Classifications

• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
  • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
  • B63B21/00—Tying-up; Shifting, towing, or pushing equipment; Anchoring
  • B63B21/50—Anchoring arrangements or methods for special vessels, e.g. for floating drilling platforms or dredgers
  • B63B21/507—Anchoring arrangements or methods for special vessels, e.g. for floating drilling platforms or dredgers with mooring turrets
  • B63B21/508—Anchoring arrangements or methods for special vessels, e.g. for floating drilling platforms or dredgers with mooring turrets connected to submerged buoy
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
  • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
  • B63B21/00—Tying-up; Shifting, towing, or pushing equipment; Anchoring
  • B63B21/20—Adaptations of chains, ropes, hawsers, or the like, or of parts thereof
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
  • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
  • B63B21/00—Tying-up; Shifting, towing, or pushing equipment; Anchoring
  • B63B21/50—Anchoring arrangements or methods for special vessels, e.g. for floating drilling platforms or dredgers
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
  • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
  • B63B21/00—Tying-up; Shifting, towing, or pushing equipment; Anchoring
  • B63B21/50—Anchoring arrangements or methods for special vessels, e.g. for floating drilling platforms or dredgers
  • B63B21/502—Anchoring arrangements or methods for special vessels, e.g. for floating drilling platforms or dredgers by means of tension legs
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
  • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
  • B63B21/00—Tying-up; Shifting, towing, or pushing equipment; Anchoring
  • B63B21/50—Anchoring arrangements or methods for special vessels, e.g. for floating drilling platforms or dredgers
  • B63B21/507—Anchoring arrangements or methods for special vessels, e.g. for floating drilling platforms or dredgers with mooring turrets
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
  • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
  • B63B21/00—Tying-up; Shifting, towing, or pushing equipment; Anchoring
  • B63B2021/003—Mooring or anchoring equipment, not otherwise provided for
  • B63B2021/005—Resilient passive elements to be placed in line with mooring or towing chains, or line connections, e.g. dampers or springs
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
  • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
  • B63B21/00—Tying-up; Shifting, towing, or pushing equipment; Anchoring
  • B63B21/20—Adaptations of chains, ropes, hawsers, or the like, or of parts thereof
  • B63B2021/203—Mooring cables or ropes, hawsers, or the like; Adaptations thereof

Definitions

• the present invention relates to a connector or mooring connector, such as a marine/floating/buoyant/subsea/underwater/offshore (mooring) connector, for example, for connecting a line or lines, such as a mooring line(s), to a structure, such as a marine/floating/buoyant/subsea/underwater/offshore structure, for example, a submerged turret loading or a submerged turret production buoy.
• the invention also relates to an associated apparatus, structure and methods.
• a mooring line for example, a wire, chain or synthetic mooring line (such as polyester line) used subsea, for example, in the oil, gas, offshore wind, or tidal energy industries, or the like, can be attached to a (subsea) structure by means of a connector.
• the mooring of such a structure may be permanent.
• degradation of the line for example, corrosion of the wire or chain may require replacement of the degraded line.
• ROV remotely operated vehicle
• WO2014/155094 discloses a subsea connector comprising a first portion comprising a male part, a second portion comprising a female part, and a means or arrangement for connecting the first and second portions, wherein the arrangement for connecting comprises at least part of a through-passage in the second portion, the first portion comprises means for connecting the first portion to one or more mooring line(s), the means for connecting the first portion to one or more line(s) being configured to allow rotational movement of the first portion with respect to one or more line(s) about a transverse axis of the first portion, the second portion comprises means for connecting the second portion to an underwater structure, wherein the means for connecting the second portion to an underwater structure are configured to allow rotational movement of the second portion with respect to a structure about a transverse axis of the second portion, and wherein the transverse axis of the first portion is substantially perpendicular to the transverse axis of the second portion when the first and second portions are connected.
• the prior art suffers from a number of problems and/or disadvantages.
• An object of at least embodiment of at least one aspect of present invention may be to seek to obviate or at least mitigate one or more problems and/or disadvantages in the prior art.
• a connector such as a mooring connector, subsea connector, underwater connector and/or offshore connector.
• the connector may comprise a first portion.
• the connector may comprise a second portion.
• the connector may comprise an arrangement for releasably locking the first portion and the second portion.
• the releasable lock arrangement may comprise at least one movable lock or stopper member which may be (resiliently/sprung) biased toward(s) a first position.
• the first portion may comprise a male portion.
• the second portion may comprise a female portion.
