EP2647789A2 - Procédés et appareil pour la cimentation de puits - Google Patents

Procédés et appareil pour la cimentation de puits Download PDF

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Publication number
EP2647789A2
EP2647789A2 EP13162620.2A EP13162620A EP2647789A2 EP 2647789 A2 EP2647789 A2 EP 2647789A2 EP 13162620 A EP13162620 A EP 13162620A EP 2647789 A2 EP2647789 A2 EP 2647789A2
Authority
EP
European Patent Office
Prior art keywords
liner
well
anchor
sleeve
assembly
Prior art date
Legal status (The legal status 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 status listed.)
Withdrawn
Application number
EP13162620.2A
Other languages
German (de)
English (en)
Other versions
EP2647789A3 (fr
Inventor
Michael J. Harris
Martin Alfred Stulberg
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Schlumberger Technology BV
Original Assignee
Key Energy Services LLC
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
Priority claimed from US13/506,227 external-priority patent/US9303477B2/en
Application filed by Key Energy Services LLC filed Critical Key Energy Services LLC
Publication of EP2647789A2 publication Critical patent/EP2647789A2/fr
Publication of EP2647789A3 publication Critical patent/EP2647789A3/fr
Withdrawn legal-status Critical Current

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    • 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
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like in wells
    • 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
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
    • E21B33/14—Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/12—Valve arrangements for boreholes or wells in wells operated by movement of casings or tubings
    • 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
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/06—Sleeve valves

