of claim 1, wherein the floating platform comprises a topsides with a valve, and wherein the riser from the buoyant extension is configured to be fluidicly coupled with the valve.

14. A floating platform coupled with the buoyant system of claim 1, wherein the floating platform comprises a topsides with a well tree, and wherein the riser from the buoyant extension is configured to be fluidicly coupled with the well tree.

15. A method of using an offshore floating platform with a buoyant system having a buoyant extension and a first guide tube coupled to the buoyant extension and configured to allow a rigid portion of a riser to be moved through the guide tube alternatively between a first elevation below the offshore floating platform and a higher second elevation at the floating platform, and wherein the riser has been coupled through the guide tube on the buoyant extension to the floating platform, the method comprising: disconnecting the riser from the floating platform; allowing the rigid portion of the riser to descend to the first elevation below the offshore floating platform while sliding through the first guide tube on the buoyant extension; disconnecting the floating platform from the buoyant extension with the riser remaining on the buoyant extension; and moving the floating platform to a location other than a location of the buoyant extension.

16. The method of claim 15, wherein allowing the riser to slide through the first guide tube on the buoyant extension comprises allowing the rigid portion of the riser to descend below the buoyant extension at a nonvertical angle independent of a spool piece, arch support, and flexible joint for the riser.

Description

BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS

[0021] FIG. 1A is a schematic cross sectional view of a known disconnect system with a buoyant upper hull structure connected with a buoyant lower mooring module.

[0022] FIG. 1B is a schematic cross sectional view of the known disconnect system of FIG. 1A with the buoyant upper hull structure disconnected with the buoyant lower mooring module.

[0023] FIG. 2A is a schematic cross sectional view of another known disconnect system with a buoyant upper hull structure connected with a buoyant lower mooring module.

[0024] FIG. 2B is a schematic cross sectional view of the known disconnect system of FIG. 2A with the buoyant upper hull structure disconnected with the buoyant lower mooring module.

[0025] FIG. 3A is a schematic side view of another known disconnect system with a buoyant upper hull structure connected with a buoyant lower mooring module.

[0026] FIG. 3B is a schematic side view of the known disconnect system of FIG. 3A with the buoyant upper hull structure disconnected with the buoyant lower mooring module.

[0027] FIG. 3C is a schematic perspective view of the buoyant lower mooring module of FIGS. 3A and 3B.

[0028] FIG. 4 is a schematic perspective view of an example of a buoyant system of the present invention having a buoyant extension that is coupled with a hydrocarbon offshore floating platform.

[0029] FIG. 5 is a schematic perspective view of the buoyant system of FIG. 4.

[0030] FIG. 6A is a schematic side view of the buoyant system of FIG. 4.

[0031] FIG. 6B is a schematic perspective detail view of the buoyant system of FIG. 6A.

[0032] FIG. 7A is a schematic side view of the offshore floating platform coupled with the buoyant system.

[0033] FIG. 7B is a schematic perspective detail view of the floating platform decoupled from the buoyant system of FIG. 4.

[0034] FIG. 8 is a schematic side view of another example of the buoyant system.

[0035] FIG. 9 is a schematic top view of an embodiment of the buoyant system.

[0036] FIG. 10 is a schematic top view of another embodiment of the buoyant system.

[0037] FIG. 11 is a schematic perspective view of a hydrocarbon offshore floating platform coupled with another embodiment of the buoyant system.

