Abstract: A buckle prevention ring assembly for use within a conduit, such as casing, having at least one buckle prevention ring may be provided. The buckle prevention ring may be bonded and may provide a fluid and gas tight seal to prevent fluid and gas from leaking out of the casing in a downhole environment.

Abstract: Completion Systems and Methods to Perform Completion Operations are disclosed. A completion system includes a tubular having a wall that defines a flowbore within the tubular and extending into a zone of an annular region external to the tubular. The completion system also includes a first port disposed in the wall and configured to provide fluid communication between the flowbore and the annular region, and a communication path disposed at least partially within the wall and configured to provide fluid communication with an annulus of a well outside of the zone. The completion system further includes a second port disposed in the wall and configured to provide fluid communication between the flowbore and the communication path, a cover disposed over the second port and configured to prevent fluid communication during a fracturing operation, and a diverter seat disposed in the flowbore of the tubular uphole of the second port.

Abstract: A method for sealing a wellhead assembly having a first outer tubular member, a second outer tubular member mounted on the first outer tubular member and an inner tubular member landed in the first outer tubular member. The method includes: providing a packoff assembly having a lower packoff which is releasably connected to an upper packoff releasably connecting an installation tool to the upper packoff; positioning the lower packoff between the inner tubular member and the first outer tubular member and the upper packoff between the inner tubular member and the second outer tubular member; locking the lower packoff to the first outer tubular member; disconnecting the installation tool from the upper packoff; removing the second outer tubular member from the first outer tubular member; removing the upper packoff from the lower packoff; and mounting a third outer tubular member on the first outer tubular member.

Abstract: Use of a sealing material which is a multifilament or spun yarn coated with a joint sealing composition to seal a joint in a pipe system in which system a fluid having corrosion inhibitors such as diammonium dimolybdate or benzotriazole; and/or sludge removers; and/or an alcohol such as propane diol, or ethylene glycol; and/or a hydrocarbon such as diesel, including biodiesel, fuel oil, or hydraulic oil; and/or steam at a temperature of at least 180° C. and a pressure of at least 10 bar (1000 kPa); is to be passed through the sealed joint. It is surprising that the sealing materials of the invention can maintain a sealed joint despite exposure to such materials.

Abstract: A packoff device is disclosed for sealing an annulus within a wellbore, and for bypassing the sealed annulus. The packoff device may include a mandrel having a bore formed axially therethrough and first and second ports extending radially from the bore. A sealing element that extends radially-outwardly from the mandrel may be positioned axially between the first and second ports, and may create a seal within an annulus between the mandrel and a casing, to isolate a portion of the annulus above the sealing element from a portion below the sealing element. A sleeve within the bore may, with the mandrel, form a channel providing fluid communication between the first and second ports. The sleeve may be movable between open and closed states. The first and second ports may be unobstructed by the sleeve in the open state, one or more may be obstructed in the closed state.

Abstract: A packoff assembly for sealing between an inner tubular member and an outer tubular member has a lower packoff which is configured to seal between the inner and outer tubular members, an upper packoff which is configured to seal between the inner and outer tubular members above the lower packoff, the upper packoff being releasably connected to the lower packoff and, when connected to the lower packoff, being axially movable relative to the lower packoff between a first position and a second position, a latch ring which is supported on the lower packoff, the latch ring being radially expandable into a corresponding locking groove in the outer tubular member, and a locking mandrel which is operably engaged by the upper packoff such that upon axial movement of the upper packoff from the first position to the second position, the locking mandrel expands the latch ring into the locking groove to thereby lock the upper and lower packoffs in position between the inner and outer tubular members.

Abstract: Embodiments disclosed herein describe fracturing methods and systems, wherein pressure differentials and fluid flow rates may be utilized to stimulate multiple zones, sleeves, or ports with the same tool.

Abstract: A valve collar for use with a fluid actuated downhole tool includes a mandrel having one or more valve cylinders formed in the wall thereof, the valve cylinders formed at an angle to the mandrel. The valve cylinders may be connected to each other, to the interior of the mandrel, and to the fluid actuated downhole tool through end holes, slant shell holes, and radial holes. Each valve cylinder may include a valve assembly inserted thereinto.

Abstract: The invention discloses a test joint assembly for testing subsea BOP stack valves and annulars in one trip. The test joint assembly has an outer mandrel and a telescopically extendable inner mandrel. The inner mandrel seals against a bottom sub member using a bullnose sealing member.