• the first portion may be receivable within the second portion.
• the second portion may comprise a through-bore.
• the through-bore may have first portion entry and/or exit ends.
• The/each at least one movable lock member may be provided on the second portion, such as at or adjacent a/the exit end of a/the through-bore, and may be connected, for example, hingably attached thereto.
• the at least one movable lock member When in the first position the at least one movable lock member may overlap (with) a/the through-bore of the second portion when viewed along an axis of the through- bore.
• the at least one movable lock member may be resiliently movable (e.g., against an action of a spring or biasing arrangement) from the first position to a second position and to a third position by insertion of the first portion into the second portion.
• each lock or stopper member may be resiliently movable (e.g., against an action of a/the spring or biasing arrangement) from the third position to the second position and to the first position by withdrawal of the first portion from the second portion.
• the first position and the third position may be one and the same.
• the first position may be a radially proximal position
• the second position may be a radially distal position
• the third position may be a radially proximal position relative to an/the axis of a/the through-bore of the second portion.
• the or each stopper member may be movable against the action of a biasing arrangement by insertion of the first portion into the second portion and/or by removal of the first portion from the second portion.
• the releasable lock arrangement may be adapted to take or transmit tension between a line, such as a mooring line, and a structure through the connector.
• the connector may comprise an (rotation) arrangement for rotating the first portion relative to the second portion when the first portion is inserted into and/or withdrawn from the second portion.
• the rotation arrangement may cause the first portion and second portion to adopt a pre-selected rotational disposition when mated.
• the rotation arrangement may comprise at least one or one cam follower, pin or protrusion on one of the first portion (or the second portion) and a guide or cam track on (the other of) the second portion (or the first portion).
• At least one biassing arrangement/member or spring member There may be provided at least one biassing arrangement/member or spring member.
• a first end of the/each biassing member may be connected to a first movable lock member.
• a second end of the/each biassing member may be connected to a second movable lock member.
• a first end of the first movable lock member may be connected to a first end of a (first) biassing member. (A second end of the first movable lock member may be connected to the second biassing member).
• a first end of the second movable lock member may be connected to a second end of the (first) biassing member.
• a second end of the second movable lock member may be connected to the second biassing member.
• the first portion may comprise at least one recess or notch adapted to receive the/one of the movable lock -member(s), such as in a lock position, such as a/the third position.
• the first portion may comprise at least one opposing pair of recesses or notches adapted to lock or engage with a/the pair of opposing or facing movable lock members, such as when in a/the respective third positions.
• the first portion may provide a mooring line connection arrangement.
• the first portion may have a first end adapted for insertion into the second portion.
• the first portion may have a second end adapted for connection to a mooring line.
• the first portion may have an arrangement for allowing movement of the first portion relative to a mooring line, preferably the movement allowing arrangement being provided at or adjacent an end/the second end of the first portion and/or being adapt to allow relative movement in two perpendicular axes.
• the connector may comprise a mooring line or leg connector for use with a mooring line or leg extending up from a floor of a body of water, such as a sea floor, for example, to connect a floating structure to be moored to the floor of the body of water.
• Connection and disconnection of the connector or the line may be done by pulling in and/or out on the first portion (which may comprise an elongate body), for example, using a work line.
• the at least one movable lock member may comprise at least part of a latch mechanism for connecting or fixing a/the line to a/the structure to be moored.
• an arrangement for releasably connecting the first and second portions Preferably there may be provided an arrangement for releasably connecting the first and second portions.
• the at least one movable lock member may comprise at least part of the releasable connection arrangement.
• the releasable connection arrangement may comprise at least part of a/the through-passage in the second portion.
• the first portion may comprise an arrangement/means for connecting or connection to one or more lines, such as mooring lines, preferably allowing rotational movement around or about at least one transverse axis of the first portion with respect to the line.
• lines such as mooring lines
• the second portion may comprise an arrangement/means for connecting or connection to a (subsea) structure, preferably allowing rotational movement around or about a transverse axis of the second portion with respect to the structure.
• the transverse axis of the first portion may be substantially perpendicular to the transverse axis of the second portion (e.g., when the first and second portions are connected/mated).
• A/the through-passage of the second portion may be capable of receiving a workline or wire.
• A/the arrangement for connecting the first portion to a line may comprise one or more first bearing means.
• the one or more first bearing means may comprise a clevis arrangement.
• A/the arrangement for connecting the second portion to a structure may comprise one or more second bearing means.