DETAILED DESCRIPTION

[0038] The Figures described above and the written description of specific structures and functions below are not presented to limit the scope of what Applicant has invented or the scope of the appended claims. Rather, the Figures and written description are provided to teach any person skilled in the art to make and use the inventions for which patent protection is sought. Those skilled in the art will appreciate that not all features of a commercial embodiment of the inventions are described or shown for the sake of clarity and understanding. Persons of skill in this art will also appreciate that the development of an actual commercial embodiment incorporating aspects of the present disclosure will require numerous implementation-specific decisions to achieve the developer's ultimate goal for the commercial embodiment. Such implementation-specific decisions may include, and likely are not limited to, compliance with system-related, business-related, government-related, and other constraints, which may vary by specific implementation or location, or with time. While a developer's efforts might be complex and time-consuming in an absolute sense, such efforts would be, nevertheless, a routine undertaking for those of ordinary skill in this art having benefit of this disclosure. It must be understood that the inventions disclosed and taught herein are susceptible to numerous and various modifications and alternative forms. The use of a singular term, such as, but not limited to, a, is not intended as limiting of the number of items. Further, the various methods and embodiments of the system can be included in combination with each other to produce variations of the disclosed methods and embodiments. Discussion of singular elements can include plural elements and vice-versa. References to at least one item may include one or more items. Also, various aspects of the embodiments could be used in conjunction with each other to accomplish the understood goals of the disclosure. Unless the context requires otherwise, the term comprise or variations such as comprises or comprising, should be understood to imply the inclusion of at least the stated element or step or group of elements or steps or equivalents thereof, and not the exclusion of a greater numerical quantity or any other element or step or group of elements or steps or equivalents thereof. The device or system may be used in a number of directions and orientations. The terms top, up, upward, bottom, down, downwardly, and like directional terms are used to indicate the direction relative to the figures and their illustrated orientation and are not absolute in commercial use but can vary as the assembly varies its orientation. The order of steps can occur in a variety of sequences unless otherwise specifically limited. The various steps described herein can be combined with other steps, interlineated with the stated steps, and/or split into multiple steps. Similarly, elements have been described functionally and can be embodied as separate components or can be combined into components having multiple functions. Some elements are nominated by a device name for simplicity and would be understood to include a system of related components that are known to those with ordinary skill in the art and may not be specifically described. Various examples are provided in the description and figures that perform various functions and are non-limiting in shape, size, description, but serve as illustrative structures that can be varied as would be known to one with ordinary skill in the art given the teachings contained herein. As such, the use of the term exemplary is the adjective form of the noun example and likewise refers to an illustrative structure, and not necessarily a preferred embodiment.

[0039] The present invention provides a buoyant system and method for a hydrocarbon offshore floating platform to be coupled and decoupled from a subsea buoyant extension with risers slidably coupled thereto. The buoyant system can allow rigid risers to be coupled and decoupled and alternatively move between a first elevation below the offshore floating platform, such as at the buoyant extension, and a higher second elevation at the offshore floating platform independent of a spool piece, arch support, and flexible joint for the risers. The buoyant system can reduce riser stress by reducing bending required for the riser to form a catenary or other curved shape even as a rigid riser.

[0040] FIG. 4 is a schematic perspective view of an example of a buoyant system of the present invention having a buoyant extension that is coupled with a hydrocarbon offshore floating platform. The exemplary buoyant system 100 can include an offshore floating platform generally related to the hydrocarbon industry. The floating platform 102 can be, for example and without limitation, a spar, semisubmersible, floating production storage and offloading unit (FPSO) including a ship-shaped FPSO or spar-shaped FPSO and can be with or without a turret, floating storage and re-gas unit (FSRU), or other hydrocarbon-related floating platforms. In some embodiments, a turret can be coupled with the buoyant system, and a FPSO removably coupled with the turret and the buoyant system. The extension upper portion can be buoyant and at least partially subsea below the water surface, and can be wholly subsea when coupled with the offshore floating platform. The floating platform 102 generally includes a working surface, such as a topsides 104. The topsides can include, for example, well trees, valves, or other hydrocarbon-related equipment. The floating platform 102 generally also has an enclosed buoyant hull 106, which for purposes herein may include pontoons in some types of floating platforms.

