| Patent application number | Description | Published |
|---|
| 20080236844 | Packer setting device for high-hydrostatic applications - A packer setting device provides a buffered setting mechanism as a substantially incompressible fluid is selectively flowed into a compressible fluid chamber to compress a compressible fluid. This fluid transfer causes movement of a setting sleeve so that an associated packer device is set within a wellbore. | 10-02-2008 |
| 20080238252 | Piezoelectric resonant power generator - A power generation system includes a piezoelectric component, a resilient stress inducer in operable communication with the piezoelectric component, and an actuator in operable communication with the resilient stress inducer to energize and release the resilient stress inducer and method for generating power. | 10-02-2008 |
| 20080308284 | ELASTOMERIC ELEMENT INSTALLATION TOOL AND METHOD - Disclosed herein is a method of installing an elastomeric element onto a tubular. The method includes, positioning the elastomeric element onto a radially expandable member, radially expanding the radially expandable member and the elastomeric element installed thereon, positioning a tubular coaxially with the radially expandable member, and axially urging the elastomeric element off the radially expandable member thereby allowing the elastomeric element to be positioned coaxially about an outer perimetrical surface of the tubular. | 12-18-2008 |
| 20090044944 | Multi-Position Valve for Fracturing and Sand Control and Associated Completion Methods - A completion tubular is placed in position adjacent the zone or zones to be fractured and produced. It features preferably sliding sleeve valves that can assume at least two configurations: wide open and open with a screen material juxtaposed in the flow passage. In a preferred embodiment the valve assembly has three positions, adding a fully closed position to the other two mentioned. After run in, the valves can be put in the wide open position in any order desired to fracture. After fracturing, the valves can be closed or selectively be put in filtration position for production from the fractured zones in any desired order. Various ways are described to actuate the valves. The tubular can have telescoping pistons through which the fracturing can take place if the application calls for a cemented tubular. Alternatively, the tubular can be in open hole and simply have openings for passage of fracture fluid and external isolators to allow fracturing in any desired order. | 02-19-2009 |
| 20090322185 | PIEZOELECTRIC RESONANT POWER GENERATOR - A method for generating power in a wellbore includes moving an actuator; inducing an oscillating stress on a piezoelectric component with the actuator; and generating a voltage with the piezoelectric component in response to the induced stress on the piezoelectric component. | 12-31-2009 |
| 20100012323 | BEAD PACK BRAZING WITH ENERGETICS - A method of making porous shapes from unit structures such as beads involves coating the beads with two or more layers of material deposited such that it forms an energetic material. These bi-layer energetic materials are formed from a variety of materials including, but not limited to: Ti & B, Zr & B, Hf & B, Ti & C, Zr & C, Hf & C, Ti & Si, Zr & Si, Nb & Si, Ni & Al, Zr & Al, or Pd & Al, all of which can be deposited from vapor. Pressure is applied to prevent the components from moving and the solid-state reaction between the alternating layers produces exothermic heat. Heat from the reaction alone or in conjunction of an applied brazing compound joins the beads forming a porous shape that is desired. The reaction in the materials may be activated with a small pulse of local energy that can be applied using optical, electrical, or thermal sources. Common examples include an electrical pulse, spark, hot filament, a laser beam, etc. The method reduces energy consumption and the need for specialized equipment. The reactive materials and optional brazing material are preferably applied in a fluidized CVD furnace. | 01-21-2010 |
| 20100147538 | Packer Setting Device for High Hydrostatic Applications - A packer setting device provides a buffered setting mechanism as a substantially incompressible fluid is selectively flowed into a compressible fluid chamber to compress a compressible fluid. This fluid transfer causes movement of a setting sleeve so that an s associated packer device is set within a wellbore. | 06-17-2010 |
| 20100206566 | One Trip Cemented Expandable Monobore Liner System and Method - An apparatus to protect the mounting area of casing and a locating profile and optionally a sliding sleeve valve and a flow path from the outside of the valve to the annulus when subsequent attachment of an expanded liner is intended and the expanded liner is to be cemented in place. A barrier sleeve, nose, and outer sleeve define a sealed cavity having a loose incompressible material inside that covers the mounting location on the casing. A locating profile and an optional sliding sleeve valve and a flow path from the outside of the valve to the annulus can be provided. The cementing of the casing takes place through the barrier sleeve. After the cementing, the sleeve and nose are drilled out and the incompressible material is removed to the surface with the drill cuttings. A liner is inserted in the casing and is preferably expanded into sealing contact with the mounting location on the casing. After expansion a cement retainer positioned at the bottom of the expanded liner and the sliding sleeve located either above the mounting location of the liner in the casing shoe or in the liner below the mounted top section allow cement to be delivered outside the expanded liner and the displaced wellbore fluid to return into the casing through so that the liner can be cemented. The cement retainer can be delivered with either the liner or the expansion tools to allow expansion and cementing in a single trip. A shifting tool can be run on the expansion string to actuate the sliding sleeve and if necessary to allow for cement to be pumped from the drill string into the annulus through the sliding sleeve. The cement retainer can be milled out in a separate trip. | 08-19-2010 |
