WO2012168702A1 - Protecteur de détérioration de contact de tube goulotte - Google Patents

Protecteur de détérioration de contact de tube goulotte Download PDF

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Publication number
WO2012168702A1
WO2012168702A1 PCT/GB2012/051265 GB2012051265W WO2012168702A1 WO 2012168702 A1 WO2012168702 A1 WO 2012168702A1 GB 2012051265 W GB2012051265 W GB 2012051265W WO 2012168702 A1 WO2012168702 A1 WO 2012168702A1
Authority
WO
WIPO (PCT)
Prior art keywords
sleeve
male
riser
female
section
Prior art date
Application number
PCT/GB2012/051265
Other languages
English (en)
Inventor
Ben STILLITS
John Mcnab
Craig KEYWORTH
Original Assignee
Flexlife Limited
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Flexlife Limited filed Critical Flexlife Limited
Publication of WO2012168702A1 publication Critical patent/WO2012168702A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/01—Risers
    • E21B17/015—Non-vertical risers, e.g. articulated or catenary-type
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
    • E21B17/1042—Elastomer protector or centering means
    • E21B17/105—Elastomer protector or centering means split type
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
    • F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
    • F16L1/00—Laying or reclaiming pipes; Repairing or joining pipes on or under water
    • F16L1/12—Laying or reclaiming pipes on or under water
    • F16L1/123—Devices for the protection of pipes under water
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
    • F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
    • F16L57/00—Protection of pipes or objects of similar shape against external or internal damage or wear
    • F16L57/02—Protection of pipes or objects of similar shape against external or internal damage or wear against cracking or buckling

