Abstract: Disclosed is a system for using pressure differential between completion fluid in an oil well and produced fluids to power downhole devices, including instruments and actuators. A conduit is provided bypassing a packer which seals a production string to a well casing. A control system, including a flow valve, allows fluid to flow to an electrical generator as needed to charge an electrical storage device. Downhole electrically operated devices, e.g. a temperature sensor and signal transmitter, draw power from the storage device. Alternatively, fluid may also be directed to hydraulically driven actuators to, for example, operate a production fluid control valve.

Abstract: A method and apparatus for use in a subterranean well is described. The apparatus typically includes a mandrel and a packing element. The mandrel may have an outer surface and a non-circular cross-section and a the packing element may be arranged about the mandrel, the packing element having a non-circular inner surface matching the mandrel outer surface such that concentric rotation between the mandrel and the packing element is precluded. The apparatus may include slips having cavities to facilitate removal of the apparatus. The apparatus also may include a valve for controlling fluid flow through a hollow mandrel. The valve may include a flapper having at least one tab to engage at least one recession in the mandrel such that rotation between the mandrel and the valve is precluded when the valve is in a closed position. The apparatus may further include a central member which is releaseably attached to the mandrel by a release mechanism.

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: A valve has a pair of surfaces, such as those of pipes, with an inflatable bladder disposed therebetween. Controlled inflation and deflation of the bladder provides for control of flow through the valve. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims. 37 CFR 1.72(b).

Abstract: A downhole zone isolation device is disclosed that features a non-spherical valve member that will not rotate while being drilled out. The valve member is retained in the isolation device so that flow uphole will not allow the valve member to exit the body of the isolation device. Bypass passages around the valve member are provided so that flow uphole can lift the valve member off its seat and flow can go around its periphery. Pressure from above seats the valve member. Nonmetallic materials speed drill-out.

Abstract: A downhole zone isolation device is disclosed that features a non-spherical valve member that will not rotate while being drilled out. The valve member is retained in the isolation device so that flow uphole will not allow the valve member to exit the body of the isolation device. Bypass passages around the valve member are provided so that flow uphole can lift the valve member off its seat and flow can go around its periphery. Pressure from above seats the valve member. Non-metallic materials speed drill-out.

Abstract: A method of pumping well fluid from a well having casing with perforations includes connecting an electrical motor to a lower end of a pump and securing the pump to tubing. A restrictor is mounted to the tubing above the pump, the restrictor having a restrictor passage. The well annulus contains a well fluid with a static level under static conditions. When the motor is started to cause the pump to operate, downward flow of well fluid contained in the well annulus flows through the restrictor passage. This reduces the amount of downward flow to increase well fluid flow through the perforations.

Abstract: A packer and method for sealing an annulus in a wellbore is provided. In one aspect the packer comprises a body having one or more conduits formed there-through; a chamber disposed within the body, wherein the chamber is in fluid communication with each of the one or more conduits; and an aperture for pressurizing the chamber. In another aspect, the packer comprises a body having one or more conduits formed there-through; a lock body disposed on a first end of the body; a collapsible member threadably engaged to the body at a first end and shouldered against the lock body at a second end; and a slideable member disposed within the collapsible member. In yet another aspect, the packer comprises a body having one or more conduits formed there-through, wherein the one or more conduits comprises an enlarged first end; and a cutting member disposed with the enlarged first end.

Abstract: A method and apparatus for use with two or more hydraulic conduits deployed downhole reduces a number of penetrations required through a well bulkhead for a given number of fluid paths extending therethrough. In a described embodiment, a fluid conductor includes multiple fluid paths extending therein. The fluid conductor is installed in an aperture formed through a bulkhead. Couplings are connected on opposite sides of the bulkhead to opposite ends of the fluid conductor. Multiple hydraulic lines are connected to each of the couplings.

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: An apparatus for in situ borehole testing having a drill string with drill pipe and drill bit. An upper sleeve and lower sleeve are telescopically coupled together. A valve seat is located in an interior passage and closes the interior passage when a valve member is seated in the valve seat. A plurality of separate inflatable packers are coupled to the lower sleeve and activated when the valve member is seated in the valve seat. A latching collet having teeth positively interlocks with spline teeth affixed to the inner wall of the upper sleeve. A hydraulic valve assembly is attached to the lower sleeve and is activated by fluid in one of a plurality of separate fluid chambers which communicate with and inflate the separate packers.

