WO2014135861A2 - Wireline device - Google Patents

Wireline device Download PDF

Info

Publication number
WO2014135861A2
WO2014135861A2 PCT/GB2014/050637 GB2014050637W WO2014135861A2 WO 2014135861 A2 WO2014135861 A2 WO 2014135861A2 GB 2014050637 W GB2014050637 W GB 2014050637W WO 2014135861 A2 WO2014135861 A2 WO 2014135861A2
Authority
WO
WIPO (PCT)
Prior art keywords
downhole tool
wireline
retaining ring
arrangement according
housing
Prior art date
Application number
PCT/GB2014/050637
Other languages
French (fr)
Other versions
WO2014135861A3 (en
Inventor
Gavin David Cowie
Robin Barclay Mair
Original Assignee
Well-Centric Oilfield Services Ltd
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Well-Centric Oilfield Services Ltd filed Critical Well-Centric Oilfield Services Ltd
Publication of WO2014135861A2 publication Critical patent/WO2014135861A2/en
Publication of WO2014135861A3 publication Critical patent/WO2014135861A3/en

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
    • E21B33/072—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells for cable-operated tools
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/09—Locating or determining the position of objects in boreholes or wells, e.g. the position of an extending arm; Identifying the free or blocked portions of pipes

Definitions

  • the present invention relates to a wireline device for use in wireline operations and, in particular though not exclusively, for use in wireline operations in an oil or gas well.
  • a wireline may be used for raising and lowering tools into a wellbore. Specifically, this is achieved by attaching a toolstring to the end of a reel of a single strand or braided wire.
  • the wireline passes through a stuffing box which is installed on top of a lubricator stack.
  • the stuffing box is used to facilitate a seal and retain well pressure around moving and stationary wireline.
  • the winch operator must know the position of his tools within the well. Technologies exist for monitoring this position, but they are not completely reliable and the situation frequently arises where the toolstring is erroneously drawn into the stuffing box. This typically results in the wireline breaking, causing the toolstring to be dropped into the well. An end of the wireline may then be blown out of the stuffing box and a hydrocarbon leak may occur. This may also mean that it is necessary for the toolstring to be recovered before well operations can recommence.
  • a downhole tool motion resistor arrangement for use in indicating a position of a downhole tool.
  • the downhole tool motion resistor arrangement may comprise a base member.
  • the downhole tool motion resistor arrangement may comprise a carriage member for engaging a downhole tool.
  • the carriage member may be moveable relative to the base member.
  • the downhole tool motion resistor arrangement may comprise a resilient member for resisting movement of the carriage member relative to the base member when a downhole tool is pulled into engagement with the carriage member using a wireline which is connected to the downhole tool and which extends through the carriage member. If wireline tension is monitored, such a motion resistor arrangement may provide an operator with an indication of the position of the downhole tool relative to the base member by virtue of the increased force that must be exerted by the downhole tool on the carriage member to overcome the bias provided by the resilient member.
  • the base member may comprise part of a wellhead housing.
  • the base member may comprise part of a wireline stuffing box or lubricator housing.
  • the carriage member may be configured for engagement with a conventional downhole tool. This may avoid any requirement for a bespoke or specially modified downhole tool for use with the position indicator arrangement.
  • the resilient member may comprise a compression spring.
  • the resilient member may comprise an elastomeric member such as an elastomeric sleeve.
  • the resilient member may comprise a plurality of voids.
  • the resilient member may comprise a sponge.
  • the resilient member may be moveable with the carriage member relative to the base member.
  • the resilient member may comprise an inwardly biased resilient ring or sleeve such as an inwardly biased split ring or an inwardly biased c-ring.
  • the base member may define a conical outer surface.
  • the inwardly biased resilient ring may engage an outer surface of the base member.
  • Such an inwardly biased resilient ring may provide an increasing resistance as the ring moves in a direction opposite to the direction of a taper of the conical outer surface of the base member.
  • the resilient member may comprise a sleeve having one or more resilient collet fingers.
  • the base member may define one or more features on an outer surface thereof.
  • the base member may define one or more recesses and/or one or more projections on an outer surface thereof.
  • the collet fingers of the sleeve may be configured for engagement with the one or more features on the outer surface of the base member.
  • Each collet finger may be naturally unbiased.
  • the collet fingers of the sleeve may engage one or more projections defined on an outer surface of the base member to thereby displace each collet finger from the its natural unbiased state and induce an inward bias in the collet finger.
  • This may provide an increase in resistance to relative motion between the sleeve and the base member.
  • This may provide multiple peaks in resistance to relative motion between the sleeve and the base member which may translate into multiple peaks in wireline tension which, if monitored, may serve as warnings to a wireline winch operator of the approach of a downhole tool to the wireline device.
  • Each collet finger may be inwardly biased.
  • the collet fingers of the sleeve may engage one or more recesses and/or one or more projections defined on the outer surface of the base member to thereby provide an increase in resistance to relative motion between the sleeve and the base member. This may provide multiple peaks in resistance to relative motion between the sleeve and the base member which may translate into multiple peaks in wireline tension which, if monitored, may serve as warnings to a wireline winch operator of the approach of a downhole tool to the wireline device.
  • the base member may define an aperture which is configured to permit a wireline to extend therethrough.
  • the base member may be tubular.
  • the resilient member may comprise an outwardly biased resilient ring or sleeve.
  • the outwardly biased resilient ring may engage an inner surface of the base member.
  • the resilient member may comprise a sleeve having one or more resilient collet fingers.
  • the base member may define one or more features on an inner surface thereof.
  • the base member may define one or more recesses and/or one or more projections on an inner surface thereof.
  • the collet fingers of the sleeve may be configured for engagement with the one or more features on the inner surface of the base member.
  • Each collet finger may be naturally unbiased.
  • Each collet finger may be inwardly biased.
  • the resilient member may comprise a damper.
  • the damper may comprise a piston.
  • the piston may act against a fluid which is in fluid communication with an accumulator.
  • the base member may be configured to permit a downhole tool to extend at least partially therethrough.
  • the carriage member may comprise a receptacle portion for engagement with a downhole tool.
  • the receptacle portion may be arranged to move within the base member.
  • the receptacle portion may define an aperture which is configured to permit the wireline to extend therethrough.
  • the carriage member may comprise a base ring which is configured to move over an outer surface of the base member.
  • the arrangement of the carriage member and the resilient member relative to a tubular base member may provide support to both the carriage member and the resilient member. This may provide for a relatively simple and stable load path from the downhole tool to the carriage member.
  • the position indicator arrangement may comprise a wireline tension sensor.
  • the position indicator arrangement may be configured for installation within a wellhead housing.
  • such a motion resistor arrangement may be used to provide an indication of the position of a downhole tool relative to the wellhead housing. This may permit a wireline winch operator to control winching of the wireline according to the proximity of the downhole tool relative to the wellhead housing.
  • the motion resistor arrangement may be configured for installation within a housing comprising a wireline lubricator housing or a stuffing box housing. If wireline tension is monitored, such a motion resistor arrangement may provide an indication of the position of a downhole tool relative to the wireline lubricator housing or the stuffing box housing. This may permit a wireline winch operator to control winching of the wireline according to the proximity of the downhole tool relative to the wireline lubricator housing or the stuffing box housing. As such, the motion resistor arrangement may serve to alert the operator to the approach of the downhole tool to the stuffing box so that the operator may control winching of the wireline to avoid retracting the downhole tool into the stuffing box thereby minimising the resulting risk of wireline breakage.
  • a latch arrangement for latching a downhole tool.
  • the latch arrangement may comprise an inwardly biased retaining ring.
  • the latch arrangement may comprise a release member which is moveable relative to the retaining ring between a first position in which the release member prevents the retaining ring from collapsing inwardly and a second position in which the retaining ring is permitted to collapse inwardly around a downhole tool to at least partially restrict movement of the downhole tool through the retaining ring.
  • Such a latch arrangement may be used to retain a downhole tool so as to prevent the downhole tool dropping into or otherwise moving within a wellbore in the event of failure of a wireline which supports the downhole tool in the wellbore. This may avoid any requirement to retrieve the downhole tool from the wellbore at a later time.
  • the latch arrangement may comprise a body member.
  • the retaining ring may be axially fixed relative to the body member.
  • the release member may be axially moveable relative to the body member.
  • Such a latch arrangement may be used to automatically retain a downhole tool relative to the body member.
  • the retaining ring may be split.
  • the retaining ring may comprise a split ring, snap ring or the like.
  • the retaining ring may comprise a pair of opposing lugs. Each lug may be configured to engage the downhole tool.
  • the release member may comprise a tab.
  • the tab may be configured for engagement with the lugs of the retaining ring to prevent the retaining ring from collapsing inwardly around a downhole tool when the release member is in the first position.
  • the tab may be configured for disengagement from the lugs of the retaining ring to permit the retaining ring to collapse inwardly around a downhole tool when the release member is in the second position.
  • the latch arrangement may be arranged to prevent movement of a downhole tool relative to the retaining ring in at least one direction when the retaining ring is collapsed inwardly around the downhole tool.
  • the latch arrangement may be arranged to prevent downward movement of a downhole tool relative to the retaining ring when the retaining ring is collapsed inwardly around the downhole tool.
  • the latch arrangement may be configured to prevent movement of a feature of the downhole tool relative to a complementary feature of the retaining ring when the retaining ring is collapsed inwardly around the downhole tool.
  • the latch arrangement may comprise a plurality of retaining rings.
  • a plurality of retaining rings may retain a downhole tool more securely than a single retaining ring.
  • Each retaining ring may be configured to engage a profile of a downhole tool.
  • Each retaining ring may be configured to engage a fishing neck profile such as a conventional fishing neck profile of a downhole tool. This may avoid any requirement for a bespoke or specially modified downhole tool for use with the latch arrangement.
  • the release member may be moveable from the first position to the second position in response to a force communicated from a downhole tool to the release member.
  • a latch arrangement may be used to automatically retain a downhole tool so as to prevent the downhole tool dropping into or otherwise moving within a wellbore in the event of failure of a wireline which supports the downhole tool in the wellbore.
  • Such a latch arrangement may, in particular, be used to automatically capture a downhole tool at or within a lubricator so as to prevent the downhole tool dropping into a wellbore in the event of failure of a wireline which supports the downhole tool in the wellbore.
  • the release member may be moveable from the first position to the second position in response to a force communicated from the downhole tool to the release member indirectly through an intermediate member.
  • the intermediate member may comprise a carriage member which is configured to move with the downhole tool.
  • the release member may be biased towards the first position. This may result in the retaining ring adopting a normally expanded configuration. This may serve to avoid the retaining ring from unintentionally retaining a downhole tool.
  • the latch arrangement may be configured for installation within a housing comprising a wireline lubricator housing or a stuffing box housing.
  • a latch arrangement for latching a downhole tool.