Definitions

  • the present invention relates to a marine riser contact damage protector, typically for a flexible riser.
  • Marine risers are pipes (typically with a large inner diameter) that connect a subsea wellhead located on the sea bed to a floating surface rig or ship. Flexible risers can carry fluids to and from the wellhead.
  • Risers can be rigid or flexible.
  • Flexible risers typically have multiple layers. Usually inner layers form pipelines to contain fluids, and other layers (typically outer layers) incorporate reinforcing wires, tapes or bands etc to provide support, protection and stability to the pipeline. Different layers may have different properties and may contain wires or bands in different respective orientations, e.g. circumferential, axial and/or helical arrangements, e.g. to resist hoop stress in one layer, and axial tension in another layer. Other layers can be used to prevent heat loss or may have other functions. In deep water, a flexible riser is generally installed in a free hanging catenary for ease of installation, and near to the wellhead a portion of the riser will usually engage the sea bed.
  • TDP touch down point
  • the TDP of the catenary where the catenary touches down on the sea bed is particularly prone to abrasive and contact damage as a result of vessel movement causing the riser to drag or impact against the sea bed and other subsea structures in the vicinity.
  • Flexible riser outer sheaths are generally constructed from relatively low strength polymers, and the cyclic motion normally encountered in the region of the TDP of the riser as it moves can result in damage and eventual penetration of the outer sheath. Seawater ingress through the outer sheath leads to secondary damage in the form of corrosion of metal reinforcements and degradation of other materials in the inner layers.
  • a marine riser contact damage protector comprising at least first and second sleeve elements connected together to form a sleeve, the sleeve elements each having two ends and an axial bore extending between the ends, the bore being adapted to receive a riser within the bore, each of the sleeve elements having a male section at one end and a female section comprising a socket with a neck at the other end, and wherein the male section on the first sleeve element is adapted to be received within the socket of the female section on the other sleeve element, wherein the inner diameter of the neck of the female section at its narrowest point is smaller than the outer diameter of the male section at its widest point so that in the assembled sleeve the male section is retained by the neck of the socket, whereby the sleeve elements are connected together against axial separation, and wherein the riser is protected from contact damage by the sleeve elements.
  • the invention also provides a housing for a riser comprising a male section at one end and a female section at the other end, and wherein the male section comprises a stem and a head on the end of the stem and wherein the female section comprises a socket with a neck that is narrower than the socket, and wherein the neck of the female section has a larger diameter than the diameter of the stem of the male section, but a smaller diameter than the diameter of the head.
  • the invention provides a method of protecting a marine riser from contact damage by assembling a protective sleeve onto the riser, the method comprising providing first and second sleeve elements, the sleeve elements each two ends and an axial bore extending between the ends, each of the sleeve elements having a male section at one end and a female section comprising a socket with a neck at the other end, and wherein the method includes assembling the sleeve elements so that the male section on the first sleeve element is located within the socket of the female section on the other sleeve element, such that the outer diameter of the male section at its widest point is retained within the socket by the neck of the socket, and wherein the method includes assembling the sleeve elements such that the bore of the sleeve elements accommodates the riser within the bore, and such that the sleeve elements protect the riser from contact damage.
  • the male and female sections allow relative rotation between the sleeve elements when the two are connected.
  • the male and female sections allow relative pivotal movement between the sleeve elements when the two are connected.
  • the male and female sections can comprise respective ball and socket members.
  • the ball on one of the sleeve elements is received within the socket on the other of the sleeve elements.
  • the ball can be spherical as can the socket but other configurations of ball and socket members can be used, as long as the socket and ball match one another and the ball can be axially restrained within the socket.
  • the male section can optionally have some (or all) arcuate and/or flat faces to permit pivotal articulation in some planes but to prevent pivotal movement in other planes. All faces of the male sections can be arcuate but can have different radii or shapes. In other embodiments the faces of the male section can be flat.
  • each sleeve element has the male section at its upper end and the female section at its lower end.
  • the sleeve elements connect by interlocking.
  • the female section typically has a wider diameter than the male section, and is typically formed with relative thick walls which receive the male section on the adjacent sleeve element.
  • the male and female sections are typically connected by a shaft, which can have a smaller diameter than either of the male or female sections.
  • the sleeve elements are not uniformly stiff, and the shaft typically has greater flexibility than the male or the female sections.
  • the female section is generally resistant to bending.
  • sleeve elements can be used to make up the sleeve by joining the adjacent sleeve elements end to end to create a long string of the desired length.
  • the sleeve elements can be identical to one another, and can typically be used in any order, thereby facilitating assembly of the sleeve onto the riser.
  • the sleeve can have an end terminal sleeve element, typically two end terminal sleeve elements, which can optionally terminate the string of sleeve elements at an end of the sleeve, and optionally the end terminal sleeve elements can be different from the sleeve elements in that they do not require (but can optionally have) both a male and a female section at opposite ends of the end terminal sleeve element.
  • the end terminal sleeve elements can have only one of a male section and a female section, but not both. Typically one end terminal sleeve element has a male section only, and the other end terminal sleeve element has a female section only.
  • the sleeve elements have a latching mechanism adapted to lock the male section within the female section. The latching mechanism can be activated or deactivated from outside the bore of the sleeve elements.
  • the latching mechanism permits relative rotation of the sleeve elements when they are connected.
  • the latching mechanism permits relative pivotal movement of the sleeve elements when they are connected, but typically limits the maximum pivotal movement permitted to within a particular range.
  • each sleeve element is identical, simplifying both construction and installation.
  • Each string of sleeve elements typically starts and finishes with the relevant start/finish end terminal sleeve element.
  • the sleeve is particularly suited to be fitted to risers where abrasion is already evident to further protect a partially damaged riser from further loss of sheath material.
  • the bore of the sleeve is typically of sufficient inner diameter to receive and contain a riser.
