Abstract: A flow collar for use on a dual rod drill rod assembly includes an uphole end defined in part by a first interior portion having a first interior diameter and a downhole end defined in part by a second interior portion having a second interior diameter that is larger than the first interior diameter. The flow collar further includes a plurality of radially-extending peripheral fluid passages extending through the flow collar to the second interior portion. An outer rod interfacing surface defines a continuous annular surface with a constant outer diameter.

Abstract: A technique facilitates flow control downhole via at least one flow control valve. According to an example, a flow control valve has an internal piston. Additionally, an electrically powered actuator is mounted externally to the flow control valve and connected to the internal piston via a linkage. The electrically powered actuator is responsive to electrical inputs to shift the internal piston to desired flow positions of the flow control valve.

Abstract: The dissolvable bridge plug is designed for temporarily plugging an oil and gas wellbore, and includes a mandrel, a rubber tube, a conical sleeve, a slip, and a lower sub, wherein, the mandrel, rubber tube, conical sleeve, slip, and lower sub are made of a dissolvable material. The inner surface of one end of the lower sub is arranged with an anti-preset mechanism that contacts with the other end of the mandrel. As the temperature in the wellbore is recovered and meets the condition under which the components in the bridge plug can be dissolved after the setting and fracturing operation is completed. The dissolvable bridge plug contacts with the fluids in the oil and gas well and has a dissolution reaction with the fluids, and finally is dissolved into fine particles completely.

Abstract: The present invention relates to the technical field of downhole tools of oil-gas wells, and specifically discloses a large-diameter soluble bridge plug. The large-diameter soluble bridge plug includes a fracturing ball, a cone, slips and a guide shoe. The lower end of the cone is connected with the upper end of the slips; the lower end of the slips is connected with the upper end of the guide shoe; a sealing component is arranged at a joint of the cone and the slips; and the fracturing ball is connected with the upper end of the cone in a sealing manner. A shear pin hole is formed at the upper end of the cone; and a groove is formed in an internal surface of the lower end of the guide shoe.

Abstract: A packer including a body having a first axial end and a second axial end, an element disposed about the body, and a flow passage within the body extending from the first axial end to the second axial end. The body defines a first pathway including a first port dimensioned and configured to receive a first penetrator and a second opening having a dimension smaller than the first port, the first port being located at the first axial end of the body and the second opening being located at the second axial end of the body. A second pathway defined by the body includes a second port dimensioned and configured to receive a second penetrator and a first opening having a dimension smaller than the second port, the second port being located at the second axial end of the body and the first opening being located at the first axial end of the body.

Abstract: A method for fracturing a wellbore in a formation, including positioning one or more bidirectional rotary sleeves on tubular members into the wellbore; engaging a unidirectional rotary source in a first position with a first bidirectional rotary sleeve of the one or more bidirectional rotary sleeves; operating the unidirectional rotary source to rotate the first bidirectional rotary sleeve in a first rotational direction to open at least one port in the first bidirectional rotary sleeve for providing an open fluid pathway between the first bidirectional rotary sleeve and the formation; pumping fluid through the tubular members and through the opened port to fracture the formation; engaging the unidirectional rotary source in a second position with the first bidirectional rotary sleeve; and operating the unidirectional rotary source to rotate first bidirectional rotary sleeve in a second rotational direction to close the at least one port in the first bidirectional rotary sleeve.

Abstract: A tool for fracking a formation at spaced intervals, which has an actuatable “dump” port to flush an annular space surrounding the tool when in a wellbore to thereby flush sand and reduce tendency for “sanding-in” of the tool in the wellbore. An uphole and downhole packer is provided, intermediate of which is a frac port. The dump port is located uphole thereof. Locking jaw members and a ‘j’ slot subassembly downhole of both the dump port and frac port are together used to set and unset the tool in the wellbore. A slidable sleeve opens and closes the dump port, which sleeve may be actuated by movement of the tool in the wellbore or alternatively by an actuating tool inserted in the bore of the tool. A method of carrying out fracking of the formation and flushing of the tool after each fracking operation is further disclosed.

Abstract: A down-hole tool for pressure testing production tubing within a borehole of a well returning the well to production, includes an anti-rotational device comprising a tubular housing having a first end, a second end, an outer surface, and at least one anti-rotational wing disposed on the outer surface of the tubular housing, radially extendable to engage a radial surface of the borehole to anchor the production tubing thereto; a valve for controlling the flow of down-hole fluids within the production tubing, the valve comprising a first valve member fixedly positioned within the tubular housing of the anti-rotational device and a second valve member positionable between a closed position and an open position; and a reactivation device comprising means for axially engaging an axial surface of the borehole, the reactivation device affixed to the first end of the tubular housing, wherein the production tubing may be pressure tested when the valve is in the closed position.