  • the latch arrangement may comprise a retaining member.
  • the retaining member may comprise a retaining ring.
  • the retaining ring may be split.
  • the retaining ring may be inwardly biased.
  • the retaining member may be configured to be displaced radially outwardly in response to a force communicated from the downhole tool to the retaining member. This may induce or increase an inward bias in the retaining member in response to a force transferred from the downhole tool, for example as the downhole tool is pulled upwardly against the retaining member.
  • An upper surface of the downhole tool may be configured for this purpose.
  • the upper surface of the downhole tool may be generally conical.
  • the downhole tool may engage a carriage member as the downhole tool is pulled upwardly and the downhole tool may urge the carriage member against the retaining member.
  • the retaining member may be configured so as to snap back under a fishing neck shoulder of the downhole tool after further upward motion of the downhole tool.
  • the retaining member may comprise a sleeve having one or more resilient collet fingers.
  • Each collet finger may be configured to engage a fishing neck shoulder of a downhole tool.
  • the retaining member may be configured such that each collet finger may be displaced radially outwardly in response to a force transferred from the downhole tool to the collet finger.
  • Each collet finger may be configured to snap back under a fishing neck shoulder of the downhole tool after movement of the downhole tool relative to the collet finger.
  • Each collet finger may be naturally unbiased.
  • Each collet finger may be inwardly or outwardly biased.
  • a seal arrangement for use in sealing a wellbore.
  • the seal arrangement may comprise a valve body defining an aperture for a wireline.
  • the seal arrangement may comprise a valve which is biased towards a closed position in which the valve seals the aperture defined by the valve body.
  • the seal arrangement may comprise a release member which is moveable relative to the valve between a first position in which the release member prevents the valve from moving towards the closed position and a second position in which the valve is permitted to move towards the closed position.
  • Such a seal arrangement may be used to seal an aperture through which a wireline normally extends from the wellbore to an environment surrounding the wellbore in the event of breakage of the wireline and blow out of the wireline from the aperture.
  • Such a seal arrangement may, therefore, be used to contain leakage from the wellbore to the surrounding environment. This may provide both a safety benefit and an environmental benefit.
  • Such a seal arrangement may, in particular, be used to seal an aperture or passage which extends through a wall of a housing of a lubricator or a stuffing box when a downhole tool is inadvertently drawn into the housing of the lubricator or the stuffing box.
  • the valve may comprise a flapper valve.
  • the valve may comprise a ball valve, a gate valve, a check valve or the like.
  • the release member may be moveable relative to the valve from the first position to the second position in response to a force communicated from a downhole tool to the release member.
  • Such a seal arrangement may be used to automatically seal an aperture through which a wireline normally extends from the wellbore to an environment surrounding the wellbore in the event of a breakage of the wireline and blow out of the wireline from the aperture. Such a seal arrangement may, therefore, be used to automatically contain leakage from the wellbore to the surrounding environment. Such a seal arrangement may, in particular, be used to automatically seal an aperture or passage which extends through a wall of a housing of a lubricator or a stuffing box when a downhole tool is inadvertently drawn into the housing of the lubricator or the stuffing box.
  • the release member may be moveable relative to the valve from the first position to the second position in response to a force communicated from a downhole tool to the release member via an intermediate member.
  • the intermediate member may comprise a carriage member which is configured to move with the downhole tool.
  • the release member may be biased towards the first position. This may result in a normally open configuration of the valve so as to avoid inadvertent closure of the valve. This may avoid any inadvertent interference between the valve and the wireline.
  • the seal arrangement may be configured for installation within a wireline lubricator housing or a stuffing box housing.
  • a wireline device comprising at least one of the motion resistor arrangement, the latch arrangement, and the seal arrangement.
  • the wireline device may be configured for installation within a wellhead housing such as a wireline lubricator housing or a stuffing box housing.
  • the wireline device may be configured such that installation within a conventional wellhead housing requires only minor modifications.
  • the wireline device may define a shoulder on an outer surface thereof which is configured to engage a complementary shoulder of a wellhead housing for suspension of the wireline device from the wellhead housing.
  • Such a 'hang-off shoulder may be simply formed, for example by machining an inner bore of a conventional wellhead housing so as to define an annular recess thereon.
  • a wireline system comprising a housing and at least one of the motion resistor arrangement, the latch arrangement, and the seal arrangement.
  • the housing may be configured for installation at a head of an oil or gas well.
  • the housing may comprise a wireline lubricator housing or a stuffing box housing.
  • the wireline system may comprise a downhole tool and a wireline connecting the downhole tool to surface.
  • a method of restricting motion of a downhole tool for use in indicating a position of the downhole tool for use in indicating a position of the downhole tool.
  • the method of restricting motion of a downhole tool may comprise pulling a downhole tool into engagement with a carriage member using a wireline which is connected to the downhole tool and which extends through the carriage member.
  • the method of restricting motion of a downhole tool may comprise resisting movement of the carriage member relative to a base member.
  • the method of restricting motion of a downhole tool may comprise sensing tension in the wireline.
  • the method for latching a downhole tool may comprise locating a release member relative to an inwardly biased retaining ring so as to prevent the retaining ring from collapsing inwardly.
  • the method for latching a downhole tool may comprise moving the release member relative the retaining ring so as to permit the retaining ring to collapse inwardly around a downhole tool to at least partially restrict movement of the downhole tool through the retaining ring.
  • Moving the release member relative to the retaining ring may comprise communicating a force from the downhole tool to the release member so as to move the release member relative the retaining ring.
  • Moving the release member relative to the retaining ring may comprise applying a tensile force to the downhole tool through a wireline which is connected to the downhole tool and which extends through the release member and the retaining ring so as to communicate the force from the downhole tool to the release member.
  • the method for use in sealing a wellbore may comprise locating a release member relative to a valve so as to prevent the valve from moving under the action of a bias towards a closed position in which the valve seals an aperture defined by a valve body.
  • the method for use in sealing a wellbore may comprise moving the release member relative to the valve so that the valve is permitted to move to the closed position under the action of the bias.
  • Moving the release member relative to the valve may comprise communicating a force from a downhole tool to the release member so as to move the release member relative to the valve
  • the method for use in sealing a wellbore may comprise applying a tensile force to the downhole tool through a wireline which is connected to the downhole tool and which extends through the aperture defined by the valve body so as to communicate the force from the downhole tool to the release member.
  • the method for use in sealing a wellbore may comprise applying sufficient tensile force to the downhole tool through the wireline so as to break the wireline and withdraw an end of the wireline through the aperture defined by the valve body so that the valve moves to the closed position under the action of the bias.
  • a method for use in wireline operations comprising at least one of: the method of restricting motion of a downhole tool;
  • the method for use in indicating a position of a downhole tool, the method for latching a downhole tool and the method for sealing a wellbore may be performed in any order.
  • the method of restricting motion of a downhole tool, the method for latching a downhole tool and the method for sealing a wellbore may at least partially overlap.
  • a method for improving well safety comprising at least one of:
  • the method of restricting motion of a downhole tool may be performed in any order.
  • the method of restricting motion of a downhole tool, the method for latching a downhole tool and the method for sealing a wellbore may at least partially overlap.
  • a method for use in retrieving a downhole tool from a wellbore comprising:
  • the method for use in retrieving a downhole tool may comprise removing the downhole tool from the housing.
  • the housing may be configured for installation at a head of an oil or gas well.
  • the housing may comprise a wireline lubricator housing or a stuffing box housing.
  • a method of providing an indication of the position of a wireline toolstring as it is being pulled into a stuffing box of a wireline lubricator comprising:
  • a system for providing an indication of the position of a wireline toolstring as it is pulled into a stuffing box of a wireline lubricator comprising:
  • a base member for receiving said toolstring and through which said wireline passes, said base member being located in said stuffing box;
  • an indicator for providing an indication of increased tension in said wireline when a toolstring is pulled into engagement with said carriage member and movement of said toolstring is resisted by said resilient member.
  • a wireline lubricator safety system comprising:
  • a downhole tool motion resistor arrangement for use in indicating a position of a downhole tool relative to a stuffing box of a wireline lubricator
  • a latch arrangement for latching a downhole tool within the stuffing box; and a seal arrangement for use in sealing a wireline aperture in a wall of the stuffing box in the event of wireline failure.
  • the downhole tool motion resistor arrangement may comprise: a base member;
  • a carriage member for engaging a downhole tool, the carriage member being moveable relative to the base member;
  • a resilient member for resisting movement of the carriage member relative to the base member when a downhole tool is pulled into engagement with the carriage member using a wireline which is connected to the downhole tool and which extends through the carriage member.
  • the latch arrangement may comprise:
  • a release member which is moveable relative to the retaining ring between a first position in which the release member prevents the retaining ring from collapsing inwardly and a second position in which the retaining ring is permitted to collapse inwardly around a downhole tool to at least partially restrict movement of the downhole tool through the retaining ring.
  • the seal arrangement may comprise:
  • valve body defining an aperture for a wireline
  • valve body which is biased towards a closed position in which the valve seals the aperture defined by the valve body
  • a release member which is moveable relative to the valve between a first position in which the release member prevents the valve from moving towards the closed position and a second position in which the valve is permitted to move towards the closed position.
  • Figure 1 is a longitudinal cross-section of a wireline toolstring suspended on a wireline extending through a wireline system comprising a wireline device, a stuffing box and lubricator sections; is a detail longitudinal cross-section of a portion of the wireline system of Figure 1 ; is a longitudinal cross-section of the wireline device in isolation; is a broken view to a larger scale of the upper and lower portions of the wireline device; is an enlarged detail view of the upper portion of the wireline device; is a broken view of the upper and lower portions of the wireline device, with the top of a wireline toolstring present and making initial contact with a shuttle member; is a detail view of the shuttle member in contact with a release ring; is a detail view of the release ring and collapsed snap rings after displacement of the release ring by the shuttle member; is a detail view of the shuttle member in contact with and showing a trigger member displaced to permit closure of a flapper valve; is a detailed view of the release ring in contact with an upper body
  • Figure 14 is a longitudinal sectional perspective view of the components of a seal arrangement with the trigger member in a downward position, retaining the flapper valve in an open position;
  • Figure 15 is a sectional perspective view similar to Figure 14 with the trigger member in an upward position to permit the flapper valve to rotate to a closed position;
  • Figure 16 is a sectional perspective view similar to Figure 14 after the flapper valve has rotated to the closed position.
