Abstract: This disclosure describes various implementations of a downhole-blower system that can be used to boost production in a wellbore. The downhole-blower system includes a blower and an electric machine coupled to the blower that can be deployed in a wellbore, and that can, in cooperation, increase production through the wellbore.

Abstract: This disclosure describes various implementations of a downhole-blower system that can be used to boost production in a wellbore. The downhole-blower system includes a blower and an electric machine coupled to the blower that can be deployed in a wellbore, and that can, in cooperation, increase production through the wellbore.

Abstract: Systems and methods are disclosed that enable flushing the wellbore before, during and after a fracturing or treatment operation, such that a resettable plug is not trapped or buried by fluids and particulates in the hole and the sealing element of the resettable plug is not damaged. Systems and methods which mitigate and prevent accumulation of fluids and particulates above a resettable plug are also provided. A system and method for delivering pressurized fluid to a subterranean formation is also disclosed.

Abstract: A deflection mechanism may include a first incline and a second incline for interacting with legs of a junction assembly to selectively deflect each of the legs in a desired direction in a multilateral wellbore system. The deflection mechanism may include a window assembly for a main borehole of the wellbore and having a selective-deflection profile positioned proximate to an entrance into a lateral borehole extending from the main borehole. One leg of the junction assembly may include a surface profiled corresponding to an angle of the first incline to deflect the leg toward the lateral borehole. Another leg of the junction assembly may include a surface profiled corresponding to an angle of the second incline to deflect the leg toward a whipstock assembly positioned internal to the window assembly.

Abstract: A casing plug assembly and method for performing an operation in a well pipe includes a running tool for connection to a drill pipe, an equalizing module, a seal module, and an anchor module. A continuous fluid channel is formed through the casing plug assembly. The anchor module is set in the well pipe by pumping fluid through the continuous fluid channel. The anchor module is, in the set state, providing a support in the well pipe used by the running tool to operate the seal module.

Abstract: A borehole plug or packer for treating is designed to be flowed back to a surface location after use. When the treatment is concluded pressure from above is relieved or lowered, and well fluid is flowed back, so that the plug or plugs disengages at slips designed to resist differential pressure from above. The application of differential pressure from below causes the lower slips to release one or more of such plugs in the hole into specialized sub surface or surface capture equipment so that well pressure is relieved before removal of the plugs from specialized subsurface or surface capture equipment.

Abstract: An expandable slips system for use on a mandrel having a longitudinal axis, the mandrel adapted to be run into a borehole, the expandable slips system comprising: at least one slip which in use is adapted to be moved outwardly from the longitudinal axis of the mandrel to grip against and thereby engage a downhole formation, the at least one slip comprising at least one angled member; at least one cone member for engagement with the at least one slip, the cone member comprising at least one angled member for engagement with the at least one angled member of the slip; and at least one cone member expansion device for engagement with the at least one cone member, the cone member expansion device comprising at least one angled member for engagement with another at least one angled member of the cone member.

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

Abstract: An expandable slips system for use on a mandrel having a longitudinal axis, the mandrel adapted to be run into a borehole, the expandable slips system comprising: at least one slip which in use is adapted to be moved outwardly from the longitudinal axis of the mandrel to grip against and thereby engage a downhole formation, the at least one slip comprising at least one angled member; at least one cone member for engagement with the at least one slip, the cone member comprising at least one angled member for engagement with the at least one angled member of the slip; and at least one cone member expansion device for engagement with the at least one cone member, the cone member expansion device comprising at least one angled member for engagement with another at least one angled member of the cone member.

Abstract: A releasable production packer employs lock ring segments that are biased radially inwardly for engaging a mating pattern external to the packer mandrel. The mandrel has openings aligned with the segments and a release tool that latches to the mandrel for support and then moves the segments radially outwardly away from engagement with the mandrel so that the slips and sealing elements can extend axially and retract radially. After those movements the packer is retrieved. The release tools moves the locking segments only radially for the maximum mechanical advantage without risk of bending or deforming small parts.

Abstract: An apparatus that is usable with a well includes a first portion and a second portion. The first portion includes a first plurality of segments, and the second portion includes a second plurality of segments. The apparatus is deployable in a tubing string that is installed in the well, and the second plurality of segments is adapted to engage the tubing string and exert a force on the first plurality of segments. The first plurality of segments is adapted to expand to form a seat in the tubing string to receive an untethered object in response to the force, and the second plurality of segments is adapted to be released from the first plurality of segments downhole in the well.