Abstract: A downhole tool for perforating a wellbore. A slidable plunger valve is provided, biased to cover jetting ports during run-in of the tool. A compressible packer may be provided below the jetting ports, and a jaw member provided below the packer. A “J” slot and pin arrangement may allow a three-position configuration, namely a run-in position where the packer is uncompressed and jetting ports closed, a set position where the packer is uncompressed and the jaw member forcibly frictionally engaged with the wellbore casing, and a jetting position where the packer is compressed, the tool is supplied with pressurized abrasive fluid, and the plunger valve has uncovered the jetting ports. The plunger valve may be made dual-acting, where during run-in the jetting ports are closed and a bypass port is uncovered, and in the jetting position the jetting ports are open and the bypass port is closed.

Abstract: A plug for isolating a wellbore. The plug can include a body having a first end and a second end, wherein the body is formed from one or more composite materials and adapted to receive a setting tool through the first end thereof, at least one malleable element disposed about the body, at least one slip disposed about the body, at least one conical member disposed about the body, and one or more shearable threads disposed on an inner surface of the body, adjacent the second end thereof, wherein the one or more shearable threads are adapted to receive at least a portion of a setting tool that enters the body through the first end thereof, and wherein the one or more shearable threads are adapted to engage the setting tool when disposed through the body and adapted to release the setting tool when exposed to a predetermined axial force.

Abstract: A fluid management tool for introducing fluids into a casing string incorporates a mud saver valve configured to open and allow fluid flow in response to fluid flow pressure reaching a predetermined opening pressure, and will automatically close when fluid flow pressure is reduced to or below a predetermined closure pressure, thereby preventing fluid spillage when the tool is withdrawn from the casing. The mud saver valve includes a mud saver spool having a slotted spool cage and being axially movable within a longitudinal bore in the main body of the tool, between an upper or open position in which fluid can flow out of the spool cage and into a discharge bore at the lower end of the main body, and a lower or closed position in which the lower end is seated against the exit bore to prevent flow therethrough. A check valve may be incorporated into the lower end of the mud saver spool.

Abstract: A downhole plug includes a body and an element system disposed about the body. The plug further includes a first and second back-up ring member having two or more tapered wedges. The tapered wedges are at least partially separated by two or more converging grooves. First and second cones are disposed adjacent the first and second back-up ring members.

Abstract: A bottom hole assembly is provided. The bottom hole assembly comprises an upper component, a lower component and a telescoping assembly disposed between the upper component and the lower component.

Abstract: A bottom hole assembly is provided. The bottom hole assembly comprises an upper component, a lower component and a telescoping assembly disposed between the upper component and the lower component.

Abstract: Devices and methods for fluid flow control within a production tubing string wherein a temporary flow blockage is established and selectively removed from the tubing string so that pressure testing or operation of a hydraulic tool within the string may be performed. A flow control device includes a housing that defines a flowbore therethrough with a restricted diameter portion. The restricted diameter portion presents a seating surface for a plug member and is provided by an annular shell that is shaped to project convexly inwardly. The shell may be fashioned of metal, elastomer or another suitable material, and it is capable of yielding to permit passage of a plug member upon application of a suitably great amount of fluid pressure. In operation, a plugging member is dropped in to the tubing string from the surface of the well and seats upon the seating surface.

Abstract: An apparatus (100) for actuating a hydraulically controllable device (102) disposed in a wellbore is disclosed. The apparatus (100) comprises a downhole hydraulic fluid source (134), a hydraulic fluid passageway (136) providing a communication path between the downhole hydraulic fluid source (134) and the hydraulically controllable device (102), a valve (144) disposed within the hydraulic fluid passageway (136) and a downhole electronics package (138). The downhole electronics package (138) receives a signal from the surface to operate the valve (144) from the closed position to the open position such that hydraulic pressure from the downhole hydraulic fluid source (134) actuates the hydraulically controllable device (102).

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: A packer is disclosed having a setting piston mounted on the body thereof. The packer is hydraulically set prior to treating or cementing. The packer has a sliding sleeve valve which is open during run-in. After the packer has set, the setting tool is released from the valve. The valve may then be operated through manipulation of the tubing string. The tubing string can be disengaged and reengaged into the packer body to determine if the valve has closed by measuring the pressure conditions at the surface.