  • FIG. 1 there is shown a wireline toolstring 10 suspended on a wireline 12 which extends through a wireline system generally designated 14 comprising a wireline device 20, a wireline stuffing box 22 an upper wireline lubricator section 24a and a lower wireline lubricator section 24b.
  • the upper lubricator section 24a defines an upwardly-facing shoulder 21a on an inner surface thereof and the wireline device 20 defines a complementary downwardly-facing shoulder 20a on an outer surface thereof.
  • the upper lubricator section 24a is axially locked relative to the lower lubricator section 24b by a lower locking member 25b and the stuffing box 22 is axially locked relative to the upper lubricator section 24a by an upper locking member 25a so that a lower end face 22a of the stuffing box 22 engages and locks the shoulder 20a of the wireline device 20 in engagement with the shoulder 21a of the upper lubricator section 24a.
  • the wireline device 20 is shown in isolation in Figure 2 and includes a downhole tool motion resistor arrangement generally designated 26, a latch arrangement generally designated 28 and a seal arrangement generally designated 30.
  • the downhole tool motion resistor arrangement 26 includes a base member in the form of a tubular mandrel 34.
  • a generally tubular lower body member 36 is fixed to an upper end of the tubular mandrel 34.
  • a collar 38 is fixed to a lower end of the tubular mandrel 34.
  • the downhole tool motion resistor arrangement 26 further includes a moveable carriage member in the form of a shuttle member 40 and a main compression spring 42 which extends around the tubular mandrel 34.
  • the shuttle member 40 is configured for reciprocal motion along the tubular mandrel 34.
  • the shuttle member 40 is shown in isolation in Figure 11 and includes a receptacle 44 at an upper end thereof and a base ring 46 at a lower end thereof.
  • the receptacle 44 is configured to receive an upper end of the toolstring 10 (not shown in Figure 11).
  • the receptacle 44 defines an aperture 45 through which the wireline 12 passes when in use.
  • the receptacle 44 further defines an upwardly protruding nose 47.
  • the receptacle 44 is joined to the base ring 46 by two elongate members 48.
  • the tubular mandrel 34 defines two elongated axially extending slots 50.
  • Each slot 50 is configured to receive a corresponding elongate member 48 of the shuttle member 40.
  • the main compression spring 42 extends axially between the lower body member 36 and the base ring 46 of the shuttle member 40 so as to bias the shuttle member 40 downwardly towards the collar 38.
  • the latch arrangement 28 and the seal arrangement 30 are shown in more detail in Figure 4 prior to engagement of the shuttle member 40 (not shown in Figure 4) with the latch arrangement 28.
  • the latch arrangement 28 includes a release member in the form of a release ring 54 and two retaining rings in the form of two snap rings 52 which are configured to retain the tool string 10 relative to the lower body member 36 as will be described in more detail below.
  • the snap rings 52 and the release ring 54 are shown in more detail in Figures 12 and 13 at different stages during operation of the latch arrangement 28.
  • Each snap ring 52 has two opposing lugs 53.
  • the release ring 54 has two, downward facing, elongated tabs 55.
  • the tabs 55 of the release ring 54 displace the lugs 53 of the snap rings 52 to an outer or expanded condition.
  • the snap rings 52 are inwardly biased so that the lugs 53 are compressed into engagement with the tabs 55.
  • the release ring 54 is surrounded by a sleeve 57 which extends axially between the snap rings 52 and the upper body member 60.
  • the upper body member 60 is screw coupled to the lower body member 36 via threaded connection 58 so as to trap the snap rings 52 axially between the lower body member 36 and the and the sleeve 57.
  • the snap rings 52 are fixed radially relative to the lower body member 36 by pins 56.
  • the release ring 54 is frangibly connected to the sleeve 57 by a shear screw 59.
  • the seal arrangement 30 has an upper body member 60 having seals 62 disposed on an outer surface thereof for sealing engagement with an inner surface of the upper lubricator section 24a shown in Figures 1 and 1A.
  • the seal arrangement 30 includes a trigger member 64, a valve body 66 and a cap member 68 which are all accommodated within a bore defined by the upper body member 60.
  • the trigger member 64, valve body 66 and cap member 68 are shown in isolation from the upper body member 60 in Figures 14 to 16 at different stages during operation of the seal arrangement 30 as will be described in more detail below.
  • a shoulder 70 of the trigger member 64 engages a lip 72 of the upper body member 60.
  • Resilient members in the form of compression springs 74 bias the valve body 66 in an upward direction away from the trigger member 64 against a lower surface 76 of the cap member 68.
  • the cap member 68 is screw coupled within the bore of the upper body member 60 so as to lock the valve body member 66 in place within the bore of the upper body member 60.
  • a seal 78 is disposed on an outer surface of the valve body 66 for sealing engagement with an inner surface of the upper body member 60.
  • the trigger member 64, valve body 66 and cap member 68 each have an aperture formed therein which is configured to permit the wireline 12 (not shown in Figure 4) to extend therethrough.
  • the apertures of the trigger member 64, valve body 66 and cap member 68 are aligned so as to define a passage 80 for the wireline 12.
  • the seal arrangement 30 further comprises a flapper valve 82 shown most clearly in Figures 14 to 16.
  • An O-ring seal 84 is disposed on a surface of the flapper valve 82.
  • the flapper valve 82 is biased by a torsion spring (not shown) from an open position shown in Figures 14 and 15 towards a closed position shown in Figure 16 in which the O-ring seal 84 of the flapper valve 82 sealingly engages a surface of the valve body 66 to create a pressure tight barrier across the wireline passage 80.
  • the seal arrangement 30 also includes release members in the form of two release pins 86 which extend laterally from an inner surface of the trigger member 64. When the trigger member 64 and the valve body 66 are separated as shown in Figure 14, the release pins 86 prevent closure of the flapper valve 82. When the trigger member 64 and the valve body 66 are moved into engagement as shown in Figures 15 and 16, the release pins 86 permit closure of the flapper valve 82 under the action of the torsion spring (not shown).
  • Figures 5 to 10 Each of Figures 5 to 10 illustrates the configuration of the downhole tool motion resistor arrangement 26, the latch arrangement 28, and the seal arrangement 30 at a different stage in the operating sequence of the wireline device 20.
  • the toolstring 10 and the shuttle member 40 may continue their upward travel in response to the ongoing retraction of the wireline 12.
  • an upper surface of the receptacle 44 of the shuttle member 40 engages internal shoulders 90 of the release ring 54 as shown in Figure 6.
  • the tabs 55 of the release ring 54 still extend between and displace the lugs 53 of the snap rings 52 to the outer or expanded condition as shown most clearly in Figure 12.
  • the shear screw 59 is still intact so as to prevent axial movement of the release ring 54 relative to the sleeve 57.
  • the release ring 54 moves upward together with the shuttle member 40 until the latch arrangement 28 reaches the configuration shown in Figure 7 in which the tabs 55 of the release ring 54 have disengaged from the lugs 53 of the snap rings 52 and the snap rings 52 have collapsed under the action of their own inward bias as shown most clearly in Figure 13.
  • the latch arrangement 28 is configured such that this collapse event occurs when a standard reduced diameter 92 of the tool string 10 is adjacent to the snap rings 52.
  • An end stop against downward motion of the toolstring 10 is then established by virtue of a shoulder 93 of a standard fishing neck profile 94 of the tool string 10 and upper surfaces 53a of the lug 53 of the snap rings 52.
  • the upper part of the broken wireline 12 With the continued application of tension on the upper part of the broken wireline 12, the upper part of the broken wireline 12 is pulled through the stuffing box 22 and the flapper valve 82 closes under the action of the torsion spring (not shown) to seal the wireline passage 80 thereby effecting containment of wellbore fluids.
  • the retaining ring 54 may be downwardly biased with respect to the upper body member 60 so that the tabs 55 of the release ring 54 normally extend between the lugs 53 of the snap rings 52 so as to displace the lugs 53 of the snap rings 52 to an outer or expanded condition.
  • the wireline device 20 may include one or more resilient members in the form of one or more compression springs (not shown) located between the upper surface 96 of the release ring 54 and the lower surface 98 of the upper body member 60 for this purpose.
  • the main compression spring 42 may be replaced by a resilient member of any kind.
  • the main compression spring 42 may be replaced by an elastomeric member such as an elastomeric sleeve.
  • the resilient member may comprise a plurality of voids.
  • the resilient member may comprise a sponge.
  • the resilient member may comprise an inwardly biased resilient ring or sleeve such as an inwardly biased split ring or an inwardly biased c-ring which is configured to engage a conical outer surface of a base member.
  • an inwardly biased resilient ring may provide an increasing resistance as the ring moves in a direction opposite to the direction of a taper of the conical outer surface of the base member.
  • the resilient member may comprise a sleeve having one or more resilient collet fingers.
  • the base member may define one or more features on an outer surface thereof.
  • the base member may define one or more recesses and/or one or more projections on an outer surface thereof.
  • the collet fingers of the sleeve may be configured for engagement with the one or more features on the outer surface of the base member.
  • Each collet finger may be naturally unbiased.
  • the collet fingers of the sleeve may engage the one or more projections of defined on an outer surface of the base member to thereby displace each collet finger from the its natural unbiased state and induce an inward bias in the collet finger.
  • This may provide an increase in resistance to relative motion between the sleeve and the base member.
  • This may provide multiple peaks in resistance to relative motion between the sleeve and the base member which may translate into multiple peaks in wireline tension which, if monitored, may serve as warnings to a wireline winch operator of the approach of a downhole tool to the wireline device.
  • Each collet finger may be inwardly biased.
  • the collet fingers of the sleeve may engage one or more recesses and/or one or more projections defined on the outer surface of the base member to thereby provide an increase in resistance to relative motion between the sleeve and the base member.
  • This may provide multiple peaks in resistance to relative motion between the sleeve and the base member which may translate into multiple peaks in wireline tension which, if monitored, may serve as warnings to a wireline winch operator of the approach of a downhole tool to the wireline device.
  • the resilient member may comprise an outwardly biased resilient ring or sleeve.
  • the outwardly biased resilient ring may engage an inner surface of a tubular base member.
  • the resilient member may comprise a sleeve having one or more resilient collet fingers.
  • the base member may define one or more features on an inner surface thereof.
  • the base member may define one or more recesses and/or one or more projections on an inner surface thereof.
  • the collet fingers of the sleeve may be configured for engagement with the one or more features on the inner surface of the base member.
  • Each collet finger may be naturally unbiased.
  • Each collet finger may be outwardly biased.
  • the resilient member may comprise a damper.
  • the damper may comprise a piston.
  • the piston may act against a fluid which is in fluid communication with an accumulator.
  • the latch arrangement may comprise a retaining member without a release member.
  • the latch arrangement may comprise a retaining member which may be configured to be displaced radially outwardly under the action of a downhole tool in response to a force transferred from the downhole tool. This may induce or increase an inward bias in the retaining member in response to a force transferred from the downhole tool, for example as the downhole tool is pulled upwardly against the retaining member.
  • An upper surface of the downhole tool may be configured for this purpose.
  • the downhole tool may engage a carriage member as the downhole tool is pulled upwardly and may urge the carriage member against the retaining member.
  • the retaining member may be configured so as to snap back under a fishing neck shoulder of the downhole tool after further upward motion of the downhole tool.
  • the retaining member may comprise a sleeve having one or more resilient collet fingers. Each collet finger may be configured to engage a fishing neck shoulder of a downhole tool.
  • the retaining member may be configured such that each collet finger may be displaced radially outwardly in response to a force transferred from the downhole tool to the collet finger.
  • Each collet finger may be configured to snap back under a fishing neck shoulder of the downhole tool after movement of the downhole tool relative to the collet finger.
  • Each collet finger may be naturally unbiased.
  • Each collet finger may be inwardly or outwardly biased.