• the one or more second bearing means may comprise one or more protrusions or trunnions.
• the one or more protrusions or trunnions may provide a/the transverse axis of the second portion.
• A/the transverse axis of the second portion may be substantially horizontal (for example, in use).
• A/the transverse axis of the first portion may be substantially orthogonal or perpendicular to the transverse axis of the second portion, for example, in use, when the first and second portions are connected.
• the connector may comprise the first portion, the second portion, and a/the arrangement for connecting the first and second portions, wherein the arrangement for connecting may comprise at least part of a/the through-passage in the second portion, the through-passage optionally being capable of receiving a work-line or wire, the first portion comprising an arrangement for releasably connecting to the work-line or wire, the line connecting arrangement preferably comprising first and second line connection means, the first line connection means preferably being configured for releasably engaging with the second line connection means, and the engagement between the first and second line connection means preferably being caused by tension created between the work line or wire and the first portion of the connector.
• the connector may comprise a/the first portion comprising a male part, a/the second portion comprising a female part, and a/the arrangement or means for connecting the first and second portions, wherein the arrangement for connecting may comprise at least part of a/the through- passage in the second portion, the first portion may comprise means for connecting the first portion to one or more (mooring) line(s), the means for connecting the first portion to one or more line(s) preferably being configured to allow rotational movement of the first portion with respect to one or more line(s) about a transverse axis B, C of the first portion, the second portion may comprise a/the arrangement or means for connecting the second portion to a structure, such as an underwater structure or submersible or semisubmersible structure, wherein the arrangement or means for connecting the second portion to a structure may be configured to allow rotational movement of the second portion with respect to a structure about a transverse axis D of the second portion, the means for connecting the second portion to a structure preferably comprising bearing means which provide rotational movement
• the connector may comprise a/the first portion comprising a male part, a second portion comprising a female part, and a/the arrangement or means for connecting the first and second portions, wherein the means for connecting may comprise at least part of a/the through-passage in the second portion, the first portion may comprise means for connecting the first portion to one or more (mooring) line(s), the means for connecting the first portion to one or more line(s) preferably being configured to allow rotational movement of the first portion with respect to one or more line(s) about a transverse axis B, C of the first portion, the second portion may comprise means for connecting the second portion to an underwater structure, wherein the means for connecting the second portion to an underwater structure may be configured to allow rotational movement of the second portion with respect to an underwater structure about a transverse axis D of the second portion, the means for connecting the second portion to an underwater structure preferably comprising bearing means comprising a pair of protrusions or trunnions provided on the transverse axis of the second portion on opposite
• the at least one movable lock member may be moved from the first position to the second position by insertion of the first portion into the second portion.
• the at least one movable member may be moved from the second position to the third position be further insertion of the first portion/member into the second portion/member.
• Such insertion and further insertion may be referred to as an “engage/install/lock sequence”.
• the at least one movable lock member may be moved from the third position to the second position by yet further insertion of the first portion into the second portion.
• the at least one movable member may be moved from the second position to the first position be removal of the first portion/member from the second portion/member.
• Such yet further insertion and removal may be referred to a “disengagement/de-install/release sequence”.
• the at least one movable lock member may be moved from the first position to the second position by insertion of the first portion into the second portion.
• the at least one movable member may be moved from the second position to the third position be further insertion of the first portion/member into the second portion/member.
• Such insertion and further insertion may be referred to as an “engage/install/lock sequence”.
• the at least one movable lock member may be moved from the third position to the second position by a release member.
• the release member may be moved/controlled by a release line, e.g., by pulling/tensioning the release line.
• the at least one movable member may be moved from the second position to the first position by a/the at least one biasing member and/or the release member, e.g., by releasing/de-tensioning the release line thereby allowing the at least one biasing member to act on the at least one movable lock member.
• Such pulling and release of the release line may be referred to a “disengagement/de-install/release sequence”.
• the first portion may be removed from the second portion by yet further insertion of the first portion into the second portion followed by removal of the first portion from the second portion.
• Such yet further insertion and removal may be referred to a/the “disengagement/de-install/release sequence”.
• the first implementation may be referred to as “an automatic connector”.
• the second implementation may be referred to as “a semi-automatic connector”.
• a connector such as a mooring connector, subsea connector, underwater connector and/or offshore connector.
• the connector may comprise: at least one movable lock member; a first portion; and/or a second portion.
• the at least one movable lock member may be moved from a first (closed) position to the second (opened) position by insertion of the first portion into the second portion, e.g., into a through-bore of the second portion.
