Abstract: The finger or other protrusion allows downward movement of both fluid and balls, darts, or plugs through the tool or sliding sleeve until the ball, dart, or plug releases or actuates the gate. Once actuated the gate prevents further downward movement of any ball, dart, or plug past the gate while allowing fluid flow past both the gate and the ball, dart, or plug.

Abstract: In order to overcome the need to remove each fracturing plug after a plug and perforate operation it is desirable to utilize a profile latch in conjunction with a coupling profile. By having a profile in each coupling or at least in predetermined couplings a tool such as a perforating assembly including a fracturing plug may be precisely placed. A profile in the couplings also provides a means to latch the perforating assembly or other tool securely to the casing without using slips. Such profiles typically provide for securing the tool or perforating assembly in one direction although a particular profile may secure the assembly in place in two directions. By securing the tool or perforating assembly in one direction only the tool may be easily relocated or removed from the casing.

Abstract: An erosion resistant nozzle is brazed to the surface of a tubular, such as a shunt tube of a wellscreen apparatus, for use in a wellbore. The nozzle is elongated and defines an aperture for communicating exiting flow from the tubular's port. The lead end of the nozzle disposed downstream of the exiting flow can be lengthened to prevent erosion to the tubular. The lead endwall of the nozzle's aperture can be angled relative to the nozzle's length and can be rounded. The nozzle can be composed of an erosion resistant material or can be composed of a conventional material having an erosion resistant coating or plating thereon. Being elongated with a low height, the nozzle can have a low profile on the tubular, and the aperture's elongating can be increased or decreased to increase or decrease the flow area through the nozzle.

Abstract: A multiplier sleeve has a releasable seat coupled to a dog within the slidable sleeve allows a single sized ball, dart, or plug to actuate several sliding sleeves. Upon actuation by properly sized ball the ball, slidable sleeve, seat, and dog move downward where the dog is no longer supported allowing the seat to move within the slidable sleeve to a point where the seat is no longer supported thereby releasing the ball. With the slidable sleeve moved downward the port or ports in the sliding sleeve is exposed. A staged port and piston assembly inserted into the ports maintain pressure within the tubular assembly to allow the ball to move through and actuate the targeted sliding sleeves.

Abstract: The present invention relates to an inflow control device for controlling the flow of fluid into a tubular deployed in a wellbore comprising coupling between joints of tubulars. The inflow control device is mounted transversely through the coupling in any inflow can control devices the initial condition fluid flow between the exterior and interior of the tubular is prevented. As sufficient pressure is exerted upon the inflow control device from the interior of the tubular the inflow control device is actuated to allow fluid flow between the interior and exterior the tubular. A nozzle in the inflow control device allows fluid to pass at a preset rate.

Abstract: In order to overcome the need to remove each fracturing plug after a plug and perforate operation it is desirable to utilize a profile latch in conjunction with a coupling profile. By having a profile in each coupling or at least in predetermined couplings a tool such as a perforating assembly including a fracturing plug may be precisely placed. A profile in the couplings also provides a means to latch the perforating assembly or other tool securely to the casing without using slips. Such profiles typically provide for securing the tool or perforating assembly in one direction although a particular profile may secure the assembly in place in two directions. By securing the tool or perforating assembly in one direction only the tool may be easily relocated or removed from the casing.

Abstract: In order to overcome the need to remove each packer after a plug and perforate operation in order to produce a well it is desirable to utilize an erodible packer that may allow one way flow. An erodible packer may be constructed of a material such as polyglycolic acid as a binder. The same packer may also allow one way flow past the packer, such as flow from the casing below the packer to the casing above the packer. The packer may erode upon the expiration of a predetermined period of time or upon exposure to an activating agent.

Abstract: An erosion resistant nozzle is brazed to the surface of a tubular, such as a shunt tube of a wellscreen apparatus, for use in a wellbore. The nozzle is elongated and defines an aperture for communicating exiting flow from the tubular's port. The lead end of the nozzle disposed downstream of the exiting flow can be lengthened to prevent erosion to the tubular. The lead endwall of the nozzle's aperture can be angled relative to the nozzle's length and can be rounded. The nozzle can be composed of an erosion resistant material or can be composed of a conventional material having an erosion resistant coating or plating thereon. Being elongated with a low height, the nozzle can have a low profile on the tubular, and the aperture's elongating can be increased or decreased to increase or decrease the flow area through the nozzle.