Definitions

  • the present invention relates to methods and tools for cementing liners in oil and gas wells and, more particularly, methods and tools for hanging, sealing, and cementing liners in a single downhole trip.
  • Hydrocarbons such as oil and gas
  • the formations typically consist of a porous layer, such as limestone and sands, overlaid by a nonporous layer. Hydrocarbons cannot rise through the nonporous layer, and thus, the porous layer forms a reservoir in which hydrocarbons are able to collect.
  • a well is drilled through the earth until the hydrocarbon bearing formation is reached. Hydrocarbons then are able to flow from the porous formation into the well.
  • a drill bit is attached to a series of pipe sections referred to as a drill string.
  • the drill string is suspended from a derrick and rotated by a motor in the derrick.
  • a drilling fluid or "mud" is pumped down the drill string, through the bit, and into the well bore. This fluid serves to lubricate the bit and carry cuttings from the drilling process back to the surface.
  • the drill string is extended by adding more pipe sections.
  • the casing Once the casing is cemented in place, it is perforated at the level of the oil bearing formation so oil can enter the cased well. If necessary, various completion processes are performed to enhance the ultimate flow of oil from the formation.
  • the drill string is withdrawn and replaced with a production string. Valves and other production equipment are installed in the well so that the hydrocarbons may flow in a controlled manner from the formation, into the cased well bore, and through the production string up to the surface for storage or transport.
  • liner anchors or "hangers” have included various forms of mechanical slip mechanisms that are connected to the liner.
  • the slips themselves typically are in the form of cones or wedges having teeth or roughened surfaces.
  • An installation tool is used to position the anchor in place and drive the slips from their initial, unset position, into a set position where they are able to bite into and engage the existing casing.
  • the setting mechanisms typically are either hydraulic, which are actuated by increasing the hydraulic pressure within the tool, or mechanical, which are actuated by rotating, lifting, or lowering the tool, or some combination thereof.
  • Those types of mechanical hangers typically require a separate annular seal or "packer” in order to seal the liner to the casing.
  • U.S. Pat. 7,225,880 to B. Braddick discloses an expandable liner.
  • the liner is set within the casing by actuating an expander that radially expands the upper portion of the liner into engagement with a casing. Once expanded, the expanded portion of the liner provides a seal that prevent fluids from flowing between the liner and casing.
  • the tubular expander is not withdrawn from the liner after the expandable portions have been expanded. It is designed to remain in the liner and provide radial support for the expanded liner.
  • U.S. Pat. 7,387,169 to S. Harrell et al. also discloses various methods of hanging liners and tying in production tubes by expanding a portion of the tubular via, e.g. , a rotating expander tool. All such methods rely on creating direct contact and seals between the expanded portion of the tubular and the existing casing.
  • the liner necessarily is fabricated from relatively ductile metals. Such metals typically have lower yield strengths, thus limiting the amount of weight and, thereby, the length of liner that may be supported in the existing casing. Shorter liner lengths, in deeper wells, may require the installation of more liner sections, and thus, significantly greater installation costs. This problem is only exacerbated by the fact that expansion creates a weakened area between the expanded portion and the unexpanded portion of the liner. This weakened area is a potential failure area which can damage the integrity of the liner.
  • the liner portion tends to relax to a greater degree than if the liner were made of harder metal. This may be acceptable when the load to be supported is relatively small, such as a short patch section. It can be a significant limiting factor, however, when the expanded liner portion is intended to support long, heavy liners.
  • the liner necessarily must have an external diameter smaller than the internal diameter of the casing into which it will be inserted.
  • This clearance especially for deep wells where a number of progressively smaller liners will be hung, preferably is as small as possible so as to allow the greatest internal diameter for the liner. Nevertheless, if the tool is to be passed reliably through existing casing, this clearance is still relatively large, and therefore, the liner portion is expanded to a significant degree.
  • the liner may not be possible to fabricate the liner from more corrosion resistant alloys.
  • Such alloys typically are harder and less ductile. In general, they may not be expanded, or expanded only with much higher force, to a degree sufficient to close the gap and grip the existing casing.
  • expandable liners also create tradeoffs in cementing the liner. Because they establish a seal between the liner and existing casing, once an expandable liner is fully set fluids displaced up the annulus as cement is injected, the so-called “returns,” can no longer flow around the liner on their way to the surface. Thus, some expandable liners, such as those disclosed in Braddick '880, are not set until after cementing has been completed.
  • expandable liners partially expand the liner in such a way as to leave vertical return flow paths between the liner and casing.
  • U.S. Pat. 7,441,606 to P. Maguire disclose expandable liners which are expanded in two stages. In the first stage, the liner is partially expanded so as to engage a casing wall, but not completely seal the annulus around the liner. Vertical flow paths are left to allow returns from a cementing operation to flow around the liner to the casing above. After cementing is complete, the liner is fully expanded around its entire circumference and a separate annular seal is set.
  • expandable liners such as liners disclosed in Baugh '677
  • Baugh '677 are partially expanded to create an initial seal before cementing.
  • a flow path for returns is created by providing a port in the expandable liner and passageways through the swage which is used to expand the liner.
  • the swage remains engaged with the liner, and returns entering the liner through the port flow through the passageways in the swage.
  • the swage is actuated to finish expanding the liner, including the area around the port, thus sealing off the port.
  • Baugh '677 also discloses a similar hanger where, instead of sealing the port by expanding the liner around it, a slidable cover is provided on the exterior of the liner. The cover is actuated to shut the port after cementing has been completed, but there is no disclosure of any mechanism or method of doing so. In any event, the swage remains engaged with the liner and is not withdrawn until after cementing is complete and the port is shut.
  • the subject invention provides for novel hydraulic actuators and hydraulic setting assemblies which may be used in downhole, oil and gas well tools.
  • the novel hydraulic actuators include a cylindrical mandrel and an annular stationary sealing member connected to the mandrel.
  • a hydraulic cylinder is slidably supported on the mandrel and stationary sealing member and is releasably fixed in position on the mandrel.
  • the stationary sealing member divides the interior of the cylinder into a bottom hydraulic chamber and a top hydraulic chamber.
  • An inlet port provides fluid communication into the bottom hydraulic chamber, and an outlet port provides fluid communication into the top hydraulic chamber.
  • the novel actuators further include a balance piston.
  • the balance piston is slidably supported within the top hydraulic chamber of the actuator, preferably on the mandrel.
  • the balance piston includes a passageway extending axially through the balance piston. Fluid communication through the piston and between its upper and lower sides is controlled by a normally shut valve in the passageway.
  • the balance piston is able to slide in response to a difference in hydrostatic pressure between the outlet port, which is on one side of the balance piston, and the portion of the top hydraulic chamber that is on the bottom side of the balance piston.
  • the novel actuators therefore, are less susceptible to damage caused by differences in the hydrostatic pressure inside and outside of the actuator.
  • the balance piston of the novel actuators is able to prevent the ingress of debris into the actuator.
  • the normally shut valve in the novel actuators preferably is a rupturable diaphragm.
  • Other preferred embodiments include a pressure release device allowing controlled release of pressure from the top hydraulic cylinder.
  • the subject invention provides for anchor assemblies that are intended for installation within an existing conduit.
  • the novel anchor assemblies comprise a nondeformable mandrel, an expandable metal sleeve, and a swage.
  • the expandable metal sleeve is carried on the outer surface of the mandrel.
  • the swage is supported for axial movement across the mandrel outer surface from a first position axially proximate to the sleeve to a second position under the sleeve. The movement of the swage from the first position to the second position expands the sleeve radially outward into contact with the existing conduit.
  • the swage of the novel anchor assemblies has an inner diameter substantially equal to the outer diameter of the mandrel and an outer diameter greater than the inner diameter of the expandable metal sleeve.
  • the mandrel of the novel anchor assemblies preferably is fabricated from high yield metal alloys and, most preferably, from corrosion resistant high yield metal alloys.
  • the novel anchor assemblies preferably have a load capacity of at least 100,000 lbs, more preferably, a load capacity of at least 250,000 lbs, and most preferably a load capacity of at least 500,000 lbs.
  • the novel anchors thus are able to support the weight of liners and other relative heavy downhole tools and well components.
  • the novel anchor assemblies are intended to be used in combination with a tool for installing the anchor in a tubular conduit.
  • the anchor and tool assembly comprises the anchor assembly, a running assembly, and a setting assembly.
  • the running assembly releasably engages the anchor assembly.
  • the setting assembly is connected to the running assembly and engages the swage and moves it from its first position to its second position.
  • the mandrel and swage provide radial support for the sleeve, thereby enhancing the load capacity of the novel anchors.
  • the novel anchors may achieve, as compared to expandable liners, equivalent load capacities with a shorter sleeve, thus reducing the amount of force required to set the novel anchors.
  • the mandrel of the novel anchor assemblies is substantially nondeformable and may be made from harder, stronger, more corrosion resistant metals.
  • novel clutch mechanisms which may be and preferably are used in the mandrel of the novel anchor and tool assemblies and in other sectioned conduits and shafts used to transmit torque. They comprise shaft sections having threads on the ends to be joined and prismatic outer surfaces adjacent to their threaded ends. A threaded connector joins the threaded ends of the shaft sections. The connector has axial splines. A pair of clutch collars is slidably supported on the prismatic outer surfaces of the shaft sections. The clutch collars have prismatic inner surfaces that engage the prismatic outer surfaces of the shaft sections and axial splines that engage the axial splines on the threaded connector.
  • the novel clutch mechanisms also comprise recesses adjacent to the mating prismatic surfaces that allow limited rotation of the clutch collars on the prismatic shaft sections to facilitate engagement and disengagement of the mating prismatic surfaces.
  • the novel clutch mechanisms provide reliable transmission of large amounts of torque through sectioned conduits and other drive shafts without damaging the threaded connections.
  • Yet other aspects of the subject invention provide for novel methods of installing and cementing a liner in a well, novel flow diverters, and novel liner assemblies.
  • One such embodiment provides a method for installing and cementing a liner in a well. The method comprises running the liner into the well on a work string, anchoring the liner to an existing casing in the well, and sealing the liner to the existing casing. The seal substantially prevents direct fluid flow around the liner to the existing casing from the annulus between the liner and the well. The liner then is released from the work string and the work string raised to provide a flow path inside the liner. Cement is injected into the liner and allowed to flow into the annulus.
  • Fluid displaced from the annulus by the cement is returned through a port in the liner, the port being disposed downhole of the seal, and via the flow path established by the releasing of the liner and the raising of the work string. The work string then is pulled out of the well.
  • the installation tool is actuated to set the anchor to secure and seal the liner in an existing casing of the well and thereby substantially preventing direct fluid flow around the liner assembly from the annulus to the existing casing.
  • the installation tool then is disengaged and raised away from the anchor to provide a path for fluid flow through the anchor and around the conduit and cement is injected through the conduit into the liner and annulus. Fluid displaced by the cement is allowed to flow from the annulus into the existing casing via the diverter port and the path provided by the disengaging and raising the installation tool.
  • the liner assembly comprises a tubular liner and an anchor connected to the liner, the anchor being in an unset position in which fluid is able to flow around the liner assembly in the annulus between the liner assembly and the well.
  • the liner assembly also comprises an installation tool releasably engaging the anchor, a return flow diverter connected to the liner below the anchor and having a port allowing fluid communication from the annulus into the flow diverter, a tubular conduit extending through the anchor, installation tool, and the flow diverter and into the liner; and a one-way seal mounted between the tubular conduit and the liner or the flow diverter above the flow diverter port.
  • the one-way seal allows fluid flow upward through the one-way seal and prevents fluid flow downward past the one-way seal.
  • the installation tool is actuated to set the anchor, the anchor securing and sealing the liner in an existing casing of the well and thereby substantially preventing direct fluid flow around the liner assembly from the annulus to the existing casing.
  • the seal established by setting the anchor then is pressure tested.
  • the return flow diverter comprises a cylindrical body adapted for installation in a well as part of the liner.
  • the cylindrical body has a fluid port therein adapted to allow fluids displaced by a cementing operation to flow from an annulus between the liner and the well into the cylindrical body.
  • the return flow diverter also comprises a cover supported on the cylindrical body for movement from an open position, in which the port is open, to a closed position, in which the port is closed by the cover, a transmission disposed within the cylindrical body and defining a cylindrical passageway adapted to accommodate a tubular conduit.
  • the tubular conduit is adapted to extend through the cylindrical body and inject cement into the liner below the body and the transmission is releasably connected to the cover and operable to move the cover from the open position to the closed position.
  • novel liner assemblies comprising such return flow diverters and further comprising an anchor adapted to secure the liner assembly in the well and having an unset position in which fluid is able to flow around the liner assembly when the liner assembly is run into a well, and an installation tool releasably engaging the anchor and adapted to set the anchor in an existing casing of the well.
  • Still other embodiments of the invention provide for a liner assembly for allowing return flow during cementing of the liner assembly in a well.
  • the liner assembly comprises an anchor adapted to secure and seal the liner assembly in the well.
  • the anchor comprises a nondeformable cylindrical mandrel, an expandable metal sleeve carried on the outer surface of the mandrel, and a cylindrical swage supported for axial movement across the mandrel outer surface from a first position axially proximate to the sleeve to a second position under the sleeve; wherein the movement of the swage expands the sleeve radially outward and anchors and seals the liner assembly to an existing casing in the well.
  • the liner assembly further comprises an installation tool releasably engaging the anchor and adapted to actuate the swage and a flow diverting tool.
  • the flow diverting tool has a cylindrical body defining a port adapted to allow fluids displaced by a cementing operation to flow from an annulus between the liner and the well into the tool, a cover mounted on the body, the cover movable from an open position, in which the port is open, to a closed position, in which the port is closed, and a transmission operable to move the cover from the open position to the closed position.
  • an aspect of the present invention provides a method for installing and cementing a liner in a well, said method comprising running said liner into said well on a work string, anchoring said liner to an existing casing in said well sealing said liner to said existing casing, said seal substantially preventing direct fluid flow around said liner to said existing casing from the annulus between said liner and said well releasing said liner from said work string; raising said work string to provide a flow path inside said liner; injecting cement into said liner and allowing said cement to flow into said annulus returning fluid displaced from said annulus by said cement through a port in said liner, said port being disposed downhole of said seal, and said flow path established by said releasing of said liner and said raising of said work string; and pulling said work string out of said well.
  • said method further comprises pressure testing said liner seal by increasing the fluid pressure in said existing casing.