Abstract: A hydraulic setting tool for setting a packer with a sliding valve therein in an operating position in a well bore. The setting tool comprises an outer housing portion slidably disposed with respect to an inner mandrel portion. A piston is connected to the outer housing portion and slidable with respect to the inner portion. The piston is responsive to tubing pressure for setting the packer. A locking dog is provided for locking said piston against further movement after setting of the packer. An actuating mandrel forms a part of the inner mandrel portion and is adapted for engaging a valve in the packer. Longitudinal movement of the tool string allows selective opening and closing of the valve in the packer.

Abstract: A subsurface well flow control system includes a series of movable sleeve type flow control devices installed in a well flow conductor at various fluid-containing fracture zones, and a shifter tool movable through the conductor and operable to selectively shift any selected number of the sleeve portions of the flow control devices, in either direction between their open and closed positions, without removing the tool from the conductor. Radially retractable anchor and shifter key sets are carried in side wall openings of the tool body, and are respectively configured to be lockingly engaged with interior side surface groove sets on the body and movable sleeve portions of any of the flow control devices. The key sets are spring-biased radially outwardly toward extended positions, and an electromechanical drive system disposed within the tool body is operative to radially retract the key sets, and to axially drive the shifter key set toward or away from the anchor key set.

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 well test string includes an annulus pressure responsive tester valve and a tubing conveyed perforating gun including a tubing pressure actuated time delay firing mechanism. A compression set packer is disposed in the test string between the tester valve and the perforating gun. The packer includes a bypass valve for communicating the well below the packer with the tubing bore. The bypass valve is operably associated with the packer so that the bypass valve is open prior to setting the packer and so that the bypass valve is closed as the packer is set. The compression set packer also includes a one-way equalizer valve for allowing one-way fluid flow from the well below the packer to the tubing bore. The equalizer valve is operably associated with a bypass valve so that the equalizer valve is inoperable when the bypass valve is open, and so that the equalizer valve is operable when the bypass valve is closed.

Abstract: The present invention provides an apparatus for casing a well. The inventive apparatus comprises: an outer casing; an inner casing positionable inside the outer casing; and a squeeze packer assembly incorporatable in the inner casing. The squeeze packer assembly is mechanically operable for sealing the annulus between the inner casing and the outer casing.The present invention also provides a method of installing an inner casing inside an outer casing. The inventive method comprises the steps of: (a) incorporating a mechanically operable squeeze packer assembly in the inner casing and (b) inserting the inner casing into the outer casing.

Abstract: A downhole tool apparatus and methods of drilling the apparatus. The apparatus may include, but is not limited to, packers and bridge plugs utilizing non-metallic slip components. The non-metallic material may include engineering grade plastics. In one embodiment, the slips are separate and held in place in an initial position around the slip wedge by a retainer ring. In another embodiment, the slips are integrally formed with a ring portion which holds the slips in the initial position around the wedge; in this embodiment, the ring portion is made of a fracturable non-metallic material which fractures during a setting operation to separate the slips. Methods of drilling out the apparatus without significant variations in the drilling speed and weight applied to the drill bit may be employed. Alternative drill bit types, such as polycrystalline diamond compact (PDC) bits may also be used.

Abstract: Treating apparatus arranged to be positioned in well bores that includes a packer that is retrievable and resettable and that provides a spaced pair of sealing elements to isolate a zone in the well bore. A valve operable within the packer is moveable among positions wherein fluid can be circulated through the operations, an open position wherein the treating fluids can be injected into the zone to be treated, and a closed position wherein the selected zone can be sealed off.

Abstract: A retrievable gravel packer and retrieving tool therefor. The gravel packer includes an inner mandrel assembly attached to an operating tool by a left-hand threaded connection. The packer is set without rotation by the operating tool to move a pusher sleeve downwardly with respect to the mandrel, compressing a packer element and setting slips into engagement with a well bore. A ratchet prevents the pusher sleeve assembly from moving upwardly with respect to the mandrel. The packer may be retrieved by the retrieving tool which has a lower collet engagable with a releasing mandrel in the packer. After releasing collets held by the releasing mandrel, the inner mandrel of the packer is released so that the packer element and slips engaged by the mandrel are disengaged from the well bore. An upper collet in the retrieving tool engages the left-hand thread in the packer mandrel so that the packer and retrieving tool may be raised out of the well bore.

