Abstract: A method of monitoring a reservoir comprising setting at least one barrier in a well separating it into upper and lower isolated sections. A perforating gun or other perforating device is provided in the lower isolated section, along with a control mechanism, wireless communication device and a pressure sensor. After the barrier is set, the perforating gun is activated in order to create at least one perforation between the well and a surrounding reservoir. The well, or part of it, is suspended or abandoned but the pressure is still monitored and a wireless, preferably acoustic or electromagnetic, data signal is transmitted from the lower isolated section to above the barrier. Data from the suspended/abandoned part of the well may be used to infer characteristics of the reservoir so that it may be exploited more appropriately especially through another well.

Abstract: A system and method to controlling fluid flow to/from multiple intervals in a lateral wellbore. The system and method can include a unitary multibranch inflow control (MIC) junction assembly (a primary passageway through a primary leg and a lateral passageway through a lateral leg) installed at an intersection of main and lateral wellbores. An upper energy transfer mechanism (ETM) can be mounted along the primary passageway, and control lines 100 can provide communication between the upper ETM 214 and lower completion assembly equipment. A lower ETM can be mounted along the lateral passageway, with the upper ETM in communication with the lower ETM via the control lines. A tubing string can be extended through the primary passageway to access lower completion assembly equipment. The upper ETM can communicate with a tubing string ETM to receive/transmit control, data, and/or power signals from/to lower completion equipment in the lateral wellbores.

Abstract: A method for reviving a well may include deploying a tube between a casing and a wellbore tubular of the well. The tube may extend from a surface through a port at a wellhead of the well to a section of the well at a depth above a packer. The method may include pumping down, through the tube, non-corrosive material into the section of the well. The well may be blocked below the packer by well blockage. The method may include destroying the well blockage by dissolving the well blockage using the non-corrosive material. The method may include pumping up, through the wellhead, the well blockage dissolved in the non-corrosive material.

Abstract: Systems and a method for efficient downhole separation of gas and liquids while providing well access are provided. An exemplary system provides a downhole gas separator for an artificial lift system. The downhole gas separator includes an outer casing joined to production tubing at one end and comprising a fitting for a plug at an opposite end from the production line. The outer casing comprises openings through the outer casing. A dip tube extends through the interior of the outer casing, wherein the dip tube is fluidically coupled to the production tubing at one end, and is open to the outer casing at an opposite end, wherein the opposite end is proximate to the fitting for the plug. The plug is disposed in the fitting, and comprises a retrieval bar configured to allow the plug to be pulled through the production tubing to the surface.

Abstract: A method of latching a production tubing to a packer in a wellbore, an assembly, and a connection, of which the method includes lowering the production tubing into the wellbore, the production tubing being coupled to a first body comprising a slot and a blocking member. The production tubing is lowered until a lug on a second body contacts the blocking member, the second body being coupled to a packer. The method includes raising the production tubing relative to the packer which causes the lug to move out of contact with the blocking member, lowering the production tubing into the wellbore again until the lug contacts and removes the blocking member, and rotating the production tubing such that the lug advances into the slot, so as to latch the production tubing and the packer together.

Abstract: A well system includes an annular barrier separating the tubing-casing annulus into an upper annulus and a lower annulus and a barrier valve coupled with the annular barrier, the barrier valve permitting one-way fluid communication from the upper annulus to the lower annulus. The annular barrier may include dual cup packers.

Abstract: A wellbore plug isolation system and method for positioning plugs to isolate fracture zones in a horizontal, vertical, or deviated wellbore is disclosed. The system/method includes a wellbore casing laterally drilled into a hydrocarbon formation, a wellbore setting tool (WST) that sets a large inner diameter (ID) restriction sleeve member (RSM), and a restriction plug element (RPE). The WST is positioned along with the RSM at a desired wellbore location. After the WST sets and seals the RSM, a conforming seating surface (CSS) is formed in the RSM. The CSS is shaped to engage/receive RPE deployed into the wellbore casing. The engaged/seated RPE isolates heel ward and toe ward fluid communication of the RSM to create a fracture zone. The RPE's are removed or left behind prior to initiating well production without the need for a milling procedure. A large ID RSM diminishes flow constriction during oil production.