Abstract: A packer deactivation system can include a packer and a safety joint. Activation of the safety joint can prevent setting of the packer. A method for use with a subterranean well can include activating a safety joint in the well, and deactivating a packer connected to the safety joint, in response to the safety joint activating. Another packer deactivation system can include a safety joint and a packer drag block locking mechanism. Activation of the safety joint can operate the drag block locking mechanism, thereby preventing a drag block from displacing in a certain direction relative to a mandrel of a packer.

Abstract: A packer that may be used to isolate a portion of a wellbore and a method of using the packer within the wellbore. The packer includes a body with a central bore, an upper sealing element, a lower sealing element, treatment ports, upper equalization ports, and a sleeve positioned within the central bore. The sleeve may be moved to selectively permit fluid communication through the treatment ports and the upper equalization ports. The packer may include lower equalization ports and the sleeve may be moved to also selectively permit fluid communication through the lower equalization ports. The sleeve may include a closed end and an inner wall that separates a secondary cavity from a main cavity. The sleeve includes a plurality of openings that either permits or inhibits fluid communication through the ports of the packer depending on the position of the sleeve within the central bore of the packer.

Abstract: A downhole tool having a throughbore is disclosed for use in a tubular located in a wellbore. The downhole tool has a sealing element configured to seal an annulus between the downhole tool and an inner wall of the tubular; at least one flow path formed in the downhole tool, wherein the flow path is configured to allow fluids in the annulus to flow past the sealing element when the sealing element is in a sealed position; and at least one valve in fluid communication with the flow path and configured to allow the fluids to flow through the flow path in a first direction while preventing the fluids from flowing through the flow path in a second direction. A guard may be installed proximate anchor elements. The guard extends radially beyond an outer diameter of the anchor elements when the anchor elements are in a retracted position.

Abstract: A downhole tool has a mandrel with packing elements. Collars between the packing elements define ports communicating with gaps between the packing elements and the mandrels. Opposing piston housings on the mandrel can move in opposing directions to compress the packing elements against the collars. Each piston housing defines a space with the mandrel and has a second port communicating with the gap. Pistons disposed in the spaces are temporarily affixed thereto. Hydraulic pressure communicated through the mandrel's bore acts against the pistons. While affixed to the piston housings, the pistons move the piston housings toward the packing elements to compress then. When the packing elements set, continued pressure breaks shear pins affixing the pistons to the piston housings so the pistons move and eventually seal fluid communication between the second ports in the pistons and the gaps.

Abstract: Novel hydraulic actuators and hydraulic setting assemblies are provided for use in downhole, oil and gas well tools. The novel hydraulic actuators include a cylindrical mandrel and an annular stationary sealing member connected to the mandrel. A hydraulic cylinder is slidably supported on the mandrel and stationary sealing member and is releasably fixed in position on the mandrel. The stationary sealing member divides the interior of the cylinder into a bottom hydraulic chamber and a top hydraulic chamber. An inlet port provides fluid communication into the bottom hydraulic chamber, and an outlet port provides fluid communication into the top hydraulic chamber. A balance piston is slidably supported within the top hydraulic chamber of the actuator. The piston includes an axially extending passageway. Fluid communication through the piston and between its upper and lower sides is controlled by a normally shut valve in the passageway.

Abstract: A downhole retrievable dual directional isolation tool, comprising a mandrel, a compressor ring concentric with the mandrel, and a packing element concentric with the mandrel and having an outer surface defining a plurality of grooves. A downhole retrievable dual directional isolation tool, comprising a mandrel, a packing element concentric with the mandrel, a compressor ring concentric with the mandrel and having a first side wall proximate to a second side wall of the packing element, and a stop ring concentric with the mandrel having a third side wall proximate to a fourth side wall of the packing element, wherein the first side wall of the compressor ring or the third side wall of the stop ring have a circumferential land, whereby in a set state of the tool a contact area between the circumferential land and the second side wall of the packing element or the fourth side wall of the packing element achieves higher contact pressure.