Abstract: The present invention relates to a valve system that may be used to pressure test tubing, such as a tubing string deployed in a wellbore for the production of fluids.

Abstract: A downhole tool for sealing a wellbore. The downhole tool includes a packer with a ball seat defined therein. A sealing ball is carried with the packer into the well. The movement of the sealing ball away from the ball seat is limited by a ball cage which is attached to the upper end of the packer. The ball cage has a plurality of ports therethrough for allowing flow into the ball cage and through the packer at certain flow rates. A spring is disposed in a longitudinal opening of the packer and engages the sealing ball to prevent the sealing ball from engaging the ball seat until a predetermined flow rate is reached. When the packer is set in the hole, flow through the frac plug below a predetermined flow rate is permitted. Once a predetermined flow rate in the well is reached, a spring force of the spring will be overcome and the sealing ball will engage the ball seat so that no flow through the frac plug is permitted.

Abstract: A test, drill and pull system for testing a well formation or zone of interest and further drilling of the well in a single trip into the wellbore. The system includes a surface readout tester valve, a rotation-operated reversing valve, a resettable packer, a packer lockout, a perforated anchor and a drill bit. In operation, the apparatus is run into the bottom of the well adjacent to the formation or zone of interest and the packer set and unset as desired. With the packer set, a surface readout tester valve probe is lowered into the apparatus on a wireline and latched into the tester valve so that multiple testing operations may be carried out if desired. After testing, the fluid recovery may be reversed out and analyzed by actuating the reversing valve by rotation of the tool string. Further, rotation engages the packer lockout such that when weight is picked upon the packer, the packer cannot be reset.

Abstract: A system for preventing backflow of a fluid from one zone to another, e.g. from a lower wellbore zone to an upper wellbore zone. The system is deployed in cooperation with a tube, such as a tube utilized to protect electrical or optical signal transfer lines. A one-way check valve is deployed in the fluid flow path created by the tube to prevent the backflow of an undesired fluid along the tube. A separate feed-through allows for passage of the signal transfer lines.

Abstract: An expandible packer provides a crescent-shaped cross-sectional area for more and larger diameter data cable and fluid control conduits by eccentrically offsetting the packer mandrel relative to the expandable element. The expandible element of the packer eccentrically surrounds the mandrel to provide an eccentric volume zone between the packer collars. One or more data cable or fluid carrier conduits may be laid between the collars within this eccentric zone, all of greater diameter than would be possible within an annulus between two concentric mandrels. The eccentric zone conduits are secured and protected by a compliant filler material such as rubber or other elastomer that is applied around and between the control conduits within the eccentric zone. This filler material is trimmed or cast to a substantially cylindrical surface about an axis that is substantially coextensive with the expandable element axis.

Abstract: A retrievable bridge plug having an internal bypass passage and external retrieving lugs, and a retrieving tool therefor. When the bypass passage is sealed, both the top and bottom openings of the bypass passage are closed, preventing debris from entering the bypass passage through either opening. A directing shroud is provided adjacent the top opening of the bypass passage, such that when the bypass passage is opened, part of any fluid flowing uphole through the bypass passage is directed over the retrieving lugs, clearing them of any debris and facilitating latching by the retrieving tool. The shroud also prevents debris from packing around the top opening of the bypass passage. A retrieving tool is also provided, which retrieving tool, through cooperation of a sleeve having a “J” shaped slot, and an inner latch sleeve having a straight slot, locks the retrieving tool onto the retrieving lugs.

Abstract: Apparatus for completing a subterranean well and associated methods provide economical and efficient well completions. In one described embodiment, a well completion apparatus includes a packer which is settable by application of a compressive axial force thereto. The packer sealingly engages a wellbore of the well when set therein, but does not anchor to the wellbore. The apparatus further includes a screen and an attachment device. The attachment device permits the apparatus to be attached to another packer previously set and anchored within the wellbore.

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: The invention relates to a safety packer assembly for use in a cement-lined pipe. The assembly provides for the use of a packer body which carries one or more resilient collars that expand in response to a compression force created by rotation of an upper part of the packer body. A safety valve is provided in the upper part of the packer body to prevent escape of the downhole pressure. A safety centralizer is detachably secured to a lower part of the packer body, the centralizer being provided with a plurality of arcuate resilient members which extend along the length of the centralizer body and frictionally contact the wall of the cement-lined pipe to maintain the packer body in its predetermined position within the pipe and resist rotation of a lower part of the packer body when the upper part is rotated.