Abstract: A method of treating a first bore and at least one second bore connected to the first bore in one downhole trip includes guiding a treating tool including a seal assembly defining and a shroud extending about the seal assembly downhole, guiding the seal assembly and the shroud along a diverter positioned near an intersection of the first bore and the at least one second bore into the at least one second bore, shifting the shroud relative to the seal assembly exposing the seal assembly in the at least one second bore, performing a first treatment in the at least one second bore, positioning the seal assembly and the shroud uphole of the diverter, passing the seal assembly through an opening in the diverter having a diverter opening, and performing a second treatment in the first bore.

Abstract: A method of plugging a well extending into a formation to facilitate temporary or permanent abandonment of the well. The method comprises conveying in one trip, a plug assembly and one or more explosive charges through the well together with a structure for providing wet sealant. The plug assembly comprises a foundation plug for supporting the wet sealant. The plug assembly is set beneath a plug formation location, prior to providing the wet sealant. The method also comprises providing the wet sealant to the plug formation location via the structure, so as to submerge the one or more explosive charges in the wet sealant, and then detonating the one or more explosive charges in the wet sealant at the plug formation location to cut through a tubular or tubulars of the well and into the formation.

Abstract: The invention concerns a radially expandable metal tubular element having on its outer surface a series of spaced apart annular sealing modules. This element is noteworthy in that each sealing module comprises two annular metal abutments between which there are inserted an annular seal and two anti-extrusion rings, the seal being positioned between the two anti-extrusion rings and the two metal abutments being secured against the outer surface of the said tubular element, in that the two anti-extrusion rings are made in elastically and plastically deformable material and are in one or two parts, and in that the two anti-extrusion rings and/or the seal comprise at least two opposite facing bevelled surfaces capable of sliding relative to one another under the effect of axial movement of the said seal so as to cause outward radial displacement of one of the anti-extrusion rings or at least one of the two parts thereof.

Abstract: Methods and apparatus are provided for conducting multiple successive same-location firings of a number of shaped charges carried by a perforating gun that is lowered into the wellbore and precisely positioned to align its charges with the penetration created by the first fired-charges in order to produce deeper and larger diameter penetrations that result in enhanced hydraulic fracturing of the reservoir and increased gas production from the completed well.

Abstract: A gravel pack system can include a manifold having at least three flow passages isolated from each other, with each of the passages intersecting a same lateral cross-section. A method can include displacing a service string, thereby controlling flow through ports that provide communication with a manifold exterior, the manifold including at least three flow passages, one port providing communication between one passage and the manifold exterior, and another port providing communication between another passage and the manifold exterior, and in one position of the service string, the one passage is in communication with a well annulus via another port providing communication with the manifold exterior, and the one passage is in communication with another well annulus via the one port, the annuli being isolated from each other by a packer, and the other port is in a seal bore and disposed longitudinally between the other ports.

Abstract: A downhole tool or plug is used for sealing in tubing. A mandrel of the tool has a first shoulder disposed toward a downhole end of the mandrel. A sealing element for sealing in the tubing is disposed on the mandrel adjacent the first shoulder, a slip is disposed on the mandrel adjacent the sealing element, and a cone is disposed on the mandrel adjacent the slip. In setting the tool, the cone moves toward the first shoulder, wedges the slip against the tubing, and compresses the sealing element between the slip and the first shoulder. Force applied against a seated plug in the mandrel transfers through the mandrel to the cone and slip without passing through the sealing element.

