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: A piston tractor system can include at least two piston assemblies which sealingly engage a wellbore, and a pump which transfers fluid between an annulus isolated between the piston assemblies, and another annulus. A method of operating a piston tractor system can include sealingly engaging at least two piston assemblies with a wellbore, grippingly engaging one piston assembly with the wellbore, and then pumping a fluid from an annulus formed between the piston assemblies, while the other piston assembly is secured to a tubular string, thereby biasing the tubular string to displace through the first piston assembly. A method of advancing a tubular string through a wellbore can include sealingly engaging piston assemblies with the wellbore, each of the piston assemblies including a gripping device which selectively grips the wellbore, and one piston assembly including another gripping device which selectively grips the tubular string.

Abstract: An apparatus that is usable with a well includes an operator and a generator. The operator is disposed in the well and configured to respond to a differential pressure between hydraulically isolated zones of the well to produce mechanical motion. The generator is disposed in the well to convert the mechanical motion into electricity. A method that is usable with a well is provided including maintaining hydraulic isolation between a first and second zone of a well. While maintaining the hydraulic isolation, the method further includes producing a mechanical motion in response to a differential pressure between the first and second zones and generating electricity in response to the mechanical motion.

Abstract: An apparatus and method for operating a packer and a fracture valve. The packer may include a tubular mandrel having a longitudinal bore with an annular packing element and a first piston disposed around the mandrel, wherein the first piston is operable to set the packing element, and a second piston operable to isolate fluid communication between the first piston and the mandrel bore. The fracture valve may include a tubular mandrel having a longitudinal bore and a port, a piston operable to close fluid communication between the bore and the port, and a latch disposed between the piston and the mandrel operable to resist movement of the piston.

Abstract: An anchoring device for stopping movement of a sliding component in a mandrel or case is disclosed. The anchoring device includes an elastically deformable anchor seat and an elastically deformable anchor retainer insertable into the anchor seat. The anchor seat has a groove profile thereon which will mate with a groove profile on the mandrel in an anchoring position. The retainer is insertable into the anchor seat and will hold the anchor seat in the anchoring position.

Abstract: A method of operating an isolation valve in a wellbore includes: deploying a work string into the wellbore through a tubular string disposed in the wellbore. The work string comprises a deployment string, a shifting tool, and a bottomhole assembly (BHA). The tubular string comprises the isolation valve and an actuator. The method further includes rotating the actuator using the shifting tool, thereby opening or closing the isolation valve. The isolation valve isolates a formation from an upper portion of the wellbore in the closed position.

Abstract: A fill up tool includes a mandrel; a primary sealing member disposed around the mandrel; and a selectively operable secondary sealing member activated by rotation of the mandrel. In another embodiment, the selectively operable secondary sealing member is activated using hydraulic pressure.

Abstract: A downhole actuator apparatus that selectively maintains a pressure differential between two pressure regions in a well. The apparatus includes a body defining first and second chambers. A piston is slidably disposed in the body and is selectively moveable between first and second positions. A barrier is disposed in the body to selectively separate the first and second chambers. A fluid is disposed in the first chamber between the barrier and the piston. A control system that is at least partially disposed within the body is operable to generate an output signal responsive to receipt of a predetermined input signal. The output signal is operable to create a failure of the barrier such that at least a portion of the fluid flows from the first chamber to the second chamber and the piston moves from the first position to the second position.

Abstract: An apparatus that is usable with a well includes an operator and a generator. The operator is disposed in the well and configured to respond to a differential pressure between hydraulically isolated zones of the well to produce mechanical motion. The generator is disposed in the well to convert the mechanical motion into electricity. A method that is usable with a well is provided including maintaining hydraulic isolation between a first and second zone of a well. While maintaining the hydraulic isolation, the method further includes producing a mechanical motion in response to a differential pressure between the first and second zones and generating electricity in response to the mechanical motion.