Abstract: A retrievable packoff assembly for temporarily sealing a well pipe and anchoring equipment at a subsurface location within the pipe. The assembly is connected to a tubular actuation tool which is manipulated from the surface to position the assembly at a subsurface well location, set the assembly and then release from the set assembly. Right-hand tool rotation sets the assembly, releases the tool, and is subsequently employed to reengage and unset the assembly for retrieval to the surface. A bypass flow passage in the assembly is controlled by a sliding sleeve valve which is automatically closed by the right-hand tool rotation during setting and release and automatically reopened by tool rotation occurring during retrieval of the assembly. Flow through both the assembly and the bypass is confined within the actuation tool. A control flow passage in the apparatus is sealed by a retrievable blanking plug which may be removed to permit passage of equipment through the anchored assembly.

Abstract: A retrievable production packer is conditioned for initial wireline installation in a well utilizing an adapter comprising an outer sleeve and an inner rod connected to a mandrel carrying the slip assembly of the packer. The packer is frangibly supported in an initial transport condition for being set by means of a wireline setting device. A flow control device, such as a blanking plug, may be seated in the packer mandrel at the very top of the packer while being lowered into position and set with a wireline setting device. Thereafter, the tubing string may be connected to the packer downhole to release the packer and retrieve it from the well.

Abstract: A packer for a subterranean oil and/or gas well. The packer has a control signal bypass passage incorporated in the packer body. The control signal bypass passage may be opened and closed via reeled tubing to selectively allow and disallow passage of a control signal through the packer. The packer supports an electric submersible pump for enhancing flow of well fluids. The control signal bypass passage of the packer connects with a control line from the surface and with a separate control line extending downhole from the packer in the well. The control line, downhole from the packer, connects with a safety valve operable by control signal passed from the surface, through the packer, and downhole through the control signal bypass passage of the packer.

Abstract: A method and apparatus for performing a block squeeze cementing job. The invention provides for perforating the wellbore above and below the desired well formation on a single wireline trip and setting a lower packer on a wireline above the lower perforations. A stinger is positioned in the lower packer, and secondary packer elements on an upper packer are set above the upper perforations. Cementing of the lower perforations is carried out through the lower packer. The secondary packer elements are unset, and the stinger is repositioned adjacent to the upper perforations. Primary packer elements on the upper packer are then set, and the cementing of the upper perforations is carried out through the upper packer and stinger. Setting of the secondary packer elements requires only vertical movement of the tubing string and no rotation. Both cementing steps are carried out on a single tubing trip. The upper packer is retrievable, and the lower packer is of a drillable type.

Abstract: A tubular body containing a sleeve actuated safety valve is attachable to the top end of a hurricane plug. A running tool has a floating nut connection with the tubular body and a tubular extension on the running tool effects the opening of the safety valve while connected to the tubular body. After setting the hurricane plug, the running tool is disconnected from the tubular body by setdown weight, followed by rotation. A retrieving tool has an external threaded section which is threaded through an internal threaded section in the tubular body to engage the actuating sleeve for the safety valve, and effect the opening of the safety valve. Further rotation of the running tool engages the retrieving tool with the tubular body to effect the unsetting of the hurricane plug and permit the removal of the tubular body, hurricane plug and depending tool string from the well by the retrieving tool.

Abstract: A single bore packer is modified by a dual flow seal unit for gas lift completion. This permits the operator to inject lift gas into the upper casing annulus at the well head, bypass the hanger packer and conduct the lift gas into the suspended production tubing below the fluid level. The dual flow seal assembly is sealed internally against the packer mandrel, with the lift gas being conducted through a bypass flow passage between the seal mandrel and the packer mandrel, and being discharged into the lower casing annulus through a discharge port formed through the packer mandrel below the packer seal element package. The hang weight load of the production tubing is decoupled with respect to the packer seal elements by a set of internal ratchet slips which transfers the hang weight load from the packer mandrel onto the anchor slips and well casing at a location below the seal element package.

Abstract: A retrievable bridge plug apparatus, and associated methods, are provided for sealing the bore of a drill pipe string to control a well that is flowing out of control.

Abstract: A lock system for wells which includes a landing nipple in the well tubing and two embodiments of a lock mandrel, which are sealingly engageable and releasably lockable in the landing nipple to control flow through the well tubing. One lock mandrel is closed to flow and "plugs" the landing nipple. The other lock mandrel, which will operate as a standing valve, has a through flow passage and a check valve preventing downward flow through the flow passage and lock mandrel. Both lock mandrels utilize "C" rings for locking in landing nipples and may be released for expending downwardly from landing nipples by a predetermiend downward force.