Abstract: A method of completing a wellbore is disclosed that in one non-limiting embodiment includes: placing a lower completion assembly that includes a flow device to provide fluid communication between the lower completion assembly and a production zone associated with the lower completion assembly; placing an isolation assembly with a packer above the lower completion assembly for isolating an annulus between the lower completion assembly and the wellbore; placing a flow restriction device above the packer; setting the flow restriction device in the annulus to restrict flow of fluid through the annulus; and setting the packer after setting the flow restriction device.

Abstract: A convertible downhole device comprises at least one sacrificial material to provide two or more configurations so that two or more different operations or functions are performable by the downhole device, one in which the sacrificial material is fully intact and another in which the sacrificial material is at least partially removed or disappeared. The sacrificial material may be removable through any suitable method or device, such as by contacting with a fluid, by temperature, by pressure, or by combustion, ignition, or activation of a fusible or energetic material, or crushing or breaking up of a frangible material. Upon removal of the sacrificial material, the downhole device has at least one additional configuration so that at least a second operation can be performed by the downhole device.

Abstract: A packing element comprising a tube having a longitudinal length. The tube includes a first end and a second end opposing the first end, an external portion including a plurality of circumferential ribs, and an internal portion opposing the external portion. The internal portion of the tube includes i) a central portion extending along a portion of the longitudinal length of the tube between the first end and second end of the tube, wherein the central portion includes a relief, ii) a first tapered portion radially tapering along the longitudinal length from the central portion towards the first end, and iii) a second tapered portion tapering along the longitudinal length from the central portion towards the second end.

Abstract: Methods and apparatus are provided for conducting multiple successive same-location firings of a number of shaped charges carried by a perforating gun that is lowered into the wellbore and precisely positioned to align its charges with the penetration created by the first fired-charges in order to produce deeper and larger diameter penetrations that result in enhanced hydraulic fracturing of the reservoir and increased gas production from the completed well.

Abstract: A method for inserting a conduit into a wellbore includes inserting the conduit into the wellbore until an upper end of a predetermined section thereof is disposed proximate a selected position in the wellbore and reducing pressure in the conduit to a predetermined pressure.

Abstract: A buoyancy fluid is sealed in an interior central bore of a completion liner with a plug assembly in the interior central bore. The buoyancy fluid has a lower density than the fluid contained in the wellbore. The buoyancy fluid reduces the force, and thus friction, at the interface between the liner and the bottom of the wellbore while the completion liner is being run to final depth. When the buoyancy fluid is no longer needed, the plug assembly can be withdrawn uphole from the completion liner and to the surface.

Abstract: An apparatus (10) for coupling a monobore riser or lubricator system (11) to a dual bore (12) subsea well, the apparatus has a rotatable bore selector (30) within a housing (20). The bore selector has at least one conduit (35) to provide through bore communication between the riser bore or lubricator (11) and selectively at least one or other of main (60) and annulus (70) bores in the dual bore (12) well. The bore selector in a first position connects the conduit between the riser or lubricator bore and the main bore, and in a second position connects the conduit between the riser or lubricator bore and the annulus bore. The rotatable selector can be offset or set at a tilt angle of up to ±5° with respect to the length of the apparatus.

Abstract: A method and apparatus for commingling sweet gas and sour gas production in a gas well having an upper sweet zone and a lower sour zone. The apparatus comprises a commingling valve which prevents cross flow of sour fluids into the sweet zone or casing annulus.

Abstract: Methods and systems of treating hydrocarbon containing formations are described herein. A system for treating a subterranean hydrocarbon containing formation includes a wellbore, and one or more packers positioned in the wellbore. At least one of the packers allows fluid to be injected in a subterranean hydrocarbon containing formation while allowing fluid to be produced from the wellbore.

Abstract: A subterranean tool can drop multiple objects to landing locations in a tubular string. The tool can keep at least one ball out of the fluid stream until ready for release. A dart or wiper plug can be kept in the fluid stream with an open bypass until axial mandrel movement allows release of the plug or dart. The tool is rotationally locked at a lower location for run in and then can rotationally lock at an upper location upon release of the dart or ball shifting relative rotation capabilities to different members. Axial movement that releases the dart also aligns a ball with a decreasing depth groove so that relative part rotation can cam the ball against a leaf spring detent and into the mandrel flow path.