  • Another aspect of the present invention provides a method for installing and cementing a liner in a well, said method comprising running a liner assembly into said well, said liner assembly comprising a tubular liner, an anchor connected to said liner, said anchor being in an unset position in which fluid is able to flow around said liner assembly in the annulus between said liner assembly and said well, an installation tool releasably engaging said anchor, a return flow diverter connected to said liner below said anchor and having a port allowing fluid communication from said annulus into said flow diverter, and a tubular conduit extending through said anchor, installation tool, and said flow diverter and into said liner actuating said installation tool to set said anchor, said anchor securing and sealing said liner in an existing casing of said well and thereby substantially preventing direct fluid flow around said liner assembly from said annulus to said existing casing disengaging and raising said installation tool away from said anchor to provide a path for fluid flow through said anchor and around said conduit injecting cement through said conduit into said liner and
  • said anchor comprises an expandable tubular.
  • said anchor comprises an expandable sleeve.
  • said anchor comprises a nondeformable cylindrical mandrel, an expandable metal sleeve carried on the outer surface of said mandrel, and a cylindrical swage supported for axial movement across said mandrel outer surface from a first position axially proximate to said sleeve to a second position under said sleeve, wherein said movement of said swage expands said sleeve radially outward and anchors and seals said liner assembly to said existing casing.
  • said liner assembly includes a seal for sealing said conduit in said liner downhole of said return flow diverter and substantially preventing direct flow of fluid around said conduit.
  • said conduit seal is preset.
  • said method comprises setting said conduit seal.
  • said method further comprises pressure testing said liner seal by increasing the fluid pressure in said existing casing.
  • return flow diverter comprises a cylindrical body defining a port adapted to allow fluids displaced by a cementing operation to flow from an annulus between said liner and said well into said tool, a cover mounted on said body, said cover movable from an open position, in which said port is open, to a closed position, in which said port is closed, and a transmission operable to move said cover from said open position to said closed position.
  • Another aspect of the present invention provides a method for installing a liner in a well, said method comprising running a liner assembly into said well, said liner assembly comprising a tubular liner, an anchor connected to said liner, said anchor being in an unset position in which fluid is able to flow around said liner assembly in the annulus between said liner assembly and said well, an installation tool releasably engaging said anchor, a return flow diverter connected to said liner below said anchor and having a port allowing fluid communication from said annulus into said flow diverter, a tubular conduit extending through said anchor, installation tool, and said flow diverter and into said liner; and a one-way seal mounted between said tubular conduit and said liner or said flow diverter above said flow diverter port and allowing fluid flow upward through said one-way seal and preventing fluid flow downward past said one-way seal actuating said installation tool to set said anchor, said anchor securing and sealing said liner in an existing casing of said well and thereby substantially preventing direct fluid flow around said line
  • a yet further aspect of the present invention provides a return flow diverter adapted to allow return flow during cementing of a liner for a well, said return flow diverter comprising a cylindrical body adapted for installation in a well as part of said liner, said cylindrical body having a fluid port therein adapted to allow fluids displaced by a cementing operation to flow from an annulus between said liner and said well into said cylindrical body a cover supported on said cylindrical body for movement from an open position, in which said port is open, to a closed position, in which said port is closed by said cover a transmission disposed within said cylindrical body and defining a cylindrical passageway adapted to accommodate a tubular conduit, said tubular conduit being adapted to extend through said cylindrical body and inject cement into said liner below said body, said transmission being releasably connected to said cover and operable to move said cover from said open position to said closed position.
  • said flow diverter comprises a tubular conduit, said tubular conduit being disposed in said cylindrical passageway and extending through said cylindrical body, and wherein said transmission is slidably supported on said tubular conduit.
  • said cover is a cylindrical sleeve supported for axial movement across the outer surface of said cylindrical body from said open position to said closed position.
  • said cover is a cylindrical sleeve supported for axial movement across the inner surface of said cylindrical body from said open position to said closed position.
  • said cover is a cylindrical sleeve supported for rotational movement from said open position to said closed position.
  • said transmission comprises a cylindrical carriage, said carriage being adapted to receive and be supported on said tubular conduit such that said tubular conduit is capable of translational movement therein, and a collet assembly, said collet assembly being releasably engaged with said carriage and releasably engaging said cover.
  • said cylindrical body defines one or more slots
  • said cover is a cylindrical sleeve supported for axial movement across the outer surface of said cylindrical body from said open position to said closed position
  • said transmission comprises a cylindrical carriage adapted to support said collet assembly, said collet assembly being releasably engaged with said carriage and releasably engaging said cover through said slots.
  • said flow diverter comprises a one-way seal mounted above said fluid ports.
  • a yet further aspect of the present invention provides a liner assembly adapted to allow return flow during cementing of said liner assembly in a well, said liner assembly comprising an anchor adapted to secure said liner assembly in said well and having an unset position in which fluid is able to flow around said liner assembly when said liner assembly is run into a well, an installation tool releasably engaging said anchor and adapted to set said anchor in an existing casing of said well, and the flow diverting tool.
  • said assembly comprises a tubular conduit adapted for injecting cement into said liner assembly.
  • a yet further aspect of the present invention provides a liner assembly for allowing return flow during cementing of said liner assembly in a well, said liner assembly comprising an anchor adapted to secure and seal said liner assembly in said well, said anchor comprising; a nondeformable cylindrical mandrel, an expandable metal sleeve carried on the outer surface of said mandrel, and a cylindrical swage supported for axial movement across said mandrel outer surface from a first position axially proximate to said sleeve to a second position under said sleeve; wherein said movement of said swage expands said sleeve radially outward and anchors and seals said liner assembly to an existing casing in said well, an installation tool releasably engaging said anchor and adapted to actuate said swage; and a flow diverting tool having a cylindrical body defining a port adapted to allow fluids displaced by a cementing operation to flow from an annulus between said liner and
  • said assembly comprises a tubular conduit adapted for injecting cement into said liner assembly.
  • the liner assemblies of the subject invention may be used to install novel liners within an existing conduit. They generally comprise liner tubulars, an anchor connected to the liner tubulars, an installation tool releasably engaging the anchor, and a return flow diverter. Other embodiments comprise a tubular conduit extending through the anchor, installation tool, and flow diverter, novel anchors, and novel return flow diverters.
  • the novel methods of installing and cementing liners in a well generally comprise running a liner into the well on a work string.
  • the liner is anchored and sealed to an existing casing in the well.
  • the liner then is released, and the work string is raised to provide a flow path inside the liner.
  • Cement is injected into the liner and allowed to flow into the annulus between the liner and the well. Since the liner has been sealed to the existing casing, fluid displaced from the annulus by the cement is substantially prevented from flowing around the liner to the existing casing. Thus, return fluids are allowed to flow through a port in the liner and the fluid path that was provided by releasing the liner and raising the work string. After the desired amount of cement has been injected into the annulus, the work string is pulled out of the well.
  • the liner assembly comprises liner tubulars and an anchor.
  • the anchor is in an unset position in which fluid is able to flow around the liner assembly.
  • the liner assembly also comprises an installation tool releasably engaging the anchor and a return flow diverter connected to the liner below the anchor.
  • the return flow diverter has a port allowing fluid communication from the annulus between the liner and the well to the interior of the diverter.
  • the liner assembly further comprises a tubular conduit which extends through the anchor, installation tool, and flow diverter into the liner.
  • the installation tool is actuated to set the anchor which in turn secures and seals the liner in an existing casing of the well.
  • the anchor Once the anchor is set and the seal established, fluid is substantially prevented from flowing directly around the liner assembly from the annulus below the anchor to the existing casing above the anchor.
  • the installation tool then is disengaged and raised away from the anchor to provide a path for fluid flow through the anchor and around the conduit.
  • cement is injected through the conduit into the liner and annulus. Well fluid displaced by the cement then is able to flow from the annulus into the existing casing via the diverter port and the path provided by disengagement and raising of the installation tool.
  • the anchors of the subject invention are intended for installation within an existing conduit. They comprise a nondeformable mandrel, an expandable metal sleeve, and a swage.
  • the expandable metal sleeve is carried on the outer surface of the mandrel.
  • the swage is supported for axial movement across the mandrel outer surface from a first position axially proximate to the sleeve to a second position under the sleeve. The movement of the swage from the first position to the second position expands the sleeve radially outward into contact with the existing conduit.
  • the novel anchors are intended to be used in combination with a tool for installing the anchor in a tubular conduit.
  • the installation tool comprises a running assembly and a setting assembly.
  • the running assembly releasably engages the anchor.
  • the setting assembly is connected to the running assembly and engages the swage and moves it from its first position to its second position.
  • the anchor and installation tool assembly is used, for example, in drilling oil and gas wells and to install liners and other well components. It is connected to a work string, preferably as part of a liner assembly, which can be raised, lowered, and rotated as desired from the surface of the well.
  • a liner or other well component may be attached to the liner hanger tool. If a liner is attached, the liner preferably includes a port allowing return fluids from cementing operations to enter the liner. Most preferably, the liner assembly comprises a novel return flow diverter.
  • the liner assembly then is lowered into the well through an existing conduit to position the anchor at the desired depth.
  • the swage is moved axially over the mandrel outer surface by a setting assembly. More particularly, the swage is moved from a position proximate to the expandable metal sleeve to a position under the sleeve, thereby expanding the sleeve radially outward into contact with the existing conduit.
  • the tool is manipulated to release the running assembly from the anchor assembly.
  • the anchor is set and released before the liner is cemented in the well. In any event, the running and setting assemblies ultimately are retrieved from the conduit to complete installation of the liner or other well component.
  • FIG. 1A shows a preferred liner assembly 1 of the subject invention.
  • Liner assembly 1 includes a preferred embodiment 11 of the novel liner hangers which is connected to an installation tool 3.
  • Tool 3 is connected at its upper end to a work string 5 assembled from multiple lengths of tubular sections threaded together through connectors.
  • Work string 5 may be raised, lowered, and rotated as needed to transport liner assembly 1 through an existing casing 6 cemented in a borehole through earth 7.
  • Work string 5 also is used to pump fluid into liner assembly 1 and to manipulate it as required for setting hanger 11.
  • Preferred liner assembly 1 also includes a liner 2 which is attached to the lower end of hanger 11.
  • Liner 2 is assembled primarily from multiple lengths of tubular sections, such as liner tubular 8, threaded together through connectors.
  • Liner assembly 1, as it is run into a well, also typically will have various other tools and components as may be need to perform various operations in the well, both before and after setting hanger 11.
  • liner assembly 1 incorporates various tools and components used to perform cementing operations, such as a preferred embodiment 10 of the return flow diverters of the subject invention, cement packoff 14, a slick joint 15, and a liner wiper plug (not shown). Operation of installation tool 3, as discussed in detail below, is accomplished in part by increasing hydraulic pressure within tool 3.
  • liner assembly 1 also preferably incorporates a mechanism to allow pressure to be built up in work string 5, such as a ball seat (not shown) onto which a ball may be dropped.
  • liner assembly 1 also may include a drill bit (not shown) so that the borehole may be drilled and extended as liner assembly 1 is lowered through existing casing 6.
  • references to a liner assembly includes the entire collection of tools and tubulars that are run into the well on a work string and manipulated to install a liner.
  • references to liner 2 or to a liner generally refer to the liner tubulars, such as tubulars 8, that constitute the major portion of its length and may include, as the context dictates, other unreferenced components.
  • references to liner 2 or an installed liner generally include not only the liner tubulars, but also those tools or components of a liner assembly that remain in the well after completion of the operations described herein and constitute part of the overall liner conduit. While some imprecision is inevitable, it is believed workers of ordinary skill in the art will readily understand such references in the context in which they are used.
  • Hanger 11 includes a hanger mandrel 20, a swage 21, and a metal sleeve 22.
  • Liner 2 is attached to the lower end of hanger 11, more specifically to hanger mandrel 20.
  • the anchors and installation tools of the subject invention are not limited in their application to any specific liner assemblies or a liner.
  • the novel anchors may be used to install a variety of liners, and in general, may be used to install any other downhole tool or component that requires anchoring within a conduit, such as whipstocks, packers, bridge plugs, cement plugs, frac plugs, slotted pipe, and polished bore receptacles (PBRs).
  • preferred liner assembly 1 is exemplified by showing a liner suspended in tension from hanger 11, the novel anchors may also be used to support liners or other well components extending above the anchor, or to secure such components in resistance to torsional forces.
  • a "casing” is generally considered to be a tubular conduit lining a well bore and extending from the surface of the well.
  • a “liner” is generally considered to be a tubular conduit lining a well bore that does not extend from the surface of the well, and instead is supported within an existing casing or another liner.
  • casing shall refer to any existing conduit in the well into which the anchor assembly will be installed, whether it extends to the surface or not
  • “liner” shall refer to a conduit having an external diameter less than the internal diameter of the casing into which the anchor is installed.
  • novel tools will be exemplified in the context of casings and liners used in drilling oil and gas wells.
  • the invention is not so limited in its application.
  • the novel tools and anchors may be used advantageously in other conduits where it is necessary to install an anchor by working a tool through an existing conduit to install other tools or smaller conduits.
  • liner assembly 1 is shown in its "run-in” position. That is, it has been lowered into existing casing 6 to the depth at which hanger 11 will be installed. Hanger 11 has not yet been “set” in casing 6, that is, it has not been installed.
  • FIG. 1B shows liner 2 after it has been installed, that is, after hanger 11 has been set in casing 6 and a running tool 12 (not shown) and setting tool 13 have been retrieved from the well.
  • hanger mandrel 20 has remained in substantially the same position relative to casing 6, that swage 21 has travelled downward approximately the length of sleeve 22, and that sleeve 22 has been expanded radially outward into contact with casing 6.
  • FIGS. 7 show liner hanger 11 and various components of running tool 12.
  • FIG. 7A shows hanger 11 in its "run-in” position
  • FIG. 7B shows hanger 11 after it has been “set”
  • FIG. 7C shows hanger 11 after it has been “released” from running tool 12
  • FIG. 7D shows hanger 11 after running tool 12 has been partially withdrawn from hanger 11.
  • hanger mandrel 20 is a generally cylindrical body providing a conduit. It provides a connection at its lower end to, e.g. , a liner string (such as liner 2 shown in FIGS. 1 ) through threaded connectors or other conventional connectors.
  • liner string such as liner 2 shown in FIGS. 1
  • Other liners such as a patch liner, and other types of well components or tools, such as a whipstock, however, may be connected to mandrel 20, either directly or indirectly.
  • liner hanger 11 it also may be viewed as the uppermost component of the liner or other well component that is being installed.
  • mandrel 20 also is releasably engaged to running tool 12.