Abstract: A technique facilitates control over a multi-position well tool. A hydraulic control module may be engaged with a multi-position well tool for controlling actuation of the multi-position well tool through a plurality of actuation positions. The multi-position well tool is moved through the plurality of actuation positions by applying pressurized fluid through a first control line. A metering piston is uniquely arranged within the hydraulic control module to control actuation of the multi-position well tool from an initial actuation position through a plurality of incremental actuation positions. Additionally, a single pressurization of actuation fluid delivered through a second control line may be used to return the multi-position well tool back to the initial actuation position from any incremental position.

Abstract: A circulating sub is run in with the circulating port closed. A dart blocks a central passage and moves two concentric pistons in tandem to open the circulation port while retaining the dart. The outer piston shoulders out in the circulation port open position. A second dart lands on the first and with applied pressure moves the inner piston relative to the shouldered outer piston to close the circulation port and only then discharge both darts. Subs can be used in tandem as long as higher located subs accept larger darts than lower subs and preferably the two darts for each sub are the same size. The ejected darts can be used to pressure actuate a downhole tool like a packer.

Abstract: Apparatus and methods are provided for a cementing operation for use with a drilling with casing application. In one embodiment, an apparatus is provided for stage cementing using a full opening stage tool. In another embodiment, an apparatus is provided for reverse cementing of the casing.

Abstract: System and method for circulating fluid within a well bore. A circulation sub configured with communication elements on its ends to link the sub to a downhole communication network. A slideable piston in the sub isolates or exposes an outer port on the sub to an inner fluid flow along the sub depending on a signal transmitted along the communication network. Methods for activating the circulation sub via signals transmitted along the downhole communication network.

Abstract: A downhole circulation sub or valve (105) includes a tubular housing with an outer port (140) and a valve piston (170) slidably disposed in the housing. A primary fluid flow path (130) extends through an inner flow bore of the housing and valve piston. In a first position, the valve piston isolates the outer port to prevent fluid communication between the inner flow bore and a well bore annulus. In a second position, the valve piston is moved to obstruct the inner flow bore and expose the outer port to the inner flow bore and allow fluid communication between the inner flow bore and the well bore annulus. An indexing mechanism (165) is coupled between the housing and the valve piston to guide the valve piston between the first and second positions. In some embodiments, the indexing mechanism includes a rotatable component (175).

Abstract: A downhole tool can perform a series of operations with balls of the same size where movement caused by pressuring up on the first ball positions the next seat to accept another ball just like it. In a preferred embodiment a circulation sub is run in with a port closed and a first seat comprising of collets pushed together and preferably lined with a sleeve are in position to accept a first ball to perform a downhole operation and thereafter pass the ball and open the port. The act of opening the port gives support, by reducing their dimension, to the next assembly of collets also preferably lined with a sleeve so that they are energized to accept the same size ball. Pressuring up on the second ball can shift another sleeve to close the circulation port. The tool is modular and more than one module can be deployed in a given bottom hole assembly.

Abstract: An activating mechanism for controlling the operation of a downhole tool in a drill string and which is intended to be housed in a portion of the drill string upstream of the downhole tool, in which: the activating mechanism has a first mode in which it allows through-flow of drilling fluid to the downhole tool and a second mode in which through-flow of fluid is blocked; and the activating mechanism has a number of through-flow ports permitting through-flow of drilling fluid in said first mode of the mechanism and which are capable of being blocked by launching a number of flow blocking activator balls down the drill string and which each are of such size and shape that they can block access to said through-flow ports in order to activate the mechanism to the second mode and thereby adjust the downhole tool from one mode of operation to another.

