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    • 专利摘要:
    WELL LOCATION CONNECTOR, E, METHOD FOR CONNECTING COMPONENTS FROM A WELL LOCATION A well location connector is provided to connect components from a well location. The well site has a well extending into a subsurface formation. The well location connector includes a connector body, having an end adapted to mate with a first component and a cavity for receiving a second component, an axially movable piston in the connector body and having a piston profile along an internal surface, and a plurality of indicator claws. The indicator claws are positioned around the connector body, adjacent to the piston and radially movable around it. The indicator claws have an indicator claw profile along their outer surface, corresponding to the piston profile of the piston. The indicator claws also have a grip profile, along their internal surface, selectively interlockable with the second of the components, whereby the indicator claws are selectively engaging around the second of the components.
    公开号:BR112014024680B1
    申请号:R112014024680-7
    申请日:2013-04-04
    公开日:2020-12-01
    发明作者:Douglas A. Jahnke
    申请人:National Oilwell Varco, L.P.；
    IPC主号:
    专利说明:

    [0001] [0001] The present description refers generally to connectors used in well site operations. More specifically, the present description relates to wellhead connectors, such as wellhead and / or submarine connectors, for connecting wellhead components.
    [0002] [0002] Various oil field operations can be carried out to locate and assemble valuable downhole fluids. Oil platforms are positioned at wellhead locations and downhole tools, such as drilling tools, are positioned inside the earth to reach subsurface reservoirs. Once the downhole tools of a well hole (or borehole) reach a desired reservoir, the casing tubes can be cemented into position within the well hole and the well hole is completed to start production. reservoir fluids. Tubular (or tubular columns) can be provided to pass subsurface fluids to the surface.
    [0003] [0003] A wellhead can be provided around the top of the wellbore to support the casing tubes within the wellbore. A wellhead connector can be provided to connect the wellhead to surface components, such as a preventive eruption controller (BOP) and / or a Christmas tree. In some wells, a tubular wellhead is located on the seabed. During drilling operations, a riser extends from a vessel on the surface to the wellhead. A wellhead connector connects the bottom end of the vertical or rising tube to the wellhead. A wellhead connector can also be used to connect an underwater production tree to the wellhead.
    [0004] [0004] Connectors can be used in subsea applications, Subsea connectors are used to join subsea devices in an underwater chimney. If seabed gas migrates into an underwater connector, under correct conditions, the gas can form hydrates, which are solids from hydrocarbon gases and water, inside the connector. Hydrates can accumulate inside the connector to an extent that they interfere with the operation of the connector's engagement mechanism. To prevent or control hydrate build-up in the connector, a hydrate seal can be used to prevent or control the migration of gas into the connector. Some examples of connectors are provided in U.S. Patent Applications Nos. 4,557,508; 8,016,042; 7,614,453; 4,902,044; 2010/0006298; 4606555; 4606555 and 5332043. SUMMARY OF THE INVENTION
    [0005] [0005] In at least one aspect, the techniques here can refer to a wellhead connector for connecting components from a wellhead. The well site has a well extending into a subsurface formation. The pit location connector includes a connector body, a piston and a plurality of indicator claws. The connector body has an end adapted to mate with a first component and a cavity for receiving a second component. The piston is axially movable in the connector body, the piston having a piston profile along its internal surface. The indicator claws are positioned around the connector body adjacent to the piston and radially movable around it. The indicator claws also have an indicator claw profile along its outer surface corresponding to the piston profile of the piston, and a grip profile along its internal surface selectively interlockable with the second of the components, whereby the indicator claws are selectively latched around the second of the components.
    [0006] [0006] The wellhead connector may also include a floating sealing member, comprising a flexible ring having a hole through it to seal the second of the components, the sealing member is slidably movable within the cavity of the connector body. transversely to a geometric axis of the connector body, whereby the second component is aligned with the first component for connection between them. The connector body includes a cover operably connectable to the first component and a sub having a hole through it to receive the second component. The cover has a cover location that fits in with the indicator jaw profile of the indicator jaws. The connector body also includes a body ring operatively coupled between the cover and the sub.
    [0007] [0007] The indicator claws have a body profile selectively nestable with the connector body. The connector body defines an indicator jaw cavity for receiving the indicator jaws. The indicator claws are mobile at a distance from a cover receptacle and define an interstice between them. The connector body has an internal surface defining a cavity to slide the piston. The piston includes a support ring on its inner surface, the support ring defining a part of the piston profile to support the plurality of indicator claws on it in the retracted position. The piston includes an engagement ring on its inner surface. The engagement ring defines a portion of the piston profile to support the indicator claws in the engaged position. The piston includes a primary piston that can be plugged in with the indicator claws and a secondary piston supporting the primary piston. The secondary piston is slidably movable in the connector body, when the primary piston exceeds the maximum shape.
    [0008] [0008] The piston separates the cavity of the connector body in a first variable volume and a second variable volume. The first variable volume chamber and the second variable volume chamber are operably connectable to a fluid source to selectively deflect fluid from it, whereby the piston is movable within the body between an upward stroke and a downward stroke position . The components include at least two of a tubular, a casing column, a riser, a wellhead, an eruption preventive controller, a lower marine suppression pump and their combinations.
    [0009] [0009] In another aspect, the description may refer to a method of connecting components from a well site. The pit location has a borehole extending into a subsurface formation. The method includes providing the well location connector, operatively connecting the end of the connector body to the first of the components, receiving the second of the components in the cavity of the connector body and selectively engaging the indicator claws around the second of the components by selectively fitting the profile of indicator claw of the plurality of indicator claws with the piston profile of the piston and the grip profile of the indicator claws with the second of the components.