| 20100206587 | One Trip Cemented Expandable Monobore Liner System and Method - An apparatus to protect the mounting area of casing and a locating profile and optionally a sliding sleeve valve and a flow path from the outside of the valve to the annulus when subsequent attachment of an expanded liner is intended and the expanded liner is to be cemented in place. A barrier sleeve, nose, and outer sleeve define a sealed cavity having a loose incompressible material inside that covers the mounting location on the casing. A locating profile and an optional sliding sleeve valve and a flow path from the outside of the valve to the annulus can be provided. The cementing of the casing takes place through the barrier sleeve. After the cementing, the sleeve and nose are drilled out and the incompressible material is removed to the surface with the drill cuttings. A liner is inserted in the casing and is preferably expanded into sealing contact with the mounting location on the casing. After expansion a cement retainer positioned at the bottom of the expanded liner and the sliding sleeve located either above the mounting location of the liner in the casing shoe or in the liner below the mounted top section allow cement to be delivered outside the expanded liner and the displaced wellbore fluid to return into the casing through so that the liner can be cemented. The cement retainer can be delivered with either the liner or the expansion tools to allow expansion and cementing in a single trip. A shifting tool can be run on the expansion string to actuate the sliding sleeve and if necessary to allow for cement to be pumped from the drill string into the annulus through the sliding sleeve. The cement retainer can be milled out in a separate trip. | 08-19-2010 |
| 20100294376 | TWO-WAY ACTUATOR AND METHOD - Disclosed herein is a two-way actuator. The actuator includes, a tubular, movably positionable within a structure between at least a first position and a second position, the tubular having a first density selected such that buoyancy forces urge the tubular toward the first position in response to submersion of the tubular within a fluid having a second density that is greater than the first density, and at least one flow resistor disposed at the tubular configured to urge the tubular toward the second position in response to fluid flow interacting with the at least one flow resistor. | 11-25-2010 |
| 20100314133 | FRAC SLEEVE SYSTEM AND METHOD - A system including a plurality of differential pressure actuated tools; a seat receptive to a plug; a first conduit fluidly communicating tubing pressure upstream of the seat to one end of each of the plurality of tools; and a second conduit fluidly communicating tubing pressure downstream of the seat to an opposite end of each of the plurality of tools and method. | 12-16-2010 |
| 20110005763 | Subterranean Valve Operated by String Relative Movement - A valve is mounted to a tubular string and has an actuation assembly that is isolated from well fluids. The valve member can be a ball that rotates on a pivot and is actuated by relative rotation of string components that straddle the ball. Rotation of one string component is linked to the closure ball by an external slanted slot with an operating ball that rides in it and connects the rotating string component to the closure ball. Travel stops limit the desired rotation of the closure ball in opposed directions. The closure ball can alternatively be rotated by relative longitudinal string component movement that is converted to relative rotation such as through the use of a j-slot mechanism. Internal seals isolate the slanted slot and operating ball from well fluids. | 01-13-2011 |
| 20110056678 | Reduced Wear Position Indicating Subterranean Tool - A positioning tool engages a profile with retaining members such as dogs so that a pulling force can be applied for a predetermined time as a signal that the tool is at the proper location. The time delay is a fluid system that drives fluid through a narrow restriction. The restriction is variable to allow unloading of the resistance from the fluid system while the dogs are still adequately supported. As a result the dogs are released from the profile without regional overstressing. A lock can prevent the tool from resetting to limit its use to locating at a single location. The lock holds the hydraulic system in a defeated position so that even if the dogs engage another profile when locked they will immediately exit that profile. | 03-10-2011 |
| 20110120726 | Multi-Position Valve for Fracturing and Sand Control and Associated Completion Methods - A completion tubular is placed in position adjacent the zone or zones to be fractured and produced. It features preferably sliding sleeve valves that can assume at least two configurations: wide open and open with a screen material juxtaposed in the flow passage. In a preferred embodiment the valve assembly has three positions, adding a fully closed position to the other two mentioned. After run in, the valves can be put in the wide open position in any order desired to fracture. After fracturing, the valves can be closed or selectively be put in filtration position for production from the fractured zones in any desired order. Various ways are described to actuate the valves. The tubular can have telescoping pistons through which the fracturing can take place if the application calls for a cemented tubular. Alternatively, the tubular can be in open hole and simply have openings for passage of fracture fluid and external isolators to allow fracturing in any desired order. | 05-26-2011 |