Abstract: The present invention relates to a cementing valve (1) for conducting cementing operations in a wellbore comprising a casing (2), wherein the cementing valve (1) comprises an inner sliding sleeve (3) which in a closed position covers a number of openings (4) through an outer pipe (5) surrounding the inner sliding sleeve (3), and in an open position uncovers said openings (4), the sliding sleeve (3) comprising an actuating means (6) requiring a predetermined force to be actuated from both the closed position to the open position and vice versa, engaging means (22) being arranged on the inside of the sliding sleeve (3) for being engaged by a well running tool comprising corresponding gripping means (23).

Abstract: A control system for a subsurface safety valve features a control line from the surface leading to one side of an operating piston. The operating piston is exposed to tubing pressure and is in pressure balance from tubing pressure. The opposite end of the operating piston is exposed to a chamber in the housing of the subsurface safety valve and that chamber is open through a port to the surrounding annulus. The operating piston is coupled to the flow tube and a power spring so that pressure in the control line shifts the operating piston and the flow tube against the power spring to rotate the flapper open. Provisions for fail closed mode if certain seals fail are also made though a passage extending from between seals near the upper end of the operating piston to the chamber open to the annulus.

Abstract: A by-pass tool for incorporation in a drillstring is adjustable between an inactive mode in which it allows fluid flow lengthwise of the drillstring during normal drilling operation, and an active by-pass mode when drilling is to be interrupted. The tool includes an outer casing, an axially displaceable sleeve within the casing, a valve seat associated with the sleeve and arranged to receive an activating ball, and by-pass port means in the casing. The valve seat receives the activating ball when the ball is launched from the surface and down the drillstring. The valve seat displaces the sleeve axially to adjust the tool from the inactive mode to the active by-pass mode. The by-pass port means allows a locking ball to partially block the port means and thereby initiate flushing-out of any drillstring fluid debris above the valve seat via the port means.

Abstract: A tubing string assembly for fluid treatment of a wellbore includes substantially pressure holding closures spaced along the tubing string, which each close at least one port through the tubing string wall. The closures are openable by a sleeve drivable through the tubing string inner bore.

Abstract: A by-pass tool to be incorporated in a drill string, in combination with an activating ball assembly operative to adjust the tool between an activated mode and a de-activated mode. The tool has a valve seat engageable by the activating ball assembly to move its sleeve to a by-pass mode which diverts drilling mud from flowing through the housing to a by-pass flow through the by-pass port. The activating ball assembly has a deformable ball of a size sufficient to engage and to be held captive by the salve seat and a weight attached to the ball and operative to assist in movement of the assembly under the action of gravity to engage the ball with the valve seat. The weight has smaller transverse dimensions that the ball so that it moves downwardly through the valve seat and pulls the ball into engagement with the valve seat.

Abstract: A float apparatus for use in a casing string. The float apparatus includes an outer case having a check valve positioned therein. A body portion which may be comprised of high compressive strength cement affixes the check valve to the outer case. The check valve includes a valve body and a valve element. The valve body defines a valve seat and the valve element is deformable so that it will conform to the shape of the valve seat and seal against flow in the casing.

Abstract: A small diameter stage cementer assembly 10 and a hydraulically operated packer collar stage cementer 110, including a cementer housing 12 for interconnection with a casing string 14 positionable in a slim-hole wellbore for a cementing operation. The cementer housing 12 including a seat 11 for receiving a lower, drillable portion 335 of an opening sleeve assembly 135 after the upper drillable portion 235 of the opening sleeve assembly 135 has been drilled out. The lower, drillable portion 335 wedges into engagement with the seat 11 to prevent rotation of the drillable portion 335 during drill-out, such that the lower portion 335 may be drilled up using a small diameter bit and drill string, and accommodating a reduced weight on bit. The packer collar embodiment includes a hydraulically actuatable packer 70.

Abstract: A lifting top drive sub sea staging cement head in which cement slurry flows from outside into its central bore, thru a rotating swivel connection. The cement head has a rotatably indexable reservoir cylinder with multiple cells which may be loaded with balls, and/or darts, and/or staging bombs. One first cell is kept open for circulation. The cylinder is rotatably aligned, at will to the flow path, so that the staging elements may be washed down the drill string. In addition, the cement head is hydraulically remotely controlled such that no operators protrude from the smooth body, yet the remote system may be manually over-ridden.