    [0010] [00010] The method may also involve aligning the second components with the first component for connection between them by slidingly moving the sealing member on the connector body transversely to a geometric axis and / or selectively engaging comprises moving the piston by pumping selectively the fluid for the first and second variable chambers. Selectively engaging may involve supporting the indicator claws on a piston claw ring, pivoting the plurality of indicator claws by axially moving the piston within the connector body, fitting a piston piston profile with an indicator claw profile of the indicator claw, press the plurality of indicator claws against the second of the components, fitting a piston engagement ring with the plurality of indicator claws, retract the indicator claws by aligning the piston profile of the piston with the indicator claw profile of the indicator claws, extending the claws indicator by misaligning the piston profile of the piston with the indicator claw profile of the indicator claws, selectively fitting a body part of the indicator claws with the connector body and / or operatively connecting at least two of a tubular, a column of tubes, a tube upstream, a wellhead, an eruption preventive controller, a supply pump marine essences and their combinations.
    [0011] [00011] In another aspect, the description can refer to an underwater connector for a tubular of an underwater well location. The submarine connector includes a connector body having an open end to accept a tubular column or tool having a connection profile, at least one indicator clamp movably fixed for vertical support in said connector body, a horizontal support fixed in said body, for contact selective with a first end of said indicator claw, and at least one axially movable piston, having a horizontal support surface, after selective movement of said piston cams a profile in a second end of said indicator claw to fit and retain said profile in tubular column or tool connection profile. The movement of said piston can cause said first end of said indicator claw to contact said fixed horizontal support.
    [0012] [00012] The foregoing general description and the following detailed description are exemplary of the invention and are intended to provide an assessment or outline for understanding the nature and character of the invention as claimed. The accompanying drawings are included to provide a further understanding of the invention and are incorporated and constitute a part of this report. The drawings illustrate various embodiments of the invention and, together with the description, serve to explain the principles and operation of the invention. BRIEF DESCRIPTION OF THE DRAWINGS
    [0013] [00013] So that the details and advantages mentioned above can be understood in detail, a more particular description, briefly summarized above, can be taken by reference to its embodiments that are illustrated in the attached drawings. It should be noted, however, that the attached drawings illustrate only typical embodiments and are therefore not to be considered as limiting their scope. The figures are not necessarily to scale and certain details and certain views of the figures can be shown exaggerated in scale or schematically, in the interests of clarity and conciseness.
    [0014] [00014] Figures 1A and 1B are schematic views of a well location off the coast, having a well location connector connecting various components.
    [0015] [00015] Figures 2A and 2B are seen in vertical cross section of the well location connector of Figure 1B, taken along line 2-2 and shown in an unengaged position and an engaged position, respectively.
    [0016] [00016] Figure 3 is a detailed view of a part of the well location connector of Figures 2A and 2B in an assembled position.
    [0017] [00017] Figure 4 is an exploded view of the well location connector of Figure 2A.
    [0018] [00018] Figure 5 is a flow chart representing a method of connecting subsea components.
    [0019] [00019] Figs. 6A - 6C are seen in cross section of a submarine connector in an unlocked state, an unlocked and misaligned state, and a locked state, respectively.
    [0020] [00020] Figure 7 is a flow chart representing another method of connecting subsea components. DETAILED DESCRIPTION OF THE INVENTION
    [0021] [00021] In the following detailed description, numerous specific details can be exposed in order to provide a complete understanding of the embodiments of the description. However, it will be obvious to a person skilled in the art when embodiments of the description can be practiced without some or all of these specific details. In other examples, well-known details or processes may not be described in detail, so as not to unnecessarily obscure the subject. In addition, the same or identical reference numerals can be used to identify common or similar elements.
    [0022] [00022] Wellhead connectors can read a housing that slides over the wellhead. In one type, a plurality of tabs can be contained by the wellhead connector. Connectors can include grooves on their inner sides. A cam ring can move the tabs inward to engage with the grooves formed on the outside of the wellhead. A plurality of pistons can be spaced circumferentially around the wellhead body, to move a cam ring axially between a locked and an unlocked position. Alternatively, an annular piston can be used to move the cam ring. Due to the large cross section of the cam ring and the number of pistons, the submarine connectors can be large, heavy and expensive to manufacture.
    [0023] [00023] Certain subsea connectors may employ gripping segments that are radially driven by an axially moving piston. For mounting the connection, the annular piston can be above the engagement tabs, so that a recess in the piston is located to allow the tabs to retract when the connection is mounted. When the annular piston is actuated, it can provide support near the upper and lower ends of the engagement tabs which are arcuate segments nested within the annular piston.
    [0024] [00024] The description refers to a well location connector, such as connectors with a fixed upper support for the locking segments that are rotated to the locking position with the movement of the actuation piston, so that a profile of lower body can be used. The pit location connector can have details, such as a fixed upper indicator claw holder with indicator claws configured to be installed or removed without interference. The annular piston is disposed under the waste holder and is axially driven to rotate the indicator claws around an upper profile at the top of the pit location connector. An initial interstice between the indicator jaw and the fixed support allows rotation. The piston height can be shorter and, with the piston top formed in the shape of the fixed support, it can also contribute to the height and associated weight reduction of the pit location connector. A hydraulic system drives the piston. The well location connector can be a land-based or subsea connector to connect various well location components, such as a tubular, a column of tubes, a riser, a wellhead, an eruption preventive controller, a lower marine suppression pump (LMRP) etc.