Abstract: Sliding sleeve mechanisms including protective sheaths for debris protection are disclosed. Protective sheaths can be formed from materials such as composites, metal, foil, rubber, plastic, glass, ceramic, wire mesh, tape, etc. The protective sheaths can be substantially cylindrical shells (having one or more pieces), plugs in the flow ports, and/or tape or wire wrappings. The protective sheaths can be retained by recesses in the sliding sleeve or mechanical fasteners such as screws, pins, rivets, snap rings, bands, and buckles. The protective sheath can be outside or inside the sliding sleeve. The protective sheath can protect the sliding sleeve from debris by retaining grease that has been packed into the sliding sleeve for that purpose or positively preventing entry of debris into the sliding sleeve. The protective sheath can be cleared by permitting fluid flow through the sliding sleeve, which can act to destroy and/or wash away the protective sheath.

Abstract: A tandem packer seals a wellbore annulus with first and second seals. The packer has a body defining a bore therethrough and has a shoulder disposed on the body. A compressible element is disposed on the body adjacent the shoulder. A piston is movably disposed on the body adjacent the compressible element and is activated by fluid pressure communicated through a port in the packer's bore. When actuated, the piston fits between the compressible element and the body to initially expand it outward. With further fluid pressure, the piston compresses the compressible element against the shoulder to expand the element radially outward and produce a first seal with a surrounding surface. A swellable element also disposed on the body is swellable in the presence of an agent and expands radially outward to produce a second seal with the surrounding surface.

Abstract: A packer seals a wellbore annulus. The packer has a body defining a bore therethrough and has a swellable element disposed on the body. An expander movably disposed on the body adjacent the swellable element is actuated by fluid pressure communicated through a port in the body's bore. When actuated, the expander fits between the swellable element and the body to expand the swellable element radially outward an initial expansion amount. While downhole, the swellable element swells in the presence of an agent downhole and expands radially outward a subsequent expansion amount to produce a seal with a surrounding surface. With further fluid pressure, the expander can also compress the swellable element to further increase the expansion amount of the swellable element.

Abstract: A packer provides multiple seals when deployed downhole. Exposed to an activating agent, a swellable element on the packer's mandrel expands radially outward to form a seal with the borehole wall. Deformable elements, are disposed on the mandrel adjacent the swellable element. These deformable elements deform outward to the surrounding borehole wall to at least partially isolate the downhole annulus and the swellable element. Bias units releasable affixed on the tool adjacent the deformable elements can deform the elements. These bias units can be released either by swelling of the swellable element or by fluid pressure. Once released, the bias units are axially biased toward the deformable elements to deform them. In this way, the packer can form multiple seals with the borehole wall, and the deformable elements can isolate the swellable element from the downhole annulus, which can keep the swellable element from degrading or being overly extruded.

Abstract: Sliding sleeve mechanisms including protective sheaths for debris protection are disclosed. Protective sheaths can be formed from materials such as composites, metal, foil, rubber, plastic, glass, ceramic, wire mesh, tape, etc. The protective sheaths can be substantially cylindrical shells (having one or more pieces), plugs in the flow ports, and/or tape or wire wrappings. The protective sheaths can be retained by recesses in the sliding sleeve or mechanical fasteners such as screws, pins, rivets, snap rings, bands, and buckles. The protective sheath can be outside or inside the sliding sleeve. The protective sheath can protect the sliding sleeve from debris by retaining grease that has been packed into the sliding sleeve for that purpose or positively preventing entry of debris into the sliding sleeve. The protective sheath can be cleared by permitting fluid flow through the sliding sleeve, which can act to destroy and/or wash away the protective sheath.

Abstract: Sliding sleeve mechanisms including protective sheaths for debris protection are disclosed. Protective sheaths can be formed from materials such as composites, metal, foil, rubber, plastic, glass, ceramic, wire mesh, tape, etc. The protective sheaths can be substantially cylindrical shells (having one or more pieces), plugs in the flow ports, and/or tape or wire wrappings. The protective sheaths can be retained by recesses in the sliding sleeve or mechanical fasteners such as screws, pins, rivets, snap rings, bands, and buckles. The protective sheath can be outside or inside the sliding sleeve. The protective sheath can protect the sliding sleeve from debris by retaining grease that has been packed into the sliding sleeve for that purpose or positively preventing entry of debris into the sliding sleeve. The protective sheath can be cleared by permitting fluid flow through the sliding sleeve, which can act to destroy and/or wash away the protective sheath.