  • the bore typically accommodates the manufacturing tolerances and radial expansion of the flexible riser.
  • the particular dimensions of the bore and the riser to which the sleeve is fitted does not need to be accurately controlled, and some lateral or other movement of the riser within the bore of the assembled sleeve does not affect the protective functions of the sleeve.
  • the riser is typically a flexible riser.
  • the minimum bend radius (MBR) of the sleeve is typically limited to a threshold equal to or above the MBR of the riser within the bore of the sleeve, so that the riser within the sleeve does not bend past its MBR and thereby suffer damage.
  • the limitation is achieved by restricting the relative movement of the male and female sections on the sleeve elements (e.g. the ball and the socket).
  • the MBR is limited by a bearing surface of the female section on the first sleeve element engaging on the outer surface of the second sleeve element between the male section and the female section on the second sleeve element.
  • At least one of the surfaces that engage to limit the MBR is typically conical, typically the bearing surface on the female section, and the two inter-engaging surfaces acting to limit the MBR are typically provided outside of the socket.
  • the bearing surface on the female section is located below the neck, i.e. outside the socket.
  • the material of the sleeve elements is a hard durable plastics material such as a polyurethane e.g. polyurethane polyether, and can be formed into a sleeve that has an equal or higher MBR than the MBR of the riser.
  • the male and female sections on the sleeve elements permit limited bending but optionally not beyond the MBR of the sleeve , which is typically determined by shape of the interconnecting surfaces of the male and female sections, and typically by the bearing surfaces outside of the socket, i.e. below the neck.
  • the sleeve elements are typically formed from a polymer such as a plastics material and can optionally be cast or extruded or otherwise formed in a single piece, i.e. in a single moulding.
  • the sleeve elements are cast from a heavy polyurethane material such as 90A PU, but other materials can be used.
  • the sleeve elements can be constructed from resilient material to allow for a degree of bending between the ends of the sleeve element, which can assist in reducing internal shelf points in the bore between the connected sleeve elements.
  • the male and female sections allow for connection between the sleeve elements at a variety of different relative angular positions of the sleeve elements, thereby permitting a progressive curve to be adopted by the sleeve.
  • the latching mechanism can allow for relative pivotal movement between the sleeve elements during connection.
  • the sleeve is typically deployed in the TDP of a flexible riser pipe and can provide effective protection to the riser against abrasion or other contact damage to the outer sheath of the riser, reducing damage caused by abrasion or impact of the pipe against coral, rock, sand and other pipes.
  • the sleeve elements are optionally adapted to deployed and assembled by an ROV.
  • Sleeve elements can be custom made to accommodate the bend radius of a specific riser, and can optionally be adjusted and optionally locked to a specific bend radius.
  • the sleeve typically contains no external exposed metallic components.
  • the sleeve can have a 'hanger' and a 'stopper' to prevent axial movement of the riser within the sleeve, thereby reducing the tendency of the sleeve to migrate beyond the TDP.
  • the sleeve can optionally be installed on a riser in service, i.e. without loss or interruption to service conditions, and can optionally be removed from a riser in service to allow for servicing and intervention operations on the riser before subsequently re installation of the sleeve.
  • Individual units of the sleeve elements can optionally be replaced if necessary.
  • each sleeve section is maintained at the same distance in relation to adjacent members.
  • the latching mechanism can optionally comprise a male and female part wherein either the male or the female part comprises a resilient component which deforms upon insertion and after insertion resists withdrawal.
  • the latching mechanism can comprise a tension band that comprises a flexible but non-extensible band that is tensioned by a tensioning device.
  • the tensioning device can comprise a latch.
  • the latching mechanism can optionally include a locking mechanism adapted to secure the male and female parts together and lock the latching mechanism against withdrawal of the male part from the female part.
  • the latching mechanism has a multi-stage closure with an initial stage of closure that typically allows for loose fitting and alignment of the male and female parts, and a second stage which completes the closure and prevents or restricts separation of the connected male and female parts.
  • the second stage closure can comprise a threaded fixing such as a bolt which can optionally be driven into a threaded socket on the latch mechanism when the male and female parts are correctly aligned to secure them against disconnection without removing the bolt.
  • the bolt or other fixing can engage the resilient component of the latching mechanism and prevent or restrict its deformation once the connector has been made up in order to resist withdrawal of the male section from the female section.
  • the latching mechanism can be recessed within the body of the sleeve element, typically on the female section of the sleeve element.
  • the latching mechanism can optionally be configured to apply radial compression to the female section of the sleeve element, typically to the outside of the female section.
  • the female section of the sleeve element may include an insert.
  • the insert may be a clamping insert.
  • the insert may be made of polyurethane polyether and may have a shore hardness of 80D.
  • the insert may include a mating sleeve that in use grips onto the riser.
  • the mating sleeve may be made of polychloroprene neoprene and may have a shore hardness of 70A.
  • the material forming the sleeve can have additives adapted to enhance the abrasion resistance of the sleeve, and further reduce the contact damage experienced by the riser and the sleeve.
  • Suitable abrasion resistant additives could include nylon and ceramics materials added to the polymer (e.g. the polyurethane polyether).
  • the sleeve elements can have at least one split extending between the two ends of the sleeve elements, allowing the sleeve elements to be split and assembled onto an existing riser.
  • the split is an axial split extending parallel to the central axis, but helical or other splits could be used provided that it extends between the two ends.
  • the sleeve elements can have more than one split and can be optionally formed as separate partial shells, for example in two, three, four or more segments that assemble around the riser to complete the sleeve element and accommodate the riser within the bore of the assembled sleeve element.
  • the sleeve elements can be formed by two half-shell segments. The shell segments can be of equal size or unequal size.
  • Half segments are typically packaged in pairs (or in threes etc if three shell segments are necessary to assemble a sleeve element).
  • a pair of segments can be banded together with sacrificial bands and the assembled shells can be arranged on a skid for deployment to the sea bed for assembly of the sleeve by an ROV (remotely operated vehicle).
  • ROV remotely operated vehicle
  • the sleeve elements are assembled on spigots on the skid that are provided to space the pairs from one another on the skid so as to permit recovery by an ROV and to restrict premature activation of the latching mechanism.