    [0025] [00025] The subject seeks to provide a project that is compact, light and economically constructed. The design provides a superior rubbish support for latches or engagement indicator claws in the separate piston housing. In the upper position of the piston, a clearance in the fixed support, combined with the piston configuration, allows the indicator claws to be kept retracted at their lower end for assembly. Downward axial movement of the piston rotates the lower end of the indicator claws to fit the well tubular fitting pattern, while moving the top of the indicator claws to the fixed support to lock the marine riser or wellhead to the well tubular.
    [0026] [00026] The total height of the project can be reduced, since no part of the piston may need to be above the indicator claws to assemble the connection, when it is fully assembled and moved over the wellhead or a riser in the unlocked position. The indicator claws articulate close to the upper profile in the assembly and space is provided adjacent to the fixed support to accommodate such rotation of the unconnected indicator claw. The design can be configured to make installing and removing the indicator claws simpler and to remove interference when the index claw fingers open. These and other aspects of the present description will be more readily apparent to those skilled in the art by a recap of the description of the preferred embodiment and the associated drawings, while recognizing that the entire scope of the invention is to be found in the appended claims.
    [0027] [00027] Figures 1A and 1B represent a well site off the coast 100 with various connection configurations. The well site 100 has an undersea system 102 and a surface system 104. The well site 100 is described as being a subsea operation, but can be for any well site environment (eg, land based or Water). Submarine system 102 includes a wellhead 106 extending from a well 112 on a seabed 114, and a wellhead connection unit 108 above it.
    [0028] [00028] Figure 1A shows a connection unit 108. which includes a BOP pr 111, a mandrel 107 and a pair of well location connectors 110a, b. An upper part of the well location connector pair 110a, b is represented as connecting an upper part of the BOP pair 111 with mandrel 107. Mandrel 107 connects the upper well location 110a, b to a lower pair of BOP pair 111. The bottom part of the well location connector pair 110a, b is shown as connecting the lower BOP 111a to the well head 106.
    [0029] [00029] Figure 1B shows another connection unit 108 ', which includes an LMRP 106, a mandrel 107, a lower chimney 109 and a pair of well location connectors 100a, b. An upper part of the well location connector pair 110a is represented as connecting the LMRP 105 with the chuck 107. A lower part of the well location connector pair 110b is represented as connecting the lower chimney 100 to the well head 106. A subsea controller 120 is provided for operation, monitoring and / or control of the well site connector (s) 110a, b, the LMRP 105, the lower chimney 109 and / ου other parts of the well site.
    [0030] [00030] Although Figures 1A and 1B show specific configurations, a variety of well location components (or devices) can be operably connected, such as one or more tubulars, casing tubes, risers, wellheads, guards against explosions, lower marine suppression pump, their combinations and the like. One or more wellhead connectors can connect one or more pairs of components. One or more of the same or different components and / or connectors can be used.
    [0031] [00031] The surface system 104 includes a platform 124, a platform 126 (or vessel), a riser (or tubular) 128 and a surface controller 122. The riser 128 extends from platform 126 to the connection units 108, 108 'to pass fluid through it. Part of (or all) riser tube 128 and / or wellhead 106 can pass through connection unit 108, 108 'and provide fluid communication between them.
    [0032] [00032] Surface controller 122 is provided to operate, monitor and / or control platform 124, platform 126 and / or other parts of well location 100. As shown, surface controller 122 is located on a surface location and submarine controller 120 is located in an underwater location (eg, on platform 126, a ship (not shown) or off-site). However, we note that the one or more controllers 120/122 can be located in several locations to control surface 104 and / or subsea systems 102. Communication links 130 can be provided for communication with several pars of the well site 100, such as 120/122 controllers.
    [0033] [00033] Figures 2A - 4 show several views of the well location connector 110b of Figure 1A. The well location connector 110b, as shown, is an undersea connector connecting two subsea components, that is, a BOP 111 and a well head 106. Figures 2A and 2B represent views in vertical cross section of the well location connector. 110b in an unengaged position and an engaged position, respectively. Figure 3 shows a detailed view of part of the well location connector 110b being assembled, with the upper component supported on the indicator claws for quick assembly. Figure 4 shows an exploded view of the well site connector 110b.
    [0034] [00034] The pit location connector 110b includes a connector body 232, a piston (or piston or annular sleeve) 234 and clamping indicator claws (or locking fingers or fingers) 236, The connector body 232 includes a cover 238, a body ring 240 and a sub 242. BOP 111 is fastened with screws 252 and sealed with seal 214 (eg, an elastomeric metal or other seal) to connector cover 238. Cover 238 is attached to the ring body 240 using screws 254. Body ring 240 is attached to the lower sub 242 using screws 256. A geometry axis X extends longitudinally through the well location connector 110b.
    [0035] [00035] BOP 111 has a hole 246 in fluid communication with hole 248 in cover 238. A fluid passage 244 extends through well location connector 110b and communicates with hole 246 of BOP lll, the hole 248 of the cover 238 and a hole 250 of the wellhead 106 for passing the fluid through it.
    [0036] [00036] The well location connector 110b can be lowered into the well hole over the BOP 111 and positioned by a riser 128 at the subsea location for assembly as shown in Figure 3. The well location connector 110b can be pre- mounted on BOP 111 (and / or riser 128) for attachment to the wellhead (or tubular) 106 as shown in Figure 2A.