Abstract: A method and apparatus for maintaining the fluid column in an annulus are provided. The fluid column support, or fluid column seal is disposed about a second casing being lowered into a well through a first casing already cemented in the well. The fluid column support includes a seal connected to the second casing that engages the first casing as it is lowered therethrough. The seal will allow flow in an upward direction but prevents downward flow. The seal will support, or maintain a fluid column in the annulus between the first and second casing in the event that the fluid level below the seal drops for any reason, such as lost circulation or the failure of a buoyancy chamber in the second casing. The fluid seal, in conjunction with stage tools, provides hydrostatic pressure in the well to maintain proper fluid placement therein.

Abstract: An apparatus and method for cementing a casing string in a wellbore. A self-filling tubular cementing collar connected to the lower end of a casing string is provided with one-way flow valving that allows well fluid to enter and self-fill the casing string as it is lowered into the wellbore and automatically prohibits reverse fluid flow from the collar when washing or cementing during forward circulation through the collar. The one-way valving is carried by an axially movable support that can be shifted by a cementing plug moved by pump pressure to permanently seal the entry flow passage after the casing sting is properly positioned in the wellbore.

Abstract: An apparatus and method for the completion of wells through a production tube includes a tool body having cement flow ports and pressure displaced port closure elements. A perforated mandrel tube concentrically aligned within the production tube is secured to said tool body at its upper end. Concentrically within the mandrel tube is a dart transport tube. The dart transport tube is releasably secured to the tool body by a set of locking dogs. A first dart plug is placed in the production tubing bore at the well surface to be pumped or allowed to gravitate onto a closure seat in the lower end of the of the transport tube. This seat closure allows the production tubing to be pressurized for setting well annulus packers and opening of a cement port closure sleeve. After the production tube has been set by cement pumped down the production tubing bore and through the cement flow port, a second dart plug is positioned atop the cement column in the production tube.

Abstract: A check valve assembly for the bottom of a casing string with increased open area is provided. Multiple check valves are provided for assurance of ultimate closure. Bypass flow paths are available during run in that increase the normal available open area from about 3 square inches to a range of about 10 square inches and even higher. Components freely float during run in to provide the greater open area and are subsequently repositioned with known techniques of dropping a ball and pressurization when the casing has reached the desired depth.

Abstract: A jet pump assembly 10 for use in a subterranean wellbore 82 to lift produced fluids 72 to the surface, comprising a fixed type jet pump assembly 10 including a retrievable insert assembly 30 for retrieving substantially all working components of the jet pump assembly 10 which may be subject to wear or size change, including retrieving the standing valve assembly in the production intake section 50, and having a power section 40 which is reversible such that the same components may be used for operating the jet pump assembly 10 in “normal” circulation or “reverse” circulation. Included is an embodiment of a jet pump assembly 10 providing at least one pressure sensor 90 and at least one temperature sensor 92 built into the through bore of the retrievable insert section 30 for monitoring fluid pressure and temperature in the through bore of the jet pump assembly 10 and thereby improving operational efficiency of the jet pump assembly 10.

Abstract: An apparatus for launching at least two plugs, said apparatus comprising a mandrel (2), a lower plug (22) and an upper plug (21) releasably disposed with respect to said mandrel (2), wherein said upper plug (21) comprises a body (23) having a flow path (24) therethrough and a cap (25) for blocking fluid flow through said flow path (24) characterized in that said cap (25) is detachable from said body (23) in use if the upper plug (21) is prematurely ejected.