Abstract: An improved packer is provided for sealingly engaging a well casing above a pressure responsive device within a petroleum recovery well. A sleeve-like packer body interior of the packer sealing elements is provided for structurally interconnecting lower and upper sections of a tubing string, and retains a large internal diameter for passing fluids or various downhole tools through the tubing string and to the bore of the packer. A plurality of tubular passageways are provided within the packer each positioned radially between the packer body and the packer sealing elements, and each extending axially from above to below the packer sealing elements. The passageways allow for communications of a fluid pressure signal from the annulus above the set packer to the firing head of a hydraulically actuatable device below the packer.

Abstract: A retrievable bridge plug apparatus has slip segments and packing elements which are extendable to outward positions. In a cased well, the slip segments grip the casing and prevent the longitudinal movement of the bridge plug. The packing elements contact the casing to provide a seal to isolate the well interval above the bridge plug from the well interval below the bridge plug. The bridge plug is retrieved from the well by equalizing pressure and then retracting the slip segments and packing elements. Pressure is equalized by pulling up on the retrieving tool, which couples to a fishing neck at the upper end of the bridge plug. Pulling up on the fishing neck opens a valve and exposes a flow path for fluid. The slip segments, and consequently the packing elements, are prevented from retracting during the equalization of pressure by a locking device. Then, the retrieving tool is set down to lower the fishing neck. Lowering the fishing neck releases the locking device.

Abstract: A through tubing bridge plug is disclosed. In the preferred and illustrated embodiment, a central hollow tube having a passage therein supports the external parts. The central passage terminates top and bottom with openings or passages. At the top end, a sleeve valve mechanism originally pinned in an open position is installed. When the installation is completed, the sleeve valve is closed by a sequence of operations to permanently close the flow path. The device is set and anchored by applying a relative downward force to an external sleeve thereby deploying multiple link toggle means to lock the device in location, additionally deploying a upwardly facing petal basket to receive a charge of sand and cement to form a plug, and also deploying a centralizer.

Abstract: An annular safety assembly comprising, between an upper cylindrical body and a lower cylindrical body, through which connecting tubes of production tubes pass, a packer and a low-bulk anchorage system consisting of a radial spacing ring, a resilient anchorage ring split along a generatrix and provided with peripheral anchorage teeth and a thrust ring which can be moved upwardly by thruster-plungers extending from the lower cylindrical body to apply the anchorage ring to the casing, and a safety valve arranged separately from the connecting tubes, which extend between the said cylindrical bodies, and below the lower cylindrical body.

Abstract: A downhole tool for controlling the flow of fluids through the well casing includes a tubular mandrel with a flow control valve therein. A radially expandable seal member encircles the mandrel and a sub-bottom defines an abutment member, attached to and movable with the mandrel, for engaging one side of the seal member. A bottom cone is positioned around the mandrel and on the opposite of the seal member from the sub-bottom. The cone has a sleeve extending therefrom positioned between the seal and the mandrel on which the seal member is carried. An upper cone is positioned around the mandrel with slips segments being positioned between the upper and bottom cones. An upper radially expandable seal member encircles the mandrel and its carried on a sleeve extending from the upper cone. A lock hub is positioned around the mandrel and on the side of the upper cone opposite the upper seal and slip segments.

Abstract: A tubing retrievable completion assembly includes a surface-controllable, safety control valve interposed between the production tubing string and a production seal unit. A gas-lift safety valve is carried within a side pocket mandrel connected in the upper production string. The upper production string, production flow safety valve and gas-lift safety valve are run in and removed as a single unit from a single-bore hanger packer which is releasably anchored within the well casing. Separate concentric flow passages are provided through the packer bore for the upward flow of formation fluid through a production stinger conduit which extends through the packer bore, and for downward flow of lift gas through the annulus between the packer bore and the stinger conduit. The completion assembly is locked into place below the hanger packer by a latch having fixed and movable collets.

Abstract: A through tubing bridge plug is disclosed. In the preferred and illustrated embodiment, a central hollow tube having a passage therein supports the external parts. The central passage terminates top and bottom with openings or passages. At the top end, a sleeve valve mechanism originally pinned in an open position is installed. When the installation is completed, the sleeve valve is closed by a sequence of operations to permanently close the flow path. The device is set and anchored by applying a relative downward force to an external sleeve thereby deploying slips to lock the device in location, additionally deploying an upwardly facing petal basket to receive a charge of sand and cement to form a plug, and also deploying a centralizer.