Abstract: Wellbore assembly for injecting fluid into a subsurface formation having multiple intervals comprising a plurality of packers having bypass channels at desired locations between the respective intervals. The assembly allows fluid to be injected down a tubing string, back up an annular region, and through the series of packers to impart incremental pressure drops along the intervals. The assembly enhances pressure support by allowing the operator to optimize wellbore injection along intervals having different formation characteristics.

Abstract: A plug for a seal bore in a packer mandrel has a shiftable annular member that can selectively open bypass ports to facilitate latching and then be shifted as part of a release from the plug by a running tool to close the bypass passage that go around a frangible barrier that will later be broken by impact force. The annular member has minimal structure internally to allow attachment of the running tool. The annular member drillout proceeds quickly with minimal cuttings and the frangible member is broken by impact. On an assembly with multiple packers getting plugs a trip is saved as a plug is delivered into a lower packer with a string supporting the packer above. The plug is set in the lower packer allowing release of the running string for subsequent placement and setting of the next packer in the same trip.

Abstract: A downhole tool having a throughbore is disclosed for use in a tubular located in a wellbore. The downhole tool has a sealing element configured to seal an annulus between the downhole tool and an inner wall of the tubular; at least one flow path formed in the downhole tool, wherein the flow path is configured to allow fluids in the annulus to flow past the sealing element when the sealing element is in a sealed position; and at least one valve in fluid communication with the flow path and configured to allow the fluids to flow through the flow path in a first direction while preventing the fluids from flowing through the flow path in a second direction. A guard may be installed proximate anchor elements. The guard extends radially beyond an outer diameter of the anchor elements when the anchor elements are in a retracted position.

Abstract: A technique enables sealing of downhole components by providing a downhole pressure barrier for communication lines. The system comprises a communication line cementing sub that may be coupled into a tubing string. The cementing sub comprises a flow passage, a radially protruding region, a first connector, and a second connector. The first connector is generally disposed on a first longitudinal end of the radially protruding region, and the second connector is disposed on a second longitudinal end of the radially protruding region. Additionally, a passageway extends through the radially protruding region from the first connector to the second connector. The first and second connectors enable routing of a communication line through the radially protruding region.

Abstract: A snubbing plug is configured to be secured within a component of a mineral extraction system by an internal locking mechanism. In addition, the snubbing plug enables pressure equalization of regions above and below the plug before removal of the plug. Upon insertion of the snubbing plug into a well component, pressure may be equalized via fluid pathways through the snubbing plug. The pathways are sealed closed during snubbing operations and opened again when snubbing operations are complete. Manipulation of the fluid pathways may be accomplished via rotation of a load ring within the snubbing plug.

Abstract: A downhole tool has a mandrel with packing elements. Collars between the packing elements define ports communicating with gaps between the packing elements and the mandrels. Opposing piston housings on the mandrel can move in opposing directions to compress the packing elements against the collars. Each piston housing defines a space with the mandrel and has a second port communicating with the gap. Pistons disposed in the spaces are temporarily affixed thereto. Hydraulic pressure communicated through the mandrel's bore acts against the pistons. While affixed to the piston housings, the pistons move the piston housings toward the packing elements to compress then. When the packing elements set, continued pressure breaks shear pins affixing the pistons to the piston housings so the pistons move and eventually seal fluid communication between the second ports in the pistons and the gaps.

Abstract: Further disclosed herein is a method for controlling fluid flow. The method includes, selectively deforming at least one selectively deformable member disposed between two tubular members that are radially aligned with one another, at least one of the at least one deformable member being positioned between a fluid inlet and a fluid outlet. The method further includes regulating flow of fluid by deforming the at least one deformable member positioned between the fluid inlet and the fluid outlet sufficiently to achieve a desired flow rate.

Abstract: A gas lift system is provided for use in unloading a fluid from a perforation interval of a subterranean well to facilitate producing gas from a gas-bearing formation. The system may include a packer having dual ports, a tubing string running from the surface to the packer for producing the well, and an injection tool extending below from the packer into the perforation interval. The injection tool may include at least one gas lift valve for injecting gas into the perforating interval of the well.

Abstract: The invention concerns a unit for a down hole well tool comprising a tool unit comprising at least one first fluid conduit and a return fluid conduit in use forming a well annulus space between the tool unit and the well bore. The tool unit is arranged with at least one piston provided for dividing the well annulus space into at least two well annulus spaces. The communication of fluid between the adjacent well annulus spaces at each side of the piston is controlled by the relative movement between the first fluid conduit and a control element.