  • Swage 21 is supported for axial movement across the outer surface of mandrel 20. In the run-in position, it is proximate to expandable metal sleeve 22, i.e., it is generally axially removed from sleeve 22 and has not moved into a position to expand sleeve 22 into contact with an existing casing. In theory it may be spaced some distance therefrom, but preferably, as shown in FIG. 7A , swage 21 abuts metal sleeve 22. Sleeve 22 also is carried on the outer surface of mandrel 20.
  • sleeve 22 is restricted from moving upward on mandrel 20 by swage 21 as shown and restricted from moving downward by its engagement with annular shoulder 23 on mandrel 20. It may be restricted, however, by other stops, pins, keys, set screws and the like as are known in the art.
  • hanger 11 is set by actuating swage 21 as will be described in greater detail below.
  • swage 21 moves across the outer surface of mandrel 20 from its run-in position, where it is proximate to sleeve 22, to its set position, where it is under sleeve 22.
  • This downward movement of swage 21 causes metal sleeve 22 to expand radially into contact with an existing casing, such as casing 6 shown in FIGS. 1 and FIG. 7D .
  • Movement of swage 21 under sleeve 22 preferably is facilitated by tapering the lower end of swage 21 and the upper end of sleeve 22, as seen in FIG. 7A .
  • the facing surfaces of mandrel 20, swage 21, and sleeve 22 also are polished smooth and/or are provided with various structures to facilitate movement of swage 21 and to provide seals therebetween.
  • outer surface of mandrel 20 and inner surface of sleeve 22 are provided with annular bosses in the areas denoted by reference numeral 24.
  • bosses not only reduce friction between the facing surfaces as swage 21 is being moved, but when swage 21 has moved into place under sleeve 22, though substantially compressed and/or deformed, they also provide metal-to-metal seals between mandrel 20, swage 21, and sleeve 22. It will be understood, however, that annular bosses may instead be provided on the inner and outer surfaces of swage 21, or on one surface of swage 21 in lieu of bosses on either mandrel 20 or sleeve 22. Coatings also may be applied to the facing surfaces to reduce the amount of friction resisting movement of swage 21 or to enhance the formation of seals between facing surfaces.
  • the outer surface of swage 21, or more precisely, that portion of the outer surface of swage 21 that will move under sleeve 22 preferably is polished smooth to reduce friction therebetween.
  • the inner surface of swage 21 preferably is smooth and polished to reduce friction with mandrel 20.
  • the upper portion of swage 21 is able to provide a polished bore receptacle into which other well components may be installed.
  • the novel anchor assemblies also include a ratchet mechanism that engages the mandrel and swage and resists reverse movement of the swage, that is, movement of the swage back toward its first position, in which it is axially proximate to the sleeve, and away from its second position, where it is under the sleeve.
  • Liner hanger 11 for example, is provided with a ratchet ring 26 mounted between mandrel 20 and swage 21.
  • Ratchet ring 26 has pawls that normally engage corresponding detents in annular recesses on, respectively, the outer surface of mandrel 20 and the inner surface of swage 21.
  • Ratchet ring 26 is a split ring, allowing it to compress circumferentially, depressing the pawls and allowing them to pass under the detents on swage 21 as swage 21 travels downward in expanding sleeve 22.
  • the pawls on ring 26 are forced into engagement with the detents, however, if there is any upward travel of swage 21.
  • the effective outer diameter of the mandrel and the effective inner diameter of the swage are substantially equal, whereas the effective outer diameter of the swage is greater than the effective inner diameter of sleeve.
  • swage 21 acts to radially expand sleeve 22 and, once sleeve 22 is expanded, mandrel 20 and swage 21 concentrically abut and provide radial support for sleeve 22, thereby enhancing the load capacity of hanger 11.
  • hanger 11 may achieve equivalent load capacities with a shorter sleeve 22, thus reducing the amount of force required to set hanger 11.
  • effective diameter it will be understood that reference is made to the profile of the part as viewed axially along the path of travel by swage 21.
  • the effective diameter takes into account any protruding structures such as annular bosses which may project from the nominal surface of a part.
  • projections such as annular bosses are provided on mandrel 20 or swage 21
  • the outer diameter of mandrel 20 will be slightly greater than the inner diameter of swage 21 so that a seal may be created therebetween.
  • substantially equal is intended to encompass such variations, and other normal tolerances in tools of this kind.
  • hanger mandrel 20 is in a sense the uppermost component of liner 2 to be installed, it will be appreciated that its inner diameter preferably is at least as great as the inner diameter of liner 2 which will be installed. Thus, any further constriction of the conduit being installed in the well will be avoided. More preferably, however, it is substantially equal to the inner diameter of liner 2 so that mandrel 20 may be made as thick as possible.
  • the mandrel of the novel anchor assemblies is substantially nondeformable, i.e., it resists significant deformation when the swage is moved over its outer surface to expand the metal sleeve.
  • expansion of the sleeve is facilitated and the mandrel is able to provide significant radial support for the expanded sleeve.
  • some compression may be tolerable, on the order of a percent or so, but generally compression is kept to a minimum to maximize the amount of radial support provided.
  • the mandrel of the novel anchors preferably is fabricated from relatively hard ferrous and non-ferrous metal alloys and, most preferably, from such metal alloys that are corrosion resistant.
  • Suitable ferrous alloys include nickel-chromium-molybdenum steel and other high yield steel.
  • Non-ferrous alloys include nickel, iron, or cobalt superalloys, such as Inconel, Hastelloy, Waspaloy, Rene, and Monel alloys.
  • the superalloys are corrosion resistant, that is, they are more resistant to the chemical, thermal, pressure, and other corrosive conditions commonly encountered in oil and gas wells. Thus, superalloys or other corrosion resistant alloys may be preferable when corrosion of the anchor is a potential problem.
  • the swage of the novel anchors also is preferably fabricated from such materials.
  • high yield alloys not only is expansion of the sleeve facilitated, but the mandrel and swage also are able to provide significant radial support for the expanded sleeve and the swage may be made more resistant to corrosion as well.
  • the sleeve of the novel anchor assemblies preferably is fabricated from ductile metal, such as ductile ferrous and non-ferrous metal alloys.
  • the alloys should be sufficiently ductile to allow expansion of the sleeve without creating cracks therein. Examples of such alloys include ductile aluminum, brass, bronze, stainless steel, and carbon steel.
  • the metal has an elongation factor of approximately 3 to 4 times the anticipated expansion of the sleeve. For example, if the sleeve is required to expand on the order of 3%, it will be fabricated from a metal having an elongation factor of from about 9 to about 12%.
  • the material used to fabricate the sleeve should have an elongation factor of at least 10%, preferably from about 10 to about 20%.
  • the sleeve should not be fabricated from material that is so ductile that it cannot retain its grip on an existing casing.
  • the choice of materials for the mandrel, swage, and sleeve should be coordinated to provide minimal deformation of the mandrel, while allowing the swage to expand the sleeve without creating cracks therein.
  • higher yield materials are used in the mandrel and swage, it is possible to use progressively less ductile materials in the sleeve. Less ductile materials may provide the sleeve with greater gripping ability, but of course will require greater expansion forces.
  • the novel hangers do not have a weakened area such as exists at the junction of expanded and unexpanded portions of expandable liners. Thus, other factors being equal, the novel hangers are able to achieve higher load ratings.
  • expandable liners must be made relatively thick in part to compensate for the weakened area created between the expanded and unexpanded portions.
  • the expandable sleeves of the novel hangers are much thinner. Thus, other factors being equal, the expandable sleeves may be expanded more easily, which in turn reduces the amount of force that must be generated by the setting assembly.
  • Ductile alloys from which both conventional expandable liners and the expandable sleeves of the novel hangers may be made, once expanded, can relax and cause a reduction in the radial force applied to an existing casing.
  • Conventional tools have provided support for expanded liner portions by leaving the swage or other expanding member in the well.
  • the nondeformable mandrel of the novel liner hangers has substantially the same outer diameter as the internal diameter of the swage. Thus, both the mandrel and the swage are able to provide radial support for the expanded sleeve.
  • Expandable liner hangers since they necessarily are fabricated from ductile alloys which in general are less resistant to corrosion, are more susceptible to corrosion and may not be used, or must be used with the expectation of a shorter service life in corrosive environments.
  • the mandrel of the novel hangers may be made of high yield alloys that are much more resistant to corrosion.
  • the expandable sleeve of the novel hangers are fabricated from ductile, less corrosion resistant alloys, but it will be appreciated that as compared to a liner, only a relatively small surface area of the sleeve will be exposed to corrosive fluids.
  • the length of the seal formed by the sleeve also is much greater than the thickness of a liner, expanded or otherwise. Thus, the novel hangers may be expected to have longer service lives in corrosive environments.
  • the expandable sleeve of the novel anchor assemblies also preferably is provided with various sealing and gripping elements to enhance the seal between the expanded sleeve and an existing casing and to increase the load capacity of the novel hangers.
  • sleeve 22 is provided with annular seals 27 and radially and axially spaced slips 28 provided on the outer surface thereof.
  • Annular seals may be fabricated from a variety of conventional materials, such as wound or unwound, thermally cured elastomers and graphite impregnated fabrics.
  • Slips may be provided by conventional processes, such as by machining slips into the sleeve, or by soldering crushed tungsten-carbide steel or other metal particles to the sleeve surface with a thin coat of high nickel based solder or other conventional solders.
  • the sleeve also preferably is provided with gage protection to minimize contact between such elements and the casing wall as the anchor assembly is run into the well.
  • the precise dimensions of the expandable sleeve may be varied so as to, other factors being equal, to provide greater or lesser load capacity and to allow for greater or lesser expansion forces.
  • the external diameter of the sleeve necessarily will be determined primarily by the inner diameter of the casing into which the anchor will be installed and the desired degree of expansion.
  • the thickness of the sleeve will be coordinated with the tensile and ductile properties of the material used in the sleeve so as to provide the desired balance of load capacity and expandability. In general, the longer the sleeve, the greater the load capacity.
  • the sleeve typically will have a length at least equal to its diameter, and preferably a length of at least 150% of the diameter, so as to provide sufficient surface area to provide load capacities capable of supporting relatively heavy liners and other downhole tools and well components.
  • the novel anchor assemblies thus may be provided with load capacities of at least 100,000 lbs, more preferably, at least 250,000 lbs, and most preferably, at least 500,000 lbs.
  • novel anchors of the subject invention provide significant advantages and preferably are used in practicing the novel methods for installing and cementing a liner in a well and in the novel liner assemblies.
  • hangers that provide a seal with an existing casing when they are set, or hangers with separate seal members may be used in the novel methods and the novel liner assemblies.
  • expandable liners such as those disclosed in Braddick '880, Harrell '169, and Baugh '667, which establish a seal with an existing casing as they are set, may be adapted for use in the subject invention.
  • the expandable liner and overall liner weight will be coordinated so that the liner may be substantially supported and immobilized during the cementing process.
  • the novel anchor assemblies are intended to be used in combination with a tool for installing the anchor in a tubular conduit.
  • installation tool 3 may be used to install liner hanger 11. More specifically, running tool 12 is used to releasably engage hanger 11 and setting tool 13 is used to actuate swage 21 and set sleeve 22.
  • the subject invention does not encompass any specific tool or mechanism for releasably engaging, actuating, or otherwise installing the novel anchor assemblies.
  • the novel anchors are used with the tools disclosed herein. Those tools are capable of installing the novel anchors easily and reliably.
  • they incorporate various novel features and represent other embodiments of the subject invention.
  • Tool mandrel 30 provides a base structure to which the various components of liner hanger 11, running tool 12, and setting tool 13 are connected, directly or indirectly.
  • Tool mandrel 30 is connected at its upper end to a work string 5 (see FIG. 1A ). Thus, it provides a conduit for the passage of fluids from the work string 5 that are used, among other purposes, to balance hydrostatic pressure in the well, to hydraulically actuate setting tool 13 and, ultimately, swage 21, and to inject cement into liner 2. Mandrel 30 also provides for transmission of axial and rotational forces from work string 5 as are necessary to run in hanger 11 and liner 2, drill a borehole during run-in, set hanger 11, and release and retrieve running tool 12 and setting tool 13, all as described in further detail below.
  • Tool mandrel 30 is a generally cylindrical body. Preferably, as illustrated, it comprises a plurality of tubular sections 31 to facilitate assembly of installation tool 3 and liner hanger 11 as a whole. Tubular sections 31 may be joined by conventional threaded connectors. Preferably, however, the sections 31 of tool mandrel 30 are connected by novel clutch mechanisms of the subject invention.
  • the novel clutch mechanisms comprise shaft sections having threads on the ends to be joined.
  • the shaft sections have prismatic outer surfaces adjacent to their threaded ends.
  • a threaded connector joins the threaded ends of the shaft sections.
  • the connector has axial splines.
  • a pair of clutch collars is slidably supported on the prismatic outer surfaces of the shaft sections.
  • the clutch collars have prismatic inner surfaces that engage the prismatic outer surfaces of the shaft sections and axial splines that engage the axial splines on the threaded connector.
  • the novel clutch mechanisms also comprise recesses adjacent to the mating prismatic surfaces that allow limited rotation of the clutch collars on the prismatic shaft sections to facilitate engagement and disengagement of the mating prismatic surfaces.
  • mandrel 30 of installation tool 3 includes a preferred embodiment 32 of the novel clutch mechanisms. More particularly, mandrel 30 is made up of a number of tubular sections 31 joined by novel connector assemblies 32. Connector assemblies 32 include threaded connectors 33 and clutch collars 34. FIGS. 8-9 show the portion of mandrel 30 and connector assembly 32a which is seen in FIGS. 2 and which is representative of the connections used to make up mandrel 30. As may be seen in those figures, lower end of tubular section 31a and upper end of tubular section 31b are threaded into and joined by threaded connector 33a.
  • Clutch collars 34a and 34b are slidably supported on tubular sections 31a and 31b, and when in their coupled or "made-up" position as shown in FIG. 8A , abut connector 33a. Connector 33a and collars 34a and 34b have mating splines which provide rotational engagement therebetween.
  • Tubular sections 31 have prismatic outer surfaces 35 adjacent to their threaded ends. That is, the normally cylindrical outer surfaces of tubular sections 31 have been cut to provide a plurality of flat surfaces extending axially along the tubular section such that, when viewed in cross section, flat surfaces define or can be extended to define a polygon.
  • tubular section 31a has octagonal prismatic outer surfaces 35.
  • the inner surface of clutch collar 34a has mating octagonal prismatic inner surfaces 36.
  • Clutch collar 34b is of similar construction.
  • prismatic surfaces 35 and 36 provide rotational engagement between sections 31a and 31b and collars 34a and 34b. It will be appreciated, therefore, that torque may be transmitted from one tubular section 31 to another tubular section 31, via collars 34 and connectors 33, without applying torque to the threaded connections between the tubular sections 31.
  • FIGS. 8B and 9B show connector assembly 32a in uncoupled states.
  • prismatic surfaces 35 extend axially on tubular sections 31a and 31b and allow the splines on collars 34a and 34b to slide into and out of engagement with the splines on connector 33a, as may be appreciated by comparing FIGS. 8A and 8B .
  • Recesses preferably are provided adjacent to the mating prismatic surfaces to facilitate that sliding.
  • recesses 37 are provided adjacent to prismatic surfaces 36 on collar 34a. Those recesses allow collar 34a to rotate to a limited degree on tubular sections 31a. When rotated to the left, as shown in FIG.
  • the novel clutch mechanisms provide for reliable and effective transmission of torque in both directions through a sectioned conduit, such as tool mandrel 30.
  • a sectioned conduit such as tool mandrel 30.
  • mating prismatic surfaces and splines on the connector and collars provide much greater surface area through which right-handed torque is transmitted.
  • much greater rotational forces, and forces well in excess of the torque limit of the threaded connection may be transmitted in a clockwise direction through a sectioned conduit and its connector assemblies without risking damage to threaded connections.
  • the novel clutch mechanisms therefore, are particularly suited for tools used in drilling in a liner and other applications that subject the tool to high torque.