• the at least one movable member may be moved from the second (opened) position to a third (closed) position be further insertion of the first portion/member into the second portion/member.
• Such insertion and further insertion may be referred to as an “engage/install/lock sequence”.
• the at least one movable lock member may be moved from a/the third (closed) position to a/the second (opened) position by a release member.
• the release member may be moved/controlled by a release line, e.g., by pulling/tensioning the release line.
• the at least one lock movable member may be moved from the second (opened) position to a/the first (closed) position by at least one biassing member and/or the release member, e.g., by releasing/de-tensioning the release line thereby allowing the at least one biasing member to act on the at least one movable lock member.
• the first portion may be removed from the second portion by yet further insertion of the first portion into the second portion followed by removal of the first portion from the second portion. Such yet further insertion and removal may be referred to a/the “disengagement/de-install/release sequence”.
• Such pulling/tensioning, release/de-tensioning and release of the release line and (intermediate) further insertion of the first portion into the second portion may be referred to a “disengagement/de-install/release sequence”.
• Embodiments of the invention according to the second aspect of the present invention may be referred to as “a semi-automatic connector”.
• a connector according to the first/second aspect of the present invention may optionally and/or beneficially comprise or include one or more features of a connector according to the second/first aspect of the present invention.
• a structure or a marine, floating, buoyant, subsea, underwater and/or offshore structure, apparatus, equipment or vessel, when moored by one or more lines.
• At least one or more lines may be connected to the structure, or the marine, floating, buoyant, subsea, underwater or offshore structure, apparatus, equipment or vessel, by a connector according to the first or second aspect of the present invention.
• the structure, apparatus, equipment or vessel may comprise: a buoy, for example, a submerged turret loading or a submerged turret production buoy.
• the structure, apparatus, equipment or vessel may be adapted to be semisubmersible.
• the structure, apparatus, equipment or vessel may comprise a floating (oil or gas) platform, for example, a production platform or SPAR, or (offshore) renewable energy generator or wind turbine.
• a floating (oil or gas) platform for example, a production platform or SPAR, or (offshore) renewable energy generator or wind turbine.
• a fourth aspect of the present invention there is provided a method of mooring, anchoring or fixing a structure, or floating, buoyant, subsea, underwater and/or offshore structure, apparatus, equipment or vessel, by one or more lines.
• the method may comprise the step of connecting at least one line to a structure, or a subsea, underwater or offshore equipment, apparatus or structure, by using a connector according to the first or second aspect of the present invention.
• Figure 1 a perspective view of a mooring connector according to a first embodiment of the present invention
• Figure 2(a) a cross-sectional side view of the mooring connector of Figure 1 ;
• FIG. 2(b) a further side view of the mooring connector of Figure 1 ;
• Figure 3 a perspective view of a first portion of the mooring connector of Figure 1 ;
• Figure 4(a) a perspective view of a second portion of the mooring connector of Figure 1 ;
• Figure 4(b) a further perspective view of the second portion of the mooring connector of Figure 1 ;
• Figure 5(a) a perspective view of the first portion of Figure 3 being engaged or mated with the second portion of Figure 4(a);
• Figure 5(b) a first partially cut-away perspective view of the mooring connector of Figure 1 ;
• Figure 6(a) a second partially cut-away perspective view of the mooring connector of Figure 1 ;
• Figure 6(b) a third partially cut-away perspective view of the mooring connector of Figure 1 ;
• Figure 7(a) a fourth partially cut-away perspective view of the mooring connector of Figure 1 ;
• Figure 7(b) a fifth partially cut-away perspective view of the mooring connector of Figure 1 ;
• Figure 8(a) a sixth partially cut-away perspective view of the mooring connector of Figure 1 ;
• Figure 8(b) a seventh partially cut-away perspective view of the mooring connector of Figure 1 ;
• Figure 9 a perspective view of the first portion of Figure 3 being disengaged from the second portion of Figure 4(a);
• Figures 10(a) to (e) a series of side views of the first portion of Figure 3 illustrating relative movement between a cam track of the first portion and a cam follower or pin of the second portion during an engage and a disengage procedure;
• Figure 11 a schematic view of a (subsea) structure connected to a vessel with the structure moored to the seabed with one or more mooring connectors according to Figure 1 ;
• Figure 12 a schematic view of a mooring connector according to Figure 1 connected to a structure
• FIG. 13(a) and (b) schematic views of the mooring connector of Figure 12 where the first portion is being pulled towards the second portion;
• Figure 14 a schematic view of the mooring connector of Figure 12 where the first portion has been received within the second portion;
• Figure 15 a schematic view of the structure of Figure 11 , the structure having retaining members configured for (releasably) securing the second portion to the structure;
• Figure 16(a) and (b) a perspective view of the first portion of the mooring connector according to a second embodiment of the present invention and a perspective view of the mooring connector of the second embodiment;
• Figure 17(a) and (b) a perspective view of the first portion of the mooring connector according to a third embodiment of the present invention and a perspective view of the mooring connector of the third embodiment;
• Figures 18(a) to (f) a series of figures illustrating an install sequence of the mooring connector of Figure 17(b);
• Figure 19 a partial side view of the mooring connector of Figure 17(a) illustrating a release stage
• Figure 20 (a) to (c) a series of figures of a side view of a second portion of the mooring connector of Figure 17(b) illustrating a release
• Figure 21(a) and (b) first and second drawings of a top view of the second portion of the mooring connector of Figure 17(b) corresponding to Figures 20 (a) and 20 (c), respectively.