[0041] The floating platform 102 can be detachably coupled with a buoyant extension 110. In general, an extension upper portion 108 of the buoyant extension 110 can form a transition for the buoyant extension 110 with the floating platform 102, and some such embodiments are illustrated herein. However, it is expressly stated that the buoyant extension 110 does not require the extension upper portion 108 for the buoyant extension 110 to be coupled to the floating platform 102. The buoyant extension 110 generally is at least partially buoyant. The buoyancy is generally sufficient for the weight of the structure with the risers and mooring lines coupled to the structure to maintain the risers above a seabed and reduce riser stress by reducing bending required for the riser to form a catenary or other curved shape even as a rigid riser. In some embodiments, the extension upper portion 108 can have sufficient buoyancy for the remaining portion of the buoyant extension 110. In other embodiments, the extension upper portion 108 as well as other structure of the buoyant extension 110 can both contribute to the buoyancy. For example and without limitation, tubular components of the buoyant extension 110 may be at least partially sealed to create buoyancy. Other chambers, buoyant fill material, or structure can be provided for the buoyant extension 110 to have buoyancy independent of the extension upper portion 108. In other embodiments, the extension upper portion 108 may not contribute a significant amount, if any, to the buoyancy of the buoyant extension 110 and the buoyancy can be designed into other portions of the structure of the buoyant extension 110. In yet other embodiments, the extension upper portion 108 may not be present, so that the buoyant extension 110 is designed for buoyancy without the extension upper portion 108.

[0042] The length of the remaining portion of the buoyant extension 110 can be for example and without limitation at least the length of the extension upper portion 108 and longer such as at least twice the length of the extension upper portion. In at least one embodiment, the buoyant extension can be an open structure. An open structure is intended to mean a structure that allows water to pass through laterally, that is, the structure is not a sealed container with closed sides and closed bottom. An open structure buoyant extension 110 can be formed as a truss structure with vertical legs, horizontal legs, and cross bracing. Alternatively, the buoyant extension can be an at least partially closed container that restricts water passing through laterally, such as having sides and/or a bottom that allow at least some water to pass therethrough where the sides could be closed. The shape of the buoyant extension can vary and can include various geometrical shapes, including cylindrical, cubic, conical and frustoconical (such as without limitation having a larger base cross section than an upper cross section), and cross sections of square, rectangular, circular, elliptical, rhombus, and other polygons.

[0043] The buoyant extension 110 can be moored to a subsurface structure, such as a seabed, by one or more mooring lines 114 that for purposes herein can include traditional mooring lines or tendons. In some embodiments, the extension upper portion can be temporarily dynamically positioned, such as with thrusters, prior to being moored at a given location, particularly if the extension upper portion is wholly subsea, and reduce the need for mooring lines. In the embodiment shown in FIG. 4, the mooring lines 114 attached to the buoyant extension 110, such to the extension upper portion 108 if present, are sufficiently strong to also support the mooring of the floating platform 102 when coupled to the buoyant extension 110. Thus, no additional mooring lines would generally be needed separately to the floating platform. In other embodiments, the mooring lines can be coupled to the both the buoyant extension and the floating platform. In yet other embodiments, the mooring lines can be coupled to just the floating platform, and the buoyant extension can remain in the general location by risers (described below) coupled thereto.

[0044] At least one riser 113 and generally a plurality of risers are slidably coupled through the buoyant extension 110 and the extension upper portion 108 if present between a first elevation below the offshore floating platform, such as at the buoyant extension 110, and a generally higher second elevation at the offshore floating platform 102, as explained below. The term riser is broadly used herein and includes Steel Catenary Risers (SCRs), Steel Lazy Wave Risers (SLWRs), rigid risers, flexible risers, and umbilical lines. Advantageously, the riser can be rigid or at least partially rigid for reduced cost.