Abstract: Well apparatus is disclosed in which the bore through a lower tubular body adapted to be packed off and anchored within a well bore is opened and closed by a flapper pivotally mounted on the lower body and spring pressed toward closed position, and a flow tube mounted for reciprocation within the bore of an upper tubular body releasably connected to the lower body extends downwardly through the bore of the upper and lower bodies to a position for engaging and moving the flapper to open position, as the flow tube is lowered by means of control fluid supplied to a pressure responsive operator connected to the flow tube, and permitting the flapper to close as the control fluid is exhausted from the operator.

Abstract: A lower formation of a multizone well is perforated by a perforating gun lowered by wireline, and then fractured. A packer (modified Pengo packer) with a central bore and a valve seat is positioned within the casing between the lower and upper formations. A plug is set into the packer valve seat by a perforating gun and released by shearing a shear pin. The well is pressurized to maintain the plug in the valve seat, the perforating gun raised, and the casing opposite the upper formation perforated. The gun is removed, and the upper formation fractured. After a suitable flow-back period, another packer is then positioned in the casing above the upper perforated formation. The pressure differential between formations maintains the plug seated, allowing the upper formation to be produced. When a change in pressure differential raises the plug off the valve seat, the lower formation may be produced.

Abstract: The present invention comprises a mechanically set pack-off device adapted to be run into a wellbore on a tubing or pipe string, the pack-off device including upper and lower slip means, packing element means therebetween, drag block means, J-slot means to releasably maintain the pack-off device in an unset mode, ratchet means to releasably lock the device in a set mode, biasing means to maintain the set of the slip means and compression of the packing element means in the device's set mode, and closeable bypass means around said packing element means.

Abstract: A retrievable well tool for use in a subterranean well conduit utilizes plural valving elements to establish a fluid bypass around at least one annular elastomeric sealing element in response to movement of a control mandrel. The annular elastomeric sealing element actuates slips carried on the tool to engage the conduit wall in response to a differential pressure across the sealing element. The fluid bypass established by movement of the control mandrel is accomplished prior to an effective disengaging movement being imparted to the actuated slip elements.

Abstract: This application discloses apparatus in which a body means having a bore therethrough connected as part of a tubing string is packed off within a well bore, and means including a passageway in the body means by-passes the packer to connect the annulus about the tubing string above and below the packer. The packer is expanded into engagement with the well bore upon release of a means for locking it in an inoperative position, and a means for so releasing the locking means includes a piston in the passageway which in responsive to control fluid supplied through a control line in the annulus which connects with the passageway. Upon release and setting of the packer, the piston is removed from the passageway and circulation of well fluid through the connecting means between the annulus above and below the packer is controlled by a safety valve which normally closes the passageway, but which is responsive to control fluid supplied thereto through the same control line.

Abstract: A plug for coupling to the mandrel of a well packer, to convert the packer to a bridge plug, includes an equalizing valve. A fixed component of the plug is an elongated tubular member coupled to the upper end of the packer mandrel and closed at its upper end, and having longitudinally elongated ports in its side walls. The movable component of the plug includes an outer housing for receiving the upper portion of the fixed component and an inner sleeve coupled to the outer housing by means of pins extending through the elongated ports. Seals between the fixed components and the inner sleeve seal the elongated ports in the closed condition of the valve. In the open condition of the valve, ports in the inner sleeve and the outer housing communicate with the elongated ports of the fixed component. The movable component includes a fishing neck attached to the upper end of the outer housing.

Abstract: A packer actuated vent assembly comprising an outer barrel attached to a packer body, and a mandrel extension attached to the lower end of the mandrel of the packer. A valve means on the mandrel extension has a slidable valve element which slidably engages a medial portion of the outer peripheral surface of the mandrel and normally is in the opened position. The valve element has a boss thereon which engages a shoulder on the barrel and is thereby moved from the opened to the closed position when the packer mandrel, and therefore the mandrel extension, is properly manipulated to seat the packer. This combination of elements enables a tubing string to be run downhole into a borehole with the tubing string in the open configuration, so that fluid contained within the annulus flows through the opened valve means into the tubing string, thereby balancing the fluid pressure on either side of the tubing string; and when the packer is set, the interior of the tubing string is isolated from the borehole annulus.