  • the sleeve elements can also be secured to the bottom of the skid offering a solid mounting location and high density packaging.
  • the skid can optionally be deployed to the sea bed on a container base where the skids can either be removed individually and placed along the length of the pipe ready for installation, or the sleeve element sections can be removed as an individual pair from the container base.
  • the skids on the container base can optionally be slid out from one end and can be secured against accidental movement from this location by a locking pin. If the riser TDP extends far above the seabed the container base can be raised and held off on the vessel crane or winch.
  • the sleeve elements are typically installed onto the riser by an ROV, typically fitted with an installation tool adapted to lift and orientate the pair of half shells for assembly on the riser. Complexities of the connection can be engineered into the tool (e.g. alignment and tightening capabilities) rather than being incorporated in an element of the sleeve that remains in the harsh subsea environment.
  • the ROV carries a four pronged tool and the sleeve can be installed by a work class ROV.
  • the installation tool typically enables the alignment and subsequent activation of the latching mechanism before being removed from the sleeve after the connection has been made up. The tool then allows for selection of the next sleeve element from a subsea racking system or deployment basket.
  • the tool allows the two half shells of the sleeve element to be
  • the point of lock out of the sleeve elements is selected to limit the MBR of the sleeve to be equal to or greater than the MBR of the riser itself.
  • high bending loads are not typically transferred to the riser, and are spread evenly along the tubular sleeve from one sleeve element to the next.
  • the tolerances between the sleeve elements e.g. especially on the mating faces of the male and female sections, typically allow sufficient clearance to permit free relative rotation in the assembled connector and typically allow for a moderate degree of swelling as a result of water absorption by the plastics material while still allowing the sleeve elements to carry out their full functions.
  • compositions, an element or a group of elements are preceded with the transitional phrase "comprising”, it is understood that we also contemplate the same composition, element or group of elements with transitional phrases “consisting essentially of, “consisting”, “selected from the group of consisting of, “including”, or “is” preceding the recitation of the composition, element or group of elements and vice versa.
  • Fig 1 is side sectional view of a sleeve assembly in place over a riser
  • Fig. 2 is a perspective view of the sleeve assembly and riser of Fig. 1;
  • Fig. 3 is a perspective view of a half shell from a sleeve element of the Fig. 1 sleeve assembly;
  • Figs. 4 and 5 are left and right side views of the Fig. 3 half shell;
  • Fig. 6 is a front of the Fig. 3 half shell
  • Fig. 7 is a top view of the Fig. 3 half shell
  • Fig. 8 is a deployment skid loaded with pairs of half shells as shown in Fig. 3;
  • Figs. 9, 10 and 11 are side, end and plan views of the Fig. 8 skid;
  • Fig. 12 is an expanded view of one of the half shell pairs on the Fig. 8 skid;
  • Fig. 13 is an expanded view of a pair of sleeve elements in the Fig. 1 sleeve;
  • Figs. 14, 15 and 16 are perspective, side and plan views of a latching mechanism used in the sleeve of Fig. 1;
  • Figs. 17 and 18 are sequential views of a riser floating procedure prior to installation of the sleeve
  • Figs. 19 to 23 are sequential perspective views of the installation procedure of the riser 1 from a sea bed skid using an ROV tool to assemble sleeve elements around the riser R;
  • Fig. 24 is a side sectional view of the sleeve assembly including a clamping insert and mating sleeve;
  • Fig. 25 is a perspective view of the sleeve assembly and clamping insert of Fig. 24;
  • Fig. 26 is a cross-sectional view of the two sleeve elements, clamping inserts and mating sleeve;
  • Fig. 27 is a cross-sectional view of the mating sleeve
  • Fig. 28 is an end view of the sleeve shown in Fig. 26;
  • Fig. 29 is a plan view of the sleeve shown in Fig. 26.
  • Fig. 30 is a perspective view of the clamping inserts corresponding to the two sleeve elements.
  • a riser R connected between a vessel and a wellhead (not shown) has a touch down region T in the form of catenary loop.
  • the touch down point T usually suffers from abrasive damage as a result of cyclic movement of the flexible riser R by local wave and tidal forces.
  • the sleeve 1 is installed on the outer surface of the riser R in the region of the touch down point T in order to reduce the susceptibility of the riser R to contact damage such as abrasion and contact between the riser R and other subsea structures.
  • the sleeve 1 is typically in the form of a sleeve that extends around the entire outer circumference of the riser R, to cover the whole outer surface, but a partial sleeve can optionally suffice that covers only some of the surface.
  • the sleeve is typically made up of sleeve elements 3, 4, 5, 6 etc.. At least two sleeve elements are required to make up the sleeve, but typically the sleeve comprises a larger number of sleeve elements.
  • the sleeve elements can be added to the riser in any particular number in order to suit the dimensions and environmental conditions of the touch down point T.
  • Sleeve elements 3, 4 are shown in more detail in Fig. 13.
  • Sleeve elements making up the sleeve 1 are typically identical, except that the terminal sleeve elements at the upper and lower ends of the sleeve 1 can be different if desired.
  • Sleeve elements can be made shorter for use in risers that have low MBRs (i.e. risers that are able to withstand bends with a small radius), and longer for risers that have higher MBRs.
  • Sleeve elements 3 and 4 each have an upper end with a male section in the form of a generally spherical ball 10, a lower end with a female section in the form of a socket housing 14, and a tubular shaft 12 between the male and female sections.
  • the ball 10 typically has partially rounded outer surfaces which extend radially outward from the ball to form a head on the upper end of the sleeve element. The diameter of the radially expanded head on the ball is larger than the outer diameter of the shaft 12.
  • the socket housing 14 is typically formed with a large diameter, typically larger than the ball 10. Both the socket housing 14 and the ball 10 are larger in diameter than the shaft 12.
  • the shaft 12 is typically more flexible than the ball 10 and the socket housing 14, which are typically substantially inflexible.
  • the socket housing 14 at the other end of the sleeve element 3 has a generally spherical socket 15 with a neck 15n at its open end.
  • the rounded inner walls of the socket 15 have an internal radius which typically matches and accommodates the outer radius of the ball 10.
  • the neck 15n of the socket 15 has a diameter that is smaller than the maximum diameter of the ball 10 and larger than the maximum diameter of the shaft 12, so that when the ball 10 is received within the socket 15, the minimum diameter at the apex of the neck 15n of the socket 15 retains the ball 10 within the socket 15, thereby preventing axial movement of the ball 10 out of the socket 15. As shown in Fig.
  • the ball 10 can be received within the socket 15 in different angular positions, because the outer diameter of the shaft 12 is less than the inner diameter of the neck 15n, as most clearly shown by the close up view in Fig. 13 of the socket housing 14 on sleeve element 3.