Abstract: The application discloses a safety valve including a flapper valve and a packer assembly to be installed in a bore to isolate a first zone from a second zone. Preferably, the safety valve includes a hydraulic conduit bypassing the flapper valve to allow communication therethrough when the valve is closed. Furthermore, the safety valve preferably allows unobstructed passage of tools and fluids therethrough when the flapper valve is open. The application discloses a method to install a safety valve in an existing string of tubing by deploying a packer assembly having an integral safety valve.

Abstract: An open hole packer uses mandrel expansion and a surrounding sealing element that can optionally have a swelling feature and further a seal enhancing feature of a ring with an internal taper to match an undercut on the mandrel exterior. As a swage progresses to the taper at the transition between the ring and the extending flat fingers, the fingers get plastically deformed in an outward radial direction to push out the sealing element. Shrinkage of the mandrel axially due to radial expansion brings a ring on the mandrel outer surface under the fingers to act as a support for the fingers against the seal which is pushed against the open hole. Mirror image orientations are envisioned to aid in retaining pressure differentials in opposed directions. Another external mandrel ring extends into the seal to keep its position during differential pressure loading.

Abstract: An open hole packer uses mandrel expansion and a surrounding sealing element that can optionally have a swelling feature and further a seal enhancing feature of a ring with an internal taper to match an undercut on the mandrel exterior. As a swage progresses to the taper at the transition between the ring and the extending flat fingers, the fingers get plastically deformed in an outward radial direction to push out the sealing element. Shrinkage of the mandrel axially due to radial expansion brings a ring on the mandrel outer surface under the fingers to act as a support for the fingers against the seal which is pushed against the open hole. Mirror image orientations are envisioned to aid in retaining pressure differentials in opposed directions. Another external mandrel ring extends into the seal to keep its position during differential pressure loading.

Abstract: A completion system delivers lifting gas supplied from the surface via a casing annulus through the packer for injecting to the wellbore at bottom hole. So, lifting gas maximizes hydrocarbon producing from a subterranean well while maintaining integrity and serviceability as a typical gas lift well. More specifically, a single completion system uses the same tubing string for both producing the well and delivering lifting gas to the wellbore at downhole. The top section of the tubing is used for producing the well, while the bottom section of the tubing is used for delivering lifting gas for injecting at bottom hole. The lifting gas will be injected to the wellbore proximately at perforation intervals for helping unloading liquid and producing the well. The use of modified equipment named “TK Bypass Mandrel” and “JP Bypass Nipple Sub” allows delivering and controlling of the lifting gas for injecting at bottom hole via a single tubing string.

Abstract: Apparatuses and methods to communicate with a zone below a subsurface safety valve (104, 204) independent of the position of a closure member (106) of the safety valve are disclosed. The apparatuses and methods include deploying a subsurface safety valve (104, 204) to a profile located within a string of production tubing. The subsurface safety valve (104, 204) is in communication with a surface station through an injection conduit (150,152; 250,252) and includes a bypass pathway (144, 244) to inject various fluids to a zone below.

Abstract: A downhole retrievable dual directional isolation tool, comprising a mandrel, a compressor ring concentric with the mandrel, and a packing element concentric with the mandrel and having an outer surface defining a plurality of grooves. A downhole retrievable dual directional isolation tool, comprising a mandrel, a packing element concentric with the mandrel, a compressor ring concentric with the mandrel and having a first side wall proximate to a second side wall of the packing element, and a stop ring concentric with the mandrel having a third side wall proximate to a fourth side wall of the packing element, wherein the first side wall of the compressor ring or the third side wall of the stop ring have a circumferential land, whereby in a set state of the tool a contact area between the circumferential land and the second side wall of the packing element or the fourth side wall of the packing element achieves higher contact pressure.

Abstract: The application discloses a safety valve including a flapper valve and a packer assembly to be installed in a bore to isolate a first zone from a second zone. Preferably, the safety valve includes a hydraulic conduit bypassing the flapper valve to allow communication therethrough when the valve is closed. Furthermore, the safety valve preferably allows unobstructed passage of tools and fluids therethrough when the flapper valve is open. The application discloses a method to install a safety valve in an existing string of tubing by deploying a packer assembly having an integral safety valve.