Abstract: Apparatus and method for completing a wellbore including providing a packer having an inner mandrel, alternate flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting packer to tubular body, then running the packer and connected tubular body into the wellbore. In one aspect, the packer and connected tubular body may be placed along an open-hole portion of the wellbore. Tubular body may be a sand screen, with the sand screen comprising a base pipe, a surrounding filter medium, and alternate flow channels. The method includes setting a packer and injecting a gravel slurry into an annular region formed between the tubular body and the surrounding wellbore, and then further injecting the gravel slurry through the alternate flow channels to allow the gravel slurry to at least partially bypass sealing element of the packer.

Abstract: A filter sub apparatus comprising a housing configured to contain a filter and a bypass mechanism is provided. The bypass mechanism may be actuated upon debris buildup on the filter resulting in a load applied to the bypass mechanism rising above a predetermined lower level. A method to prevent chemical injection process failures may also be provided. The method may comprise the steps of providing a filter sub prior to a check valve. The filter sub may include a filter and a bypass mechanism. Another step may be passing fluid through the filter. In addition, the steps may also include containing at least some debris on a side of the filter such that the debris is prevented from reaching the check valve. A further step may be actuating the bypass mechanism after the debris builds up to a level in which a resulting load applied to the bypass mechanism exceeds a lower limit.

Abstract: A well production and injection string includes a plurality of spaced apart packers each adapted to seal with a wall of the wellbore. A plurality of flow control devices are provided in the string, distributed between pairs of adjacent packers. The flow control devices are adapted to communicate flow between an interior and an exterior of the string with less restriction to flow from the interior to the exterior of the string than to flow from the exterior to the interior of the string.

Abstract: Apparatuses and methods to communicate with a zone below a subsurface safety valve (104, 204) independent of the position of a closure member (106) of the safety valve are disclosed. The apparatuses and methods include deploying a subsurface safety valve (104, 204) to a profile located within a string of production tubing. The subsurface safety valve (104, 204) is in communication with a surface station through an injection conduit (150,152; 250,252) and includes a bypass pathway (144, 244) to inject various fluids to a zone below.

Abstract: A downhole tool has housing components that are relatively movable. One of the components is supported downhole while a control line provides fluid pressure to move the other housing component relative to the supported component to put the tool in a first position. Loss of control line pressure allows the weight of tubulars bearing on the upper housing or rods to move it to put the tool in another position. The tubing weight overcomes the hydrostatic pressure in the control line even when there is no applied pressure in the control line to cause relative housing or rods movement to operate a tool. In that sense the tool can be fail safe to shut off flow, for example, on loss of control line pressure while reducing or elimination the need for a large return spring to offset hydrostatic pressure.

Abstract: A system for positioning a downhole tool along a pipe string, the system having a series of seating subs inserted along the length of the pipe string wherein each seating sub has a seating aperture disposed around its internal periphery so as to form a bore plug seat of smaller diameter than the diameter of the pipe. The seating apertures are given distinctive diameters that are consecutively arranged along the pipe string length so that the aperture diameters decrease with increasing depth. A drop assembly having an aperture plugging diameter selected to pressure seal a selected aperture includes a bore pressure activated by-pass valve and firing head.

Abstract: A tool assembly having a downhole shut-in valve, a packer, and one or more ports. The downhole shut-in valve may be configured to selectively permit flow from a conduit to a target zone of a wellbore. The packer may be configured to isolate the target zone of the wellbore. The ports may be between the conduit and the target zone. The downhole shut-in valve may be configured to close in about 5 seconds or less.

Abstract: A system for positioning a wireless pipe recovery tool in a wellbore, the system having a series of locator pipe subs inserted along the length of a pipe string in a wellbore, wherein each locator pipe sub has a seat disposed around its internal periphery so as to form an aperture of s smaller diameter than the diameter of the pipe sub. The pipe subs have apertures of varied diameter and are consecutively arranged along the pipe string so that the aperture diameters decrease with increasing depth. A locator housing selected from a plurality of locator housings of varied outer diameter is attached to the wireless pipe recovery tool, the outer diameter of the locator housing selected to be slightly larger than the aperture in which the tool is intended to seat.