    [0037] [00037] The piston 234 is positioned in a cavity 265 of the connector body 232. Figure 2A shows piston 234 drawn upwards with the indicator claws 136 in a retracted position. Figure 2B shows piston 234 downwards to hang the wellhead connector 110b to the wellhead 106. In the example in Figure 2A, the wellhead connector 110b is lowered over a wellbore tubular 106 with the piston 134 in an elevated position and indicator claws 236 in a retracted (or disengaged) position to receive wellhead 106. Once in position around wellhead 106, ο well location connector 110b can be activated to move to the engaged position of Figure 2B with the piston lowered to engage the indicator claws with the wellhead 106.
    [0038] [00038] The lower sub 242 has an open lower end 258, which accepts a tubular borehole well, such as the wellhead 106. The wellhead 106 has a wellhead profile (either threads or gripping details) ) 160 near its upper end 262. Grip indicator claws 236 are a formation of circumferential segments having a body profile (or threads or grip details) 266a around their upper end and a grip profile (or threads or grip details) 266b over its lower end. The body profile 266a is suspended for mounting on the body ring 240 in the cover profile (or location) 264 on the cover 238, as shown in Figures 2B and 3. The body profile 266a is receivable in the cover profile 264 on the coverage 238.
    [0039] [00039] As shown in Fig. 3, the cover profile 264 is a support location for the indicator claws 236 during assembly. The interstices 268 occur above the cover profile 264, to allow the indicator claws 236 space to rotate radially inward to remove the gripping ring 270 which is preferably integrally formed with the piston 234. In assembly, the recess 272 will align with the support ring 270 of the piston 234, as shown in Figures 2A.
    [0040] [00040] An engagement ring 275 is also integrally formed on the piston 234 to support the indicator claws 236. The support ring 270 and engagement ring 275 define a piston profile along the internal surface of the piston. When this occurs, the interstice 268 shown in Fig. 3 will close, placing the indicator claws 236 in full alignment with the surrounding annular piston 234. However, to avoid interference with the assembly, there may still be an interstice seen in Fig. 2A between the surface support plate 276 that is fixed and a part of the body ring 240. The connector body 232 defines a receptacle 279 in it near the cover 238 and body ring 240 to receive the indicator claws 236, and surface 278 near the top 280 of the indicator claws 236, which will finally be in contact when piston 134 is activated.
    [0041] [00041] The piston 234 forms a variable volume chamber 282a along an internal surface of the connector body 232 in the cavity 265 between the connector ring 234 and sub 232. The variable volume chamber 282a can be accessed through the pass at 284a to supply hydraulic pressure from a fluid source 283 to retain piston 234 of Figure 2A in the upper position. Fig. 2B illustrates an opposite chamber of variable volume 282b, which is accessed through passage 284b, to apply hydraulic pressure to move piston 234 to the position of Fig. 2B.
    [0042] [00042] The downward movement of piston 234 rotates the indicator claws 236 on the cover profile 264 to close the gap between surfaces 276 and 278, which in turn pushes the profiles 264 and 266a together while the gripping ring 270 slides the surface ring below (or ramp) 286 of the indicator claws 236 until a surface of the gripping ring 270 aligns with the surface ring 286 of the indicator claw 236 to push the lower end 290 of the indicator claws 236 inward to secure the profiles 264 and 266a together, as shown in Fig. 2B. A pressure energized metal gasket 273 can be provided around connecting chuck 107 and cover 238 to seal the interface between wellhead 108 and cover 238 and thereby prevent fluid leakage through passage 244. Other sealing members and / or seals can be provided on the wellhead connector as described here.
    [0043] [00043] An upper end 292 of piston 234 conforms to the shape of a fixed support 294, which extends radially from the body ring 240. The piston 234 does not need to extend above the indicator claws 236, which can reduce the component height and can save weight and space, while still allowing retrofit with other designs employing a similar hitch concept. The fixed support 294 is in the sense of a cantilevered structure, however being contacted with the cover 238 giving it some additional support when the surface 278 of the indicator clamp 236 presses on the support surface 276 of the fixed support 294.
    [0044] [00044] Those skilled in the art will note that piston 234 can be a single annular piston or a plurality of smaller pistons, each acting on a separate indicator claw 236. An additional support piston 277 is shown. This additional piston can be activated when necessary, for example, to move with piston 234 when additional pressure is applied to the wellhead connector. The initial interstice 268, between the upper ends 278 of the indicator claws 236 and the support surface 276, together with the positioning of the gripping profile 266b, can seek to allow rapid assembly of the indicator claws 236 and their removal, without interference problems.
    [0045] [00045] Ο use of the fixed support and the conformable shape of the piston 234 may allow a shorter piston that is in general axial alignment with the indicator claws 236 for mounting the connection as in Fig. 2A and for the engaged position as in Fig 2B. This can reduce the size of the well location connector 110b and can make it lighter and cheaper to produce. The location of the grip profile (or support location) 266b and contact above that location can allow the lower ends of indicator clamp 290 swings out for mounting without interference. Upon removal, the indicator claws 236 can again retract so that they can be easily pulled with the cover 248, as shown in Fig. 3, for installation as well as for removal.