Abstract: A stimulation technique is provided for use in an open hole well. The stimulation technique utilizes a system which comprises one or more isolation devices positioned to isolate desired regions of the open hole well. At least one release mechanism is used to provide controlled release of stimulation material to a desired wellbore region of the open hole well. Additionally, a protection mechanism cooperates with each release mechanism to prevent undesirable contact between stimulation material and the surrounding wellbore wall of the open hole well. In many applications, the entire system is deployed and operated during a single trip downhole into the well.

Abstract: The completion system for delivering lifting gas supplied from surface via a casing annulus thru the packer for injecting to the wellbore at bottom hole as lifting gas for maximizing hydrocarbon producing from a subterranean well while maintaining integrity and serviceability as a typical gas lift well. A single completion, which uses the same tubing string for both producing the well and delivering lifting gas to the wellbore at downhole. The top section of the tubing is used for producing the well while the bottom section of the tubing is used for delivering lifting gas for injecting at bottom hole. The lifting gas will be injected to the wellbore proximately at perforation intervals for helping unloading liquid and producing the well. The use of modified equipment named “TK Bypass Mandrel” and “JP Bypass Nipple Sub” allows delivering and controlling of the lifting gas for injecting at bottom hole via a single tubing string.

Abstract: Apparatuses and methods to communicate with a zone below a subsurface safety valve (104, 204, 404) independent of the position of a closure member (106) of the safety valve. The apparatuses and methods include deploying a subsurface safety valve (104, 204, 404) to a profile located within a string of production tubing. The subsurface safety valve (104, 204, 404) is in communication with a surface station through an injection conduit (150,152; 250,252; 450; 452) and includes a bypass pathway (144, 244, 444) to inject various fluids to a zone below. A redundant control to actuate subsurface safety valve (104, 204, 404) can include a three-way valve (180, 280) or three-way manifold 480 connecting the injection conduit (150,152; 250,252; 452) or the hydraulic ports (140,142; 240,242; 442?) to the subsurface safety valve (104, 204, 404).

Abstract: Bypassing damaged lines in a well. A subterranean well system includes a circuit extending in the well to a well tool. A set of multiple redundant lines is provided at a location along the circuit. Each of the set of lines is capable of providing conductivity between portions of the circuit. A method of providing conductivity across a damaged portion of a circuit in a subterranean well includes the steps of: damaging at least one line of a set of redundant lines extending along a tubular string; and isolating the damaged at least one line from an undamaged portion of the circuit.

Abstract: There is disclosed a downhole packer for use in a well bore, and in particular, a packer which can be used for downhole testing. In an embodiment of the invention, a packer tool (10) for mounting on a work string to provide a seal against a tubular (32) is disclosed, the packer tool comprising a body (12) with one or more packer elements (18) and a sleeve (14), the packer tool being set by movement of the sleeve relative to the tool body compressing the one or more packer elements, wherein the tool has a plurality of bypass channels (16) to provide a fluid path past the packer elements, the sleeve including at least owe anchoring member (22, 50), the at least one anchoring member being actuate to contact the tubular by fluid pressure from the bypass channels when the packer is set.

Abstract: A well packer assembly with an annular fluid bypass and a check valve. The well packer assembly has an upper packer apparatus and a lower packer apparatus with a stimulation port therebetween. An annular fluid bypass in the upper packer apparatus communicates the well annulus from above packer elements on the upper packer apparatus to below the packer elements. The well fluid circulated through the fluid bypass is discharged into the well annulus below the packer elements on the upper packer apparatus to circulate stimulation fluid through the stimulation port and upwardly through the upper packer apparatus and the tubing used to lower the upper packer apparatus into the well.

Abstract: Apparatuses and methods to communicate with a zone below a subsurface safety valve (104, 204) independent of the position of a closure member (106) of the safety valve are disclosed. The apparatuses and methods include deploying a subsurface safety valve (104, 204) to a profile located within a string of production tubing. The subsurface safety valve (104, 204) is in communication with a surface station through an injection conduit (150,152; 250,252) and includes a bypass pathway (144, 244) to inject various fluids to a zone below.

Abstract: A system and a method for installing a liner conduit in a borehole. The system includes a packer assembly, a running tool or a packer assembly and a running tool. The method uses a packer assembly and a running tool for installing a liner conduit in a borehole. The system and the method both use pressure to perform functions relating to the system and the method.