• a connector (mooring connector), generally designated 5, according to a first embodiment of the present invention.
• the connector 5 comprises a first portion 10.
• the connector 5 comprises a second portion 15.
• the connector 5 comprises an arrangement, generally designated 20, for releasably locking the first portion 10 and the second portion 15.
• the releasable lock arrangement 20 comprises at least one movable lock or stopper member 25 which is (resiliently/sprung) biased toward(s) a first position - see Figure 4(a).
• the first portion 10 comprises a male portion 30.
• the second portion 15 comprises a female portion 35.
• the first portion 10 is receivable within the second portion 15.
• the second portion 15 comprises a through-bore 40.
• the through-bore 40 has first portion entry and exit ends 45, 50.
• The/each at least one movable lock member 25 is provided on the second portion 15, such as at or adjacent a/the exit end 50 of the through-bore 40, and is hingably attached thereto by hinges 55.
• the at least one movable lock member 25 overlaps with a/the through-bore 40 of the second portion 15 when viewed along an axis A of the through-bore 40.
• the at least one movable lock member 25 is resiliently movable (e.g., against an action of at least one biassing arrangement, member or spring 60) from the first position ( Figures 5(a) and (b), to a second position ( Figures 6(a) and (b)), and to a third (locked) position ( Figures 7(a) and (b)) by insertion of the first portion 10 into the second portion 15.
• each movable lock member 25 is resiliently movable (e.g., against an action of biassing arrangement or spring 60) from the third position to the second position and to the first position by withdrawal of the first portion 10 from the second portion 15.
• the first position and the third position can be one and the same.
• the first position is a radially proximal position
• the second position is a radially distal position
• the third position is a radially proximal position relative to the axis X of the through-bore 40 of the second portion 15.
• the or each movable lock member 25 is movable against the action of the biasing arrangement 60 by insertion of the first portion 10 into the second portion 15 and/or by removal of the first portion 10 from the second portion 15.
• the releasable lock arrangement 20 is adapted to take or transmit tension between a line 100, such as a mooring line, and a structure 105 through the connector 5.
• the connector 5 comprise an arrangement, generally designated 61 , for rotating the first portion 10 relative to the second portion 15 when the first portion 10 is inserted into and/or withdrawn from the second portion 15.
• the rotation arrangement 61 comprises at least one or one cam follower, pin or protrusion 62 on one of the first portion 10 (or the second portion 15) and a guide or cam track 63 on (the other of) the second portion 15 (or the first portion 10).
• At least one (a first) biassing member or spring 60a is also provided.
• a first end 65a of the biassing member 60a is connected to the first movable lock member 25a.
• a second end 70a of the biassing member 60a is connected to the second movable lock member 25b.
• a first end 75a of the first movable lock member 25a is connected to the first end 65a of the biassing member 60a.
• a second end 80a of the first movable lock member 25a is connected to a second biassing member 60b).
• a first end 75b of the second movable lock member 25b is connected to a second end 70a of the biassing member 60a. (In said modification, a second end 80b of the second movable lock member 25b is connected to the second biassing member 60b).
• the first portion 10 comprises at least one recess or notch 82 adapted to receive the/one of the movable lock member(s) 25, such in a lock position, such as a/the third position.
• the first portion 10 comprises at least one opposing pair of recesses or notches 82a, 82b adapted to lock or engage with a/the pair of opposing or facing movable lock members 25a, 25b, such as when in a/the respective third positions.