    [0046] [00046] Figure 5 shows a flow chart of a method 500 of connecting well location components. The method involves providing a 595 wellhead connector. The pit location connector includes a connector body reading an end adapted to mate with a first component and a cavity for receiving a second component, an axially movable piston in the connector body (the piston having a piston profile along of its internal surface) and a plurality of indicator claws positioned on the body adjacent to the piston and radially movable around it. The indicator claws are positioned on the connector body adjacent to the piston and radially movable around it, have an indicator claw profile along an external surface corresponding to the piston profile of the piston and have a grip profile along its inner surface, selectively nestable with the second of the components, The method also involves 596 operatively connecting the end of the connector body to a first of the 597 components, receiving a second of the components in the cavity of the connector body and 598 selectively engaging the plurality of indicator claws on the second of the components, selectively fitting the profile of the vests' claw with the piston profile of the piston and the grip profile of the indicator claws with the second of the components.
    [0047] [00047] The piston can separate a cavity in the connector body in the first and second chambers of variable volume, and the method can selectively engage engaging to move the piston selectively by pumping fluid in the first and second variable chambers. Selectively engaging may involve supporting the plurality of indicator claws in a ring of piston indicator claws, hingedly moving the plurality of indicator claws by axially moving the piston in the connector body, fitting a piston piston profile with a claw indicator claw profile indicator, press the plurality of indicator claws against the second of the components by fitting a piston engagement ring with the plurality of indicator claws, retract the plurality of indicator claws by aligning the piston piston profile with the indicator claw profile with the plurality of claws indicator, extend the plurality of indicator claws by aligning the piston profile of the piston with the indicator claw profile of the plurality of indicator claws and / or operatively connect at least two of a tubular, a casing tube, a riser tube, a head of well, a preventive eruption controller, a lower marine suppression pump , and their combinations. The method may also selectively engage a body part of the plurality of indicator claws with the connector body.
    [0048] [00048] The well location connector may also include the floating sealing member, including the flexible ring having a through hole to seal the second of the components (the sealing member slidably movable in the connector body transversely to a geometric axis) ). The method may also involve aligning the second components with the first component for connection between them, slidingly moving the sealing member in the connector body transversely to a geometric axis. The steps can be performed in any order and repeated if desired.
    [0049] [00049] In another aspect, the description refers to a subsea connector to form a connection between a first subsea device and a second subsea device. The subsea connector comprises a connector body having an end adapted for coupling to the first subsea device and a cavity adapted to receive a connecting member of the second subsea device. A sealing member is disposed in the cavity to provide the underwater connector with a hydrate seal when the connector member extends through the sealing member. The sealing member is buoyant in a direction transverse to a longitudinal geometric axis of the connector body, in order to safely allow a predetermined range of angular misalignments between the connector body and the connecting member.
    [0050] [00050] A subsea connector to form a connection between a first subsea device and a second subsea device includes a connector body having an end adapted for coupling to the first subsea device and a cavity adapted to receive a connection member from the second subsea device. A sealing member is arranged in the cavity to provide the undersea connector with a hydrate seal when the connecting member extends through the sealing member. The sealing member is buoyant in a direction transverse to a longitudinal geometric axis of the connector body, in order to safely allow a predetermined range of angular misalignments between the connector body and the connecting member. The submarine connector can be an underwater or land-based well connector to connect various well-location components, such as a tubular, casing, riser, wellhead, eruption preventive controller, a low pressure marine lift pump etc.
    [0051] [00051] Figures 6A - 6C show various views of another wellhead (or submarine) connector 110a. The well location connector 110a, as shown, is an undersea connector connecting two subsea components, i.e., a BOP 111 and mandrel 107 of Figure 1B. Figures 6A - 6C represent vertical cross-sectional views of the well location connector 110a in an unengaged position, an unaligned misaligned and an engaged position, respectively.
    [0052] [00052] Submarine connector 110a has a connector body 602 having a longitudinal (or axial) geometric axis 604. Connector body 602 has a connector base (or sub) 606 and a connector head (or cover) 608. a cavity 615 is defined in the connector base 606 and the connector head 608 extends partially into the cavity 615. A hole 612, defined in the connector head 608, extends from the top end 614 of the connector head 608 to the cavity 615.
    [0053] [00053] A connection flange 616 of a first subsea device (eg, BOP 111) is attached to connector head 608, and connection chuck 107 of a second subsea device (eg, another BOP 111 ) is partially received in the cavity 615. To form a connection between the first subsea device and the second subsea device, the connecting chuck 107 can be locked in the connector body 602 using a suitable locking mechanism, an example of which will be described below.
    [0054] [00054] Submarine connector 110a has an unlocked state, as shown, for example, in Figs. 6A and 6B, where connection chuck 107 is not locked in connector body 602. Submarine connector 110a also has a locked state, as shown in Fig. 6C, where connection chuck 107 is locked in connector body 602. In state locked, the first subsea device and the second subsea device are joined together by subsea connector 110a. In the unlocked state, the first subsea device and the second subsea device are not joined by subsea connector 110a.
    [0055] [00055] When the underwater connector 110a is in the locked state, as shown in Fig. 6C, the longitudinal geometric axis 619 of the connecting mandrel 107 is aligned with the longitudinal geometric axis 604 of the connector body 602. Also a hole 621 of the connecting mandrel 602. connection 107 is aligned with ο hole 612 of connector head 608, which allows tools and fluids to pass through subsea connector 110a. A pressure-energized metal seal 623 can be provided around connecting chuck 107 and connector head 608 to seal the interface between connecting chuck 107 and connector head 608 and thereby prevent fluid leakage through the holes aligned 612, 621 into cavity 615, as shown in Figure 6C.