Abstract: Fluid setting pressure is delivered to a hydraulically set well packer through an external conduit strapped to the exterior of a well workstring above the packer assembly. The continuity of the external conduit is continued past the packer assembly by following a flow channel along the mandrel sleeve thickness. Representatively, the external conduit may serve a primary well function other than packer setting (e.g. well chemical delivery). A calibrated rupture element in the external conduit is disposed to initially obstruct external conduit flow past the packer element. Consequently, fluid pressure transferred down the external conduit is first channeled to the packer setting pressure chamber. After setting, the fluid pressure in the external conduit is increased to rupture the calibrated element. When the external conduit flow channel is opened by rupture of the calibrated element, and the additional well service function may be accomplished.

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 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 of creating a weld to connect a first element to a second element, said elements being arranged in a wellbore containing a wellbore fluid, is provided. The method comprises selecting a welding path along which the weld is to be created, selecting a volume portion of the wellbore, in which selected volume portion said path is located and sealing said selected volume portion from the remainder of the wellbore volume, and providing pressure control means for controlling the fluid pressure in said selected volume portion. The pressure control means is then operated so as to reduce the fluid pressure in said selected volume portion to a selected pressure at which the weld can be created, and the weld is created along the selected welding path.

Abstract: A packer for use inside a casing of a subterranean well includes a resilient element, a housing and a rupture disc. The resilient element is adapted to seal off an annulus of the well when compressed, and the housing is adapted to compress the resilient element in response to a pressure exerted by fluid of the annulus of a piston head of the housing. The housing includes a port for establishing fluid communication with the annulus. The rupture disc is adapted to prevent the fluid in the annulus from entering the port and contacting the piston head until the pressure exerted by the fluid exceeds a predefined threshold and ruptures the rupture disc.

Abstract: A flow and pressure control valve for injecting a fluid into a well, or for pumping the fluid out of the well, includes an outer housing, a mandrel within the outer housing, and a pressure element attached to the mandrel. The pressure element can be pressurized to move radially inward to constrict a longitudinally extending flow passage in the valve between the mandrel and the outer housing. In addition, the mandrel includes annular orifices, and channel segments along the outside diameter thereof, which form tortuous and circumferential flow paths through the valve. The annular orifices and channel segments are constructed to provide a desired frictional head loss, and to control the pressure and flow rate of the injected fluid to prevent cavitation and cascading. Pressurization of the pressure element can also be controlled to vary the tortuous flow path through the flow passage, or to seal the flow passage.

Abstract: An improved apparatus for transmitting signals through a well tool is provided. In a broad aspect, the present invention is a communication conduit in a well tool comprising: a cylindrical mandrel having a longitudinal bore therethrough, an inner diameter, an outer diameter, and an outside circumference; a well tool attached to the outside circumference of the cylindrical mandrel; and at least one signal transmitting passageway positioned in the mandrel between the inner diameter and the outer diameter. In a specific embodiment, the well tool may be a packer. The at least one signal transmitting passageway may be used as a carrier for electrical or fiber optic conductors, or it may be a pressure retaining member whereby pressurized hydraulic fluid may be passed through to a device below the well tool without interruption.

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: 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 pressure limit valve for well tools where a valve member is moveable between a first closed portion, an open position and a second closed position. A spring for closing the valve is separated from a locking chamber which contains locking elements. The locking elements are located in a locking chamber and are held deactivated by a release sleeve which separates from the valve member in an open position. When the valve moves to the second closed position it is locked by engagement of the locking elements with a stop shoulder. In use between closely coupled inflatable packers, the valve prevents trapped pressure between the packers from affecting operation of the packer valve.

Abstract: A packer set safety valve assembly for controlling annular and tubing flows within a subterranean wellbore is disclosed. The packer set safety valve assembly controls the annular and tubing flows through dual flow paths. The assembly includes a means, that is remotely actuatable, to secure the assembly within the wellbore, a means, also remotely actuatable, the allows selective control of fluid flow in the dual flow paths, and a means, remotely actuatable as well, to unsecure the assembly from within the wellbore. The packer set safety valve assembly is a "fail closed" design which prevents flows through the dual flow paths when the fluid flow control means is not actuated to allow flow.