• the first portion 10 provides a (mooring) line connection arrangement, generally designated 84.
• the first portion 10 has a first end 86 adapted for insertion into the second portion 15.
• the first portion 10 has a second end 88 adapted for connection to a (mooring) line 100.
• the first portion 10 has an arrangement, generally designated 90, for allowing movement or articulation of the first portion 10 relative to a (mooring) line 100, advantageously the movement allowing arrangement 90 being provided at or adjacent an end/the second end 88 of the first portion 10 and/or being adapt to allow relative movement in two perpendicular axes B, C.
• the connector 5 comprise a mooring line or leg connector for use with a mooring line or leg extending up from a floor of a body of water, such as a sea floor, for example, to connect a floating structure to be moored to the floor of the body of water.
• connection and disconnection of the connector 5 or the line 100 can be done by pulling in and/or out on the first portion 10 comprising an elongate body, for example, using a work line 92 (see Figures 13(a), (b) and 14).
• the at least one movable lock member 25 comprises at least part of a latch mechanism for connecting or fixing a/the line 100 to a/the structure 105 to be moored.
• the at least one movable member 25 comprises at least part of the releasable connection arrangement 20.
• the releasable connection arrangement 20 comprises at least part of a/the through-bore or through-passage 40 in the second portion 15.
• the first portion 10 comprises means for connecting or connection to one or more lines 100, such as mooring lines, advantageously allowing rotational movement around or about at least one transverse axis B, C of the first portion 10 with respect to the line 100.
• lines 100 such as mooring lines
• the second portion 15 comprises means 94 for connecting or connection to a (subsea) structure, advantageously allowing rotational movement around or about a transverse axis D of the second portion 15 with respect to the structure 105.
• the transverse axis B of the first portion 10 is substantially perpendicular to the transverse axis D of the second portion 15, in use.
• the through-bore 40 of the second portion 15 is capable of receiving a work-line or wire 92.
• the arrangement 90 for connecting the first portion 10 to a line 100 comprise one or more first bearing means 95.
• the one or more first bearing means 95 comprise a clevis arrangement.
• the arrangement 94 for connecting the second portion 15 to a structure 105 comprises one or more second bearing means 96.
• the one or more second bearing means 96 comprise one or more protrusions or trunnions.
• the one or more protrusions or trunnions provide a/the transverse axis D of the second portion 15.
• A/the transverse axis D of the second portion 15 is typically substantially horizontal (for example, in use).
• A/the transverse axis B of the first portion 10 is substantially orthogonal or perpendicular to the transverse axis D of the second portion 15, in use, when the first and second portions 10, 15 are connected.
• the connector 5 comprises the first portion 10, the second portion 15, and a/the arrangement 20 for connecting the first and second portions 10, 15, wherein the arrangement 20 for connecting comprises at least part of a/the through-bore 40 in the second portion 15, the through-bore being capable of receiving a work line or wire 92, the first portion 10 comprising an arrangement 97 for releasably connecting to the work line or wire 92, the work line connecting arrangement 97 comprising first and second line connection means 98, 99, the first line connection means 98 being configured for releasably engaging with the second line connection means 99, and the engagement between the first and second line connection means 98, 99 being caused by tension created between the work line or wire 100 and the first portion 10 of the connector 5, for example, by pulling on the work line 100.
• the connector 5 comprises a/the first portion 10 comprising a male part, a/the second portion 15 comprising a female part, and a/the arrangement or means 20 for connecting the first and second portions 10, 15, wherein the arrangement 20 for connecting comprises at least part of a/the through- passage 40 in the second portion15, the first portion 10 comprises an arrangement 84 or means for connecting the first portion 10 to one or more (mooring) line(s) 100, the arrangement 84 or means for connecting the first portion 10 to one or more line(s) 100 beneficially being configured to allow rotational movement of the first portion 10 with respect to one or more line(s) 100 about at least one transverse axis B and/or C of the first portion 10, the second portion 15 comprises a/the arrangement 94 or means for connecting the second portion 15 to a structure 105, such as an underwater structure or submersible or semi-submersible structure, wherein the arrangement 94 or means for connecting the second portion 15 to a structure 105 is configured to allow rotational movement of the second portion 15 with respect to a structure
• the connectors comprises a/the first portion 10 comprising a male part, a second portion 15 comprising a female part, and a/the arrangement or means 20 for connecting the first and second portions 10, 15, wherein the arrangement 20 for connecting comprises at least part of a/the through- passage 40 in the second portion 15, the first portion 10 comprises an arrangement 84 or means for connecting the first portion 10 to one or more (mooring) line(s) 100, the arrangement 84 or means for connecting the first portion 10 to one or more line(s) 100 beneficially being configured to allow rotational movement of the first portion 10 with respect to one or more line(s) 100 about a transverse axis B and/or C of the first portion 10, the second portion 15 comprise an arrangement 94 or means for connecting the second portion 15 to a structure 105, wherein the arrangement 94 or means for connecting the second portion 15 to a structure 105 is configured to allow rotational movement of the second portion 15 with respect to a structure 105 about a transverse axis D of the second portion 15, the arrangement 94 or means for connecting
• FIG. 11 to 15 there is shown a structure, or subsea, underwater or offshore structure, apparatus, equipment or vessel, generally designated 105, moored by one or more lines 100.