  • the collars cannot rotate in a counterclockwise direction, or if recesses are provided can rotate in a counterclockwise direction only to a limited degree, left-handed torque may be applied to a tool mandrel without risk of significant loosening or of unthreading the connection.
  • the tool may be designed to utilize reverse rotation, such as may be required for setting or release of a liner or other well component, without risking disassembly of the tool in a well bore.
  • mandrel 30 may be made up with conventional connections.
  • novel liner hangers may be used with tools having a conventional mandrel, and thus, the novel clutch mechanisms form no part of that aspect of the subject invention.
  • novel clutch mechanisms may be used to advantage in making up any tubular strings, in mandrels for other tools, or in other sectioned conduits or shafts, or any other threaded connection where threads must be protected from excessive torque.
  • Running tool 12 includes a collet mechanism that releasably engages hanger mandrel 20 and which primarily bears the weight of liner 2 or other well components connected directly or indirectly to hanger mandrel 20.
  • Running tool 12 also includes a releasable torque transfer mechanism for transferring torque to hanger mandrel 20 and a releasable dog mechanism that provides a connection between running tool 12 and tool mandrel 30.
  • Tubular section 31g of mandrel 30 provides a base structure on which the various other components of running tool 12 are assembled. As will be appreciated from the discussion follows, most of those other components are slidably supported, directly or indirectly, on tubular section 31g. During assembly of installation tool 3 and liner hanger 11 and to a certain extent in their run-in position, however, they are fixed axially in place on tubular section 31g by the dog mechanism, which can be released to allow release of the collet mechanism engaging hanger mandrel 20.
  • running tool 12 includes a collet 40 which has an annular base slidably supported on mandrel 30.
  • a plurality of fingers extends axially downward from the base of collet 40.
  • the collet fingers have enlarged ends 41 which extend radially outward and, when running tool 12 is in its run-in position as shown in FIG. 7A , engage corresponding annular recesses 29 in hanger mandrel 20.
  • a bottom collar 42 is threaded onto the end of tool mandrel 30, and its upper beveled end provides radial and axial support for the ends 41 of collet 40.
  • collet 40 is able to bear the weight of mandrel 20, liner 2, and any other well components that may be connected directly or indirectly thereto.
  • Bottom collar 42 also provides a connection, e.g. , via a threaded lower end, to a slick joint 15 or other well components that may be included below hanger 11 in liner assembly 1 as desired.
  • collet 40 or more precisely, its annular base is slidably supported on mandrel 30 within an assembly including a sleeve 43, an annular collet cap 46, an annular sleeve cap 44, and annular thrust cap 45.
  • Sleeve 43 is generally disposed within hanger mandrel 20 and slidably engages the inner surface thereof.
  • Sleeve cap 44 is threaded to the lower end of sleeve 43 and is slidably carried between hanger mandrel 20 and collet 40.
  • Thrust cap 45 is threaded to the upper end of sleeve 43 and is slidably carried between swage 21 and tubular section 31g.
  • Collet cap 46 is threaded to the upper end of collet 40 and is slidably carried between sleeve 43 and tubular section 31g.
  • the collet 40 and cap 46 subassembly is spring loaded within sleeve 43 between sleeve cap 44 and thrust cap 45.
  • thrust cap 45 abuts at its upper end an annular dog housing 47 and abuts hanger mandrel 20 at its lower end.
  • Hanger mandrel 20 and thrust cap 45 rotationally engage each other via mating splines, similar to those described above in reference to the connector assemblies 32 joining tubular sections 31.
  • tubular section 31g is provided with lugs, radially spaced on its outer surface, which rotationally engage corresponding slots in thrust cap 45.
  • the slots extend laterally and circumferentially away from the lugs to allow, for reasons discussed below, tubular section 31g to move axially downward and to rotate counterclockwise a quarter-turn.
  • Running tool 12 when running tool 12 is in its run-in position the engagement between those lugs and slots provide rotational engagement in a clockwise direction between tubular section 31g and thrust cap 45, thus ultimately allowing clockwise torque to be transmitted from tool mandrel 30 to hanger mandrel 20.
  • Running tool 12 may be used to drill in a liner. That is, a drill bit may be attached to the end liner 2 and the well bore extended by rotating work string 5.
  • dog housing 47 and tubular section 31g of mandrel 30 have cooperating recesses that entrap a plurality of dogs 48 as is common in the art. Those recesses allow dogs 48 to move radially, that is, in and out to a limited degree. It will be appreciated that the inner ends (in this sense, the bottom) of dogs 48 are provided with pawls which engage the recess in tubular section 31g. The annular surfaces of those pawls and recesses are coordinated such that downward movement of mandrel 30 relative to dog housing 47, for reasons to be discussed below, urges dogs 48 outward. In the run-in position, as shown in FIG.
  • a locking piston 50 which is slidably supported on tubular section 31g, overlies dog housing 47 and the tops of the cavities in which dogs 48 are carried.
  • dogs 48 are held in an inward position in which they engage both dog housing 47 and tubular section 31g.
  • dogs 48 are able to provide a translational engagement between mandrel 30 and running tool 12 when it is in the run-in position. This engagement is not typically loaded with large amounts of force when the tool is in its run-in position, as the weight of installation tool 3 and liner 2 is transmitted to tool mandrel 30 primarily through collet ends 41 and bottom collar 41 and torque is transmitted from mandrel 30 through thrust cap 45 and hanger mandrel 20.
  • the engagement provided by dogs 48 facilitates assembly of installation tool 3 and hanger 11 and will bear any compressive load inadvertently applied between hanger 11 and tool mandrel 30.
  • dogs 48 will prevent liner hanger 11 and running tool 12 from moving upward on mandrel 30 such as might otherwise occur if liner assembly 1 gets hung up as it is run into an existing casing. Release of dogs 48 from that engagement will be described in further detail below in the context of setting hanger 11 and release of running tool 12.
  • running tool 12 described above provides a reliable, effective mechanism for releasably engaging liner hanger 11, for securing liner hanger from moving axially on mandrel 30, and for transmitting torque from mandrel 30 to hanger mandrel 20.
  • it is a preferred tool for use with the liner hangers of the subject invention.
  • other conventional running mechanisms such as mechanisms utilizing a left-handed threaded nut or dogs only, may be used, particularly if it is not necessary or desirable to provide for the transmission of torque through the running mechanism.
  • the subject invention is in no way limited to a specific running tool.
  • Setting tool 13 includes a hydraulic mechanism for generating translational force, relative to the tool mandrel and the work string to which it is connected, and a mechanism for transmitting that force to swage 21 which, upon actuation, expands metal sleeve 22 and sets hanger 11. It is connected to running tool 12 through their common tool mandrel 30, with tubular sections 31a-f of mandrel 30 providing a base structure on which the various other components of setting tool 13 are assembled.
  • the hydraulic mechanism comprises a number of cooperating hydraulic actuators 60 supported on tool mandrel 30.
  • Those hydraulic actuators are linear hydraulic motors designed to provide linear force to swage 21.
  • actuators 60 are interconnected so as to "stack" the power of each actuator 60 and that their number and size may be varied to create the desired linear force for expanding sleeve 22.
  • the mandrel in the novel actuators preferably is a generally cylindrical mandrel.
  • a hydraulic cylinder is slidably coupled to the mandrel.
  • the hydraulic cylinder has a bottom hydraulic chamber with an inlet port and a top hydraulic chamber with an outlet port.
  • conventional hydraulic cylinders will include a stationary sealing member, such as a piston, seal, or an extension of the mandrel itself, which extends continuously around the exterior of the mandrel.
  • a hydraulic barrel or cylinder is slidably supported on the outer surfaces of the mandrel and the stationary sealing member.
  • the cylinder includes a sleeve or other body member with a pair of dynamic sealing members, such as pistons, seals, or extensions of the body member itself, spaced on either side of the stationary sealing member and slidably supporting the cylinder.
  • the stationary sealing member divides the interior of the cylinder into two hydraulic chambers, a top chamber and a bottom chamber.
  • An inlet port provides fluid communication into the bottom hydraulic chamber.
  • An outlet port provides fluid communication into the top hydraulic chamber.
  • FIGS. 4 what may be viewed as the lowermost hydraulic actuator 60e is shown in FIGS. 4 .
  • This lowermost hydraulic actuator 60e comprises floating annular pistons 61e and 61f.
  • Floating pistons 61e and 61f are slidably supported on tool mandrel 30, or more precisely, on tubular sections 31e and 31f, respectively.
  • a cylindrical sleeve 62e is connected, for example, by threaded connections to floating pistons 61e and 61f and extends therebetween.
  • An annular stationary piston 63e is connected to tubular section 31f of tool mandrel 30, for example, by a threaded connection.
  • set screws, pins, keys, or the like are provided to secure those threaded connections and to reduce the likelihood they will loosen.
  • floating piston 61f In the run-in position shown in FIG. 4A , floating piston 61f is in close proximity to stationary piston 63e. A bottom hydraulic chamber is defined therebetween, either by spacing the pistons or by providing recesses in one or both of them, and a port is provided through the mandrel to allow fluid communication with the bottom hydraulic chamber.
  • floating piston 61f and stationary piston 63e are provided with recesses which define a bottom hydraulic chamber 64e therebetween, even if pistons 61f and 63e abut each other.
  • One or more inlet ports 65e are provided in tubular section 31f to provide fluid communication between the interior of tool mandrel 30 and bottom hydraulic chamber 64e.
  • Floating piston 61e is distant from stationary piston 63e, and a top hydraulic chamber 66e is defined therebetween.
  • One or more outlet ports 67e are provided in floating piston 61e to provide fluid communication between top hydraulic chamber 66e and the exterior of cylinder sleeve 62e.
  • outlet ports could be provided in cylinder sleeve 62e, and it will be appreciated that the exterior of cylinder sleeve 62e is in fluid communication with the exterior of the tool, i.e., the well bore, via clearances between cylinder sleeve 62e and swage 21.
  • inlet ports 65e into bottom hydraulic chamber 64e will urge floating piston 61f downward, and in turn cause fluid to flow out of top hydraulic chamber 66e through outlet ports 67e and allow actuator 60e to travel downward along mandrel 30, as may be seen in FIG. 4 B.
  • Setting tool 13 includes another actuator 60d of similar construction located above actuator 60e just described. Parts of actuator 60d are shown in FIGS. 3 and 4 .
  • engagement actuator 60c comprises a pair of floating pistons 61c and 61d connected by a sleeve 62c.
  • Floating pistons 61c and 61d are slidably supported, respectively, on tubular sections 31c and 31d around stationary piston 63c.
  • One or more inlet ports 65c are provided in tubular section 31c to provide fluid communication between the interior of tool mandrel 30 and bottom hydraulic chamber 64c.
  • One or more outlet ports 67c are provided in cylinder sleeve 62c to provide fluid communication between top hydraulic chamber 66c and the exterior of actuator 60c.
  • sleeve 62c extends above swage 21 while its lower portion extends through swage 21, and that upper end of sleeve 62c is enlarged relative to its lower portion.
  • An annular adjusting collar 68 is connected to the reduced diameter portion of sleeve 62c via, e.g. , threaded connections.
  • An annular stop collar 69 is slidably carried on the reduced diameter portion of sleeve 62c spaced somewhat below adjusting collar 68 and just above and abutting swage 21. Adjusting collar 68 and stop collar 69 are tied together by shear pins (not shown) or other shearable members.
  • Setting tool 13 includes what may be viewed as additional drive actuators 60a and 60b located above engagement actuator 60c shown in FIGS. 3 .
  • the uppermost hydraulic actuator 60a comprises a pair of floating pistons 61a and 61b connected by a sleeve 62a and slidably supported, respectively, on tubular sections 31a and 31b around stationary piston 63a.
  • One or more inlet ports 65a are provided in tubular section 31a to provide fluid communication between the interior of tool mandrel 30 and bottom hydraulic chamber 64a.
  • One or more outlet ports 67a are provided in floating piston 61a to provide fluid communication between top hydraulic chamber 66a and the exterior of actuator 60a. (It will be understood that actuator 60b, as shown in part in FIGS. 2 and 3 , is constructed in a fashion similar to actuator 60a.)
  • hydraulic actuators 60 preferably are immobilized in their run-in position. Otherwise, they may be actuated to a greater or lesser degree by differences in hydrostatic pressure between the interior of mandrel 30 and the exterior of installation tool 3.
  • setting tool 13 preferably incorporates shearable members, such as pins, screws, and the like, or other means of releasably fixing actuators 60 to mandrel 30.
  • the novel hydraulic actuators include a balance piston.
  • the balance piston is slidably supported within the top hydraulic chamber of the actuator, preferably on the mandrel.
  • the balance piston includes a passageway extending axially through the balance piston. Fluid communication through the piston and between its upper and lower sides is controlled by a normally shut valve in the passageway.
  • the balance piston is able to slide in response to a difference in hydrostatic pressure between the outlet port, which is on one side of the balance piston, and the portion of the top hydraulic chamber that is on the bottom side of the balance piston.
  • actuator 60a includes balance piston 70a.
  • Balance piston 70a is slidably supported on tubular section 31a of mandrel 30 in top hydraulic chamber 66a between floating piston 61a and stationary piston 63a.
  • balance piston 70a is located in close proximity to floating piston 61a.
  • a hydraulic chamber is defined therebetween, either by spacing the pistons or by providing recesses in one or both of them, and a port is provided through the mandrel to allow fluid communication with the hydraulic chamber.
  • floating piston 61a is provided with a recess which defines a hydraulic chamber 71a therebetween, even if pistons 61a and 70a abut each other.
  • Balance piston 70a has a passageway 72a extending axially through its body portion, i.e., from its upper side to its lower side. Passageway 72a is thus capable of providing fluid communication through balance piston 70a, that is, between hydraulic chamber 71a and the rest of top hydraulic chamber 66a. Fluid communication through passageway 72a, however, is controlled by a normally shut valve, such as rupturable diaphragm 73a. When diaphragm 73a is in its closed, or unruptured state, fluid is unable to flow between hydraulic chamber 71a and the rest of top hydraulic chamber 66a.
  • a normally shut valve such as rupturable diaphragm 73a.
  • Actuator 60b also includes a balance piston 70b identical to balance piston 70a described above.
  • balance pistons 70a and 70b are able to equalize pressure between the top hydraulic chambers 66a and 66b and the exterior of actuators 60a and 60b such as might develop, for example, when liner assembly 1 is being run into a well. Fluid is able to enter outlet ports 67a and 67b and, to the extent that such exterior hydrostatic pressure exceeds the hydrostatic pressure in top hydraulic chambers 66a and 66b, balance pistons 70a and 70b will be urged downward until the pressures are balanced.
  • Such balancing of internal and external pressures is important because it avoids deformation of cylinder sleeves 62a and 62b that could interfere with travel of sleeves 62a and 62b over stationary pistons 63a and 63b.
  • balance pistons 70a and 70b further enhance the reliability of actuators 60a and 60b. That is, balance pistons 70a and 70b greatly reduce the amount of debris that can enter top hydraulic chambers 66a and 66b, and since they are located in close proximity to outlet ports 67a and 67b, the substantial majority of the travel path is maintained free and clear of debris.
  • Hydraulic chambers 66a and 66b preferably are filled with clean hydraulic fluid during assembly of setting tool 13, thus further assuring that when actuated, floating pistons 61a and 61b and sleeves 62a and 62b will slide cleanly and smoothly over, respectively, tubular sections 31a and 31b and stationary pistons 63a and 63b.
  • the exact location of the balance piston in the top hydraulic chamber of the novel actuators is not critical. It may be spaced relatively close to a stationary piston and still provide such balancing. In practice, the balance piston will not have to travel a great distance to balance pressures and, therefore, it may be situated initially at almost any location in the top hydraulic chamber between the external opening of the outlet port and the stationary piston.
  • the balance piston in the novel actuators is mounted as close to the external opening of the outlet port as practical so as to minimize exposure of the inside of the actuator to debris from a well bore. It may be mounted within a passageway in what might be termed the "port,” such as ports 67a shown in the illustrated embodiment 60a, or within what might otherwise be termed the "chamber,' such as top hydraulic chamber 66a shown in the illustrated embodiment 60a.
  • the top hydraulic chamber may be understood as including all fluid cavities, chambers, passageways and the like between the port exit and the stationary piston.
  • the balance piston 70a is mounted on tubular sections 31a in the relatively larger top hydraulic chamber 66a.