Abstract: A positive circulating valve with a retrievable standing valve therein. The valve is used with a packer positioned therebelow. The circulating valve comprises a housing with a mandrel slidably disposed therebetween. A J-slot controls movement between open and closed positions. When in the open position, mandrel ports in the mandrel are aligned with body ports in the housing so that bypassing and circulating may be carried out. The standing valve prevents fluid flow downwardly through the tool string below the circulating valve when the circulating valve is in the open position. When the circulating valve is in a closed position, the mandrel ports are in communication with a central opening through the housing, allowing fluid to be pumped downwardly through the circulating valve. The standing valve may be removed so that the circulating valve has a substantially unrestricted flow path therethrough for high flow rate fracturing jobs and the like.

Abstract: An annular safety system for a well produced by gas lift includes a packer, a landing nipple below the packer and an operating seal unit to which primary and secondary well tubings and a control line are connected. There is an inline valve in the secondary tubing and safety valve operated by the control line in a primary flow conduit in the operating seal unit. After the operating seal unit is inserted through the packer to automatically land and be locked in the landing nipple and the packer operated to anchor and seal in a well casing, flow passages are formed for conveying lift gas from the secondary tubing to around the landing nipple for lifted flow upward through the primary conduit and tubing. When the well is being produced by lift gas, and pressure in the control line is reduced purposely or by rupture of the control line, the safety valve operates to prevent upward lifted flow in the primary tubing.

Abstract: A method and apparatus for installing a gravel pack well completion wherein flow of fluid in the well can be effectively blocked and excessive hydrostatic pressure can be isolated from the top of a pre-placed column of gravel while an auger-liner assembly is rotated into the gravel. Basically, gravel is first placed within the zone after which a liner is lowered on a workstring and the liner is augered into the pre-placed gravel. A packer cup and by-pass assembly is coupled into the workstring having cup packers which effectively block flow within the well during installation of the liner. The cups are mounted on a rotatably mounted sleeve so that the workstring can be rotated while the cups are expanded against the well casing. The packer cup and by-pass assembly includes a bypass which can be opened after the liner has been placed so that the workstring can easily be withdrawn from the well.

Abstract: A method and apparatus of electrically and sequentially completing an oil and/or gas well through a tubing production string in a well casing. The operation includes electrically and sequentially actuating downhole equipment such as well packers, a safety joint, well annulus safety valve, solenoid actuated tubing safety valve, blanking block valve, circulating sleeve, and receiving electrical feedback from the equipment determining the position of the downhole equipment.

Abstract: A resettable downhole packer is provided. Circulation from the surface creates a backpressure behind the packing element that expands the packing element into contact with the wellbore or casing. The tool may be shifted to trap pressure behind the element to retain it in contact with the wellbore or casing while, at the same time permitting flow through the packing element for procedures such as injection or stimulation. The tool incorporates a release mechanism to facilitate retrieval of the tubing string if, for any reason, the tool becomes stuck. Provisions are incorporated into the design to maintain the packing element in a retracted position for the running in and removal to avoid damage to the packing element.

Abstract: The present invention relates to a subterranean well annulus pressure safety valve. In one embodiment, the valve is full opening to permit complete access therethrough of wireline and other remedial tools, and contains the annulus safety valve members completely offset from the central housing. The invention also relate to an annulus safety valve wherein a series of valve elements are placed exterior of a central housing and may be staged to open in series upon incremental increase of pressure thereacross. The annulus safety valve also provides pressure equalization means to equalize pressure across the valve cluster prior to opening of the cluster. The annulus safety valve also has selectively disengagable sealing plug means therein which may be removed while the valve is in the well to increase total fluid flow area through the valve components of the apparatus. A method of controlling an annular area interior of casing within a well using the annulus safety valve also is disclosed.

Abstract: The present invention relates to a subterranean well annulus pressure safety valve. In one embodiment, the valve is full opening to permit complete access therethrough of wireline and other remedial tools, and contains the annulus safety valve members completely offset from the central housing. The invention also relates to an annulus safety valve wherein a series of valve elements are placed exterior of a central housing and may be staged to open in series upon incremental increase of pressure thereacross. The annulus safety valve also provides pressure equalization means to equalize pressure across the valve cluster prior to opening of the cluster. The annulus safety valve also has selectively disengagable sealing plug means therein which may be removed while the valve is in the well to increase total fluid flow area through the valve components of the apparatus. A method of controlling an annular area interior of casing within a well using the annulus safety valve also is disclosed.