Abstract: A retrievable inside blowout preventer valve apparatus for use in blocking undesired upwardly flow in the bore of a rotary drill string during well drilling operations is disclosed. The valve apparatus is installed and retrieved from a subsurface receiver sub connected in the drill string by movement through the bore of the drill string. When shutting off upwardly flow through the bore of the drill string, the valve automatically operably secures and seals itself in the receiver sub. A wireline retrieving tool is used to release the valve apparatus from the receiver sub and to establish a connection therebetween for retrieving the valve apparatus with the wireline.

Abstract: An apparatus and method for the insertion and disengagement of a tubing string used in a subterranean well subject to oppositely directed pressure differentials is disclosed. A packer apparatus which anchors a portion of the tubing string against rotation is used in conjunction with a disengagable on/off connector and a valve apparatus capable of withstanding oppositely directed pressure differentials. The valve apparatus can be selectively opened and closed by rotary manipulation of the tubing string through the disengagable on/off connector. Portions of the tubing string above the valve apparatus can then be inserted into the well or removed from the well or tested for pressure integrity.

Abstract: An improved method of setting a packer in a geothermal well bore under pressure to allow isolation of the wellhead valve including the steps of connecting a lubricator to the wellhead above the valve with the improved packer of the present invention in the lubricator and with a string extending into the lubricator to connect to the packer, running the packer into the well bore below the valve, releasing the packer to allow well pressure to move the packer to set position, disconnecting and recovering the running string, removing the lubricator, repairing or replacing the valve attaching the lubricator, running and connecting the string to the set packer, equalizing pressure across the packer, unsetting the slips and recovering the packer from the well bore.

Abstract: A well logging tool, for use within a well borehole having a flowing fluid therein, has a selective bypass means for directing a portion of the flowing fluid away from the housing of the well logging tool upon the flowing fluid exerting a predetermined pressure force upon a packer, whereby damage to the packer from increased pressure forces is minimized and flow characteristics of a fluid flowing at widely varying flow rates may be measured.

Abstract: A hydraulic setting tool for use with a packer having expandable anchor means for anchoring the packer in a well bore, a conduit to permit flow through the packer, and a slidable valve positioned in the conduit having an open lower position and a closed upper position. Inner and outer tubular portions are telescopically interengaged with the inner portion receiving a slidable mandrel. The tool conduit is connected to the inner sleeve with a shearable tension collar, the mandrel passing through the collar and into the conduit for engagement with the valve. Annular pistons are provided between the inner and outer sleeves and between the mandrel and the inner sleeve. A flapper valve is pivotally attached on one side to the inner sleeve for sealing the top of the mandrel. Pressurization of the inner sleeve via tubing string from which the tool and the packer are suspended pressurizes the annular spaces beneath the pistons thus forcing the inner sleeve as well as the mandrel upwardly to set the tool.

Abstract: A sand or gravel placement or packing apparatus for positioning particulates outside well screen includes pipe to conduct slurry to below the screen and receive clear liquid returning from outside the screen as the particulates accumulate upwardly, the apparatus including valving to provide for initial injection of clear fluid, for circulation slurry, for squeezing the slurry, for flusing the tubing and parts of the tool by reverse circulation, and for closing the slurry injection part below the screen and the lower end of the slurry pipe when the latter is withdrawn.

Abstract: A novel and improved method and means have been devised for releasably bridging or isolating formations in a well. The apparatus consists of a retrievable bridge plug which can be run down into a well to the desired setting depth and a packer assembly on the plug can then be activated to set the apparatus in position. After work has been performed, a retrieving tool is run into the well in order to engage the bridge plug for its removal. If sand or other foreign matter is present on top of the plug, a circulating medium may be employed to remove the foreign matter even as the retrieving tool is being lowered into engagement with the plug. The plug is designed such that pressure can be equalized on opposite sides of the plug as a preliminary to removal from the well by the retrieving tool.

Abstract: Hollow tubular members used as piling to support offshore platforms and the like are more easily aligned with a stabbing means. The base of the stabbing means is flexibly attached to the inner surface of one end of a tubular member; the tip of the stabbing means, which is rounded and pointed, projects beyond the end of the tubular member. The stabbing means can be attached to the tubular member for easy removal and can be adapted to couple with a retaining device within a companion tubular member that is to be aligned with the first tubular member. Preferably, a cable is coiled within an elastomeric material that flexibly bonds the stabbing means to the tubular member--the cable can be pulled or ripped from the material to destroy the bond and thereafter permit removal of the stabbing means.