Abstract: A cementing apparatus is shown for use with a wireline run setting tool. The apparatus includes a retainer with external gripping and sealing members for sealing off a lower region of the well below the sealing members. The cement retainer has a plurality of cementing ports at the lower end thereof which communicate the interior of the retainer with the lower well region. A sliding valve located within the lower end of the retainer can be moved between open and closed positions to control communication of fluids between the interior of the retainer and the lower well region. An inner body is initially received within the interior of the retainer end is retained in position by means of a collet latch. Actuation of the setting tool sets the gripping and sealing elements of the retainer and moves the inner body to shear the collet latch. This action simultaneously closes the cementing ports by moving the sliding valve within the lower end of the cement retainer.

Abstract: An injection tool for use in injecting fluids through perforations in the well bore of an oil or gas well is mechanically set and mechanically releasable. Fluid can be injected between upper and lower packing elements into a selected perforation. The upper and lower packing elements on opposite sides of the perforation into which fluid is injected are retractable, and any pressure differential across the upper packing elements or across the lower packing elements can be separately equalized.

Abstract: An improved retrievable compression set straddle packer assembly for use in oil and gas wells. The straddle packer assembly comprises an hydraulic slip assembly, an injection mandrel assembly, a packer assembly, a mechanical slip assembly, a drag block assembly, and a bypass assembly.

Abstract: A retrievable well tool for use in a subterranean well utilizes plural valving elements to establish a fluid by-pass around an annular elastomeric sealing element in response to either downward or upward movement of a control mandrel. The fluid by-pass established by movement of the control mandrel is accomplished prior to any effective disengaging movement being imparted to the cooperating cone and slip elements.

Abstract: Apparatus for setting in a bore a well tool of the type having radially expandable anchor means and a mandrel-actuated slidable valve for permitting flow through the tool. Inner and outer sleeves are telescopically interengaged for suspension from a conduit string for lowering into a well bore. A shearable tension sleeve connects the tool to the lower end of the inner sleeve. A vertically shiftable mandrel having a longitudinal bore therethrough is received within the inner sleeve for engaging the well tool valve. A ball is received within a slot in the inner sleeve and is urged into a groove formed in the mandrel by a locking collar disposed about the inner sleeve. Annular pistons are provided between the inner and outer sleeves for moving the inner sleeve upwardly responsive to pressurization of the conduit string. Such upward movement shifts the mandrel downwardly with respect to the inner sleeve and shifts the locking collar to effect locking of the inner sleeve to the mandrel in its shifted position.

Abstract: A subsurface control valve for use in shutting off a well bore. The valve comprises a valve assembly and a stinger assembly, which is run into the well bore on drill pipe with a packer placed below the valve in the string. The valve is open as the string is run into the well bore, the packer then being set, and a sliding valve in the tool being closed by a plurality of rotations of the stinger assembly, which is removed from the well bore after the sliding valve is closed. To re-open the sliding valve, the stinger assembly is run back into the well bore, into the valve assembly, and rotated a number of times in the opposite direction. The present invention includes a spring-loaded stinger to constantly bias the stinger into engagement with the sliding valve and a bearing on the stinger assembly to facilitate alignment and rotation between the stinger assembly and valve assembly so as to limit the torque applied to the valve assembly.

Abstract: Disclosed are apparatus and method of closing a conduit against fluid flow in at least one longitudinal sense, and selectively disengaging and reengaging the closure mechanism without removing the closure mechanism from the conduit. In a particular embodiment, a valve assembly may be selectively anchored and sealed to a well packer, or disengaged therefrom. The valve assembly is manipulated by an operating tool to which the valve assembly is anchored in the well when the valve assembly is disengaged from the packer.

Abstract: A well tool assembly comprising a drillable cement retainer and setting tool includes a connection between a setting-tool mandrel and a retainer mandrel allowing for opening and closing of a cement valve in the retainer without disconnecting the setting tool from the retainer. A releasable locking mechanism in the connection keeps a tubular connector between the setting-tool mandrel and the retainer mandrel locked against sliding relative to one of the mandrels prior to deploying an upper slip set of the cement retainer. Additionally, a carrier in the setting tool includes radially resilient lugs connected between the setting-tool mandrel and a retaining sleeve for the upper slip set for sliding upwardly on the setting-tool mandrel to carry the sleeve into an upper position releasing the upper slip set for deployment. A set lock in the retainer holds the retainer mandrel against movement downwardly once the retainer is anchored in the well.

Abstract: A method and apparatus for gravel packing a producing formation or zone in a well without inducing fluid movement across the zone being packed during reverse circulation. Packing and reverse circulation are effected without any movement of the tool string from the time packing is initiated. Bypass and dump valves are incorporated in the isolation gravel packer to facilitate movement of the tool string within the well bore before and after packing a zone.