Abstract: An apparatus which includes an external housing (10) and a slotted internal sleeve (26) machined from cylindrical lengths of hollow metal pipe stock, and one or more partially-hollowed-out plug screws (16). This apparatus uses no seals or O-rings. The apparatus is attached between a tubing string of a well and a big bore pump. When activated, the apparatus permits fluids to drain from well tubing. The apparatus has only one moving part and is activated by pulling upward on sucker rods of a well, an action which causes the top of a big bore pump plunger to make contact with the sleeve and move the sleeve upward within the housing. The sleeve is secured inside the housing by one or more partially-hollowed-out plug screws which are sheared when the contact is made, exposing at least one opening. The opening in the sleeve aligns with the hole in the partially-hollowed-out plug screw caused by the shearing.

Abstract: The present invention provides an improved cementing inflation packer tool and methods of using the tool. The tool includes of a tubular housing having a packer inflating port disposed therein and a packer inflating port opening sleeve slidably disposed within the housing. The opening sleeve is movable between a closed position and an open position by a first cementing plug. An external packer sleeve having a pressurized fluid inflatable packer element attached thereto and a cementing port therein is sealingly disposed over the outer surface of the housing and the packer inflating port. The external packer sleeve provides a passageway from the packer inflating port to the inflatable packer element and check valve means are disposed in the passageway. A fluid rupturable member having a predetermined rupture pressure is sealingly attached over the cementing port.

Abstract: Improved well casing fill apparatus and methods for filling a casing string with well bore fluid while running the string into a well bore and then cementing the casing in the well bore are provided. A well casing fill apparatus of this invention is basically comprised of a tubular housing having a well bore fluid fill port extending through a wall thereof and a closing sleeve slidably disposed in the tubular housing between an upper open position whereby the fill port is uncovered to a lower closed position whereby the closing sleeve covers the fill port. The closing sleeve includes a cementing plug landing seat thereon for receiving a cementing plug and slidably moving the closing sleeve to the closed position.

Abstract: A downhole drilling device utilizing a spring-loaded sleeve within a casing for controlling circulation of fluid material. A plastic, i.e., deformable ball is used to block a flow opening in the sleeve for positioning the sleeve and aligning flow ports. Subsequently, the ball is deformed and the drilling operation continues. In one form, an expandable packer may be operated to close off the annulus about the casing.

Abstract: A liner cementing system and method provide for a landing collar 10 with a bypass passageway 45. Circulation port 62 in collar 10 permits initial circulation through the liner 17 until a pump down plug P1 is pumped therein to seal off circulation therethrough. An increase in pressure in the liner bore 51 acts on a piston 50 until shear ring 48 is sheared at a selected pressure. Cement 90 may then flow through the bypass passageway 45 into a cement shoe 104 and into an annulus 74 to cement the liner 17 in place. Pump down plug P2 seals off the bypass passageway 45 to stop flow into the annulus 74. The closing of circulation port 62, the opening of bypass port 53, and the closing of bypass port 53 produce pressure signals at the surface which may be used to analyze cement job success.

Abstract: A method and apparatus for cementing a casing string utilizes a port collar which may be hydraulically opened and mechanically closed, and permits the passage of downhole tools through the port collar, without opening the port collar.

Abstract: The present invention provides a cementing tool for cementing multiple stages within a well. The assembly includes a housing assembly which defines one or more cementing ports. A first sleeve assembly is retained within the housing and is movable from a first position, where the sleeve covers the port, and thereby precludes fluid flow therethrough, to a second position wherein the sleeve opens the cementing port. The apparatus also includes a second sleeve assembly which is movable from a first position away from the cementing port to a second position wherein the sleeve assembly covers the port. The first sleeve is cooperatively configured with the housing assembly to provide engaging surfaces which resist rotation of the first sleeve relative to the housing. Additionally, the first sleeve and the second sleeve assembly are configured to limit relative rotation when the two pieces are longitudinally adjacent one another.