| 20120118579 | Multi-Position Valve for Fracturing and Sand Control and Associated Completion Methods - A completion tubular is placed in position adjacent the zone or zones to be fractured and produced. It features preferably sliding sleeve valves that can assume at least two configurations: wide open and open with a screen material juxtaposed in the flow passage. In a preferred embodiment the valve assembly has three positions, adding a fully closed position to the other two mentioned. After run in, the valves can be put in the wide open position in any order desired to fracture. After fracturing, the valves can be closed or selectively be put in filtration position for production from the fractured zones in any desired order. Various ways are described to actuate the valves. The tubular can have telescoping pistons through which the fracturing can take place if the application calls for a cemented tubular. | 05-17-2012 |
| 20120227973 | Tool with Multisize Segmented Ring Seat - A wellbore tool which includes a housing having an axial flowbore and a piston sleeve movably disposed within the flowbore. The tool is moveable between first and second operating positions by an actuation mechanism having a piston with a seat having a plurality of separate arcuate segments. The tool can be moved between first and second operating positions with the use of actuating plugs of different sizes that can be landed upon the seat. | 09-13-2012 |
| 20130140041 | SELECTIVELY DISENGAGABLE SEALING SYSTEM - A seal assembly including a first tubular having a sealing surface and a seal element run with the first tubular and displaced from the surface. The seal element initially has a radial dimension that forms a radially innermost or outermost sealing dimension of the first tubular for enabling the first tubular to be sealed with a second tubular radially disposed with the first tubular. A mechanism is included that is triggerable for reconfiguring the radial dimension of the seal element. The sealing surface of the first tubular operative forms the radially innermost or outermost sealing dimension of the first tubular when the radial dimension of the seal element has been reconfigured for enabling the sealing surface of the first tubular to receive a second seal element. A method of sealing tubulars is also disclosed. | 06-06-2013 |
| 20140144619 | Resettable Selective Locking Device - A lock system works in combination with a mandrel to allow selective operation and disabling of a downhole tool. In the specific situation of a Smart Collet® the tool is locked from being able to find support when engaged to a mating profile as the tool is moved between landing locations. A lower housing features an external dog that in response to rotation takes with it a collet ring with circumferentially oriented fingers. An outer housing cams the collet heads into a respective groove in the mandrel. Reversal of such relative rotation between the upper and lower housings allows the collet heads to spring out of the mandrel groove for the unlocked position. The lock is adapted for use in a variety of tools. The rotation to unlock and then lock is accomplished by dog interaction with shaped internal profiles in a surrounding tubular assembly at strategic locations where needed. | 05-29-2014 |
| 20150013966 | Flow Control Devices Including a Sand Screen Having Integral Standoffs and Methods of Using the Same - In one aspect, a flow control device is disclosed that in one embodiment may include a sand screen that includes adjacent wraps of a longitudinal member, wherein the longitudinal member has a width, a first axial side and a second axial side, the longitudinal member further including spaced apart standoffs along the first axial side and spaced apart channels that provide fluid paths from the second axial side to the first axial side. | 01-15-2015 |
| 20150075788 | Apparatus and Methods for Locating a Particular Location in a Wellbore for Performing a Wellbore Operation - An apparatus for use in a wellbore is disclosed that in one non-limiting embodiment includes a locating device having a locating collet configured to engage with a locating profile on a housing and disengage from the locating profile when a first pull load is applied to the locating collet, a delay device that prevents application of the first pull load on the locating collet when it is engaged with the locating profile until the delay device has been activated, and a locking device configured to prevent activation of the delay device until a second pull load less than the first is applied on the locking device for a selected period of time. | 03-19-2015 |
| 20150075807 | Apparatus and Methods for Selectively Treating Production Zones - In one aspect, an apparatus for selectively treating a plurality of zones around wellbore is disclosed that in one non-limiting embodiment includes an outer string for placement in the wellbore, the outer string including a packer above a flow port corresponding to each zone, wherein each packer is configured to be set independently and the flow port is configured to supply a treatment fluid to its corresponding zone when such flow port is open, an activation device coupled to each packer, wherein each such activation device is configured to be independently activated to set its corresponding isolation packer, and an inner string for placement in the outer string, the inner string including a frac port for supplying a fluid under pressure to each flow port. | 03-19-2015 |
| 20150075815 | Apparatus and Methods Setting a String at Particular Locations in a Wellbore for Performing a Wellbore Operation - An apparatus for use in a wellbore is disclosed that in one non-limiting embodiment includes a set down tool that includes a locating device configured to engage with an outer member at a selected location, a set down device configured to set down in a set down profile in the outer member when the set down device is activated, an alignment device for activating the set down device and a locking device that operates the alignment device to activate the set down device while maintaining the locating device engaged with the outer member. | 03-19-2015 |