  • the normally shut valves in the balance position should be selected such that they preferably are not opened to any significant degree by the pressure differentials they are expected to encounter prior to actuation of the actuator. At the same time, as will be appreciated from the discussion that follows, they must open, that is, provide release of increasing hydrostatic pressure in the top hydraulic chamber when the actuator is actuated. Most preferably, the normally shut valves remain open once initially opened. Thus, rupturable diaphragms are preferably employed because they provide reliable, predictable release of pressure, yet are simple in construction and can be installed easily. Other normally shut valve devices, such as check valves, pressure relief valves, and plugs with shearable threads, however, may be used in the balance piston on the novel actuators.
  • the actuator includes stationary and dynamic seals as are common in the art to seal the clearances between the components of the actuator and to provide efficient operation of the actuator as described herein.
  • the clearances separating the balance piston from the mandrel and from the sleeve, that is, the top hydraulic chamber preferably are provided with dynamic seals to prevent unintended leakage of fluid around the balance piston.
  • the seals may be mounted on the balance piston or on the chamber as desired.
  • balance pistons 70a and 70b may be provided with annular dynamic seals (not shown), such as elastomeric O-rings mounted in grooves, on their inner surface abutting tubular sections 31a and 31b and on their outer surfaces abutting sleeves 62a and 62b, respectively.
  • annular dynamic seals such as elastomeric O-rings mounted in grooves, on their inner surface abutting tubular sections 31a and 31b and on their outer surfaces abutting sleeves 62a and 62b, respectively.
  • one or both of the seals may be mounted on the top hydraulic chambers 66a and 66b, for example, in grooves on tubular sections 31a and 31b or sleeves 62a and 62b.
  • the balance pistons Prior to actuation, the balance pistons essentially seal the top hydraulic chambers and prevent the incursion of debris. Under certain conditions, however, such as increasing downhole temperatures, pressure within the top hydraulic chambers can increase beyond the hydrostatic pressure in the well bore. The balance pistons will be urged upward until pressure in the top hydraulic chambers is equal to the hydraulic pressure in the well bore. In the event that a balance piston "bottoms" out against the outlet port, however, pressure within the top hydraulic chamber could continue to build, possibly to the point where a diaphragm would be ruptured, thereby allowing debris laden fluid from the well bore to enter the chamber.
  • the novel actuators preferably incorporate a pressure release device allowing release of potentially problematic pressure from the top hydraulic chamber as might otherwise occur if the balance pistons bottom out.
  • check valves or pressure relief valves may be mounted in passageways 72a and 72b.
  • Such valves if used, should also allow a desired level of fluid flow through passageways 72a and 72b during actuation.
  • an elastomeric burp seal (not shown) may be mounted in one or both of the clearances separating the balance pistons 70a and 70b from, respectively, tubular sections 31a and 31b and sleeves 62a and 62b.
  • burp seals would then allow controlled release of fluid from top hydraulic chambers 66a and 66b to, respectively, hydraulic chambers 71a and 71b if balance pistons 70a and 70b were to bottom out against, respectively, floating pistons 61a and 61b.
  • Such burp valves would, of course, be designed with a release pressure sufficiently below the pressure required to open the rupturable diaphragm or other normally shut valve.
  • the pressure relief device is provided in the cylindrical mandrel.
  • a check or pressure release valve (not shown) may be mounted in tubular sections 31a and 31b so as to allow controlled release of fluid from top hydraulic chambers 66a and 66b to the interior of mandrel 30.
  • Such an arrangement has an advantage over a burp seal as described above in that it would be necessary to overcome flow through a burp seal in order to build up sufficient pressure to rupture a diaphragm or otherwise to open a normally shut valve device. If a pressure relief device is provided in the cylindrical mandrel, pressure in the top hydraulic chamber will be equal to pressure within the interior of the mandrel, and there will be no flow through the pressure release device that must be overcome.
  • setting tool 13 includes a slidable, indicator ring 75 supported on tubular section 31f just below actuator 60e described above.
  • indicator ring 75 is fixed to tubular section 31f via a shear member, such as a screw or pin (not shown). It is positioned on section 31f relative to floating piston 61f, however, such that when floating piston 61f has reached the full extent of its travel, it will impact indicator ring 75 and shear the member fixing it to section 31f.
  • indicator ring 75 will be able to slide freely on mandrel 30 and, when the tool is retrieved from the well, it may be readily confirmed that setting tool 13 fully stroked and set metal sleeve 22.
  • setting tool 13 described above provides a reliable, effective mechanism for actuating swage 21, and it incorporates novel hydraulic actuators providing significant advantages over the prior art.
  • it is a preferred tool for use with the anchor assemblies of the subject invention.
  • hydraulic and other types of mechanisms which are commonly used in downhole tools to generate linear force and motion, such as hydraulic jack mechanisms and mechanisms actuated by explosive charges or by releasing weight on, pushing, pulling, or rotating the work string.
  • such mechanism may be adapted for use with the novel anchor assemblies, and it is not necessary to use any particular setting tool or mechanism to set the novel anchor assemblies.
  • the novel setting assemblies because they include hydraulic actuators having a balance piston, are able to balance hydraulic pressures that otherwise might damage the actuator and are able to keep the actuator clear of debris that could interfere with its operation.
  • Such improvements are desirable not only in setting the anchor assemblies of the subject invention, but also in the operation of other downhole tools and components where hydraulic actuators or other means of generating linear force are required.
  • the subject invention in this aspect is not limited to use of the novel setting assemblies to actuate a particular anchor assembly or any other downhole tool or component.
  • novel liner assemblies preferably incorporate tools to perform cementing operations, such as the return flow diverters of the subject invention.
  • the novel return flow diverters comprise a cylindrical body adapted for installation in a well as part of a liner.
  • the cylindrical body has a fluid port, typically a plurality of such ports, adapted to allow fluids displaced by a cementing operation to flow from an annulus between the liner and the well into the tool.
  • a cover is supported on the cylindrical body for movement from an open position, in which the port is open, to a closed position, in which the port is closed by the cover.
  • a transmission is disposed within the cylindrical body.
  • the transmission defines a cylindrical passageway adapted to accommodate a tubular conduit which extends through the cylindrical body, which conduit may be used for injecting cement into the liner below the flow diverter.
  • the transmission is releasably engaged with the cover and operable to move the cover from the open position to the closed position.
  • preferred liner assembly 1 incorporates preferred return flow diverter 10, cement packoff 14, slick joint 15, and a liner wiper plug (not shown).
  • Flow diverter 10 and cement packoff 14, as shown in FIGS. 1 are incorporated into liner assembly 1 below hanger 11.
  • slick joint 15 is a tubular section connected to running tool 12, more specifically, to bottom collar 42 at the end of tool mandrel 30. It has an outer diameter significantly less than the inner diameter of hanger mandrel 20 and, necessarily, of swage 21. It extends from running tool 12 downward through flow diverter 10, as shown in FIGS. 10 , and cement packoff 14 (not shown).
  • Preferred flow diverter 10 comprises a generally cylindrically-shaped housing 80 which, as discussed in further detail below, will ultimately form part of the liner 2 which is installed in the well. Its interior surface generally defines a cylindrical conduit which preferably has a diameter at least as large as liner tubulars 8 with which it will be assembled. An upper portion 81 of housing 80 is provided with an enlarged outer diameter and a gage ring 82 is secured to the lower end of housing 80 to provide gage protection for flow diverter 10. Both ends of housing 80 are threaded so that it may be incorporated into liner assembly 1. Specifically, housing 80 is assembled into liner assembly 1 downhole of liner hanger 11, as may be seen in FIGS. 1 , and is connected directly, or indirectly via liner tubulars or connectors, to hanger mandrel 20. Cement packoff 14 is incorporated into and connected to liner assembly 1 in a similar fashion below flow diverter 10.
  • diverter housing 80 comprises a number of ports 83 defined in the walls thereof.
  • Ports 83 are configured and sized to allow fluid to flow between the interior of housing 80 and the annulus between liner assembly 1 and the well into which it is run. In particular, as described below, they are configured and sized to allow fluid displaced from the annulus during cementing operations to flow from the annulus into housing 80.
  • a cylindrical sleeve 84 is supported on the outer surface of housing 80.
  • sleeve 84 is supported for axial movement from an open, run-in position, in which ports 83 are uncovered by sleeve 84 as shown in FIG. 10A , to a closed, installed position, in which sleeve 84 covers ports 83 as shown in FIG. 10 B.
  • Ports 83 when sleeve 84 is in its open, run-in position, allow fluid displaced from a cementing operation to flow from the annulus to the interior of liner assembly 1, as described in further detail below.
  • sleeve 84 cover ports 83 it substantially prevents fluid flow from the annulus into flow diverter 10 so that the integrity of liner 2, into which housing 80 is incorporated, will be maintained.
  • the novel flow diverters as they are assembled into and run in with a liner assembly, comprise a transmission which is disposed within the cylindrical body and releasably engaged with the cover and operable to move the cover from the open position to the closed position.
  • preferred flow diverter 10 comprises a transmission 90 which is operable to move sleeve 84 from its open position to its closed position.
  • transmission 90 comprises a carriage 91 and a collet 92.
  • Carriage 91 is a generally cylindrical, sleeve-like body disposed within diverter housing 80.
  • Collet 92 similar to collet 40, has an annular base 93 and a plurality of flexible fingers 94.
  • Annular base 93 of collet 92 is slidably supported on the outer surface of carriage 91, such that collet 92 is disposed between carriage 91 and housing 80.
  • the enlarged ends 95 of collet fingers 94 extend through slots 85 in housing 80 to engage corresponding recesses in sleeve 84. They are prevented from flexing out of engagement with sleeve 84 by an enlarged lower portion 98 of carriage 91.
  • collet 92 engages sleeve 84 when flow diverter 10 is run into the well.
  • Annular base 93 of collet 92 in turn is releasably engaged with carriage 91 by, for example, shear wire 96.
  • collet 92 may be releasably engaged with carriage 91 via shearable pins, screws and the like.
  • Collet 92 also may be releasably engaged with carriage 91 by dogs, such as radially displaceable dogs shown in FIGS. 14A and 14B and discussed below.
  • dogs such as radially displaceable dogs shown in FIGS. 14A and 14B and discussed below.
  • carriage 91 is able to slide axially within annular base 93 of collet 92 as described in further detail below.
  • Carriage 91 also is provided with a threaded cap 97, and a torsion spring is disposed between carriage cap 97 and collet base 93 to facilitate assembly of transmission 90 in diverter housing 80.
  • Carriage 91 defines a cylindrical passageway through which slick joint 15 extends.
  • Slick joint 15 is connected at its upper end to mandrel 30 which is in turn connected to work string 5. It preferably is connected at its lower end to other liner assembly components, such as a ball seat assembly, a plug holder assembly, and a liner wiper plug, which are used in cementing or other tool operations.
  • liner assembly components such as a ball seat assembly, a plug holder assembly, and a liner wiper plug, which are used in cementing or other tool operations.
  • slick joint 15 together with those other components provide a conduit through which cement may be introduced into liner 2 below flow diverter 10 and cement packoff 14. As cement is introduced into liner 2, cement packoff 14 prevents cement from flowing up into liner 2 and flow diverter 10 and returns are allowed to flow from the annulus, through ports 83, and into housing 80.
  • the novel diverters also preferably incorporate a one-way seal, such as one or more lip seals or, as shown in FIG. 10A , a swab cup 86.
  • Swab cup 86 is mounted on slick joint 15 at a point above ports 83 and provides a one-way seal between slick joint 15 and housing 80. It comprises a cup-shaped elastomeric member, as is conventional in the art, which allows fluid to flow through housing 80 in an upward direction past swab cup 86. If fluid pressure is applied above swab cup 86, however, the elastomeric member will expand against and seal with housing 80 and prevent fluid flow in a downward direction.
  • swab cup or other one-way seal facilitates pressure testing of a seal established between the liner and an existing casing before a cementing operation is undertaken, yet also allows displaced fluid to flow upward through the novel flow diverters as the liner is cemented. It also will be appreciated that swab cup 86 also helps to minimize the ingress of debris into flow diverter 10 as it is run into the well.
  • Slick joint 15 also comprises an enlargement or collar 16 so that transmission 90 may be actuated to move sleeve 84 to its closed position after a cementing operation is completed.
  • FIG. 10A which shows flow diverter 10 in its run-in position where ports 83 are open
  • FIG. 10B which shows diverter 10 after ports 83 have been closed.
  • ports 83 may be closed by pulling up on work string 5 to which slick joint 15 is ultimately connected.
  • collar 16 will engage enlarged lower end 98 of carriage 91 and cause carriage 91 to move upwardly along with slick joint 15.
  • annular base 93 of collet 92 is releasably engaged with carriage 91 and enlarged ends 95 of collet fingers 94 are releasably engaged with sleeve 84, upward movement of carriage 91 will cause sleeve 84 to move upward to its closed position shown in FIG. 10 B.
  • sleeve 84 is slotted, thus providing splines 87 that are able to flex to a limited degree and, via bosses (not shown), snap into an annular groove 88 on housing 80. Sleeve 84 is thereby secured in the closed position.
  • novel flow diverters provide significant advantages over the prior art.
  • the housing of the novel flow diverters is designed to remain in the well as part of the installed liner.
  • the flow diverter not only provide an effective and sealable flow path for returns, preferably it also does so without limiting either the effective inner diameter or outer diameter of the lining as a whole.
  • the flow diverter therefore, is well within the profile of the liner assembly as it is run into the well and, once the liner is completely installed, its inner diameter is at least as great as the liner as a whole.
  • the novel flow diverters are able to provide a relatively large flow path for returns during cementing operations and, when the transmission is removed, will not present a constriction in the installed liner. Operating a cover by an externally mounted transmission inevitably will require that the inner diameter of the housing be reduced for a given casing size, thus limiting the effective inner diameter of the installed liner or creating a constriction therein.
  • the novel flow diverters comprise an opening designed to accommodate a slick joint or other conduit that extends through the diverter.
  • cement or other work fluids may be delivered to those portions of the liner below the flow diverter without diverting injected fluids around the flow diverter. That also allows the novel tools to divert returns from a cementing operation without any prior actuation of the tool. A single operation to close the ports after actuation is all that is required.
  • novel flow diverters are not limited to preferred flow diverter 10 discussed above.
  • enlarged portion 81 of slick joint 15 or other radially projecting pins and the like provide simple and effective means for mechanically engaging and manipulating transmission 90.
  • Other mechanisms may be provided for actuating the transmission of the novel flow diverters.
  • spring loaded dogs or pins may be mounted in recesses in a carriage so that they can engage slots, grooves and the like in a slick joint as it is pulled upwards.
  • a ratchet assembly similar to the ratchet ring 26 mounted between hanger mandrel 20 and swage 21, also may be provided between the carriage and slick joint to allow the slick joint to pick up the carriage as it is raised.
  • hydraulic cylinders could be connected to a carriage, or other mechanisms also could be provided for actuating the carriage instead of mechanically engaging and manipulating a slick joint.
  • sleeve 84 is adapted for upward axial movement
  • the covers of the novel flow diverters may be adapted to move downward and cover ports situated below the sleeve.
  • Spring loaded pins or dogs could be provided as discussed above to mechanically engage a carriage and slick joint for downward movement.
  • Pivotable dogs also could be provided on a slick joint. Such pivoting dogs could be situated below the flow diverter so that they swing in and under a carriage member as the slick joint is raised and then swing out into engagement with the carriage once they have cleared its upper edge and the slick joint is moved downward.
  • a carrier could be releasably engaged with the cover directly by pins, screws, rings, or the like that would shear once the cover has traveled to its closed position.
  • Radially displaceable dogs also could be mounted in J-slots in the carriage, similar to the manner in which dogs 48 are mounted in tubular section 31g as described below.
  • a sleeve with pivotable or radially displaceable dogs could be slideably supported on, and releasably engaged with a carrier, the dogs being allowed to move out of engagement with the cover into recesses in the carrier once the carrier has traveled upwards a defined distance relative to the sleeve.
  • a second preferred embodiment 110 of the novel flow diverters comprises a sleeve 184 which is slidably supported on the inner surface of a housing 180.