Abstract: A stage cementer and inflation packer apparatus. The apparatus comprises a mandrel with an external closing sleeve and an operating sleeve interlocked therewith. Below the operating sleeve is an opening sleeve. The opening sleeve is mechanically acutated by a pump-down plug in a plug-operated embodiment or by a differential pressure acting on the opening sleeve in a hydraulically operated embodiment, to actuate the opening sleeve to allow inflation of the packer element. A back check valve prevents the packer from deflating. After the packer is inflated, additional pressure is applied which ruptures a rupture disc to open a port to the well annulus above the set packer element. Cementing may be carried out through this port, and after the cementing operating, a plug engages the operating sleeve to move the operating sleeve in the external closure sleeve, thereby closing the cementing port.

Abstract: A down hole well tool for use in operating another well tool against the resistance of incompressible well bore fluid. The down hole tool includes a pressure chamber that communicates through an adjustable pressure relief valve with the well bore fluids beneath the tool, so that when the pressure of said fluids exceeds the relief valve setting the valve opens and allows said fluids to pass into the chamber, thereby lowering the fluid pressure beneath the tool and facilitating its downward movement to actuate the other well tool.

Abstract: A propulsion apparatus is provided for attachment to a selected tool for propelling and positioning the tool in a tubular member in response to fluid pressure in the tubular member and includes a tubular mandrel terminating in a lower free end, a tubular sleeve disposed over the mandrel and adapted for coaxial sliding movement with respect thereto, a cup assembly mounted on the sleeve and cooperating therewith and with the fluid pressure exerted within the tubular member for translating fluid differential pressure developed across the cup assembly into preselected propelling forces, and sleeve retaining means for cooperating with the sleeve and mandrel for positioning and retaining the sleeve in a first position with respect to the mandrel and transmitting the propelling forces to the mandrel and attached tool for propelling and positioning the tool to selected locations within the tubular member.

Abstract: In accordance with an illustrative embodiment of the present invention, a restriction sub apparatus for use during well cementing operations includes a tubular body having an internal annular recess, and a plastic restriction sleeve mounted in the recess, such sleeve having an inner diameter which is less than the inner diameter of the body so that when a drive plate on a cement displacement plug encounters the inner portion of the sleeve during downward movement, such inner portion is progressively deformed and bulged inward until the bulge dissipates into a recessed region near the bottom end of the sleeve. The resistance afforded by the plastic sleeve to downward movement of the plug provides a positive pressure surge indication at the surface that the plug is located at a particular depth in the casing.

Abstract: A seal assembly is provided for use in a fluid flow conduit, and includes a valve seat and a valve plug. The valve seat includes a seating lip formed at least in-part of yieldable material. The valve plug is passed through the fluid flow conduit and caused to sealingly engage the valve seat. Together the valve seat and valve plug form an obstruction to the passage of fluid within the fluid flow conduit, and pressure is developed upstream. At a predetermined pressure level the valve deforms the valve seat, and is passed therethrough. A larger valve plug can be passed until it seats against the enlarged valve seat. The pass-through process can be repeated.

Abstract: A casing cementer with torque-limiting rotating positioning tool. The casing cementer comprises a housing with a rotating valve sleeve therein. A positioning tool is used to rotated the valve sleeve between open and closed positions thereof. No reciprication of the positioning tool is required. The valve sleeve has a sealing ring molded thereto for sealing between the housing and the valve sleeve. The valve sleeve preferably has an inside diameter at least as large as an inside diameter of the casing. A stop is provided to limit movement of the valve sleeve when it reaches either the open or closed position. A clutch in the positioning tool provides for torque-limitation and a ratcheting indication to the operator at the surface when the valve sleeve has been opened or closed.

Abstract: A packer apparatus, particularly a cup type casing packer shoe, includes a pressure-actuated closing sleeve and pressure-actuated pumpout seats. An upper pumpout seat moves with the closing sleeve in response to a first pressure so that the closing sleeve closes ports through which fluid is communicated to an annulus outside the apparatus. Both the upper pumpout seat and a lower pumpout seat and any intervening fluid are pumped out of the apparatus in response to a second, higher pressure so that the apparatus communicates with the well below the annulus without a drillout procedure having to be performed through the apparatus or a tubing string in which the apparatus is connected. A related method is also disclosed.