Abstract: Isolation systems for use in a wellbore include two or more tubular segments and at least one coupling assembly. The at least one coupling system is adapted to couple the first and second tubular segments together. The at least one coupling system is further adapted to block at least a portion of the wellbore annulus. The at least one coupling system is further configured as a leaky isolation assembly to separate the wellbore annulus into at least two isolated zones when disposed in the wellbore. At least one isolation zone has at least two outlets including a first outlet through an opening into the tubular and a second outlet past the leaky isolation assembly. The isolation system is configured to provide the isolation with hydraulics during well operation that preferentially drives fluids through the first outlet and at least substantially prevents fluid from passing the isolation assembly.

Abstract: A completion system for use in a well includes a first completion section and a second section. The first completion section has a sand control assembly to prevent passage of particulates, a first inductive coupler portion, and a sensor positioned proximate to the sand control assembly that is electrically coupled to the first inductive coupler portion. The second section is deployable after installation of the first completion section. It includes a second inductive coupler portion to communicate with the first inductive coupler portion, to enable communication between the first completion section's sensor and another component coupled to the second section.

Abstract: A pressure or flow responsive valve is provided in a hydraulic fracturing assembly so that if the formation sands out during proppant pumping and pressure in the bypass to the annulus around the work string rises, the bypass is closed by the valve to prevent overpressure of lower pressure rated components further uphole from the formation being treated. These components could be large casing or the blowout preventer assembly.

Abstract: Apparatuses and methods to communicate with a zone below a subsurface safety valve (104, 204, 404) independent of the position of a closure member (106) of the safety valve. The apparatuses and methods include deploying a subsurface safety valve (104, 204, 404) to a profile located within a string of production tubing. The subsurface safety valve (104, 204, 404) is in communication with a surface station through an injection conduit (150,152; 250,252; 450; 452) and includes a bypass pathway (144, 244, 444) to inject various fluids to a zone below. A redundant control to actuate subsurface safety valve (104, 204, 404) can include a three-way valve (180, 280) or three-way manifold 480 connecting the injection conduit (150,152; 250,252; 452) or the hydraulic ports (140,142; 240,242; 442?) to the subsurface safety valve (104, 204, 404).

Abstract: A flow control packer (FCP) includes a packer mandrel, and an inflatable element fixedly attached at each end to the mandrel. The inflatable element includes circumferential grooves and flow control grooves formed on an outside surface thereof configured to press against the inside diameter of a conduit to provide a flow resistant surface for controlling the flow rate of a fluid through the conduit. A system can include one or more flow control packers (FCP) configured to control fluid flow through different sections of the conduit.

Abstract: A technique involves collecting formation fluids through a single packer having at least one drain located within the single packer. The single packer is designed with an outer structural layer that expands across an expansion zone to facilitate creation of a seal with a surrounding wellbore wall. An inflatable bladder can be used within the outer structural layer to cause expansion, and a seal can be disposed for cooperation with the outer structural layer to facilitate sealing engagement with the surrounding wellbore wall. One or more drain features are used to improve the sampling process and/or to facilitate flow through the drain over the life of the single packer.

Abstract: A downhole fiber optic wet connect and gravel pack completion. In a described embodiment, a system for making fiber optic connections in a subterranean well includes a first fiber optic connector positioned in the well and a second fiber optic connector operatively connected to the first fiber optic connector after the first fiber optic connector is positioned in the well. A method of monitoring a subterranean well includes the steps of: positioning a fiber optic line in the well, the fiber optic line extending in a formation intersected by the well; positioning another fiber optic line in the well, the fiber optic line extending to a remote location; operatively connecting the fiber optic lines while the fiber optic lines are in the well; and monitoring a well parameter using a sensor operatively coupled to the fiber optic line extending in the formation.

Abstract: A fracing and production configuration including a tubular having a plurality of openings. The openings having a beaded matrix therein, a valve sub in operable communication with the tubular and an underminable plugging material plugging each of the beaded matrixes. A method for fracing and producing from a wellbore in a formation.

Abstract: Passive completion optimization with fluid loss control. A completion string includes a set of well tools interconnected as a portion of the completion string, the well tools including a well screen assembly, at least one valve which controls fluid communication between an interior and exterior of the string, and two packer assemblies, each of the packer assemblies including at least one swellable seal element, and the packer assemblies longitudinally straddling the valve and the screen assembly. Another completion string includes a set of well tools interconnected as a portion of the completion string, the well tools including two packer assemblies, a well screen assembly, and the screen assembly including an inflow control device which restricts fluid flow through the screen assembly, each of the packer assemblies including a swellable seal element, and the packer assemblies longitudinally straddling the screen assembly.