  • Diverter housing 180 is quite similar to housing 80 of diverter 10. It comprises a number of ports 183 which are configured and sized to allow fluid displaced during a cementing operation to flow into the interior of housing 180.
  • housing 180 Since sleeve 183 is supported on the inner surface of housing 184, however, housing 180 has a portion 181 with enlarged inner and outer diameters to accommodate sleeve 183. It also is not necessary to provide slots, such as slots 85 which are provided in housing 80.
  • sleeve 184 is supported for axial movement from an open, run-in position, in which ports 183 are uncovered by sleeve 184 as shown in FIG. 11A , to a closed, installed position, in which sleeve 184 covers ports 183 as shown in FIG. 11 B.
  • Sleeve 184 is releasably connected to and operated by a transmission 190 which is substantially identical to transmission 90 in diverter 10.
  • transmission 190 which is substantially identical to transmission 90 in diverter 10.
  • Transmission 190 as may be seen in FIGS. 11 , comprises a carriage 191 and a collet 192.
  • the enlarged ends 195 of collet fingers 194 engage corresponding recesses in sleeve 184. They are prevented from flexing out of engagement with sleeve 184 by an enlarged lower portion 198 of carriage 191.
  • collet 192 engages sleeve 184 when flow diverter 110 is run into the well.
  • ports 183 in diverter 110 are closed by raising slick joint 115, which causes its collar 116 to engage enlarged lower end 198 of carriage 191. Further pulling on slick joint 115 causes carriage 191 and collet 192 to travel upward, carrying sleeve 184 up to its closed position shutting off housing ports 183.
  • Covers also may be supported on the diverter housing for relative axial movement via threads as in, for example, another preferred embodiment 210 shown in FIGS. 12 .
  • Preferred flow diverter 210 comprises a sleeve 284 which is supported within a housing 280. They are similar in construction to sleeve 184 and housing 180 in flow diverter 110. Sleeve 284 and housing 280 in diverter 210, however, are engaged via mating threads 289. Otherwise, diverter housing 280 is substantially the same as housing 180 of diverter 110. It comprises a number of ports 283 which are configured and sized to allow fluid displaced during a cementing operation to flow into the interior of housing 280.
  • sleeve 284 is supported for axial movement, via rotation through mating threads 289, from an open, run-in position, in which ports 283 are uncovered by sleeve 284 as shown in FIG. 12A , to a closed, installed position, in which sleeve 284 covers ports 283 as shown in FIG. 12 B.
  • Sleeve 284 is releasably connected to a transmission 290 which is operable to move sleeve 284 from its open to its closed positions.
  • Transmission 290 as may be seen in FIGS. 12 , comprises a carriage 291 and a collet 292.
  • the enlarged ends 295 of collet fingers 294 engage corresponding recesses in sleeve 284. They are prevented from flexing out of engagement with sleeve 284 by an enlarged lower portion 298 of carriage 291.
  • collet 292 engages sleeve 284 when flow diverter 210 is run into the well.
  • Enlarged end 298 of carriage 291 is provided with a series of circumferentially spaced splines 299, which as may be seen in FIG. 12B , mate with circumferentially spaced splines 217 on slick joint collar 216 when slick joint 215 is raised.
  • slick joint 215 may be rotated via workstring 5, which will in turn rotate transmission 290 and move sleeve 284 upward to close ports 283.
  • FIGS. 13A and 13B Other covers may be adapted for rotational movement by providing pins on the slick joint which engage helical grooves in the inner surface of the carriage. Such rotating covers would be provided with ports that align with the ports in the tool housing when the cover is in its open position and rotate out of alignment in the closed position.
  • collet ends 395 may engage coarse threads or helical grooves 399 on the inner surface of sleeve 384.
  • preferred embodiment 310 of the novel flow diverters comprises a sleeve 384 which is slidably supported on the inner surface of a housing 380.
  • Diverter housing 380 is quite similar to housing 180 of diverter 110. It comprises a number of ports 383 which are configured and sized to allow fluid displaced during a cementing operation to flow into the interior of housing 380.
  • sleeve 384 in diverter 310 is provided with a series of ports 389 which align with ports 383 in housing 380 when sleeve 384 is in an open, run-in position, as shown in FIG. 13A .
  • sleeve 384 is supported for rotational movement from its open, run-in position, in which sleeve ports 389 align with housing ports 383 as shown in FIG. 13A , to a closed, installed position, in which sleeve ports 389 have rotated out of alignment with housing ports 383 such that they are closed as shown in FIG. 13 B.
  • Sleeve 384 is releasably connected to and operated by a transmission 390 which is similar to transmissions 90 and 190 in, respectively, diverters 10 and 110.
  • Transmission 390 comprises a carriage 391 and a collet 392 which are releasably engaged by, for example, shear wire 396.
  • the enlarged ends 395 of collet fingers 394 extend into and engage helical grooves 399 on inner surface of sleeve 384. They are prevented from flexing out of engagement with sleeve 384 by an enlarged lower portion 398 of carriage 391.
  • collet 392 engages sleeve 384 when flow diverter 310 is run into the well.
  • ports 383 in diverter 310 are closed by raising slick joint 315, which causes its collar 316 to engage enlarged lower end 398 of carriage 391. Further pulling on slick joint 315, however, causes ends 396 of collet fingers 394 to travel through grooves 399, which in turn causes sleeve 384 to rotate into its closed position shutting off housing ports 383.
  • the collet in the various preferred embodiments may be releasably engaged with the carriage by a variety of mechanisms.
  • 10 110, 210, and 310 it is provided, respectively, by shear wires 96, 196, 296, and 396.
  • that releasable engagement may be provided by radially displaceable dogs.
  • diverter 410 comprises a sleeve 484 which is slidably supported on the inner surface of a housing 480.
  • Diverter housing 480 is quite similar to housing 80 of diverter 10. It comprises a number of ports 483 which are configured and sized to allow fluid displaced during a cementing operation to flow into the interior of housing 480.
  • sleeve 484 is supported for axial movement from an open, run-in position, in which ports 483 are uncovered by sleeve 484 as shown in FIG. 14A , to a closed, installed position, in which sleeve 484 covers ports 483 as shown in FIG. 14 B.
  • Sleeve 484 is releasably connected to and operated by a transmission 490 which is similar to transmission 90 in diverter 10.
  • Transmission 490 comprises a carriage 491 and a collet 492 which are releasably engaged. In transmission 490, however, carriage 491 and collet 492 are releasably engaged via dogs 496.
  • Dogs 496 are carried in suitably configured slots in annular base 93 of collet 492.
  • dogs 496 engage an annular recess 499a in carriage 491, thus engaging carriage 491 and collet 492.
  • slick joint 415 is raised such its collar 416 engages enlarged lower end 498 of carriage 491, further pulling on slick joint 415 will cause sleeve 484 to move upward to its closed position shown in FIG. 14 B.
  • dogs 496 When transmission 490 has traveled upward to the point illustrated in FIG. 14B where sleeve 484 is in its closed position, dogs 496 will be in alignment with the lower portion of an annular recess 499b provided in the inner surface of housing 480. Applying further upward force to work string 5 and slick joint 415, therefore, will urge dogs 496 into recess 499b and out of engagement with carriage 491.
  • novel methods of installing a liner generally do not require use of the novel flow diverters, only that a port be provided in the liner downhole of the seal established between the liner and annulus and, preferably, that some means are provided for closing the port after cementing has been completed.
  • Liner assembly 1 is assembled with liner hanger 11, anchor installation tool 3, and flow diverter 10 in their run-in positions. It then may be lowered on work string 5 into existing casing 6, with or without rotation. If a liner is being installed, however, a drill bit preferably is attached to the end of the liner, as noted above, so that the liner may be drilled in.
  • Work string 5 provides a conduit for circulation of fluids as may be needed for drilling or other operations in the well. It also provides for transmission of axial and rotational forces as are required to operate installation tool 3, flow diverter 10, and other components of liner assembly 1.
  • work string 5 will be understood to include not only the tubular members from which liner assembly 1 is suspended, but also tool mandrel 30, slick joint 15, and any other tubulars or connectors which cooperate to provide a conduit or transmit operational forces.
  • liner hanger 11 will be set in existing casing 6 and released, liner 2 will be cemented in the well, and anchor installation tool 3 will be retrieved from the well, as now will be described in greater detail.
  • Liner hanger 11 is set by increasing the fluid pressure within mandrel 30.
  • liner assembly 1 preferably includes a ball seat (not shown) which is connected either directly or via tubular connections to slick joint 15 below flow diverter 10 and cement packoff 14.
  • a ball may be dropped through work string 5 and allowed to settle on the ball seat. Once it is on the seat, the ball effectively shuts off work string 5 and allows pressure to build above the ball.
  • pressure is increased further to blow the ball past the seat.
  • the subject invention is not limited to such mechanisms.
  • Other mechanisms such as blowable flapper valves, may be provided to shut off a work string and allow pressure to be built up in an installation tool.
  • the liner also may be cemented in the well bore, and the cement in the annulus will shut off flow from the liner and allow pressure to be increased in the work string to set the anchor.
  • there are important benefits in setting and releasing an anchor before the liner is cemented which may be realized by preferred aspects of the subject invention.
  • running tool 12 may be released from liner hanger 11 by releasing weight on mandrel 30 through work string 5. Alternately, in the event that release does not occur, running tool 12 may be released from liner hanger 11 by rotating mandrel 30 a quarter-turn counterclockwise prior to releasing weight.
  • mandrel 30 not only causes setting of liner hanger 11, but also causes a partial release of running tool 12 from mandrel 30. More specifically, as understood best by comparing FIGS. 6A and 6B , increasing fluid pressure in mandrel 30 causes fluid to pass through one or more ports 51 in tubular section 31g into a small hydraulic chamber 52 defined between locking piston 50 and annular seals 53 provided between piston 50 and section 31g. As fluid flows into hydraulic chamber 52, locking piston 50 is urged upward along tubular section 31g and away from dog housing 47.
  • That movement of locking piston 50 uncovers recesses in dog housing 47.
  • dogs 48 are able to move radially (to a limited degree) within those recesses. Once uncovered, however, dogs 48 will be urged outward and out of engagement with tubular section 31g if mandrel 30 is moved downward.
  • running tool 12 is partially released from mandrel 30 in the sense that mandrel 30, though restricted from relative upward movement, is now able to move downward relative to running tool 12.
  • Other mechanisms for setting and releasing dogs such as those including one or a combination of mechanical or hydraulic mechanisms, are known, however, and may be used in running tool 12.
  • running and setting tools 12 and 13 may be completely released from liner hanger 11 by first moving them to their "release” positions.
  • FIGS. 6C and 7C show running tool 12 in its release position.
  • running tool 12 is released from hanger 11 by releasing weight onto mandrel 30 via work string 5 while fluid pressure within mandrel 30 is reduced.
  • setting tool 13 which is held stationary by its engagement through stop collar 69 with the upper end of swage 21, is able to ride up mandrel 30.
  • dogs 48 now are able to move radially out of engagement with tubular section 31g as discussed above, and as weight is released onto liner assembly 1 mandrel 30 is able to move downward relative to running tool 12.
  • An expanded C-ring 54 is carried on the outer surface of tubular section 31g in a groove in dog housing 47. As mandrel 30 travels downward, expanded C-ring 54 encounters and is able to relax somewhat and engage another annular groove in tubular section 31g, thus laterally re-engaging running tool 12 with tool mandrel 30. The downward travel of mandrel 30 preferably is limited to facilitate this reengagement.
  • an expanded C-ring and cover ring assembly 55 is mounted on tubular section 31g such that it will engage the upper end of dog housing 47, stopping mandrel 30 and allowing expanded C-ring 54 to engage the mating groove in tubular section 31g.
  • running tool 12 In the event running tool 12 is not released from mandrel 30 as liner hanger 11 is set, it will be appreciated that it may be released by rotating mandrel 30 a quarter-turn counterclockwise and then releasing weight on mandrel 30. That is, left-handed "J" slots (not shown) are provided in tubular section 31g. Such "J" slots are well known in the art and provide an alternate method of releasing running tool 12 from hanger mandrel 20. More specifically, dogs 48 may enter lateral portions of the "J" slots by rotating mandrel 30 a quarter-turn counterclockwise. Upon reaching axial portions of the slots, weight may be released onto mandrel 30 to move it downward relative to running tool 12.
  • shear wires or other shear members are provided to provide a certain amount of resistance to such counterclockwise rotation in order to minimize the risk of inadvertent release.
  • Installation tool 3 may be retrieved from the well once it has been completely released from liner hanger 11 if desired.
  • the seal established between the existing casing and liner hanger by the anchor is pressure tested.
  • the novel diverters also preferably incorporate a one-way seal, such as swab cup 86 on diverter 110 shown in FIG. 10A .
  • Swab cup 86 is mounted on slick joint 15 at a point above ports 83 and provides a one-way seal between slick joint 15 and housing 80.
  • Swab cup 86 may be mounted on housing 80, but if so, it generally would be regarded as necessary to perform a drilling operation or provide a release mechanism so that swab cup 86 eventually may be removed from diverter 110. In any event, swab cup 86 allows fluid to flow through housing 80 in an upward direction past swab cup 86, but will substantially prevent fluid flow in a downward direction.
  • the pressure test may be conducted prior to or after release of the installation tool from the liner hanger. Especially if a pressure test is conducted before the installation tool is released from the liner hanger, it may be possible to repair or improve the seal by further manipulation of the installation tool. It also will be appreciated that a one-way seal, such as a swab cup, may be provided at other points above the ports in the novel diverter. It need not necessarily be disposed (in its run-in position) between the slick joint and the housing of the novel diverters. It may be located above the diverter in other portions of the liner.
  • a one-way seal such as a swab cup
  • the liner also may be completely installed and cemented in a single trip into the well.
  • the anchor is set and sealed to an existing casing, and the installation tool is released and translated a sufficient distance to provide a path for fluid flow through the anchor.
  • Cement packoff 14 is incorporated into liner assembly 1 below flow diverter 10. It includes conventional packing elements which are disposed between its outer housing, which will be left in the well as part of liner 2, and slick joint 15, which extends therethrough. Cement packoff 14 thus establishes a seal around slick joint 15 that will prevent cement introduced through work string 5 from flowing up liner 2 into flow diverter 10.
  • Cement packoff 14 preferably has drillable packings or, more preferably, packings that are retrievable by slick joint 15. The packing may be settable or pre-set.
  • the packing will be set before cement is introduced into the well.
  • a retrievable packing if desired, could provide a convenient enlargement on slick joint 15 that could be used to actuate transmission 90 of flow diverter 10 as slick joint 15 is raised.
  • a variety of conventional cement packoffs are available commercially and may be used in the novel liner assemblies. The subject invention in not limited to any particular packoff.
  • Anchor installation tool 3 when it is in its run-in position and even after release, substantially occupies the space between tool mandrel 30 and liner hanger 11. While not necessarily fluid tight, it will prevent flow of substantial volumes of fluid in either direction through liner assembly 3. In any event, installation tool 3 will not allow sufficient flow to accommodate the volume and rate of fluid displaced during a typical cementing operation. Thus, before cement is introduced into work string 5, installation tool 3 will be completely released, by either method described above, and raised up a relatively short distance to provide a flow path through liner hanger 11.
  • installation tool 3 may be pulled up to a point where running tool 12 has cleared swage 21, or at least dog housing 47 and thrust cap 45 have cleared swage 21. At this point, an annular clearance will be established between running tool 12 and casing 6 and swage 21. Slick joint 15 also will have been raised until it extends though hanger mandrel 20 and swage 21. Since slick joint 15 has an outer diameter less than the inner diameter of hanger mandrel 20 and swage 21, an annular flow path will be created through liner hanger 11 to existing casing 6. Thus, return fluids are able to flow up the lower annulus, through flow diverter 10, through liner 2 and liner hanger 11, into casing 6, and ultimately to the surface. It will be appreciated that slick joint 15 is sufficiently long so that it will still extend through flow diverter 10 and cement packoff 14 when installation tool is raised.
  • ports 83 in flow diverter 10 may be closed by pulling up on work string 5.
  • collar 16 on slick joint 15 will engage the lower end of carriage 91 in flow diverter 10.
  • transmission 90, installation tool 3, and other liner assembly components on work string 5 may be retrieved from the well.
  • Housing 80 of flow diverter 10, its ports 83 having been closed, remains in the well as part of liner 2.