Abstract: A multiple stage inflation packer with secondary opening rupture disc. The inflatable packer comprises a case with a closing sleeve, an opening sleeve and a releasing sleeve therein. An opening plug is dropped into the casing string and is allowed to free fall, or is pumped down, to actuate the opening sleeve to allow inflation of the packer element. A back check valve prevents the packer from deflating. After the packer is inflated, additional pressure is applied which ruptures a rupture disc to open a port to the well annulus above the set packer element. Cementing may be carried out through this port, and after the cementing operation, a closing plug is pumped down the well casing behind the cement to actuate the releasing sleeve and move the closing sleeve to seal off the ports. Another check valve insures that pressure is equalized on both sides of the rupture disc as the packer is run into the well bore.

Abstract: In accordance with an illustrative embodiment of the present invention, a restriction sub apparatus for use during well cementing operations includes a tubular body having upper and lower internal recesses, a restriction ring having a shoulder engaged with the upper recess, and depending, inwardly inclined fingers at its lower end, and a back-up rubber ring mounted in the lower recess that yieldably resists expansion of the fingers as the drive plate of a displacement plug passes downward therethrough to provide a positive surface indication in the form of a pressure change that the plug is located at a particular depth.

Abstract: A hydraulic setting and release tool has a shear out setting assembly attached to a string coupling member. Upon reaching a predetermined hydraulic pressure, a piston of the tool shears restraining shear pins and moves in a body of the tool to release dogs that engage the coupling member. When the dogs release, springs retract the dogs from engagement in sockets of the coupling member and the shear out setting assembly separates from the coupling member. When used in running in a liner, the coupling member is a running head that rotates the liner during running in and cementing. When used as a drill string release tool, the coupling member is a release sub, the tool being placed serially with other string components. If the drill string gets stuck, it is separated by merely increasing the hydraulic pressure sufficiently to shear the pins and allow the piston to move and the dogs to retract to separate the release sub from the shear out assembly.

Abstract: A cementing tool includes a tubular housing having an inner passage defined longitudinally therethrough and having a radially outer surface. The housing also has a cementing port and a longitudinal slot both disposed through a wall thereof. An outer closure sleeve is slidably received about the outer surface of the housing and is movable relative to the housing between an open position wherein the cementing port is uncovered by the closure sleeve and a closed position wherein the cementing port is closed by the closure sleeve. An inner operating sleeve is slidably received in the housing and slidable between first and second positions relative to the housing. A pin extends radially through the slot and fixedly connects the operating sleeve and the closure sleeve together for common longitudinal movement relative to the housing. When cementing is completed, a cementing plug engages the operating sleeve and causes it to move the external closure sleeve downward thus closing the cementing port.

Abstract: Apparatus is disclosed for use in placing cement within the annulus between a casing string and a well bore in which the casing string is suspended, such apparatus including a stage collar connectible as part of the casing string and having a packing element mounted thereon and adapted to be inflated into engagement with the well bore, one or more side ports through which cement may be circulated into the annulus above the packer, tubular members or sleeves for opening and closing the ports following inflation of the packing element.

Abstract: A method and device for actuating specialized equipment in a drilled well having at least one well zone, sharply slanted with respect to the vertical, and with the drilled well having at least one tubular control column along which operating equipment as remotely installed. A control member is introduced in to the first tubular control column, with a cable being attached at one end of the control member. The control member is lowered into the first tubular control column by a downward hydraulic pumping, and the cable is paid into the tubular pipe from the surface. The control member is raised by pulling on the cable from the surface and the specialized operating equipment is selectively maneuvered while the control member is flush against the equipment in a downward or upward travel of the control member in the drilled well.