Abstract: A production sleeve assembly for use downhole includes a fluid pathway configured to provide fluid communication between an exterior of a wellbore tubular and an interior of the wellbore tubular through a chamber, a flow restriction disposed in the fluid pathway, and a valve disposed in series with the flow restriction in the fluid pathway. The valve comprises a rupture disk, and a plug releasably engaged in the chamber in series with the rupture disk. The valve is configured to allow production from the exterior of the wellbore tubular to the interior of the wellbore tubular through the chamber once the rupture disk is actuated, and the valve is configured to release the plug from the chamber when the rupture disk is actuated and the pressure within the exterior of the wellbore tubular is greater than the pressure within the interior of the wellbore tubular.

Abstract: A production sleeve assembly for use downhole comprises a fluid pathway configured to provide fluid communication between an exterior of a wellbore tubular and an interior of the wellbore tubular, a flow restriction disposed in the fluid pathway, and a valve disposed in series with the flow restriction in the fluid pathway. The valve comprises: a rupture disk and a plug releasably engaged in the fluid pathway in series with the rupture disk. The valve is configured to allow production from the exterior of the wellbore tubular to the interior of the wellbore tubular through the chamber without producing past the plug once the rupture disk is actuated.

Abstract: A rupture disc assembly and a float tool incorporating the rupture disc assembly is disclosed. The rupture disc assembly may include a rupture disc assembly comprising a rupture disc, an upper tubular portion and a lower tubular portion, and a securing mechanism for holding the rupture disc between the upper and lower tubular portions. A float tool for creating a buoyant chamber in a casing string may include the rupture disc assembly and a sealing device for sealing the lower end of the casing string, the buoyant, sealed chamber may be created there between. In operation, applied fluid pressure causes the rupture disc to move downward. The rupture disc may be shattered by contact with a surface on the lower tubular portion. Full casing internal diameter may be restored in the region where the rupture disc formerly sealed the casing.

Abstract: A wellbore treatment tool for setting against a constraining wall in which the wellbore treatment tool is positionable, the wellbore treatment tool including: a tool body including a first end formed for connection to a tubular string and an opposite end; a no-go key assembly including a tubular housing and a no-go key, the tubular housing defining an inner bore extending along the length of the tubular housing and an outer facing surface carrying the no-go key, the no-go key configured for locking the no-go key and tubular housing in a fixed position relative to the constraining wall, the tubular housing sleeved over the tool body with the tool body installed in the inner bore of the tubular housing; and a sealing element encircling the tool body and positioned between a first compression ring on the tool body and a second compression ring on the tubular housing, the sealing element being expandable to form an annular seal about the tool body by compression between the first compression ring and the second c

Abstract: A method of cementing a liner string into a wellbore includes deploying a liner string into a wellbore; pumping cement slurry into a workstring; and pumping a dart through the workstring, thereby driving the cement slurry into the liner string. The dart engages a first wiper plug and releases the first wiper plug from the workstring. The dart and engaged first wiper plug drive the cement slurry through the liner string and into an annulus formed between the liner string and the wellbore. The dart and engaged first wiper plug land onto a first fracture valve. The dart releases a first seat into the first wiper plug. The dart engages a second wiper plug connected to the first fracture valve and releases the second wiper plug from the first fracture valve.

Abstract: An internal bidirectional tubing plug is adapted for insertion into a tubing string for sealing the tubing string internally while running the tubing into a fluid filled well. The tubing plug is comprised of a body having an inner surface with a recess; the recess holds petals and a keystone petal that are held by a cork that is held by a nut. At depth the tubing is filled with well fluid and the tubing plug is released at a predetermined hydraulic pressure, and the pieces are pumped to bottom or the pieces are circulated out of the well.