  • the head of the ball 10 is too large to pass through the neck 15n of the socket 15, so that the ball is always axially retained within the socket independent of the relative angular positions of the sleeve elements 3, 4.
  • the ball 10 on sleeve element 3 can freely pivot and rotate within the socket of the adjacent sleeve element 4, and the ball of the sleeve element 4 can freely pivot and rotate within the socket of the sleeve element 5, and so on, forming a gradual stepped radius in the sleeve 1 along its length.
  • the individual sleeve elements can also bend along their length, smoothing the steps in the radius.
  • the outer face of the socket neck 15n has a chamfered edge 16 immediately below the neck 15n as most clearly shown in Fig. 13.
  • the chamfered edge 16 flares radially outwardly, and typically presents a generally conical bearing surface extending from an outer edge of the neck 15n of the socket 15 in a generally straight line and at a generally consistent angle around its circumference.
  • the conical chamfered edge 16 is typically set at a chosen angle to the axis of the sleeve element which typically matches the corner angle formed between the surface of the ball 10 and the upper end of the shaft 12, as best shown in Fig 13 by the upper end of the sleeve element 3 which is received within the socket of the sleeve element 4.
  • the pivotal movement of the sleeve element 3 within the socket of the sleeve element 4 is limited by the chamfered edge 16 on the socket 15 of the sleeve element 4 pressing on the outer surface of the shaft 12 of the sleeve element 3. Therefore, the sleeve element 3 can pivot freely relative to the sleeve element 4 until the conical chamfered edge 16 abuts against the outer edge of the shaft 12, at which point, further pivotal deviation of the sleeve element 3 away from the axis of the sleeve element 4 will be prevented.
  • the socket housing 14 has a very thick wall and typically does not significantly bend in response to lateral forces applied after lock out. Bending of the sleeve element is typically focussed on the shaft 12 between the male and female sections after lock out of the chamfered edge 16 on the shaft 12. Hence the sleeve elements are typically not uniformly resistant to bending along their length.
  • the angle of the chamfer can be set at any desired value in order to allow more or less angular deviation of the two sleeve elements.
  • MBR minimum bend radius
  • the axial extension of the chamfered edge 16 can be increased or decreased to change the bearing area surface in all or some of the sleeve elements (e.g. in a localised area of the sleeve) without affecting the internal cooperating dimensions of the connection.
  • the sleeve elements 3, 4, 5, etc. all have a central bore B having an internal diameter that is adapted to receive the riser R within the bore B.
  • the interaction of the male and female sections on each adjacent sleeve element limits the MBR of the entire assembly to a value that is equal to or greater than the MBR of the riser, thereby preventing bending of the riser R beyond its MBR.
  • each sleeve element (sleeve element 3 is shown in detail in these figures) is made from two matching half shells a, b, only one of which is shown in Figs. 3-7.
  • the various parts of the connector 3 are described in Figs. 3-7 with the suffix "a", indicating the corresponding part of the sleeve element a on the half shell 3a.
  • each half shell 3a, 3b circumscribes approximately 180 degrees of the circumference of the sleeve 1.
  • two half shells are provided which connect together to form the assembled sleeve element 3, but it is possible to use three shells, or four, or some other number in accordance with the desired dimensions of the riser R.
  • the bore B through the sleeve element 3 is generally coaxial with the sleeve element, and typically consists of three parts; in a central section corresponding to the shaft 12, the bore B is essentially constant in diameter, and is slightly larger than the riser R which is accommodated within the bore.
  • the inner bore has a gentle chamfered edge 11 which increases in radius towards the open end of the sleeve element.
  • the chamfered face 11 on the inner surface of the ball 10 has a slightly steeper angle with respect to the axis of the sleeve element 3 than the corresponding angle of the chamfered face 16 on the external face of the socket 15, so that a lower sleeve element 3 pivots around the ball and socket joint in relation to an upper sleeve element 4 until the chamfered surface 16 engages the outer surface of the shaft 12, thereby limiting further pivotal movement of the two sleeve elements 3, 4, at which point the chamfered face 11 has still not engaged the outer surface of the riser R, and therefore point loads are typically not transferred to the riser by the edge of the chamfered face 11 even at the most extreme pivotal movement permitted by the sleeve 1.
  • the internal diameter of the bore B has a fairly loose tolerance with the riser, which is able to move laterally within the bore to a certain extent in order to avoid being trapped or pinched within the bore as the sleeve elements pivot relative to one another in the touch down point T.
  • the bore B widens into the semi spherical female socket 15 to receive the ball 10 of the next sleeve element below it.
  • the inner semi-spherical surface of the female socket 15 is a close tolerance with the outer surface of the ball 10, and the radiuses of the two sections match one another closely, so that while pivotal and rotational movement of the two sleeve elements 3, 4 is permitted, the ranges of the permitted movement are closely defined.
  • the ball 10 and the socket 15 can optionally have both arcuate and flat faces.
  • the outer surface of the female section 14 typically has at least one, and typically a pair of recesses 20 to receive a latching device 27.
  • the latching device 27 typically comprises a non-extensible but flexible strap 25 typically comprising a band of webbing or metal e.g. steel.
  • the strap 25 (see Figs. 9 and 10) typically extends over the recess 20, which receives and retains a pair of locking blocks 28a, b which are buried within the recess 20 preventing movement of the blocks 28a, b out of the recess 20 when the sleeve 1 is assembled with the strap covering the recess 20.
  • the blocks 28 a, b are connected to respective ends of the strap 25.
  • One of the blocks 28a contains a clip receiving recess
  • the other 28b comprises a moveable bifed clip having a pair of resilient arms which can be extended into the recess on operation of the latching mechanism.
  • the clip on the block 28b can be pushed into the recess on the other block 28a so as to keep the pair of shells together, but still allow radial separation of the two half shells to a certain extent.
  • This is the position shown in Fig. 12, where the shells are assembled onto the skid in the first stage of connection, with an axial split at zero degrees and 180 degrees on each pair of half shells.
  • the bifed arms of the clip have been received in the recess on the latching mechanism of each pair of half shells, but the connection between the two half shells has not been completed.
  • the latching mechanism typically has a second stage connection in which a securing bolt 29 is driven through the clip and through the arms of the clip into the screw threaded socket in the recess which receives the fixing bolt.
  • a securing bolt 29 is driven through the clip and through the arms of the clip into the screw threaded socket in the recess which receives the fixing bolt.
  • Continued tensioning of the fixing bolt 29 drives the two blocks 28a, b together as the fixing bolt 29 is screwed into the threaded socket, which makes up the connection by drawing the two half shells together, and interlocking them to secure them against radial separation.