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Abstract

A wireline device for use in downhole operations may comprise at least one of a position indicator arrangement, a latch arrangement and a seal arrangement. The position indicator device may alert a winch line operator of the approach of a downhole toolstring to a stuffing box located at the wellhead of an oil or gas well. This may permit the winch line operator to control winching of the wireline so as to avoid retraction of the toolstring into engagement with the stuffing box thereby minimising the resulting risk of wireline breakage. The latch arrangement may retain the tool string relative to a wellhead housing so as to avoid the toolstring dropping back into the wellbore in the event of wireline breakage. The seal arrangement may prevent a hydrocarbon leak from the wellbore to an environment external to the wellhead housing in the event of wireline breakage.

Description

WIRELINE DEVICE
FIELD
The present invention relates to a wireline device for use in wireline operations and, in particular though not exclusively, for use in wireline operations in an oil or gas well.
BACKGROUND
In drilling and other well operations, a wireline may be used for raising and lowering tools into a wellbore. Specifically, this is achieved by attaching a toolstring to the end of a reel of a single strand or braided wire. The wireline passes through a stuffing box which is installed on top of a lubricator stack. The stuffing box is used to facilitate a seal and retain well pressure around moving and stationary wireline. During wireline operations the winch operator must know the position of his tools within the well. Technologies exist for monitoring this position, but they are not completely reliable and the situation frequently arises where the toolstring is erroneously drawn into the stuffing box. This typically results in the wireline breaking, causing the toolstring to be dropped into the well. An end of the wireline may then be blown out of the stuffing box and a hydrocarbon leak may occur. This may also mean that it is necessary for the toolstring to be recovered before well operations can recommence.
SUMMARY
According to an aspect of the invention there is provided a downhole tool motion resistor arrangement for use in indicating a position of a downhole tool.
The downhole tool motion resistor arrangement may comprise a base member. The downhole tool motion resistor arrangement may comprise a carriage member for engaging a downhole tool. The carriage member may be moveable relative to the base member.
The downhole tool motion resistor arrangement may comprise a resilient member for resisting movement of the carriage member relative to the base member when a downhole tool is pulled into engagement with the carriage member using a wireline which is connected to the downhole tool and which extends through the carriage member. If wireline tension is monitored, such a motion resistor arrangement may provide an operator with an indication of the position of the downhole tool relative to the base member by virtue of the increased force that must be exerted by the downhole tool on the carriage member to overcome the bias provided by the resilient member.
The base member may comprise part of a wellhead housing. The base member may comprise part of a wireline stuffing box or lubricator housing.
The carriage member may be configured for engagement with a conventional downhole tool. This may avoid any requirement for a bespoke or specially modified downhole tool for use with the position indicator arrangement.
The resilient member may comprise a compression spring.
The resilient member may comprise an elastomeric member such as an elastomeric sleeve.
The resilient member may comprise a plurality of voids.
The resilient member may comprise a sponge.
The resilient member may be moveable with the carriage member relative to the base member.
The resilient member may comprise an inwardly biased resilient ring or sleeve such as an inwardly biased split ring or an inwardly biased c-ring.
The base member may define a conical outer surface.
The inwardly biased resilient ring may engage an outer surface of the base member.
Such an inwardly biased resilient ring may provide an increasing resistance as the ring moves in a direction opposite to the direction of a taper of the conical outer surface of the base member.
The resilient member may comprise a sleeve having one or more resilient collet fingers. The base member may define one or more features on an outer surface thereof. For example, the base member may define one or more recesses and/or one or more projections on an outer surface thereof.
The collet fingers of the sleeve may be configured for engagement with the one or more features on the outer surface of the base member.
Each collet finger may be naturally unbiased.
During relative motion between the sleeve and the base member, the collet fingers of the sleeve may engage one or more projections defined on an outer surface of the base member to thereby displace each collet finger from the its natural unbiased state and induce an inward bias in the collet finger. This may provide an increase in resistance to relative motion between the sleeve and the base member. This may provide multiple peaks in resistance to relative motion between the sleeve and the base member which may translate into multiple peaks in wireline tension which, if monitored, may serve as warnings to a wireline winch operator of the approach of a downhole tool to the wireline device.
Each collet finger may be inwardly biased. During relative motion between the sleeve and the base member, the collet fingers of the sleeve may engage one or more recesses and/or one or more projections defined on the outer surface of the base member to thereby provide an increase in resistance to relative motion between the sleeve and the base member. This may provide multiple peaks in resistance to relative motion between the sleeve and the base member which may translate into multiple peaks in wireline tension which, if monitored, may serve as warnings to a wireline winch operator of the approach of a downhole tool to the wireline device.
The base member may define an aperture which is configured to permit a wireline to extend therethrough.
The base member may be tubular.
The resilient member may comprise an outwardly biased resilient ring or sleeve. The outwardly biased resilient ring may engage an inner surface of the base member.
The resilient member may comprise a sleeve having one or more resilient collet fingers.
The base member may define one or more features on an inner surface thereof. For example, the base member may define one or more recesses and/or one or more projections on an inner surface thereof.
The collet fingers of the sleeve may be configured for engagement with the one or more features on the inner surface of the base member.
Each collet finger may be naturally unbiased.
Each collet finger may be inwardly biased.
The resilient member may comprise a damper.
The damper may comprise a piston.
The piston may act against a fluid which is in fluid communication with an accumulator. The base member may be configured to permit a downhole tool to extend at least partially therethrough.
The carriage member may comprise a receptacle portion for engagement with a downhole tool. The receptacle portion may be arranged to move within the base member.
The receptacle portion may define an aperture which is configured to permit the wireline to extend therethrough.
The carriage member may comprise a base ring which is configured to move over an outer surface of the base member.
The arrangement of the carriage member and the resilient member relative to a tubular base member may provide support to both the carriage member and the resilient member. This may provide for a relatively simple and stable load path from the downhole tool to the carriage member.
The position indicator arrangement may comprise a wireline tension sensor.
This may permit a wireline winch operator to monitor tension in the wireline and to control winching of the wireline according to the tension in the wireline.
The position indicator arrangement may be configured for installation within a wellhead housing.
If wireline tension is monitored, such a motion resistor arrangement may be used to provide an indication of the position of a downhole tool relative to the wellhead housing. This may permit a wireline winch operator to control winching of the wireline according to the proximity of the downhole tool relative to the wellhead housing.
The motion resistor arrangement may be configured for installation within a housing comprising a wireline lubricator housing or a stuffing box housing. If wireline tension is monitored, such a motion resistor arrangement may provide an indication of the position of a downhole tool relative to the wireline lubricator housing or the stuffing box housing. This may permit a wireline winch operator to control winching of the wireline according to the proximity of the downhole tool relative to the wireline lubricator housing or the stuffing box housing. As such, the motion resistor arrangement may serve to alert the operator to the approach of the downhole tool to the stuffing box so that the operator may control winching of the wireline to avoid retracting the downhole tool into the stuffing box thereby minimising the resulting risk of wireline breakage.
According to an aspect of the invention there is provided a latch arrangement for latching a downhole tool.
The latch arrangement may comprise an inwardly biased retaining ring.
The latch arrangement may comprise a release member which is moveable relative to the retaining ring between a first position in which the release member prevents the retaining ring from collapsing inwardly and a second position in which the retaining ring is permitted to collapse inwardly around a downhole tool to at least partially restrict movement of the downhole tool through the retaining ring.
Such a latch arrangement may be used to retain a downhole tool so as to prevent the downhole tool dropping into or otherwise moving within a wellbore in the event of failure of a wireline which supports the downhole tool in the wellbore. This may avoid any requirement to retrieve the downhole tool from the wellbore at a later time.
It should be understood that one or more features of one aspect of the invention may apply alone or in any combination in relation to any other aspect of the invention.
The latch arrangement may comprise a body member.
The retaining ring may be axially fixed relative to the body member.
The release member may be axially moveable relative to the body member. Such a latch arrangement may be used to automatically retain a downhole tool relative to the body member.
The retaining ring may be split. For example, the retaining ring may comprise a split ring, snap ring or the like.
The retaining ring may comprise a pair of opposing lugs. Each lug may be configured to engage the downhole tool.
The release member may comprise a tab.
The tab may be configured for engagement with the lugs of the retaining ring to prevent the retaining ring from collapsing inwardly around a downhole tool when the release member is in the first position.
The tab may be configured for disengagement from the lugs of the retaining ring to permit the retaining ring to collapse inwardly around a downhole tool when the release member is in the second position.
The latch arrangement may be arranged to prevent movement of a downhole tool relative to the retaining ring in at least one direction when the retaining ring is collapsed inwardly around the downhole tool. The latch arrangement may be arranged to prevent downward movement of a downhole tool relative to the retaining ring when the retaining ring is collapsed inwardly around the downhole tool.
The latch arrangement may be configured to prevent movement of a feature of the downhole tool relative to a complementary feature of the retaining ring when the retaining ring is collapsed inwardly around the downhole tool.
The latch arrangement may comprise a plurality of retaining rings. A plurality of retaining rings may retain a downhole tool more securely than a single retaining ring. Each retaining ring may be configured to engage a profile of a downhole tool.
Each retaining ring may be configured to engage a fishing neck profile such as a conventional fishing neck profile of a downhole tool. This may avoid any requirement for a bespoke or specially modified downhole tool for use with the latch arrangement.