Abstract: Systems include a well having a production casing and a production tubing positioned therein, forming an annulus there between. A packer is positioned in the annulus at a position sufficient to separate the annulus into a first portion and a second portion. The well further includes a tie-back conduit positioned in the first portion of the annulus and configured to allow heat transfer between a working fluid flowing through the first portion of the annulus and a production fluid flowing through the production tubing, thus separating the circulating working fluid from fluids in the second portion of the annulus. A working fluid loop is fluidly connected to the first portion of the annulus. Co-production methods, methods of modeling, and computer-readable media including the methods of modeling are disclosed.

Abstract: A separator for downhole measuring during sampling in a subterranean formation. The separator allows for mixed fluid phases to be separated while flowing formation fluid therethrough.

Abstract: A zone isolation assembly for a fluid monitoring system in an existing subsurface well includes a fluid receiving pipe, a docking receiver, a docking apparatus and a first sealer. The fluid receiving pipe includes a pipe interior and a fluid inlet structure. The fluid receiving pipe receives a fluid through the fluid inlet structure into the pipe interior. The docking receiver is connected to the fluid receiving pipe. The docking apparatus moves between (i) a docked position wherein the docking apparatus is docked with the docking receiver, and (ii) an undocked position wherein the docking apparatus is undocked with the docking receiver. The first sealer is spaced apart from the docking apparatus. In certain embodiments, the first sealer selectively forms a fluid-tight seal between the fluid receiving pipe and the casing to divide the fluid zone into a first zone and a spaced apart second zone.

Abstract: Apparatus, assembly and process for allowing gas lift operations to be conducted along a relatively long perforated interval below a packer in a subterranean well. An elongated segregation member is lowered into locking engagement with a bypass mandrel secured to a tubing string above the packer. This segregation member is configured and dimensioned to define two fluid flow paths. A first flow path extends from the surface of the earth through the annulus formed between the tubing string above the packer and casing secured in the well, the bypass mandrel, a bore through a portion of the segregation member and the interior of the tubing string below the packer. A second flow path extends from the subterranean region penetrated by the well through the annulus formed between the tubing string below the packer and casing secured in the well, the annulus between the segregation member and the packer, and the interior of the tubing string above the packer.

Abstract: A gas lift production apparatus is provided for use in flushing and snubbing well operation. The apparatus comprises upper production string and lower production string. The upper production string includes at least one side pocket mandrel carrying a gas lift valve, tubular strings connected with every side pocket mandrel, a sliding sleeve installed as part of the production string below side pocket mandrels and a latch seal assembly threaded in the tubular string below the sliding sleeve. The lower production string includes a single bore packer below the latch seal assembly, tubular strings, a landing nipple and a bell mouth at the bottom of the production string. The upper production string are run in and removed as a single unit from the packer which is anchored within the well casing. It is emphasized that this apparatus is provided with three functions such as producing a gas lift well, flushing well and snubbing well operation.

Abstract: A tubular introduced into a wellbore is perforated at pre-selected locations after the tubular has been cemented into place. The locations of the perforations are determined by modeling inflow performance of a stimulation fluid within the formation. The inflow performance parameters include reservoir porosity, permeability, pressure, damage skin and intrusion depth, perforation diameter and penetration depth or perforation crushed zone damage and intrusion depth.

Abstract: An apparatus, system, and method useful for discouraging the extrusion of at least one deformable member of a device into a space adjacent to the deformable member when the device is disposed within a borehole and the deformable member extends from the device to the borehole wall involves at least one expandable member disposed upon the device. The expandable member is expandable into the annulus to reduce the width thereof and retractable therefrom to allow movement of the device within and out of the borehole and redeployment of the expandable member. The apparatus, system, and method are particularly suited for limiting the extrusion of packer elements.