  • a pair of blocks can be provided on each side of the assembled sleeve element, i.e. at zero degrees and 180 degrees, or a single pair of blocks can be provided if desired.
  • Driving the fixing bolt through the arms of the clip has the additional advantage that the arms of the clip can no longer move towards one another in order to escape the clip receiving recess, thereby further stabilising the connection.
  • the half shells can be assembled with the first stage connection (using the clip but not the fixing bolt) and loaded onto a skid as shown in Fig. 8 for deployment to the sea bed.
  • the half shells can be assembled on the skid and held in pairs by sacrificial bands (not shown) which are broken as the pairs of half shells are lifted from respective spigots on the skid.
  • the female section 14 has a number of lateral bores 30 extending through the thickened side wall of the female section 14, and these typically extend close to the surface of the female section 14 so that they do not emerge into the internal socket 15.
  • lateral bores 30 typically, four lateral bores are provided, which are all typically aligned with one another, perpendicular to the axis of the bore B.
  • the lateral bores 30 serve as handles for an ROV installation tool to be described.
  • An installation method for installing the sleeve 1 on the riser R will now be described with reference to Figs. 17-23. If required, the riser R can be floated using buoyancy bags using established techniques to attach buoyancy modules at intervals along the riser R in order to lift the touch down point T from the sea bed.
  • an ROV approaches the skid and presents an installation tool 40 to each pair of half shells loaded on the skid.
  • the installation tool 40 typically has two pairs of spars that are parallel to one another and are set at the same spacing as the lateral bores 30 through the female section 14. One pair of spars is provided on a static bar, and another pair of spars is provided on a travelling bar.
  • the travelling bar is adapted to move laterally with respect to the static bar in order to increase and decrease the lateral spacing between the static and travelling bars, and hence to adjust the lateral spacing between the half shells 3a and 3b when they are mounted on the spars.
  • the ROV adjusts the spacing of the travelling bar by a screw thread or hydraulic mechanism or similar to match the lateral spacing between the bores 30 on the half shells 3a and 3b, and when the spars are aligned with the bores, the tool 40 stabs the spars into the bores 30 in order to engage the half shells on the spars. This configuration is shown in Fig. 20.
  • the ROV then lifts the pair of half shells supported by the spars clear of the spigot on the skid, as shown in Fig. 21, and flies them to the riser R for assembly.
  • the tool 40 can be rotated to adjust the angular position of the tool 40 relative to the angular position of the riser, and the travelling bar can be wound back by means of the screw threads, etc. to increase the lateral spacing between the half shells 3a and 3b as shown in Fig. 22.
  • the screw adjustors controlling the lateral separation between the static and travelling bars are then reversed to close the half shells together as shown in Fig. 23, and optionally the screw thread arrangement on the tool 40 can be used to apply radial pressure to hold the half shells together while the latch mechanism 27 is being secured.
  • the same ROV can optionally drive the head of the fixing bolt 29 to engage in the screw threaded socket and make up the latching mechanism to secure the two halves 3a, 3b together around the riser R.
  • the ball of the sleeve element immediately below the sleeve element 3 being applied to the riser is captured within the two half shells forming the socket 15, so that the head of the male section on the lower sleeve element is retained within the socket by the neck 15n of the female section 14 on the sleeve element 3.
  • the relative angular position of adjacent sleeve elements can be set to the desired value before the latching mechanism is activated to close the two half shells together.
  • Tensioning the band 25 can optionally apply sufficient pressure to the female section to grip the head of the male section within the socket 15, and optionally can be used to prevent relative movement, but typically the adjacent sleeve elements can be used to move relative to one another within the defined limits that are set by the chamfered edges on the male and female sections, which allows relative movement of the sleeve and the riser R without transferring forces to the riser R.
  • the outer surface of the riser R is protected from abrasion by the sleeve elements and if a sleeve element is damaged or worn it can typically be replaced by a single replacement sleeve element without disassembling or disconnecting the riser.
  • Fig. 24 shows the sleeve 100 in the region of the touch down point T.
  • the sleeve 100 forms a sleeve that is made up of identical sleeve elements 103, 104, 105 etc..
  • Terminal sleeve elements 106 and 107 include clamping inserts 110a and 110b.
  • the clamping inserts 110a and 110b include a mating sleeve 111a (and 111b (not shown)) that grip onto the riser (not shown) that passes through the bore B of the sleeve 100 to prevent the sleeve elements 103, 104, 105 and others of the sleeve 100 sliding along the riser (not shown) when in use.
  • the clamping inserts 110a and 110b are made of polyurethane polyether and may have a shore hardness of 80D. These features are shown in more detail in Fig. 26 and described below.
  • Terminal sleeve element 107 is not the same as the other terminal sleeve element 106.
  • the later 106 is the same shape and has one male and one female section as the other sleeve elements 103, 104, 105 etc., but further includes the clamping inserts 110a and 110b.
  • the terminal sleeve element 107 has two female sections in the form of socket housings 114, rather than one male and one female section like the other sleeve elements 103, 104, 105 and 106.
  • Clamping inserts 110a and 110b and mating sleeve 111a located in the terminal sleeve elements 106 and 107 are the same.
  • Terminal sleeve element 106 is installed first on the riser (not shown), and terminal sleeve element 107 installed last.
  • Fig. 25 shows a perspective view of the sleeve assembly 100 and clamping inserts 110a and 110b shown in Fig. 24 and described above.
  • Fig. 26 shows the sleeve 106 and terminal sleeve elements 106a and 106b.
  • the mating sleeve 111a is bonded to the inside surfaces 112 of the clamping inserts 110a and 110b.
  • the outside surfaces 113 of the clamping inserts 110a and 110b are shaped to match, and contact with, the inner surfaces of the sleeve elements 106a and 106b respectively.
  • the clamping insert 110a is attached to the sleeve element 106a by head screw 115a.
  • the clamping insert 110b is attached to the sleeve element 106b by head screw 115b.
  • Fig. 27 shows the mating sleeve 111a in more detail.
  • the mating sleeve 111a has a body 116 and outer surface with castellations 117 that faces the inside of the bore B of the sleeve 100 and in use, grips the riser (not shown).
  • the mating sleeve 111a (and 111b) is a rubber material and may be made of polychloroprene neoprene and may have a shore hardness of 70A.
  • Fig. 28 shows an end view of the sleeve 106 shown in Fig. 26 and described above.
  • Fig. 29 is a plan view of the sleeve 106 made up of the two sleeve elements 106a and 106b.
  • Fig. 30 is a perspective view of the clamping inserts 110a and 110b corresponding to the two sleeve elements 106a and 106b of the sleeve 106.