• At least one or more lines 100 is/are connected to the structure 105 by a connector 5 as hereinbefore described.
• the structure, or underwater or offshore structure, apparatus, equipment or vessel can comprise, for example, a submerged turret loading, a submerged turret production buoy, floating (oil/gas) production platform or SPAR, or (offshore) renewable energy generator or wind turbine.
• an ROV (not shown) can run the work line or wire 100 through the through- bore 40 of the female part.
• the ROV can connect the work line or wire 100 which comprises the first line connection means 98 to the second line connection means 99 of the male part.
• first line connection means 98 and the second line connection means 99 can be facilitated by tensioning, that is pulling, the work-line 100 in an upward direction (see Figure 13(a) and (b)) thereby creating tension between the work-line or wire 100 and the first portion 10 of the connector 5.
• the ROV can pull the male part towards the female part such that the male part is inserted into the female part.
• a (temporary/removable) sheave member 110 mounted on or to the structure 105 facilitates the pulling of the first portion 10 towards the second portion 15.
• insertion of the male part into the female part may cause the rotation arrangement 61 to act by causing the cam follower 62 to follow the cam track 63 thereby rotating the first portion 10 until the cam follower reaches a lock position in the cam track 63 where the notches 82a, 82b are rotationally aligned with the first and second lock members 25a, 25b and the lock members 25a, 25b are biased or spring into the notches 82a, 82b, respectively, thereby locking the first portion 10 within the second portion 15 in a predetermined rotational disposition.
• the work-line 100 and/or sheave can then be removed using the ROV. (See Figures 7(a) and (b)).
• the work-line 100 and/or sheave can be reinstalled using an ROV, and the work-line 105 connected to the first portion 10.
• the work line 100 can (again) be tensioned or pulled causing the cam follower 62 to follow the cam track 63 thereby rotating the first part 10 out of the predetermined rotational (lock) alignment with the second portion 15. That is to say the notches 82a, 82b are rotated out of alignment with the lock members 80a, 80b. This facilitates removal of the first portion 10 from the second portion 15, and therefore disconnection of the work-line 100 from the structure 105. (See Figures 8(a) and (b)).
• a method of mooring, anchoring or fixing a structure, or marine, floating, buoyant, subsea, underwater or offshore structure, apparatus, equipment or vessel, by one or more lines may comprise the step of connecting at least one line to a structure, or a marine, floating, buoyant, subsea, underwater or offshore equipment, apparatus or structure by using a connector 5 as hereinbefore described.
• FIG. 16(a) and (b) there is shown a connector (mooring connector), generally designated 205, according to a second embodiment of the present invention.
• the connector 205 is similar in many respects to the connector 5 of Figures 1 to 10(e), like parts being designated with like numerals but iterated by “200”.
• FIG. 17(a) to 21 (b) there is shown a connector (mooring connector), generally designated 305, according to a third embodiment of the present invention.
• the connector 305 is similar in many respects to the connector 5 of Figures 1 to 10(e), like parts being designated with like numerals but iterated by “300”.
• the at least one movable lock member 25; 225 in use, is moved from the first position to the second position by insertion of the first portion 10; 215 into the second portion 15; 215.
• the at least one movable member 25; 225 is moved from the second position to the third position be further insertion of the first portion 10; 210 into the second portion 15; 215.
• Such insertion and further insertion is referred to as an “engage/install/lock sequence”.
• the at least one movable lock member 25; 225 in use, is moved from the third position to the second position by yet further insertion of the first portion 10; 210 into the second portion 215.
• the at least one movable member 25; 225 is moved from the second position to the first position be removal of the first portion 10; 210 from the second portion 15; 215.