[0045] The extension upper portion 108 and buoyant extension 110 are configured to support and guide the riser 113 independent of a spool piece, arch support, and flexible joint that prior efforts relied on. While such structures may be optionally present, the system is configured to depend on the buoyant extension without needing such structures. While flexible risers can be used, the system can also use rigid risers. In at least one embodiment, the risers can be continuous between subsea production equipment and production equipment on the floating platform, where at least an upper portion of the riser could pass through the buoyant extension and the extension upper portion, if present (as illustrated in FIGS. 7A and 7B described below). The upper portion of the riser can be coupled to the floating platform and decoupled and lowered to the buoyant extension, so the floating platform can be decoupled from the buoyant extension. The buoyant system provides latitude to use at least partially, if not fully, rigid risers due to the ability of the system to allow rigid risers to slide through the supporting structure of the buoyant extension at an elevation above the seabed maintained by buoyancy to reduce stresses on the curvature of the riser. The invention can provide less expense, less complication, and more reliability for connecting risers between subsea production equipment and the floating platform.

[0046] FIG. 5 is a schematic perspective view of the buoyant system of FIG. 4. FIG. 6A is a schematic side view of the buoyant system of FIG. 4. FIG. 6B is a schematic perspective detail view of the buoyant system of FIG. 6A. The extension upper portion 108 can be coupled to the buoyant extension 110, as described above. The extension upper portion 108 can include a riser guide structure 120, such as a centerwell, moonpool plate, or structural framing. The riser guide structure 120 (also shown in FIGS. 9 and 10) generally includes a plurality of openings sized to allow one or more risers 113A and 113B (generally, 113) to pass therethrough and be separated from each other by a predefined distance formed through the grid structure. A riser guide tube 112 for a given riser 113 can be coupled to the buoyant extension 110 with at least one support 118, such as supports 118A and 118B. The guide tubes 112 are sized to allow the risers 113 to slide therethrough and provide support for the riser as it curves. For example, a first riser guide tube 112A can be coupled to the buoyant extension 110 in a first location at an angle. A second riser guide tube 112B can be coupled to the buoyant extension 110 at a second location, perhaps at a different angle than the first guide tube 112A. Further, the guide tube 112 can be coupled to the riser guide structure 120 (shown in FIGS. 8 and 9), so that the riser 113 is slidably supported also through the extension upper portion. Generally, the riser guide tube 113 will extend below the buoyant extension 110 at an angle to help transition the riser into a catenary shape, a lazy wave curve, or other curved shape. For example, the angle can correspond to a typical angle that the riser shape will naturally assume, that is, a catenary shape that is defined mathematically by formulae, as a suspended riser naturally approaches subsea production equipment at the lower end of the riser. The alignment of the one or more guide tubes 112 can assist in aligning the riser 113 with the curved shape. In some instances, a guide tube can align a riser in at least a partial vertical angle. Other risers 113 can have other guide tubes 112 coupled to the buoyant extension 110 in like manner. For example, a guide tube 112B is illustrated attached to external surfaces of frame members of the buoyant extension 110 and can slidably guide the riser 113B therethrough. The extension upper portion 108 can further include a mooring coupler 116 such as a fairlead, padeye, or other structure for coupling with securing lines, including mooring lines and tendons. The mooring coupler 116 extends outwardly from the extension upper portion and, for example, can be coupled with the extension mooring line 114.

[0047] FIG. 7A is a schematic side view of the offshore floating platform coupled with the buoyant system The offshore floating platform 102 can be coupled with an extension upper portion 108 of the buoyant extension 110. A lower end of the riser 113 can be coupled with subsea production equipment 136, such as a well head at the seabed, a pipe line end terminator (PLET), a manifold, or other equipment used for flowing hydrocarbons. The riser 113 can extend through the guide tube 112 coupled with the buoyant extension 110 and the extension upper portion 108 to the offshore floating platform 102. At the offshore floating platform, the riser can be fluidicly coupled (directly or indirectly) on an upper end 124 of the riser to equipment to allow fluid to flow between the riser and the equipment, such as to a valve 128 that could be on a well tree 126 or other equipment on the platform.

[0048] FIG. 7B is a schematic perspective detail view of the floating platform decoupled from the buoyant system of FIG. 4. The upper end 124 of the riser 113 can be decoupled from the valve 128 (or other equipment) and lowered from the floating platform 102 to the buoyant extension 110, such as to the extension upper portion 108, if present, below the floating platform, while lower portions of the riser can be slidably lowered through the guide tube 112 to a location below the buoyant extension 110 toward the seabed 132. The floating platform 102 can be moved to another location, leaving the buoyant extension 110 to support the riser 113.