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  • Engineering & Computer Science (AREA)
  • General Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • Mining & Mineral Resources (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)
  • Mutual Connection Of Rods And Tubes (AREA)

Abstract

L'invention porte sur un protecteur de détérioration de contact pour un tube goulotte, lequel protecteur présente des premier et second éléments de manchon reliés l'un à l'autre de façon à former un manchon. Les éléments de manchon ont une section mâle à une extrémité et une section femelle comprenant une douille avec un col à l'autre extrémité, et un perçage axial s'étendant entre les extrémités, le perçage recevant un tube goulotte. La section mâle sur le premier élément de manchon est apte à être reçue à l'intérieur de la douille de la section femelle sur l'autre élément de manchon. Le diamètre interne du col de la section femelle en son point le plus étroit est inférieur au diamètre externe de la section mâle en son point le plus large. La section mâle est maintenue par le col et les éléments de manchon sont ainsi reliés entre eux à l'encontre d'une séparation axiale. L'invention porte également sur un procédé de protection d'un tube goulotte contre des détériorations.
PCT/GB2012/051265 2011-06-06 2012-06-06 Protecteur de détérioration de contact de tube goulotte WO2012168702A1 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
GB1109448.9 2011-06-06
GBGB1109448.9A GB201109448D0 (en) 2011-06-06 2011-06-06 Housing assembly
GB1119464.4 2011-11-11
GBGB1119464.4A GB201119464D0 (en) 2011-06-06 2011-11-11 Housing assembly

Publications (1)

Publication Number Publication Date
WO2012168702A1 true WO2012168702A1 (fr) 2012-12-13

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Application Number Title Priority Date Filing Date
PCT/GB2012/051265 WO2012168702A1 (fr) 2011-06-06 2012-06-06 Protecteur de détérioration de contact de tube goulotte