Abstract: A packer provides multiple seals when deployed downhole. Exposed to an activating agent, a swellable element on the packer's mandrel expands radially outward to form a seal with the borehole wall. One or more deformable elements, such as compressible packers or cup packers, are disposed on the mandrel adjacent the swellable element. These deformable element deform outward to the surrounding borehole wall to at least partially isolate the downhole annulus and the swellable element. Bias units releasably affixed on the tool adjacent the deformable elements can deform the elements. These bias unit can be released either by swelling of the swellable element or by fluid pressure. Once released, the bias units are axially biased toward the deformable elements to deform them. In this way, the packer can form multiple seals with the borehole wall, and the deformable elements can isolate the swellable element from the downhole annulus, which can keep the swellable element from degrading or being overly extruded.

Abstract: Sliding sleeve mechanisms including protective sheaths for debris protection are disclosed. Protective sheaths can be formed from materials such as composites, metal, foil, rubber, plastic, glass, ceramic, wire mesh, tape, etc. The protective sheaths can be substantially cylindrical shells (having one or more pieces), plugs in the flow ports, and/or tape or wire wrappings. The protective sheaths can be retained by recesses in the sliding sleeve or mechanical fasteners such as screws, pins, rivets, snap rings, bands, and buckles. The protective sheath can be outside or inside the sliding sleeve. The protective sheath can protect the sliding sleeve from debris by retaining grease that has been packed into the sliding sleeve for that purpose or positively preventing entry of debris into the sliding sleeve. The protective sheath can be cleared by permitting fluid flow through the sliding sleeve, which can act to destroy and/or wash away the protective sheath.

Abstract: An improved cage slip system is disclosed. The cage is constructed so that the cones which actuate the slips extend into the cage openings. The radial extension of the slips is limited so as to retain them if they are extended in an unsupported situation. The cones have a maximum outside dimension equal to the outside dimension of the cage so as to increase the rating of the slips by increasing the bearing area of the cones on the slips. The beneficial features of the cage design are retained while a greater degree of radial expansion of the slips is possible allowing minimization of tool inventory for situations where a lighter wall casing requires further slip extension. The release system allows the lower cones to be driven out from under the lower slips, thus facilitating release of the grip of the lower slips from the casing for extraction of the packer. The mechanical release is functional through the mandrel, whether tension or compression is placed on the mandrel.

Abstract: An improved cage slip system is disclosed. The cage is constructed so that the cones which actuate the slips extend into the cage openings. The radial extension of the slips is limited so as to retain them if they are extended in an unsupported situation. The cones have a maximum outside dimension equal to the outside dimension of the cage so as to increase the rating of the slips by increasing the bearing area of the cones on the slips. The beneficial features of the cage design are retained while a greater degree of radial expansion of the slips is possible allowing minimization of tool inventory for situations where a lighter wall casing requires further slip extension.

Abstract: A configuration is provided to anchor the tubing string into a polished-bore receptacle while providing the ability to disconnect the tubing string from the polished-bore receptacle in a single trip in the wellbore. The configuration of the anchor provides for metal-to-metal sealing, and the disconnection is accomplished by a penetrating tool which accesses an annular cavity to unsupport locking dogs which facilitate removal of the tubing string from the polished-bore receptacle with applied pressure. If the packer needs to come out for any reason, a retrieving tool is described which, in a single trip, allows the retrieving tool to be advanced thru-tubing into the packer itself to unlock it. The retrieving tool is pulled out of the tubing and a pick-up force is applied to the tubing string to extend the packer to allow for its ultimate removal with the tubing. The retrieving tool preferably employs jarring forces to release the packer.

Abstract: A configuration is provided to anchor the tubing string into a polished-bore receptacle while providing the ability to disconnect the tubing string from the polished-bore receptacle in a single trip in the wellbore. The configuration of the anchor provides for metal-to-metal sealing, and the disconnection is accomplished by a penetrating tool which accesses an annular cavity to unsupport locking dogs which facilitate removal of the tubing string from the polished-bore receptacle with applied pressure. If the packer needs to come out for any reason, a retrieving tool is described which, in a single trip, allows the retrieving tool to be advanced thru-tubing into the packer itself to unlock it. The retrieving tool is pulled out of the tubing and a pick-up force is applied to the tubing string to extend the packer to allow for its ultimate removal with the tubing.