    [0056] [00056] Although the submarine connector 11a is transitioning between the locked shaft and the unlocked state, the connecting mandrel 107 or the connector body 602 can assume several inclined positions, which would lead to angular misalignment between the longitudinal geometric axes 604, 619 of the body connector 602 and connection chuck 107, respectively. The angular misalignment between the longitudinal geometric axes 604, 619 can also be expressed simply as angular misalignment between the connector body 602 and the connecting chuck 107. Fig. 6B shows an example of the angular misalignment between the connecting chuck 107 and the body connector 602. The cavity 615 is larger in diameter than the connection chuck 107, to allow this angular misalignment between the connector body 602 and the connection chuck 107.
    [0057] [00057] With reference to Fig. 6A, an annular piston (or sleeve) 620 is disposed in cavity 615 and is movable by fluid pressure differential in a direction generally parallel to the longitudinal geometric axis 604. The connector head 608 has a locking surface (or profile or cover) 622 arranged radially over bore 612, A plurality of radial locking tongues (or indicator claws or fingers) 624 is arranged between piston 620 and locking surface 622. Each of locking tabs 624 have a face (or indicator jaw profile) 626 that opposes a piston piston profile 620, and a face (or cover profile) 628 that opposes the locking surface of connector head 622. Face 626 includes a wedge profile (part of an indicator claw) 630 that is designed to fit into a joining wedge (or piston) on piston 620.
    [0058] [00058] Face 628 includes grip details 632, such as teeth. The grip details 632 on an upper part (or body profile) of the face 628 are designed to fit with the connector head locking surface 622. The grip details 632 on a lower part (or grip profile) of the face 628 are designed to fit on a locking surface 634 of the connecting chuck 107. Locking surfaces 622, 634 each have grip details for locking engagement with grip details 632 of face 628 of locking tabs 624.
    [0059] [00059] Returning to Fig. 6A, piston 620 forms separate cavity 615 in chambers of variable volume 621a, b along the inner surface of connector body 602 defining cavity 615 therein. The chambers 621a.b are defined inside the cavity 615, between the connector base 606 and the piston 620. The chambers 625a can be accessed through the passage 625a, to supply hydraulic pressure from a fluid source 627, to retain the piston 620 from the Fig. 6A in the upper position.
    [0060] [00060] Submarine connector 110a can also be transitioned to the locked state by applying fluid pressure to an upper area 636 of piston 620, so that piston 620 moves downward and tilts locking tabs 624 to in and in place with both locking surfaces 622, 634 (Fig. 6C shows locking tabs 624 fully engaged with locking surfaces 622, 634). Submarine connector 610 is unlocked by applying fluid pressure to a lower area 638 of piston 620, so that piston 620 moves upward and tilts locking tabs 624 out and away from locking surfaces 632, 634.
    [0061] [00061] Inside the cavity 615 there is an auxiliary annular piston (or sleeve) 640. The pressure differential through the piston 640 can be used to further press the locking piston 620 upwards, in a direction generally parallel to the longitudinal geometric axis 604 connector body 602, if necessary. Although submarine connector 110a is transitioning to the unlocked state, one or the other or both of the connection chuck 107 and connector body 602 can tilt and move so that the connector body 602 and connection chuck 107 become angulously misaligned. This is shown, for example, in Fig. 6B.
    [0062] [00062] Returning to Fig. 6A, a sealing member 642 is disposed in an annular retaining receptacle 644 of piston 620. Sealing member 642 can be a metallic or elastomeric member, which provides a seal at an interface between the subsea connector 110a and connection chuck 107. The seal provided by sealing member 642 is not required to contain pressure. Sealing member 642 can provide a hydrate seal that prevents hydrates from clumping and solidifying within cavity 615, particularly around the surfaces of cavity 615 that are or can be exposed to seawater, such as the surfaces of the tongues locking 624 and / or piston 620.
    [0063] [00063] Sealing member 642 can work as a one-way valve, which prevents gas migration into cavity 615, while subsea connector 110a is in use. Sealing member 642 can also be used to contain fluid, such as glycol, injected into cavity 615 to dissolve possible hydrate build-up within cavity 615. Sealing member 642 has a sealing ring 646, which has an edge 641 defining an opening 643. When the connecting chuck 107 is received in the opening 643, the edge 641 circumscribes and engages a sealing area 649 of the connecting chuck 107. The sealing area 649 can be below the chuck locking surface 634 The outer diameter of the connecting mandrel 107 on the locking surface 634 can be smaller than the outer diameter of the connecting mandrel 107 on the sealing area 649, so that the edge 641 does not fit on the locking surface 634. Figures 6A and 6B show the sealing member 642 engaging the connection mandrel 107 in various positions of the sealing area 649.
    [0064] [00064] Returning to Fig. 6A, the upper and lower walls 645, 647 of the retention receptacle 644 cause the sealing member 642 to float, that is, to move freely, in a direction that is transverse to the longitudinal geometric axis 604 connector body. Floating sealing member 642 can be used to prevent damage to underwater connector 110a or connecting chuck 107, when there is an angular misalignment between connector body 602 and connecting chuck 107 and connecting chuck 107 extends through opening 643 This angular misalignment can happen when transitioning underwater connector 610 from the locked state to the unlocked state.
    [0065] [00065] As shown in Figures 1A and 1B, the connection unit 108 'is connected to a platform on the surface. The platform can be up to 5 degrees out of position vertically from the underwater chimney, which can induce misalignment between the connector body 602 and the connecting chuck 107 if the underwater connector 110a is used for connection to the underwater chimney. Severe misalignment can occur, for example, in underwater LMRP connections because the LMRP can initially pivot away from the chimney structure before dislodging. The pivot can be up to 40 inches (101.6 cm) above or below the top of the chuck. connection 107.