The release member may be moveable from the first position to the second position in response to a force communicated from a downhole tool to the release member. Such a latch arrangement may be used to automatically retain a downhole tool so as to prevent the downhole tool dropping into or otherwise moving within a wellbore in the event of failure of a wireline which supports the downhole tool in the wellbore. Such a latch arrangement may, in particular, be used to automatically capture a downhole tool at or within a lubricator so as to prevent the downhole tool dropping into a wellbore in the event of failure of a wireline which supports the downhole tool in the wellbore.
The release member may be moveable from the first position to the second position in response to a force communicated from the downhole tool to the release member indirectly through an intermediate member.
The intermediate member may comprise a carriage member which is configured to move with the downhole tool.
The release member may be biased towards the first position. This may result in the retaining ring adopting a normally expanded configuration. This may serve to avoid the retaining ring from unintentionally retaining a downhole tool. The latch arrangement may be configured for installation within a housing comprising a wireline lubricator housing or a stuffing box housing.
According to an aspect of the invention there is provided a latch arrangement for latching a downhole tool.
The latch arrangement may comprise a retaining member.
The retaining member may comprise a retaining ring.
The retaining ring may be split.
The retaining ring may be inwardly biased.
The retaining member may be configured to be displaced radially outwardly in response to a force communicated from the downhole tool to the retaining member. This may induce or increase an inward bias in the retaining member in response to a force transferred from the downhole tool, for example as the downhole tool is pulled upwardly against the retaining member. An upper surface of the downhole tool may be configured for this purpose. The upper surface of the downhole tool may be generally conical.
Alternatively, the downhole tool may engage a carriage member as the downhole tool is pulled upwardly and the downhole tool may urge the carriage member against the retaining member.
The retaining member may be configured so as to snap back under a fishing neck shoulder of the downhole tool after further upward motion of the downhole tool.
The retaining member may comprise a sleeve having one or more resilient collet fingers.
Each collet finger may be configured to engage a fishing neck shoulder of a downhole tool.
The retaining member may be configured such that each collet finger may be displaced radially outwardly in response to a force transferred from the downhole tool to the collet finger.
Each collet finger may be configured to snap back under a fishing neck shoulder of the downhole tool after movement of the downhole tool relative to the collet finger.
Each collet finger may be naturally unbiased.
Each collet finger may be inwardly or outwardly biased.
It should be understood that one or more features of one aspect of the invention may apply alone or in any combination in relation to any other aspect of the invention.
According to an aspect of the invention there is provided a seal arrangement for use in sealing a wellbore.
The seal arrangement may comprise a valve body defining an aperture for a wireline.
The seal arrangement may comprise a valve which is biased towards a closed position in which the valve seals the aperture defined by the valve body.
The seal arrangement may comprise a release member which is moveable relative to the valve between a first position in which the release member prevents the valve from moving towards the closed position and a second position in which the valve is permitted to move towards the closed position.
Such a seal arrangement may be used to seal an aperture through which a wireline normally extends from the wellbore to an environment surrounding the wellbore in the event of breakage of the wireline and blow out of the wireline from the aperture. Such a seal arrangement may, therefore, be used to contain leakage from the wellbore to the surrounding environment. This may provide both a safety benefit and an environmental benefit. Such a seal arrangement may, in particular, be used to seal an aperture or passage which extends through a wall of a housing of a lubricator or a stuffing box when a downhole tool is inadvertently drawn into the housing of the lubricator or the stuffing box.
It should be understood that one or more features of one aspect of the invention may apply alone or in any combination in relation to any other aspect of the invention.
The valve may comprise a flapper valve.
The valve may comprise a ball valve, a gate valve, a check valve or the like. The release member may be moveable relative to the valve from the first position to the second position in response to a force communicated from a downhole tool to the release member.
Such a seal arrangement may be used to automatically seal an aperture through which a wireline normally extends from the wellbore to an environment surrounding the wellbore in the event of a breakage of the wireline and blow out of the wireline from the aperture. Such a seal arrangement may, therefore, be used to automatically contain leakage from the wellbore to the surrounding environment. Such a seal arrangement may, in particular, be used to automatically seal an aperture or passage which extends through a wall of a housing of a lubricator or a stuffing box when a downhole tool is inadvertently drawn into the housing of the lubricator or the stuffing box.
The release member may be moveable relative to the valve from the first position to the second position in response to a force communicated from a downhole tool to the release member via an intermediate member.
The intermediate member may comprise a carriage member which is configured to move with the downhole tool.
The release member may be biased towards the first position. This may result in a normally open configuration of the valve so as to avoid inadvertent closure of the valve. This may avoid any inadvertent interference between the valve and the wireline.
The seal arrangement may be configured for installation within a wireline lubricator housing or a stuffing box housing.
According to an aspect of the invention there is provided a wireline device comprising at least one of the motion resistor arrangement, the latch arrangement, and the seal arrangement. The wireline device may be configured for installation within a wellhead housing such as a wireline lubricator housing or a stuffing box housing. The wireline device may be configured such that installation within a conventional wellhead housing requires only minor modifications. For example, the wireline device may define a shoulder on an outer surface thereof which is configured to engage a complementary shoulder of a wellhead housing for suspension of the wireline device from the wellhead housing. Such a 'hang-off shoulder may be simply formed, for example by machining an inner bore of a conventional wellhead housing so as to define an annular recess thereon.
According to an aspect of the invention there is provided a wireline system comprising a housing and at least one of the motion resistor arrangement, the latch arrangement, and the seal arrangement.
The housing may be configured for installation at a head of an oil or gas well. The housing may comprise a wireline lubricator housing or a stuffing box housing.
The wireline system may comprise a downhole tool and a wireline connecting the downhole tool to surface.
According to an aspect of the invention there is provided a method of restricting motion of a downhole tool for use in indicating a position of the downhole tool.
The method of restricting motion of a downhole tool may comprise pulling a downhole tool into engagement with a carriage member using a wireline which is connected to the downhole tool and which extends through the carriage member.
The method of restricting motion of a downhole tool may comprise resisting movement of the carriage member relative to a base member.
The method of restricting motion of a downhole tool may comprise sensing tension in the wireline.
It should be understood that one or more features of one aspect of the invention may apply alone or in any combination in relation to any other aspect of the invention.
According to an aspect of the invention there is provided a method for latching a downhole tool.
The method for latching a downhole tool may comprise locating a release member relative to an inwardly biased retaining ring so as to prevent the retaining ring from collapsing inwardly.
The method for latching a downhole tool may comprise moving the release member relative the retaining ring so as to permit the retaining ring to collapse inwardly around a downhole tool to at least partially restrict movement of the downhole tool through the retaining ring.
Moving the release member relative to the retaining ring may comprise communicating a force from the downhole tool to the release member so as to move the release member relative the retaining ring.
Moving the release member relative to the retaining ring may comprise applying a tensile force to the downhole tool through a wireline which is connected to the downhole tool and which extends through the release member and the retaining ring so as to communicate the force from the downhole tool to the release member.
It should be understood that one or more features of one aspect of the invention may apply alone or in any combination in relation to any other aspect of the invention.
According to an aspect of the invention there is provided a method for use in sealing a wellbore.
The method for use in sealing a wellbore may comprise locating a release member relative to a valve so as to prevent the valve from moving under the action of a bias towards a closed position in which the valve seals an aperture defined by a valve body.
The method for use in sealing a wellbore may comprise moving the release member relative to the valve so that the valve is permitted to move to the closed position under the action of the bias.
Moving the release member relative to the valve may comprise communicating a force from a downhole tool to the release member so as to move the release member relative to the valve
The method for use in sealing a wellbore may comprise applying a tensile force to the downhole tool through a wireline which is connected to the downhole tool and which extends through the aperture defined by the valve body so as to communicate the force from the downhole tool to the release member.
The method for use in sealing a wellbore may comprise applying sufficient tensile force to the downhole tool through the wireline so as to break the wireline and withdraw an end of the wireline through the aperture defined by the valve body so that the valve moves to the closed position under the action of the bias.
It should be understood that one or more features of one aspect of the invention may apply alone or in any combination in relation to any other aspect of the invention.
According to an aspect of the invention there is provided a method for use in wireline operations comprising at least one of: the method of restricting motion of a downhole tool;
the method for latching a downhole tool; and
the method for sealing a wellbore.
It should be understood that the method for use in indicating a position of a downhole tool, the method for latching a downhole tool and the method for sealing a wellbore may be performed in any order.
It should also be understood that it may be advantageous for the method of restricting motion of a downhole tool to precede the method for latching a downhole tool so as to give a winch line operator advance warning of the approach of a downhole tool relative to a housing such as a wireline lubricator housing or a stuffing box housing.
The method of restricting motion of a downhole tool, the method for latching a downhole tool and the method for sealing a wellbore may at least partially overlap.
According to an aspect of the invention there is provided a method for improving well safety comprising at least one of:
the method of restricting motion of a downhole tool;
the method for latching a downhole tool; and
the method for sealing a wellbore.
It should be understood that the method of restricting motion of a downhole tool, the method for latching a downhole tool and the method for sealing a wellbore may be performed in any order.