Abstract: A method of gravel packing multiple zones with a single trip of the operating string into a well without inducing fluid movement across zones, and without disturbing the zone being packed in reverse circulation. Apparatus is disclosed to perform the method, comprising a screen liner assembly surrounding a concentric operating string. Mechanical force on the operating string is used to change all tool modes of the apparatus. The operating string is accurately positioned with respect to the screen liner assembly at every zone level and zones may be easily relocated if necessary. Zones may be packed in any order, and a zone may be repacked, if necessary, during the same trip into the well.

Abstract: The present invention provides a setting tool having a tubular sleeve assembly. An upper mandrel is disposed within said sleeve assembly and interconnected therewith by a rotational screw jack means. A lower mandrel is connected to the upper mandrel by a load transfer device for governing a maximum downward force which can be applied to the lower mandrel when the setting tool is set down on a packer. The load transfer means includes a casing connected to the upper mandrel, said casing having a support surface for engagement with an upper end of a packer mandrel. Resilient spring means is provided between the casing and the lower mandrel, and is constructed so that when said support surface is in engagement with said packer mandrel, a downward force applied to said lower mandrel must be transmitted through said resilient spring means.

Abstract: An improved gravel-packing tool assembly with a baffled stinger pipe for gravel-packing a perforate liner having substantially the same internal diameter as the casing string extending from the perforate liner to the earth surface. A perforate nipple and a swab cup are provided between the check valve and the baffled stinger pipe of the tool assembly to allow drainage of the annulus above the tool assembly through the stinger pipe to thereby avoid swabbing the well as the tool is retrieved from the well.

Abstract: Disclosed is a well latch for locking well tools in a well flow conductor. The latch housing has a pressure equalizing passage extending through its wall. A valve controls flow through the equalizing passage. Keys, carried by the latch housing, are expanded outwardly into a locking groove of a well flow conductor to lock the well latch therein. A fishing neck, associated with the latch, permits retrieval of the latch. This abstract is neither intended to define the scope of the invention, which, of course, is measured by the claims, nor is it intended to be limiting in any way.

Abstract: A stroke actuated well testing tool carried by a tubing string and including a packer, radial ports for maximum internal flow past the packer, and a valve controlling flow through the tubing string; the tool further including radial port control assemblies which are relatively movable axially, when the packer and tool are set, to close the radial ports, and valve control assemblies which are relatively movable to open and close the valve; the radial port control assemblies including a fluid flow restrictor to provide a time delay thereby to permit relative movement of the valve control assemblies without operation of the port control assemblies; the tool further including at least one annular sample collecting pressure resistant chamber occupying an open position for receiving well samples when the packer is set and a closed position when the tool is being pulled out.

Abstract: A releasable well anchor adapted to be set on a wire line with a running tool attached which comprises an internal and an external mandrel which are slidably mounted with respect to one another having a set of slips on the exterior which slips have two positions, one position being recessed and the other position being radially outwardly of the first to engage the well pipe thereabout in an anchoring positon. The slips are set on movement of an enlargement on the internal mandrel. A set of flexible collet fingers is attached to the internal mandrel, and positioned near first and second internally located receptacles separated by a surface within said external mandrel. The collet fingers flex outwardly into said first or second receptacles on relative movement between said mandrels wherein relative positioning of said collet fingers in said first or second receptacles define a running in position, a setting position, and a retrieval position.

Abstract: A packer actuated vent assembly comprising a packer device settable by reciprocal movement of a mandrel, a valve actuator in the form of a barrel attached to the packer body, and a mandrel extension having a valve means thereon attached to the packer mandrel. The valve means is engaged by a stop member located on the barrel and is moved to the venting position when the packer mandrel is properly manipulated to seat the packer.

Abstract: Methods and apparatus for performing a drill stem test of an offshore well utilizing a pressure controlled test valve. The test valve includes a valve element having a transverse pressure area with the high pressure side exposed to the pressure of fluids in the well annulus and the low pressure side subject to the pressure of a compressible fluid medium contained within a chamber in the test valve. The pressure in the chamber is equalized with the hydrostatic head of the well fluids so that at test depth the same pressure is acting on both sides of the transverse pressure area, whereupon this pressure is confined within the chamber. Then a fluid pressure in excess of the hydrostatic head is applied to the well fluids externally of the test valve to develop a pressure difference across the valve element which causes it to shift from closed to open position.