Abstract: A one-trip squeeze pack system has a unique service seal unit design using concentric tubing, with the inner tubing an extension of the traditional wash pipe and is later used as the production tubing. The inner tubing contains a ported sub which can be isolated in various positions within the outer tubing by way of seals located above and below the ported sub. This seal unit is raised and lowered on the production string and isolated at various positions in order to accomplish setting the packer, running a packing job, reversing out packing fluid, and receiving production fluids.

Abstract: A one-trip squeeze pack system has a unique service seal unit design using concentric tubing, with the inner tubing an extension of the traditional wash pipe and is later used as the production tubing. The inner tubing contains a ported sub which can be isolated in various positions within the outer tubing by way of seals located above and below the ported sub. This seal unit is raised and lowered on the production string and isolated at various positions in order to accomplish setting the packer, running a packing job, reversing out packing fluid, and receiving production fluids.

Abstract: A repositionable apparatus for perforating and gravel packing an underground well uses gravity or other means to reposition the apparatus instead of a conventional wireline or work string attached to a rig. Perforating and packing can be accomplished without a rig after the apparatus is initially placed and set in the well. One embodiment of the inventive apparatus uses a perforating gun assembly, a connected ported sub above the gun assembly, a translating annulus packer above the ported sub, a circumferential screen located above the packer, blank pipe connected above the screen, an openable port above the blank tubular pipe, and a second translating annulus packer attached to the blank tubular.

Abstract: A method and apparatus for repairing or isolating holes, ruptures, splits or old perforations in marginal oil and gas wells from producing perforations. The apparatus includes two packer assemblies, a tube assembly and a slip assembly. The packer assemblies further include expandable packer elements and a vent cone mounted on a mandrel. The mandrels of the packer assemblies are connected to opposite ends of the tube assembly. The slip assembly is housed on the mandrel of one packer assembly and is used to create a positive mechanical set of the repair apparatus when positioned over the damaged area. Once the packer apparatus is positioned and the packer elements expanded, gas from producing formations flow to the wellhead through the tube assembly without interfering with the operation of down-hole pumps. The length of the gas vent packer apparatus can be varied between the packer elements depending upon the depth of damaged casing requiring repair or isolation.

Abstract: A sand control screen installation for a well includes an auger type sand control screen connected to a length of smooth-walled tubing which is disposed in a tubing seal support sub connected to a packer and having a frangible coupling interconnecting the tubing with the sub whereby the assembly may be pre-installed in a wellbore, the packer set and the tubing decoupled from the sub for reciprocation relative thereto while a fluid tight seal is maintained between portions of the wellbore to prevent underbalanced or overbalanced fluid flow during installation of the sand control screen. In an alternate embodiment, the tubing seal support sub has suitable lock mechanism for installation in a landing nipple in wells with pre-installed tubing strings and packers.

Abstract: A two-way retrievable packer plug is installed in the production bore of a flow conductor by straight insertion, and is retrieved by a one trip straight pull operation. The plug assembly includes a core mandrel which is enclosed within a tubular latch mandrel on which an annular seal assembly is mounted for sealing engagement against the production bore of a flow conductor. A latch key is yieldably biased by a coil spring for interlocking engagement with a latch retainer lug carried on a landing receptacle attached to the flow conductor. The latch key is moveable from a radially extended position in which it is engageable against the latch retainer lug so that the latch key is blocked against axial displacement relative to the landing receptacle as the plug mandrel is inserted into or withdrawn out of the flow conductor.

Abstract: A latching seal unit for use on a tubing string in a well bore for connecting the tubing string into a well packer having a receiving head provided with one or more latching lugs, the seal unit including a top sub connectable on a tubing string, a tubular locator body connected with the top sub, a latching collet cage having straight-slots mounted on the locator body formed of circumferentially spaced collet fingers defining longitudinal slots and guide surfaces providing entrances into the slots and a latching recess along each of the longitudinal slots, the longitudinal slots being sized to form an interference fit with the latching lugs in the well packer, and the latching recesses being sized to receive the latching lugs, a tubular seal body connected with the locator body, annular seal elements assemblies on the seal body for sealing with a packer bore, and a mule-shoe guide on the seal body below the seal element assemblies.