It should also be understood that it may be advantageous for the method of restricting motion of a downhole tool to precede the method for latching a downhole tool so as to give a winch line operator advance warning of the approach of a downhole tool relative to a housing such as a wireline lubricator housing or a stuffing box housing.
The method of restricting motion of a downhole tool, the method for latching a downhole tool and the method for sealing a wellbore may at least partially overlap.
According to an aspect of the invention there is provided a method for use in retrieving a downhole tool from a wellbore, comprising:
inserting the latch arrangement into a housing; and
using the latch arrangement to retain a downhole tool relative to the housing after breakage of a wireline connected to the downhole tool.
The method for use in retrieving a downhole tool may comprise removing the downhole tool from the housing. The housing may be configured for installation at a head of an oil or gas well. The housing may comprise a wireline lubricator housing or a stuffing box housing.
According to an aspect of the invention there is provided a method of providing an indication of the position of a wireline toolstring as it is being pulled into a stuffing box of a wireline lubricator, said method comprising:
providing a base member through which the wireline passes, said base member being dimensioned and proportioned to receive said toolstring;
providing a carriage member moveable relative to said base member;
coupling said carriage member to a resilient member
coupling said wireline to an indicator display for monitoring tension in said wireline; and
as said toolstring is withdrawn into said stuffing box, engaging said toolstring with the carriage member to apply force to said resilient member which resists said force to cause a change in tension in said wireline which is monitorable on said indicator display.
According to an aspect of the invention there is provided a system for providing an indication of the position of a wireline toolstring as it is pulled into a stuffing box of a wireline lubricator, said system comprising:
a base member for receiving said toolstring and through which said wireline passes, said base member being located in said stuffing box;
a carriage member moveable relative to said base member;
a resilient member coupled to said base member for resisting motion of said carriage member; and
an indicator for providing an indication of increased tension in said wireline when a toolstring is pulled into engagement with said carriage member and movement of said toolstring is resisted by said resilient member.
According to an aspect of the invention there is provided a wireline lubricator safety system comprising:
a downhole tool motion resistor arrangement for use in indicating a position of a downhole tool relative to a stuffing box of a wireline lubricator;
a latch arrangement for latching a downhole tool within the stuffing box; and a seal arrangement for use in sealing a wireline aperture in a wall of the stuffing box in the event of wireline failure.
The downhole tool motion resistor arrangement may comprise: a base member;
a carriage member for engaging a downhole tool, the carriage member being moveable relative to the base member; and
a resilient member for resisting movement of the carriage member relative to the base member when a downhole tool is pulled into engagement with the carriage member using a wireline which is connected to the downhole tool and which extends through the carriage member.
The latch arrangement may comprise:
an inwardly biased retaining ring; and
a release member which is moveable relative to the retaining ring between a first position in which the release member prevents the retaining ring from collapsing inwardly and a second position in which the retaining ring is permitted to collapse inwardly around a downhole tool to at least partially restrict movement of the downhole tool through the retaining ring.
The seal arrangement may comprise:
a valve body defining an aperture for a wireline;
a valve which is biased towards a closed position in which the valve seals the aperture defined by the valve body; and
a release member which is moveable relative to the valve between a first position in which the release member prevents the valve from moving towards the closed position and a second position in which the valve is permitted to move towards the closed position.
It should be understood that one or more features of one aspect of the invention may apply alone or in any combination in relation to any other aspect of the invention.
BRIEF DESCRIPTION OF THE DRAWINGS
The invention will now be described by way of non-limiting example only with reference to the accompanying drawings of which:
Figure 1 is a longitudinal cross-section of a wireline toolstring suspended on a wireline extending through a wireline system comprising a wireline device, a stuffing box and lubricator sections; is a detail longitudinal cross-section of a portion of the wireline system of Figure 1 ; is a longitudinal cross-section of the wireline device in isolation; is a broken view to a larger scale of the upper and lower portions of the wireline device; is an enlarged detail view of the upper portion of the wireline device; is a broken view of the upper and lower portions of the wireline device, with the top of a wireline toolstring present and making initial contact with a shuttle member; is a detail view of the shuttle member in contact with a release ring; is a detail view of the release ring and collapsed snap rings after displacement of the release ring by the shuttle member; is a detail view of the shuttle member in contact with and showing a trigger member displaced to permit closure of a flapper valve; is a detailed view of the release ring in contact with an upper body after breaking of the wireline within the rope socket and full closure of the flapper valve; is a detail view of the shuttle member and wireline toolstring in the captured position with the lower surface of the fishing profile resting on the collapsed snap rings; is a perspective view of the shuttle member; is a detail perspective view of the release ring, the top end of the shuttle member, the top end of the wireline toolstring and the snap rings, where tabs of the release ring are preventing collapse of the snap rings; Figure 13 is a similar view to Figure 12 but the release ring has moved upwards allowing the snap rings to collapse;
Figure 14 is a longitudinal sectional perspective view of the components of a seal arrangement with the trigger member in a downward position, retaining the flapper valve in an open position;
Figure 15 is a sectional perspective view similar to Figure 14 with the trigger member in an upward position to permit the flapper valve to rotate to a closed position; and
Figure 16 is a sectional perspective view similar to Figure 14 after the flapper valve has rotated to the closed position.
DETAILED DESCRIPTION OF THE DRAWINGS
Terms such as "up", "down", "upward", "downward", "uphole", "downhole" and the like are used below when referring to features shown in Figures 1 to 16 for ease of illustration only. One skilled in the art will understand that such terms are intended to refer to the particular orientation of the features shown in Figures 1 to 16, but are not intended to be limiting. For example, terms such as "up", "upward" and "uphole" may be used to refer to a direction along a borehole towards a point of entry of the borehole into the ground or the seabed, whilst terms such as "down", "downward" and "downhole" may be used to refer to a direction along a borehole away from the point of entry. As such, when a borehole is deviated from the vertical or is horizontal, such terms may refer to a direction which differs significantly from a vertical direction and may even refer to a horizontal direction.
Referring initially to Figure 1 there is shown a wireline toolstring 10 suspended on a wireline 12 which extends through a wireline system generally designated 14 comprising a wireline device 20, a wireline stuffing box 22 an upper wireline lubricator section 24a and a lower wireline lubricator section 24b. As shown in more detail in Figure 1A, the upper lubricator section 24a defines an upwardly-facing shoulder 21a on an inner surface thereof and the wireline device 20 defines a complementary downwardly-facing shoulder 20a on an outer surface thereof. The upper lubricator section 24a is axially locked relative to the lower lubricator section 24b by a lower locking member 25b and the stuffing box 22 is axially locked relative to the upper lubricator section 24a by an upper locking member 25a so that a lower end face 22a of the stuffing box 22 engages and locks the shoulder 20a of the wireline device 20 in engagement with the shoulder 21a of the upper lubricator section 24a.
The wireline device 20 is shown in isolation in Figure 2 and includes a downhole tool motion resistor arrangement generally designated 26, a latch arrangement generally designated 28 and a seal arrangement generally designated 30.
The wireline device 20 is shown in more detail in Figure 3. The downhole tool motion resistor arrangement 26 includes a base member in the form of a tubular mandrel 34. A generally tubular lower body member 36 is fixed to an upper end of the tubular mandrel 34. A collar 38 is fixed to a lower end of the tubular mandrel 34. The downhole tool motion resistor arrangement 26 further includes a moveable carriage member in the form of a shuttle member 40 and a main compression spring 42 which extends around the tubular mandrel 34. As will be explained in more detail below, the shuttle member 40 is configured for reciprocal motion along the tubular mandrel 34.
The shuttle member 40 is shown in isolation in Figure 11 and includes a receptacle 44 at an upper end thereof and a base ring 46 at a lower end thereof. The receptacle 44 is configured to receive an upper end of the toolstring 10 (not shown in Figure 11). The receptacle 44 defines an aperture 45 through which the wireline 12 passes when in use. The receptacle 44 further defines an upwardly protruding nose 47. The receptacle 44 is joined to the base ring 46 by two elongate members 48.
Referring back to Figure 3, the tubular mandrel 34 defines two elongated axially extending slots 50. Each slot 50 is configured to receive a corresponding elongate member 48 of the shuttle member 40. The main compression spring 42 extends axially between the lower body member 36 and the base ring 46 of the shuttle member 40 so as to bias the shuttle member 40 downwardly towards the collar 38.
The latch arrangement 28 and the seal arrangement 30 are shown in more detail in Figure 4 prior to engagement of the shuttle member 40 (not shown in Figure 4) with the latch arrangement 28. The latch arrangement 28 includes a release member in the form of a release ring 54 and two retaining rings in the form of two snap rings 52 which are configured to retain the tool string 10 relative to the lower body member 36 as will be described in more detail below. The snap rings 52 and the release ring 54 are shown in more detail in Figures 12 and 13 at different stages during operation of the latch arrangement 28. Each snap ring 52 has two opposing lugs 53. The release ring 54 has two, downward facing, elongated tabs 55. When the latch arrangement 28 is in the initial configuration shown in Figure 4, the tabs 55 of the release ring 54 displace the lugs 53 of the snap rings 52 to an outer or expanded condition. The snap rings 52 are inwardly biased so that the lugs 53 are compressed into engagement with the tabs 55. As shown in Figure 4, the release ring 54 is surrounded by a sleeve 57 which extends axially between the snap rings 52 and the upper body member 60. The upper body member 60 is screw coupled to the lower body member 36 via threaded connection 58 so as to trap the snap rings 52 axially between the lower body member 36 and the and the sleeve 57. The snap rings 52 are fixed radially relative to the lower body member 36 by pins 56. The release ring 54 is frangibly connected to the sleeve 57 by a shear screw 59.
Referring to Figure 4, the seal arrangement 30 has an upper body member 60 having seals 62 disposed on an outer surface thereof for sealing engagement with an inner surface of the upper lubricator section 24a shown in Figures 1 and 1A. The seal arrangement 30 includes a trigger member 64, a valve body 66 and a cap member 68 which are all accommodated within a bore defined by the upper body member 60. The trigger member 64, valve body 66 and cap member 68 are shown in isolation from the upper body member 60 in Figures 14 to 16 at different stages during operation of the seal arrangement 30 as will be described in more detail below.