[0049] When appropriate, the floating platform 102 can be brought back to the extension upper portion 108 and coupled thereto. Equipment, such as winches and the like, can raise the upper end 124 of the riser 113 and fluidicly couple the upper end to production equipment on the floating platform, such as a well tree 126 and/or valve 128.

[0050] In some embodiments, it may be advantageous to attach one or more buoyancy modules 134 to the riser 113. For example, the depth of the buoyant extension may be too shallow to allow the riser 113 to maintain a normal catenary shape or other appropriate curve that may overstress the riser when the riser is lowered from the floating platform to the buoyant extension. In other scenarios, the floating platform could have a large offset response that could overstress the riser. One or more such buoyancy modules 134 may be advantageously used to elevate the riser 113 above the seabed 132 to help avoid sharp bends and overstressing the riser as it curves to the subsea production equipment.

[0051] FIG. 8 is a schematic side view of another example of the buoyant system. A plurality of two or more buoyant extensions, such as the buoyant extensions 110A and 110B, can optionally be used with an extension upper portion 108 to transition to coupling with an offshore floating platform. Risers can be guided in one or more of the buoyant extensions and associated guide tubes, as described above.

[0052] FIG. 9 is a schematic top view of an embodiment of the buoyant system. The buoyant extension 110, such as at the extension upper portion 108, can have a plurality of mooring lines 114 extending from the mooring couplers 116 around the extension periphery. The mooring lines can be sufficiently strong to also support mooring of the floating platform by the platform being coupled to the buoyant extension 110. This embodiment can avoid separately mooring the floating platform in addition to mooring the buoyant extension. The exemplary riser guide structure 120 can provide a grid for spacing the risers 113.

[0053] FIG. 10 is a schematic top view of another embodiment of the buoyant system. In this embodiment, the buoyant extension 110 can be moored with sufficient mooring lines 114, such as from mooring couplers 116, to primarily support itself when disconnected from the floating platform. Therefore, the floating platform 102, described above, could be separately moored when coupled with the buoyant extension.

[0054] FIG. 11 is a schematic perspective view of a hydrocarbon offshore floating platform coupled with another embodiment of the buoyant system. The offshore floating platform 102 could be a vessel with a turret 140, such as an FPSO. The turret 140 can be coupled with the buoyant extension 110 in one or more variations. In some embodiments, the vessel with the turret can be removably coupled to the buoyant extension 110 with optionally an extension upper portion 108. The vessel with the turret can be decoupled from the buoyant extension and moved to another location, as has been described above. In other embodiments, the vessel with the turret 140 can be coupled with the buoyant extension 110. The vessel can be decoupled from the turret (and buoyant extension), the turret generally can be sufficiently lowered with the buoyant extension to provide clearance for the vessel to move, and the vessel can be moved to another location without the turret.

[0055] The system can include the mooring lines 114 coupled to the buoyant extension (or buoyant extension and turret), as described above. Risers 113 can be slidably coupled in guide tubes 112 and extend from the platform through the buoyant extension to subsea equipment below the platform.

[0056] Other and further embodiments utilizing one or more aspects of the inventions described above can be devised without departing from the disclosed invention as defined in the claims. For example, various shapes of extension upper portions and buoyant extensions and other variations can occur in keeping within the scope of the claims, and other variations.

[0057] The invention has been described in the context of preferred and other embodiments, and not every embodiment of the invention has been described. Obvious modifications and alterations to the described embodiments are available to those of ordinary skill in the art. The disclosed and undisclosed embodiments are not intended to limit or restrict the scope or applicability of the invention conceived of by the Applicant, but rather, in conformity with the patent laws, Applicant intends to protect fully all such modifications and improvements that come within the scope or range of equivalents of the following claims.