• Such yet further insertion and removal is referred to a “disengagement/de-install/release sequence”.
• the at least one movable lock member 325 in use, is moved from the first position to the second position by insertion of the first portion 310 into the second portion 315.
• the at least one movable member 325 is moved from the second position to the third position be further insertion of the first portion 310 into the second portion 315.
• Such insertion and further insertion is referred to as an “engage/install/lock sequence”.
• the at least one movable lock member 325 in use, is moved from the third position to the second position by action of a release member 356.
• the release member 356 is moved/controlled by a release line 357, e.g., by pulling/tensioning the release line 357.
• the at least one movable member 325 is moved from the second position to the first position by the at least one biasing member 360 and/or the release member 356, e.g., by releasing/de-tensioning the release line 357 thereby allowing the at least one biasing member 360 to act on the at least one movable lock member 325.
• Such pulling and release of the release line is referred to a “disengagement/de-install/release sequence”.
• the first portion 310 is removed from the second portion 315 by yet further insertion of the first portion 310 into the second portion 315 followed by removal of the first portion 310 from the second portion 315.
• Such yet further insertion and removal is referred to a/the “disengagement/de-install/release sequence”.
• the connectors 5; 205 of the first and second embodiments may be referred to as “an automatic connector”.
• the connector 305 of the third embodiment may be referred to as “a semi-automatic connector”.
• the connector 305 of the third embodiment differs from the connector 5 of the first embodiment in a number of respects.
• the connector 305 (mooring connector, subsea connector, underwater connector and/or offshore connector) comprises: at least one movable lock member 325; a first portion 310; and a second portion 315.
• the at least one movable lock member 325 is moved from a first (closed) position to the second (opened) position by insertion of the first portion 310 into the second portion 315, e.g., into the through-bore of the second portion 315.
• the at least one movable member 325 is moved from the second (opened) position to the third (closed) position be further insertion of the first portion 310 into the second portion 315.
• Such insertion and further insertion is referred to as an “engage/install/lock sequence”.
• the at least one movable lock member 325 is moved from the third (closed) position to the second (opened) position by a release member 356.
• the release member 356 is moved/controlled by a release line 357, e.g., by pulling/tensioning the release line 357.
• the at least one lock movable member 325 is moved from the second (opened) position to the first (closed) position by at least one biassing member 325 and/or the release member 356, e.g., by releasing/de-tensioning the release line 357 thereby allowing the at least one biasing member 360 to act on the at least one movable lock member 325.
• the first portion 310 is removed from the second portion 315 by yet further insertion of the first portion 310 into the second portion 315 followed by removal of the first portion 310 from the second portion 315.
• Such pulling/tensioning, release/de-tensioning and release of the release line and (intermediate) further insertion of the first portion into the second portion is referred to (part of) a “disengagement/de-install/release sequence”.
• a surface of the/each movable lock member 25a, 25b that faces the through-bore 44 of the second portion can be of a concave shape, for example, to facilitate abutment with the first portion 10 and ease of movement of the movable lock members 25a, 25b between the first position and the second position upon insertion of the first portion 10 into the second portion 15, and/or ease of movement of the movable lock members 25a, 25b between the second position and the first position upon removal of the first portion 10 from the second portion 15.

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• Chemical & Material Sciences (AREA)
• Engineering & Computer Science (AREA)
• Combustion & Propulsion (AREA)
• Mechanical Engineering (AREA)
• Ocean & Marine Engineering (AREA)
• Connector Housings Or Holding Contact Members (AREA)
• Details Of Connecting Devices For Male And Female Coupling (AREA)
• Mechanical Coupling Of Light Guides (AREA)
• Laying Of Electric Cables Or Lines Outside (AREA)
• Earth Drilling (AREA)
• Quick-Acting Or Multi-Walled Pipe Joints (AREA)

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• 2021
  • 2021-11-30 WO PCT/EP2021/083529 patent/WO2022122466A1/en active Application Filing
  • 2021-11-30 AU AU2021394549A patent/AU2021394549A1/en active Pending
  • 2021-11-30 JP JP2023535462A patent/JP2023554613A/ja active Pending
  • 2021-11-30 EP EP21836345.5A patent/EP4240645A1/en active Pending
  • 2021-11-30 US US18/256,605 patent/US20240067308A1/en active Pending
  • 2021-11-30 CA CA3201578A patent/CA3201578A1/en active Pending
  • 2021-11-30 KR KR1020237023163A patent/KR20230113811A/ko unknown

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