Abstract: A storm plug for temporarily isolating an offshore well in deep water includes a retrievable service packer connected to a valve housing containing a movable isolation sleeve and a standing valve. The standing valve precludes the fluid flow through a portion of the isolation sleeve. The isolation sleeve being hydraulically actuated from an open position to a closed position. In the open position, fluid may flow through flow ports in the standing valve to an annular bypass area between the valve housing and the isolation sleeve. In the closed position, the isolation sleeve prevents fluid flow through the valve housing. The valve may be hydraulically actuated as compared to conventional storm valve that are set by workstring rotation. The running tool used to run the storm plug into the well may be hydraulically disconnected from the valve housing.

Abstract: Apparatuses and methods to communicate with a zone below a subsurface safety valve (104, 204, 404) independent of the position of a closure member (106) of the safety valve are disclosed. The apparatuses and methods include deploying a subsurface safety valve (104, 204, 404) to a profile located within a string of production tubing. The subsurface safety valve (104, 204, 404) is in communication with a surface station through an injection conduit (150,152; 250,252; 450;452) and includes a bypass pathway (144, 244, 444) to inject various fluids to a zone below. A redundant control to actuate subsurface safety valve (104, 204, 404) can include a three-way valve (180, 280) or three-way manifold 480 connecting the injection conduit (150,152; 250,252; 452) or the hydraulic ports (140,142; 240,242; 442?) to the subsurface safety valve (104, 204, 404).

Abstract: A system for actuating a downhole tool disposed within a work string comprising a support suspending the work string into a well bore, a launching apparatus positioned at a location remote from the work string, a tortuous path connected between the launching apparatus and the work string, and a mechanical plug that launches from the launching apparatus, traverses the tortuous path, enters the work string, and actuates the downhole tool.

Abstract: A single fluid line sliding sleeve downhole tool assembly having a top sub engaging a top connector which connects to a body that engages a middle connector which is secured to a port housing, wherein the port housing engages a lower connector and the lower connector engages a bottom sub.

Abstract: A downhole packer for providing a seal in a well bore to allow integrity testing of the well bore. The packer is set by a sleeve movable on a body of the packer being set down on a formation in the well bore. Movement of the sleeve compresses one or more packing elements. The packer further includes a by-pass channel which allows fluid to pass through the tool as it is run in the well bore, and brushes or scrapers for cleaning the well bore and preparing the location for the packer elements to be contacted upon.

Abstract: A apparatus is disclosed for attaching and sealing to the upper end of the casing allowing the inner string to be run through the apparatus. The apparatus provides a latch for anchoring the inner string and a seal for sealing on the inner string. Also disclosed is a flow path for providing for circulation of fluid between the inner string and casing annulus. Also disclosed is an inner string sub that provides a profile anchoring and sealing the inner string by the apparatus.

Abstract: A technique to facilitate deployment of power cable and at least one capillary tube through a wellbore tool, such as a packer. The technique allows both the power cable and the at least one capillary tube to extend through a single pass-through opening in the wellbore tool.

Abstract: The present invention discloses apparatus and methods for use in wellbores that comprise an inflatable element. The inflatable element is adapted for inflation by gravel. One embodiment of the invention is a method of sealing an annulus in a well that comprises expanding the inflatable element with a gravel laden slurry. The inflatable element comprises a passageway communicating between an exterior and an interior of the inflatable element. The inflatable element is capable of being connected to a sand screen and the inflatable element can be inflated with the gravel laden slurry during a gravel packing of the well.

Abstract: This invention relates to hydraulic anchor packers for use in well bores and, more particularly, to inflatable anchor packers. A hydraulic anchor packer (90) is provided having an inflatable packer element (36) incorporating a cylinder (38) and an elastomer sleeve (44) provided on the exterior surface thereof. The elastomer sleeve (44) but free of the cylinder (38) intermediate the end portions. Means are provided for causing fluid from within the cylinder (38) to flow through an aperture (48) and between the elastomer sleeve (44) and the exterior surface of the cylinder so as to radially expand the sleeve (44). Means are also provided for trapping fluid so as to prevent relaxation of the sleeve (44). Pressure relief means (92, 94, 98) permits fluid located exteriorly of the packer (90) to move past the sleeve (44) as the sleeve (44) expands whilst in engagement with a well bore wall during use. Thus, the downhole half of the sleeve (44) may freely expand and displace fluid located below the packer (90).