Referring to Figure 4 once again, a shoulder 70 of the trigger member 64 engages a lip 72 of the upper body member 60. Resilient members in the form of compression springs 74 bias the valve body 66 in an upward direction away from the trigger member 64 against a lower surface 76 of the cap member 68. The cap member 68 is screw coupled within the bore of the upper body member 60 so as to lock the valve body member 66 in place within the bore of the upper body member 60. A seal 78 is disposed on an outer surface of the valve body 66 for sealing engagement with an inner surface of the upper body member 60.
The trigger member 64, valve body 66 and cap member 68 each have an aperture formed therein which is configured to permit the wireline 12 (not shown in Figure 4) to extend therethrough. The apertures of the trigger member 64, valve body 66 and cap member 68 are aligned so as to define a passage 80 for the wireline 12.
The seal arrangement 30 further comprises a flapper valve 82 shown most clearly in Figures 14 to 16. An O-ring seal 84 is disposed on a surface of the flapper valve 82. The flapper valve 82 is biased by a torsion spring (not shown) from an open position shown in Figures 14 and 15 towards a closed position shown in Figure 16 in which the O-ring seal 84 of the flapper valve 82 sealingly engages a surface of the valve body 66 to create a pressure tight barrier across the wireline passage 80. The seal arrangement 30 also includes release members in the form of two release pins 86 which extend laterally from an inner surface of the trigger member 64. When the trigger member 64 and the valve body 66 are separated as shown in Figure 14, the release pins 86 prevent closure of the flapper valve 82. When the trigger member 64 and the valve body 66 are moved into engagement as shown in Figures 15 and 16, the release pins 86 permit closure of the flapper valve 82 under the action of the torsion spring (not shown).
The operation of the wireline device 20 will now be described with reference to
Figures 5 to 10. Each of Figures 5 to 10 illustrates the configuration of the downhole tool motion resistor arrangement 26, the latch arrangement 28, and the seal arrangement 30 at a different stage in the operating sequence of the wireline device 20.
Referring to Figure 5, as the toolstring 10 is drawn into the lubricator sections
24a, 24b (not shown in Figure 5), it contacts the receptacle 44 of the shuttle member 40. Further retraction of the wireline 12 must now overcome the increasing resistance offered by the main compression spring 42. A step change in tension is thus developed at the point of contact between the toolstring 10 and the shuttle member 40 which increases as retraction continues. This significant change in tension is more clearly visible at the tension indicator display and the winch operator may then be certain as to the precise location of the toolstring 10 within the lubricator sections 24a, 24b and can take the appropriate action to avoid retracting the toolstring 10 into engagement with the stuffing box 22 so as to minimise the resulting risk of wireline breakage.
Should the operator fail to observe the increased tension described above, the toolstring 10 and the shuttle member 40 may continue their upward travel in response to the ongoing retraction of the wireline 12. As the main compression spring 42 approaches full compression, an upper surface of the receptacle 44 of the shuttle member 40 engages internal shoulders 90 of the release ring 54 as shown in Figure 6. At this stage, the tabs 55 of the release ring 54 still extend between and displace the lugs 53 of the snap rings 52 to the outer or expanded condition as shown most clearly in Figure 12. Furthermore, the shear screw 59 is still intact so as to prevent axial movement of the release ring 54 relative to the sleeve 57. Continued upward motion of the toolstring 10 shears the shear screw 59 thereby permitting further upward motion of the shuttle member 40 and movement of the release ring 54 relative to the sleeve 57. The release ring 54 moves upward together with the shuttle member 40 until the latch arrangement 28 reaches the configuration shown in Figure 7 in which the tabs 55 of the release ring 54 have disengaged from the lugs 53 of the snap rings 52 and the snap rings 52 have collapsed under the action of their own inward bias as shown most clearly in Figure 13. With reference to Figure 7, the latch arrangement 28 is configured such that this collapse event occurs when a standard reduced diameter 92 of the tool string 10 is adjacent to the snap rings 52. An end stop against downward motion of the toolstring 10 is then established by virtue of a shoulder 93 of a standard fishing neck profile 94 of the tool string 10 and upper surfaces 53a of the lug 53 of the snap rings 52.
Further retraction of the wireline 12 brings the protruding nose 47 of the shuttle member 40 into contact with an underside of the trigger member 64. The resulting upward displacement of the trigger member 64 disengages the release pins 86 from the sides of the flapper valve 82. The flapper valve 82 is consequently released and urged to close under the action of the torsion spring (not shown). However, at this point in the sequence the flapper valve 82 is prevented from closing fully due to the presence of the wireline 12 in the wireline passage 80.
As shown in Figure 8, further retraction of the wireline 12 brings an upper surface 96 of the release ring 54 into contact with a lower surface 98 of the upper body member 60. Since the upper body member 60 is rigidly axially constrained relative to the upper lubricator section 24a, this contact acts as an end stop to the upward movement of the release ring 54, the shuttle member 40 and the tool string 10. This end stop is provided through a solid, simple load path for robust operation.
Further retraction of the wireline 12 may result in tensile failure of the wireline 12 which will most likely occur in the vicinity of a rope socket 100 of the toolstring 10 as shown in Figure 9. The combined action of gravity and compression within the spring 42 then act to push the shuttle member 40 and toolstring 10 downwards. This travel continues until a shoulder 93 of the fishing neck profile 94 of the toolstring 10 abuts the upper surfaces 53a of the snap rings 52 whereupon the toolstring 10 is axially supported in position and prevented from falling back down the well. With the continued application of tension on the upper part of the broken wireline 12, the upper part of the broken wireline 12 is pulled through the stuffing box 22 and the flapper valve 82 closes under the action of the torsion spring (not shown) to seal the wireline passage 80 thereby effecting containment of wellbore fluids.
One skilled in the art will appreciate that various modifications may be made to the wireline device 20. For example, the retaining ring 54 may be downwardly biased with respect to the upper body member 60 so that the tabs 55 of the release ring 54 normally extend between the lugs 53 of the snap rings 52 so as to displace the lugs 53 of the snap rings 52 to an outer or expanded condition. The wireline device 20 may include one or more resilient members in the form of one or more compression springs (not shown) located between the upper surface 96 of the release ring 54 and the lower surface 98 of the upper body member 60 for this purpose.
The main compression spring 42 may be replaced by a resilient member of any kind. For example, the main compression spring 42 may be replaced by an elastomeric member such as an elastomeric sleeve. The resilient member may comprise a plurality of voids. The resilient member may comprise a sponge.
The resilient member may comprise an inwardly biased resilient ring or sleeve such as an inwardly biased split ring or an inwardly biased c-ring which is configured to engage a conical outer surface of a base member. Such an inwardly biased resilient ring may provide an increasing resistance as the ring moves in a direction opposite to the direction of a taper of the conical outer surface of the base member.
The resilient member may comprise a sleeve having one or more resilient collet fingers. The base member may define one or more features on an outer surface thereof. For example, the base member may define one or more recesses and/or one or more projections on an outer surface thereof. The collet fingers of the sleeve may be configured for engagement with the one or more features on the outer surface of the base member.
Each collet finger may be naturally unbiased. During relative motion between the sleeve and the base member, the collet fingers of the sleeve may engage the one or more projections of defined on an outer surface of the base member to thereby displace each collet finger from the its natural unbiased state and induce an inward bias in the collet finger. This may provide an increase in resistance to relative motion between the sleeve and the base member. This may provide multiple peaks in resistance to relative motion between the sleeve and the base member which may translate into multiple peaks in wireline tension which, if monitored, may serve as warnings to a wireline winch operator of the approach of a downhole tool to the wireline device. Each collet finger may be inwardly biased. During relative motion between the sleeve and the base member, the collet fingers of the sleeve may engage one or more recesses and/or one or more projections defined on the outer surface of the base member to thereby provide an increase in resistance to relative motion between the sleeve and the base member. This may provide multiple peaks in resistance to relative motion between the sleeve and the base member which may translate into multiple peaks in wireline tension which, if monitored, may serve as warnings to a wireline winch operator of the approach of a downhole tool to the wireline device.
The resilient member may comprise an outwardly biased resilient ring or sleeve. The outwardly biased resilient ring may engage an inner surface of a tubular base member.
The resilient member may comprise a sleeve having one or more resilient collet fingers. The base member may define one or more features on an inner surface thereof. For example, the base member may define one or more recesses and/or one or more projections on an inner surface thereof. The collet fingers of the sleeve may be configured for engagement with the one or more features on the inner surface of the base member.
Each collet finger may be naturally unbiased.
Each collet finger may be outwardly biased.
The resilient member may comprise a damper. The damper may comprise a piston. The piston may act against a fluid which is in fluid communication with an accumulator.
Rather than comprising a latch arrangement having a retaining member and a release member, the latch arrangement may comprise a retaining member without a release member. The latch arrangement may comprise a retaining member which may be configured to be displaced radially outwardly under the action of a downhole tool in response to a force transferred from the downhole tool. This may induce or increase an inward bias in the retaining member in response to a force transferred from the downhole tool, for example as the downhole tool is pulled upwardly against the retaining member. An upper surface of the downhole tool may be configured for this purpose. Alternatively, the downhole tool may engage a carriage member as the downhole tool is pulled upwardly and may urge the carriage member against the retaining member.
The retaining member may be configured so as to snap back under a fishing neck shoulder of the downhole tool after further upward motion of the downhole tool. The retaining member may comprise a sleeve having one or more resilient collet fingers. Each collet finger may be configured to engage a fishing neck shoulder of a downhole tool.
The retaining member may be configured such that each collet finger may be displaced radially outwardly in response to a force transferred from the downhole tool to the collet finger.
Each collet finger may be configured to snap back under a fishing neck shoulder of the downhole tool after movement of the downhole tool relative to the collet finger.
Each collet finger may be naturally unbiased.
Each collet finger may be inwardly or outwardly biased.