Abstract: Gravel packing systems are disclosed which permit sand fill to be reverse circulated out of a well without tripping the gravel packing system itself out of the well. The gravel packing system can be utilized with a sump packer. An outer seal assembly is constructed to be received in a bore of the sump packer. The seal assembly has a seal assembly bore therethrough which receives a lower end of a wash pipe. A wash pipe extension is partially received in the lower end of the seal assembly bore and extends downward below the seal assembly. The wash pipe extension is communicated with the wash pipe. A releasable retaining structure is operably associated with the wash pipe and the wash pipe extension and initially retains the wash pipe in the seal assembly bore. Subsequently, the wash pipe extension is released upon upward movement of the wash pipe. Methods of gravel packing are also disclosed.

Abstract: A metal-to-metal packer seal for downhole use in a well that operates in a deleteriously corrosive atmosphere. The seal is formed by the cooperating ends of two pipe sections, one of which is vertically positioned in a well with an upwardly facing metallic socket. The corresponding upper pipe section includes a connector which is lowered onto the socket and carries with it at least one, and preferably a plurality of metal rings which are extruded to form a corrosive resistant circular seal between the engaged pipe socket and pipe connector.

Abstract: A hydraulic release tubing seal divider for connecting lower and upper tubing strings together in a wellbore, including an inner housing assembly connected with one of the tubing string and middle and outer housing assemblies connected with the other of the tubing strings, including hydraulically operable locking structure carried by the middle and outer housing assemblies for locking the tubing strings together while the strings are run into a well, and for hydraulically releasing the middle and outer housing assemblies from the inner housing assembly to permit relative telescopic movement in the well between the upper and lower tubing strings at the tubing seal divider.

Abstract: A tubing assembly is disclosed for providing fluid communication and wireline access from a tubing string through a tubing remnant extending above a packer set within a casing. In combination, the tubing assembly comprises a funnel guide connectable to the lower portion of the tubing string, and a packer connectable with the tubing string above the funnel guide for establishing a sealed zone within the casing extending from above the funnel guide to the tubing remnant packer. The funnel guide further comprises a body having a lower flared skirt adapted to receive thereinto an upper portion of the tubing remnant, a central bore extending through the body, and devices on an upper portion thereof for connection to the tubing string.

Abstract: In the representative embodiment of the apparatus of the invention disclosed herein, a packer plug is arranged with sealing means for closing off the central bore of the mandrel of a packer that is set in a well bore for selectively isolating upper and lower formation intervals. When the plug is set in the packer mandrel, collet fingers on the body of the new and improved plug for threadedly engaging internal threads in the upper end of the packer mandrel. To secure the plug against unwanted release, a retainer member is cooperatively secured to the plug mandrel by a shear pin which will fail only at a predetermined force.

Abstract: A method and apparatus for inserting a seal stack in a seal bore defined by a well tool located downhole where ambient conditions would cause radial swelling of the seal stack. The seal stack is mounted at the surface in a confined space defined between a mandrel and a constraining sleeve shearably connected to the mandrel. Upon run-in of the mandrel to enter the seal bore, the constraining sleeve engages an upwardly facing surface surrounding the entrance to the seal bore which prevents further downward movement of the constraining sleeve. Application of a downward force effects the shearing of the connection between the mandrel and the constraining sleeve and permits the mandrel and seal stack to be inserted in the seal bore while the constraining sleeve moves upwardly relative to the mandrel.

Abstract: A well tool having an hydraulically releasable coupler component, a gravel packing apparatus and method for use therewith in a subterranean well having production tubing inserted therein, wherein said coupler comprises hydraulic means for releasing the tubing from the gravel pack apparatus without rotating said tubing when the coupler is activated and the tubing removed, the lower portion of the coupler remaining in the well with the gravel pack and providing a receptacle for a packing element partially inserted therethrough.