    [0066] [00066] The floating capacity of the sealing member 642 can safely allow even severe misalignment. As an example, Fig, 6B shows the sealing member 642 floated to the right side of the subsea connector 110a, to accommodate an upward tilt of the connector body 602 relative to the connecting chuck 107. The permissible displacement length of the member seal 642 in the direction transverse to the longitudinal geometric axis 619 can determine the range of angular misalignments that can be safely allowed by the floating capacity of the seal member 642. The permissible displacement length of the seal member 642 can be selected based on a range typical of expected angular misalignment between connector body 602 and connecting chuck 107.
    [0067] [00067] In one embodiment, the holding receptacle 644 is formed on piston 620. which would make sealing member 642 move with piston 620, when piston 620 responds to the fluid pressure differential. It is possible to locate the retention receptacle 644 elsewhere, such as on the wall of the connector base 606 or in another structure disposed within the cavity 615, as long as the sealing member 642, located in the retention receptacle 644, is able to provide a seal at an interface between submarine connector 110a and connection chuck 107.
    [0068] [00068] As explained above, the sealing member 642 has a floating movement in a direction transverse to the longitudinal geometric axis of connector body 604. The sealing member 642 also experiences movement in other directions, due to being retained in the 644 receptacle. For example, the sealing member 642 can move in a direction generally parallel to the longitudinal geometric axis of the connector body 604, when the piston 620, in which the receptacle 644 is formed, moves. The sealing member 642 can also undergo tilting and displacement movements due to the tilting and displacement of the connector body 602, p. when transitioning between the locked and unlocked states of subsea connector 110a.
    [0069] [00069] O-ring 646 has a base o-ring face 648 and a side o-ring face 650. The side o-ring face 650 is located on edge 641. The base o-ring face 648 faces the base wall 647 of the retention receptacle 644 and is arranged to seal against the base wall 647 of the retention receptacle 644. The side sealing ring face 650 faces the center of the connector body 602 and is arranged to engage and seal against connection chuck 107, when connection chuck 107 is received at opening 643 defined by edge 641.
    [0070] [00070] In one embodiment, the sealing ring faces 648, 650 contain sealing elements 652, 654, respectively, such as elastomeric seals. In another embodiment, one or both of the sealing ring faces 648, 650 may contain no sealing elements and may be sealing surfaces, such as elastomeric or metallic sealing surfaces. Additional sealing elements 656, such as elastomeric seals, can be provided between connector base 606 and piston 620. Sealing elements 656 can be contained by connector base 606, so that they provide the necessary sealing, regardless of piston position 620 within cavity 615. Additional sealing elements 656 can be pressure sealing elements.
    [0071] [00071] Figure 7 shows a flow chart of another method 700 of connecting well site components. The method involves providing a 795 wellhead connector. The pit location connector includes a connector body and a flammable seal member. The connector body has an end operably connectable to a first of the components, a receptacle along its internal surface and a cavity adapted to receive a second of the components. The floating sealing member includes a flexible ring, having a through hole to receive the second of the components sealingly. The sealing member is slidably movable within the receptacle of the connector body transversely to a geometric axis of the connector body. The method also involves, 796 operatively connecting one end of the connector body to a first of the components, 797 - receiving a second of the components in a cavity of the connector body, and 798 - aligning the second components to the first component, for sliding connection between them moving the sealing member of the connector body transversely to its geometric axis.
    [0072] [00072] Details of the method in Figure 5 can also be included. The method can be performed in any order and repeated as desired.
    [0073] [00073] Although the subject has been described with reference to a limited number of embodiments, those skilled in the art, having the benefit of this description, will appreciate that other embodiments can be imagined that do not deviate from the scope of the subject as here described. Therefore, the scope of the invention should be limited only by the appended claims.
    [0074] [00074] It will be noted by those skilled in the art that the techniques described here can be implemented for automated / autonomous applications, via software configured with algorithms, to perform the desired functions. These aspects can be implemented by programming one or more computers for adequate general purposes, having appropriate hardware. Programming can be performed using one or more program storage devices readable by the processor (s) and coding one or more instruction programs executable by the computer, to perform the operations described here. The program storage device may take the form of, e.g. eg, one or more floppy disks; a CD ROM or other optical disc; A read-only memory (ROM) chip; and other forms of the species well known in the art or subsequently developed. The instruction program can be “object code”, that is, in binary form that can be executed more or less directly by the computer; in “source code” that requires compilation or interpretation before execution; or in some intermediate way, such as partially compiled code. The precise forms of the program storage device and instruction coding are insignificant here. Aspects of the invention can also be configured to perform the functions described (via appropriate hardware / software) only on-site and / or remotely controlled via an extended communication network (eg, wireless, internet, satellite, etc.).
    [0075] [00075] The above description is illustrative of the preferred embodiment and many modifications can be made by those skilled in the art, without deviating from the invention, the scope of which is to be determined by the literal and equivalent scope of the claims that follow.
    [0076] [00076] Although the embodiments are described with reference to various implementations and explorations, it will be understood that these embodiments are illustrative and that the scope of the inventive subject is not limited to them. Many variations, modifications, additions and improvements are possible. For example, one or more connectors and / or pit location components can be connected. Wellhead connectors are shown in a specific orientation, but one or more could be inverted for coupling between one or more components, as desired.