Claims

1. A downhole tool motion resistor arrangement for use in indicating a position of a downhole tool comprising:
a base member;
a carriage member for engaging a downhole tool, the carriage member being moveable relative to the base member; and
a resilient member for resisting movement of the carriage member relative to the base member when a downhole tool is pulled into engagement with the carriage member using a wireline which is connected to the downhole tool and which extends through the carriage member.
2. A downhole tool motion resistor arrangement according to claim 1 , wherein the resilient member comprises a compression spring extending between the carriage member and the body member.
3. A downhole tool motion resistor arrangement according to claim 1 or 2, wherein the resilient member comprises an elastomeric member.
4. A downhole tool motion resistor arrangement according to any preceding claim, wherein the base member is tubular.
5. A downhole tool motion resistor arrangement according to any preceding claim, wherein the base member is configured to permit a downhole tool to extend at least partially therethrough.
6. A downhole tool motion resistor arrangement according to claim 4 or 5, wherein the carriage member comprises a receptacle portion for engaging the downhole tool, the receptacle portion being arranged to move within the base member.
7. A downhole tool motion resistor arrangement according to claim 6, wherein the receptacle portion of the carriage member defines an aperture which is configured to permit a wireline to extend therethrough.
8. A downhole tool motion resistor arrangement according to any preceding claim, wherein the carriage member comprises a base ring which is configured to move over an outer surface of the base member.
9. A downhole tool motion resistor arrangement according to any preceding claim, comprising a wireline tension sensor.
10. A downhole tool motion resistor arrangement according to any preceding claim, wherein the downhole tool motion resistor arrangement is configured for installation within a housing comprising a wireline lubricator housing or a stuffing box housing.
1 1. A latch arrangement for latching a downhole tool:
an inwardly biased retaining ring; and
a release member which is moveable relative to the retaining ring between a first position in which the release member prevents the retaining ring from collapsing inwardly and a second position in which the retaining ring is permitted to collapse inwardly around a downhole tool to at least partially restrict movement of the downhole tool through the retaining ring.
12. A latch arrangement according to claim 1 1 , wherein the retaining ring is split.
13. A latch arrangement according to claim 12, wherein the retaining ring comprises a pair of opposing lugs, each lug being configured to engage a downhole tool.
14. A latch arrangement according to any of claims 1 1 to 13, wherein the release member comprises a tab which is configured for engagement with the lugs of the retaining ring to prevent the retaining ring from collapsing inwardly around a downhole tool when the release member is in the first position.
15. A latch arrangement according to claim 14, wherein the tab is configured for disengagement from the lugs of the retaining ring to permit the retaining ring to collapse inwardly around a downhole tool when the release member is in the second position.
16. A latch arrangement according to any of claims 1 1 to 15, wherein the latch arrangement is configured to prevent movement of a downhole tool relative to the retaining ring in at least one direction when the retaining ring is collapsed inwardly around the downhole tool.
17. A latch arrangement according to any of claims 1 1 to 16, wherein the latch arrangement is configured to prevent movement of a feature of the downhole tool relative to a complementary feature of the retaining ring when the retaining ring is collapsed inwardly around the downhole tool.
18. A latch arrangement according to any of claims 1 1 to 17, comprising a body member, wherein the retaining ring is axially fixed relative to the body member and the release member is axially moveable relative to the body member.
19. A latch arrangement according to any of claims 1 1 to 18, comprising a plurality of retaining rings.
20. A latch arrangement according to any of claims 1 1 to 19, wherein each retaining ring is configured to engage a profile of a downhole tool.
21. A latch arrangement according to claim 20, wherein each retaining ring is configured to engage a fishing neck profile of a downhole tool.
22. A latch arrangement according to any of claims 1 1 to 21 , wherein the release member is moveable from the first position to the second position in response to a force communicated from a downhole tool to the release member.
23. A latch arrangement according to claim 22, wherein the release member is moveable from the first position to the second position in response to a force communicated from the downhole tool to the release member indirectly through an intermediate member.
24. A latch arrangement according to claim 23, wherein the intermediate member comprises a carriage member which is configured to move with the downhole tool.
25. A latch arrangement according to any of claims 1 1 to 24, wherein the release member is biased towards the first position.
26. A latch arrangement according to any of claims 1 1 to 25, wherein the latch arrangement is configured for installation within a housing comprising a wireline lubricator housing or a stuffing box housing.
27. A seal arrangement for use in sealing a wellbore comprising:
a valve body defining an aperture for a wireline;
a valve which is biased towards a closed position in which the valve seals the aperture defined by the valve body; and
a release member which is moveable relative to the valve between a first position in which the release member prevents the valve from moving towards the closed position and a second position in which the valve is permitted to move towards the closed position.
28. A seal arrangement according to claim 27, wherein the release member is moveable relative to the valve from the first position to the second position in response to a force communicated from a downhole tool to the release member.
29. A seal arrangement according to claim 28, wherein the release member is moveable relative to the valve from the first position to the second position in response to a force communicated from a downhole tool to the release member via an intermediate member.
30. A seal arrangement according to claim 29, wherein the intermediate member comprises a carriage member which is configured to move with the downhole tool.
31. A seal arrangement according to any of claims 27 to 30, wherein the release member is biased towards the first position.
32. A seal arrangement according to any of claims 27 to 31 , wherein the seal arrangement is configured for installation within a housing comprising a wireline lubricator housing or a stuffing box housing.
33. A wireline device comprising at least one of:
the downhole tool motion resistor arrangement according to any of claims 1 to
10;
the latch arrangement according to any of claims 1 1 to 26; and
the seal arrangement according to any of claims 27 to 32.
34. A wireline system comprising:
a housing; and
at least one of:
the downhole tool motion resistor arrangement according to any of claims 1 to 10;
the latch arrangement according to any of claims 1 1 to 26; and the seal arrangement according to any of claims 27 to 32.
35. A wireline system according to claim 34, wherein the housing is configured for installation at a head of an oil or gas well.
36. A wireline system according to claim 34 or 35, wherein the housing comprises a wireline lubricator housing or a stuffing box housing.
37. A wireline system according to any of claims 34 to 36, comprising a downhole tool and a wireline connecting the downhole tool to surface.
38. A method of restricting motion of a downhole tool for use in indicating a position of the downhole tool, the method comprising:
pulling a downhole tool into engagement with a carriage member using a wireline which is connected to the downhole tool and which extends through the carriage member; and
resisting movement of the carriage member relative to a base member.
39. A method according to claim 38 comprising:
sensing tension in the wireline.
40. A method for latching a downhole tool comprising: locating a release member relative to an inwardly biased retaining ring so as to prevent the retaining ring from collapsing inwardly; and
moving the release member relative the retaining ring so as to permit the retaining ring to collapse inwardly around a downhole tool to at least partially restrict movement of the downhole tool through the retaining ring.
41. A method according to claim 40, wherein moving the release member relative to the retaining ring comprises communicating a force from the downhole tool to the release member so as to move the release member relative the retaining ring.
42. A method according to claim 41 , wherein moving the release member relative to the retaining ring comprises applying a tensile force to the downhole tool through a wireline which is connected to the downhole tool and which extends through the release member and the retaining ring so as to communicate the force from the downhole tool to the release member.
43. A method for use in sealing a wellbore comprising:
locating a release member relative to a valve so as to prevent the valve from moving under the action of a bias towards a closed position in which the valve seals an aperture defined by a valve body; and
moving the release member relative to the valve so that the valve is permitted to move to the closed position under the action of the bias.
44. A method according to claim 43, wherein moving the release member relative to the valve comprises communicating a force from a downhole tool to the release member so as to move the release member relative to the valve
45. A method according to claim 44, comprising:
applying a tensile force to the downhole tool through a wireline which is connected to the downhole tool and which extends through the aperture defined by the valve body so as to communicate the force from the downhole tool to the release member.
46. A method for use in wireline operations comprising at least one of:
a method of restricting motion of a downhole tool according to claim 38 or 39; a method for latching a downhole tool according to any of claims 40 to 42; and a method for sealing a wellbore according to any of claims 43 to 45.
47. A method for improving well safety comprising at least one of:
a method of restricting motion of a downhole tool according to any of claims 41 to 43;
a method for latching a downhole tool according to any of claims 44 to 46; and a method for sealing a wellbore according to any of claims 43 to 45.
48. A method for improving well safety, comprising:
inserting the wireline device according to claim 33 into a housing.
49. A method for improving well safety according to claim 48, wherein the housing is configured for installation at a head of an oil or gas well.
50. A method for improving well safety according to claim 48 or 49, wherein the housing comprises a wireline lubricator housing or a stuffing box housing
51. A method for improving well safety according to any of claims 47 to 50, comprising: applying a tensile force to a wireline which is connected to the downhole tool and which passes through the wireline device so as to bring the downhole tool into engagement with the wireline device and communicate a force therebetween.
52. A method for use in retrieving a downhole tool from a wellbore, comprising:
inserting the latch arrangement according to any of claims 1 1 to 26 into a housing; and
using the latch arrangement to retain a downhole tool relative to the housing after breakage of a wireline connected to the downhole tool.
53. A method according to claim 52, comprising removing the downhole tool from the housing.
54. A method according to claim 52 or 53, wherein the housing is configured for installation at a head of an oil or gas well.
55. A method according to any of claims 52 to 54, wherein the housing comprises a wireline lubricator housing or a stuffing box housing.
56. A method of providing an indication of the position of a wireline toolstring as it is being pulled into a stuffing box of a wireline lubricator, said method comprising:
providing a base member through which the wireline passes, said base member being dimensioned and proportioned to receive said toolstring;
providing a carriage member moveable relative to said base member;
coupling said carriage member to a resilient member
coupling said wireline to an indicator display for monitoring tension in said wireline; and
as said toolstring is withdrawn into said stuffing box, engaging said toolstring with the carriage member to apply force to said resilient member which resists said force to cause a change in tension in said wireline which is monitorable on said indicator display.
57. A system for providing an indication of the position of a wireline toolstring as it is pulled into a stuffing box of a wireline lubricator, said system comprising:
a base member for receiving said toolstring and through which said wireline passes, said base member being located in said stuffing box;
a carriage member moveable relative to said base member;
a resilient member coupled to said base member for resisting motion of said carriage member; and
an indicator for providing an indication of increased tension in said wireline when a toolstring is pulled into engagement with said carriage member and movement of said toolstring is resisted by said resilient member.
58. A wireline lubricator safety system comprising:
a downhole tool motion resistor arrangement for use in indicating a position of a downhole tool relative to a stuffing box of a wireline lubricator;
a latch arrangement for latching a downhole tool within the stuffing box; and a seal arrangement for use in sealing a wireline aperture in a wall of the stuffing box in the event of wireline failure.
59. A wireline lubricator safety system according to claim 58, wherein the downhole tool motion resistor arrangement comprises:
a base member;
a carriage member for engaging a downhole tool, the carriage member being moveable relative to the base member; and
a resilient member for resisting movement of the carriage member relative to the base member when a downhole tool is pulled into engagement with the carriage member using a wireline which is connected to the downhole tool and which extends through the carriage member.
60. A wireline lubricator safety system according to claim 58 or 59, wherein the latch arrangement comprises:
an inwardly biased retaining ring; and
a release member which is moveable relative to the retaining ring between a first position in which the release member prevents the retaining ring from collapsing inwardly and a second position in which the retaining ring is permitted to collapse inwardly around a downhole tool to at least partially restrict movement of the downhole tool through the retaining ring.
61. A wireline lubricator safety system according to any of claims 58 to 60, wherein the seal arrangement comprises:
a valve body defining an aperture for a wireline;
a valve which is biased towards a closed position in which the valve seals the aperture defined by the valve body; and
a release member which is moveable relative to the valve between a first position in which the release member prevents the valve from moving towards the closed position and a second position in which the valve is permitted to move towards the closed position.
62. A latch arrangement for latching a downhole tool, comprising:
a retaining member comprising a sleeve having one or more resilient collet fingers which are configured to engage a fishing neck shoulder of a downhole tool, wherein the sleeve is configured such that each collet finger is displaced radially outwardly in response to a force transferred from the downhole tool to the collet finger and each collet finger is configured to snap back under a fishing neck shoulder of the downhole tool after movement of the downhole tool relative to the collet finger.
PCT/GB2014/050637 2013-03-05 2014-03-04 Wireline device WO2014135861A2 (en)

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GBGB1303933.4A GB201303933D0 (en) 2013-03-05 2013-03-05 Wireline lubricator safety system
GB1303933.4 2013-03-05

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WO2014135861A3 WO2014135861A3 (en) 2015-02-19

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