Country Status (3)

Country Link
BR (1) BRPI1105620A2 (fr)
GB (2) GB201109448D0 (fr)
WO (1) WO2012168702A1 (fr)

Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2510569A (en) * 2013-02-06 2014-08-13 Subsea 7 Ltd A method of abandoning and recovering a pipeline
WO2015088991A1 (fr) * 2013-12-11 2015-06-18 National Oilwell Varco, L.P. Ensemble support de câble pour site de puits et son procédé d'utilisation
WO2016074039A1 (fr) * 2014-11-14 2016-05-19 Matrix Composites & Engineering Ltd. Système de protection de colonne montante de forage en mer
GB2544075A (en) * 2015-11-05 2017-05-10 Trelleborg Offshore Uk Ltd Improvements relating to bend restrictors
WO2018033703A1 (fr) * 2016-08-16 2018-02-22 Tekmar Energy Limited Segment restricteur de courbure et procédé de fabrication
WO2018044174A1 (fr) * 2016-09-01 2018-03-08 Statoil Petroleum As Installation en mer
CN108000053A (zh) * 2017-11-24 2018-05-08 无锡市永兴金属软管有限公司 一种加工抗疲劳金属软管的方法
WO2019035039A1 (fr) * 2017-08-16 2019-02-21 Baker Hughes, A Ge Company, Llc Élément de câble de forage d'articulation
US11549314B2 (en) * 2017-09-14 2023-01-10 Subsea 7 Do Brasil Servicos Ltda Subsea riser systems

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20050082824A1 (en) * 2003-10-14 2005-04-21 Luettgen Harold A. Rotatable and pivotable connector
US20100228295A1 (en) * 2009-03-09 2010-09-09 Whitefield Plastics Variable Radius Vertebra Bend Restrictor
WO2010136801A1 (fr) * 2009-05-26 2010-12-02 Pipeline Engineering & Supply Company Limited Limiteur de courbure

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20050082824A1 (en) * 2003-10-14 2005-04-21 Luettgen Harold A. Rotatable and pivotable connector
US20100228295A1 (en) * 2009-03-09 2010-09-09 Whitefield Plastics Variable Radius Vertebra Bend Restrictor
WO2010136801A1 (fr) * 2009-05-26 2010-12-02 Pipeline Engineering & Supply Company Limited Limiteur de courbure

Cited By (18)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9664307B2 (en) 2013-02-06 2017-05-30 Subsea 7 Limited Improvements relating to abandonment and recovery of pipelines
GB2522345A (en) * 2013-02-06 2015-07-22 Subsea 7 Ltd Improvements relating to abandonment and recovery of pipelines
GB2510569A (en) * 2013-02-06 2014-08-13 Subsea 7 Ltd A method of abandoning and recovering a pipeline
GB2522345B (en) * 2013-02-06 2015-12-02 Subsea 7 Ltd Improvements relating to abandonment and recovery of pipelines
GB2510569B (en) * 2013-02-06 2015-12-02 Subsea 7 Ltd Improvements relating to abandonment and recovery of pipelines
WO2015088991A1 (fr) * 2013-12-11 2015-06-18 National Oilwell Varco, L.P. Ensemble support de câble pour site de puits et son procédé d'utilisation
US9404319B2 (en) 2013-12-11 2016-08-02 National Oilwell Varco, L.P. Wellsite cable support assembly and method of using same
WO2016074039A1 (fr) * 2014-11-14 2016-05-19 Matrix Composites & Engineering Ltd. Système de protection de colonne montante de forage en mer
GB2544075A (en) * 2015-11-05 2017-05-10 Trelleborg Offshore Uk Ltd Improvements relating to bend restrictors
WO2018033703A1 (fr) * 2016-08-16 2018-02-22 Tekmar Energy Limited Segment restricteur de courbure et procédé de fabrication
WO2018044174A1 (fr) * 2016-09-01 2018-03-08 Statoil Petroleum As Installation en mer
RU2736248C2 (ru) * 2016-09-01 2020-11-12 Эквинор Энерджи Ас Морская установка
US11015398B2 (en) 2016-09-01 2021-05-25 Equinor Energy As Marine installation
WO2019035039A1 (fr) * 2017-08-16 2019-02-21 Baker Hughes, A Ge Company, Llc Élément de câble de forage d'articulation
US20190055793A1 (en) * 2017-08-16 2019-02-21 Baker Hughes, A Ge Company, Llc Articulating wireline component
US10927613B2 (en) 2017-08-16 2021-02-23 Baker Hughes, A Ge Company, Llc Articulating wireline component
US11549314B2 (en) * 2017-09-14 2023-01-10 Subsea 7 Do Brasil Servicos Ltda Subsea riser systems
CN108000053A (zh) * 2017-11-24 2018-05-08 无锡市永兴金属软管有限公司 一种加工抗疲劳金属软管的方法

Also Published As

Publication number Publication date
BRPI1105620A2 (pt) 2013-07-02
GB201109448D0 (en) 2011-07-20
GB201119464D0 (en) 2011-12-21

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