    [0077] [00077] Several examples can be provided for the components, operations or structures described here as a single example, in general the structures and functionality presented as separate components in the exemplary configurations can be implemented as a combined structure or component. Similarly, the structures and functionality presented as a single component can be implemented as separate components. These and other variations, modifications, additions and improvements may fall within the scope of the inventive subject.
    权利要求:
    Claims (11)
    [0001]
    Pit location connector (110a, b) to connect components from a pit location (100), the pit location having a pit hole (112) extending into a subsurface formation (114), the connector well location characterized by the fact that it comprises: a connector body (232, 602) having a longitudinal axis, an end adapted to couple with a first of the components, and a cavity (265, 615) for receiving a second of the components; a piston (234, 620) axially movable in the connector body, the piston having a piston profile along its internal surface; and a plurality of indicator claws (236, 624) positioned on the connector body, adjacent to the piston and radially movable around it, the plurality of indicator claws having an indicator claw profile (630) along an outer surface corresponding to the profile piston piston and the plurality of indicator claws having a gripping profile (266b) along its internal surface, selectively interlockable with the second of the components, whereby the plurality of indicator claws is selectively latched onto the second of the components ; a floating sealing member (273, 642), comprising a flexible ring having a through hole to sealingly receive the second of the components, the sealing member slidably movable in a receptacle (644) of the connector body, transversely to a geometric axis connector body, whereby the second components are aligned with the first components for connection between them.
    [0002]
    Well location connector according to claim 1, characterized in that the connector body comprises a cover (238) operably connectable to the first component and a sub (242) having a hole through it to receive the second component.
    [0003]
    Well location connector according to claim 2, characterized by the fact that the cover has a cover location on it that fits with the indicator claw profile of the plurality of indicator claws.
    [0004]
    Well location connector according to claim 2, characterized in that the connector body further comprises a body ring (240) operably coupled between the cover and the sub.
    [0005]
    Well location connector according to any one of claims 1 to 4, characterized in that the plurality of indicator claws has a body profile (266a, 626) selectively interlockable with the connector body.
    [0006]
    Wellhead connector according to any one of claims 1 to 5, characterized in that the connector body defines an indicator jaw cavity to receive the plurality of indicator jaws.
    [0007]
    Well location connector according to claim 6, characterized in that the plurality of indicator claws is movable at a distance from a receptacle (279) of the cover and defines an interstice (268) between them.
    [0008]
    Wellhead connector according to any one of claims 1 to 7, characterized in that the connector body has an internal surface defining a cavity for slidingly receiving the piston.
    [0009]
    Wellhead connector according to any one of claims 1 to 8, characterized in that the piston comprises a support ring (270) on its internal surface, the support ring defining a part of the piston profile, to support the plurality of indicator claws on it; wherein the piston comprises an engagement ring (275) on its inner surface, the engagement ring defining a part of the piston profile to support the plurality of indicator claws in the engaged position; wherein the piston comprises a primary piston interlockable with the plurality of indicator claws and a secondary piston (277, 640) supporting the primary piston, the secondary piston slidably movable within the connector body when the primary piston exceeds a maximum force; and / or in which the piston separates a cavity within the connector body in a first chamber of variable volume (282a) and a second chamber of variable volume (282b).
    [0010]
    Well location connector according to claim 9, characterized in that the first variable-volume chamber and the second variable-volume chamber are operably connectable to a fluid source (283, 627) to selectively divert fluid, by means of than the piston is movable within the body between a position shifted upwards and a position shifted downwards.
    [0011]
    Method for connecting components of a well hole site, the well site having a well hole extending into a subsurface formation, said method characterized by the fact that it comprises: providing a wellhead connector as defined in any one of claims 1 to 10; operatively connect one end of the connector body to the first of the components; receiving the second of the components in the cavity of the connector body; and selectively engaging the plurality of indicator claws on the second of the components, selectively fitting the profile of the indicator claw plurality with the piston profile of the piston and the grip profile of the plurality of indicator claws with the second of the components.
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    同族专利:
    公开号 | 公开日
    US9869148B2|2018-01-16|
    WO2013152195A3|2014-05-22|
    CA2868519A1|2013-10-10|
    WO2013152195A2|2013-10-10|
    SG11201406313QA|2014-11-27|
    CN104471184B|2018-05-08|
    SG11201406315SA|2014-11-27|
    WO2013152187A2|2013-10-10|
    BR112014024683B1|2021-02-02|
    EP2834448A2|2015-02-11|
    US20150083430A1|2015-03-26|
    CN104334823A|2015-02-04|
    CA2868814A1|2013-10-10|
    CN104471184A|2015-03-25|
    EP2834447A2|2015-02-11|
    CA2868814C|2016-05-24|
    CA2868519C|2017-02-14|
    CN104334823B|2017-03-01|
    WO2013152187A3|2014-05-22|
    US20150114659A1|2015-04-30|
    EP2834447B1|2019-12-11|
    US9169710B2|2015-10-27|
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    法律状态:
    2018-12-04| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2020-02-11| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|
    2020-09-15| B09A| Decision: intention to grant|
    2020-12-01| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 04/04/2013, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US201261620514P| true| 2012-04-05|2012-04-05|
    US61/620,514|2012-04-05|
    US201261623020P| true| 2012-04-11|2012-04-11|
    US61/623,020|2012-04-11|
    PCT/US2013/035269|WO2013152187A2|2012-04-05|2013-04-04|Wellsite connector with piston driven collets and method of using same|
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