Abstract: The invention is a well fluid production valve that is positioned downhole in a closed condition below an upper formation packer. The valve comprises a cylindrical mandrel having central bore flow connection with the upper bore of well fluid production tubing and coaxially aligned within the lower bore of the production tubing string. Flow port apertures through the mandrel wall provide well fluid flow paths between the mandrel O.D. and the bore I.D. of the lower production tubing. These flow ports are covered to close the valve by a sliding sleeve around the mandrel O.D. The sliding sleeve is spring biased to the open position but also secured at the closed valve position by an annular piston actuated sear mechanism. Actuation pressure for opening the valve to admit a flow of well fluids from the production zone is a predetermined differential between the well pressure above the packer, usually a function of the well depth, and the operator controlled pressure within attached production tubing.

Abstract: A completion string for use in a wellbore includes a main conduit, such as a production tubing, and one or more alternate path conduits, such as shunt tubes, that extend generally in parallel with the main conduit. A flow control device is positioned in each alternate path conduit to control flow through the alternate path conduit. The one or more alternate path conduits may be adapted to carry gravel slurry to perform gravel packing operations. The one or more flow control devices in the one or more alternate path conduits may be actuated to the open position to allow communication of the gravel slurry to multiple zones in the wellbore. Once the gravel packing operation is completed, the one or more flow control devices may be actuated to the closed position to block fluid flow communication between multiple zones through the alternate path conduits during operation of the well. Other types of fluids may be communicated through the one or more alternate path conduits, such as fracturing fluids.

Abstract: An annular safety valve system provides a retrievable annular safety valve and packer. In a preferred embodiment, an annular safety valve system has an annular safety valve connected to an upper tubing string extending to the earth's surface. The annular safety valve is initially connected to the hydraulically set packer which has no openings through an inner mandrel thereof. The safety valve is retrievable separate from the packer after the packer has been set. The safety valve is rotated relative to the packer in order to release the safety valve from the packer. As the safety valve is rotated, a setting line of the packer is severed. Other transmission lines, electrical wires, etc. may be severed as well. The safety valve may then be raised to the earth's surface with the tubing above it. A replacement safety valve is also provided for installing in the packer after the prior safety valve is retrieved.

Abstract: A positive circulating valve with a retrievable standing valve therein. The valve is used with a packer positioned therebelow. The circulating valve comprises a housing with a mandrel slidably disposed therebetween. A J-slot controls movement between open and closed positions. When in the open position, mandrel ports in the mandrel are aligned with body ports in the housing so that bypassing and circulating may be carried out. The standing valve prevents fluid flow downwardly through the tool string below the circulating valve when the circulating valve is in the open position. When the circulating valve is in a closed position, the mandrel ports are in communication with a central opening through the housing, allowing fluid to be pumped downwardly through the circulating valve. The standing valve may be removed so that the circulating valve has a substantially unrestricted flow path therethrough for high flow rate fracturing jobs and the like.

Abstract: A tool is disclosed, e.g. but not limited to a wellbore cementing stage tool, which has a hollow body member with one or more lined ports through which fluid can flow from an interior of the body member to space outside the body member, e.g. to the annulus of a wellbore between an exterior surface of the tool and an interior surface of the wellbore or vice versa. The port or ports are lined with a metal tube which has a portion projecting into the body member. The projecting portion may be crushed shut forming, preferably, a metal-to-metal seal to seal off the corresponding port to flow. A hollow member is disclosed with a port through it which has a metal liner with a portion projecting from the port. Methods are disclosed for using the items with one or more lined ports.

Abstract: An apparatus is provided for use in a wellbore for reducing the effects of pressure differential forces which act on settable wellbore tools suspended therein. The apparatus operates to provide a bypass fluid flow path through the settable wellbore tool for directing wellbore fluid through the settable wellbore tool in response to pressure differentials developed across the settable wellbore tool during outward radial expansion of the tool. The apparatus further includes mechanisms for maintaining the bypass fluid flow path in an open condition during at least an expansion mode of operation to diminish the effects of pressure differential developed across the settable wellbore tool. The apparatus also includes mechanisms for closing the bypass fluid flow path once a setting mode of operation is obtained.