Landscapes

  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)
  • Pipe Accessories (AREA)
  • Piles And Underground Anchors (AREA)
  • Check Valves (AREA)
EP13162620.2A 2012-04-05 2013-04-05 Procédés et appareil pour la cimentation de puits Withdrawn EP2647789A3 (fr)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US13/506,227 US9303477B2 (en) 2009-04-02 2012-04-05 Methods and apparatus for cementing wells

Publications (2)

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EP2647789A2 true EP2647789A2 (fr) 2013-10-09
EP2647789A3 EP2647789A3 (fr) 2017-07-26

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EP (1) EP2647789A3 (fr)
BR (2) BR102013008358A8 (fr)
CA (1) CA2811638C (fr)
MX (1) MX344176B (fr)

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WO2016060570A1 (fr) * 2014-10-14 2016-04-21 Archer Oiltools As Procédé de cimentation permettant d'assurer l'intégrité du revêtement initial sous pression supérieure
NO339650B1 (no) * 2014-10-14 2017-01-16 Archer Oil Tools As Sementering som tillater innledende forlengelsesrørtoppintegritetsttest
CN107246249A (zh) * 2017-08-07 2017-10-13 南充西南石油大学设计研究院有限责任公司 笼套式钻井堵漏装置及钻井堵漏方法
KR102179939B1 (ko) * 2020-07-17 2020-11-17 주식회사 송암 복동 유압식 쐐기형실린더로드 타입 패커
CN112177562A (zh) * 2019-07-03 2021-01-05 中国石油天然气集团有限公司 桥塞及其安装在井筒中的方法
CN114991703A (zh) * 2022-06-30 2022-09-02 铜陵有色金属集团股份有限公司 一种矿山探水钻孔裂缝用注浆封堵装置

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US6598677B1 (en) 1999-05-20 2003-07-29 Baker Hughes Incorporated Hanging liners by pipe expansion
US7048065B2 (en) 2001-07-13 2006-05-23 Weatherford/Lamb, Inc. Method and apparatus for expandable liner hanger with bypass
US7387169B2 (en) 2001-09-07 2008-06-17 Weatherford/Lamb, Inc. Expandable tubulars
US7441606B2 (en) 2003-05-01 2008-10-28 Weatherford/Lamb, Inc. Expandable fluted liner hanger and packer system
US7225880B2 (en) 2004-05-27 2007-06-05 Tiw Corporation Expandable liner hanger system and method

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2016060570A1 (fr) * 2014-10-14 2016-04-21 Archer Oiltools As Procédé de cimentation permettant d'assurer l'intégrité du revêtement initial sous pression supérieure
NO339650B1 (no) * 2014-10-14 2017-01-16 Archer Oil Tools As Sementering som tillater innledende forlengelsesrørtoppintegritetsttest
CN107246249A (zh) * 2017-08-07 2017-10-13 南充西南石油大学设计研究院有限责任公司 笼套式钻井堵漏装置及钻井堵漏方法
CN112177562A (zh) * 2019-07-03 2021-01-05 中国石油天然气集团有限公司 桥塞及其安装在井筒中的方法
CN112177562B (zh) * 2019-07-03 2023-04-25 中国石油天然气集团有限公司 桥塞及其安装在井筒中的方法
KR102179939B1 (ko) * 2020-07-17 2020-11-17 주식회사 송암 복동 유압식 쐐기형실린더로드 타입 패커
CN114991703A (zh) * 2022-06-30 2022-09-02 铜陵有色金属集团股份有限公司 一种矿山探水钻孔裂缝用注浆封堵装置
CN114991703B (zh) * 2022-06-30 2023-09-19 安徽铜冠产业技术研究院有限责任公司 一种矿山探水钻孔裂缝用注浆封堵装置

Also Published As

Publication number Publication date
MX2013003792A (es) 2013-10-14
BR102013008358A2 (pt) 2016-01-19
BR122016016988A8 (pt) 2017-07-11
BR102013008358A8 (pt) 2018-05-22
EP2647789A3 (fr) 2017-07-26
CA2811638C (fr) 2016-04-26
MX344176B (es) 2016-12-08
BR122016016988A2 (fr) 2016-01-19
CA2811638A1 (fr) 2013-10-05

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