Abstract: The description relates to devices, such as computing devices that have hinged portions. One example can include a first portion and a second portion. The first portion can define a first hinge axis and can be resiliently biased toward the first hinge axis. The second portion can define a second hinge axis and can be resiliently biased toward the second hinge axis. A first cam can operate relative to the first hinge axis and is slidably secured to the first portion. A second cam can operate relative to the second hinge axis and can be slidably secured to the first portion. When the first and second portions are oriented at an acute angle the second cam can force the second portion away from the second hinge axis while the first cam can allow the first portion to remain biased toward the first hinge axis.

Abstract: A refrigerator includes a cabinet defining a storage compartment, a refrigerator door configured to open and close the storage compartment, a hinge assembly configured to couple the refrigerator door to the cabinet, and a door opening device provided at the cabinet and configured to rotate the refrigerator door about the hinge assembly. The door opening device includes a frame, and a pushing member slidably provided at the frame and configured to protrude from the frame toward the hinge assembly to thereby open the refrigerator door.

Abstract: In one embodiment, the present invention relates to a belt tensioning device for a hollow blind that comprises: a holder seat equipped with a lower belt gear on the top portion of the holder, the holder seat is in clearance fit with a lumen of a side frame of the hollow blind and is provided with a group of V-shaped slots from top to bottom therein, each V-shaped slot is equipped with a clip therein, the slip has a width slightly larger than the width of the lumen of the side frame of the hollow blind when being bent. The present invention allows the belt tensioning device to move along a single direction within the side frame of the hollow blind so that the distance between two belt gears can be gradually adjusted, thereby maintaining a proper tensioning force in the belt.

Abstract: There are provided various implementations of a solar shade for covering a transmissive panel such as a window, door, sunroof or skylight of a vehicle, building, or home. Such a solar shade includes a photovoltaic sheet, which may be a flexible sheet. The solar shade is configured to absorb heat produced due to sunlight transmitted through the transmissive panel and impinging on the solar shade. The photovoltaic sheet is configured to generate an electrical current using the sunlight.

Abstract: A spring pre-tensioning device for a roll blind is provided. The pre-tensioning device includes a rotation shaft including a threaded part, with a restraining protrusion provided on the threaded part, and a locking groove. The pre-tensioning device also includes a restraining nut engaged with the threaded part of the rotation shaft, and disposed on the restraining protrusion, so as to prevent the restraining nut from moving further forward; a restraining body provided with a shaft insertion hole therein, and provided with a locking protrusion and a locking clip and a spring. The restraining body is fitted over the outer circumferential surface of the rotation shaft and is fixedly connected to the spring is rotated to apply a predetermined pretension value to the spring, and is engaged with the restraining nut that is prevented from forward rotation, thereby restraining pretension of the spring.

Abstract: The present invention relates to an access control device having at least one movably mounted barrier element, which can be moved to a blocking position, in which it blocks access, and an access position, in which access is enabled. In order to enable a variable use in different locations without time-consuming assembly, for example in order to variably delimit different spaces in a casino or an event location, the movable barrier element is mounted on a barrier support which includes free-standing ground contact means for the anchor-free, position-variable putting up of a barrier element on the ground. A lateral delimitation laterally enclosing or extending the at least one barrier element has a modular design and can be assembled from a number of side pieces which can be variably joined end to end under different angles and which together form the lateral delimitation.

Abstract: A device is provided for the movement and mutual assembly of segments of an excavation battery. The device includes four parts: an upper joint, a lower joint, a flexible element and a stop element. The upper joint is connectable to a driving tube. The lower joint is connectable to one segment of the excavation battery. The flexible element connects the upper joint to the lower joint so that the lower joint slides along the flexible element. The stop element limits the sliding of the lower joint away from the upper joint, and includes a ballast with a diameter that is less than a diameter of an inner duct in one segment of the excavation battery.

Abstract: Repeated percussive forces may be provided using various devices, systems, assemblies, and methods. Example rotary percussive devices may be used in a downhole environment, including within a drilling system that includes a percussive hammer drill bit. The rotary percussive device may include a rotational translator to convert drilling fluid pressure into a rotational force. An axial translator coupled to the rotational translator may convert the rotational force into an axial percussive force. This conversion may be done using magnets arranged in arrays of alternating polarities. The rotational translator may longitudinally overlap the axial translator. The rotational translator may include a rotational stator rotationally fixed within a bottomhole assembly. The rotational stator may include a shaft of a positive displacement motor.

Abstract: An underground directional drilling system can comprise a plurality of elongated dual-shaft segments coupled together end-to-end and forming an inner shaft assembly independently rotatable relative to an annular outer shaft assembly. The dual-shaft drilling system can include a communication segment that comprises an outer shaft having first longitudinal portion, a second longitudinal, and a gap portion that provides electrical insulation therebetween. The communication segment can generate voltage differences between the longitudinal portions that cause electrical pulses to periodically transfer across the gap portion to wirelessly communicate drilling related data to the surface. An inner shaft of the communication segment can comprise electrical insulation to avoid creating an electrical short between the first and second longitudinal portions of the outer shaft.

Abstract: A whipstock assembly includes a whipstock providing a ramped surface, and a mill releasably coupled to the whipstock with a shear bolt and providing a mill profile. A tension arm is pivotably coupled to the whipstock and movable between a stowed position, where the tension arm is received within a cavity defined in the ramped surface, and an engaged position, where an engagement head of the tension arm mates with the mill profile to assume at least a portion of a tensile load assumed by the shear bolt.

Abstract: A fully rotating bias unit for directional drilling rotates at bit speed while providing proportional control of directional response and steering force. The unit also provides added reliability by having increased redundancy (multiple independently controlled actuators). The unit disposed on a drillstring transfers rotation to a drill bit and has a bore communicating fluid from the drillstring to the drill bit. Directors are disposed on the unit to rotate with it. Each of the directors is independently movable between extended and retracted conditions relative to the unit's housing. Actuators of the unit are in fluid communication between the bore and the borehole or some other low pressure. Each actuator is independently operable to direct communicated fluid from the bore to extend a respective one of the directors toward the extended condition.

Abstract: A method for excavating a well cellar includes lowering an excavating apparatus having a cellar liner therein to a bottom of a body of water. The well cellar is excavated while contemporaneously lowering the cellar liner into the well cellar until a top of the cellar liner is substantially level with the bottom of the body of water. A pilot well is excavated below a bottom of the cellar. A well head support pipe is inserted into the pilot well. The bottom of the well cellar and a top of the cellar liner are covered.

Abstract: A rock bit for blast hole drilling includes: a bit body having a coupling formed at an upper end thereof, a plurality of lower legs, a dome formed between the legs, and a bore formed through the coupling and the dome; a plurality of skirts, each skirt covering a gap formed between adjacent legs and each skirt mounted to edges of adjacent legs; a plurality of roller cones, each rotary cone rotatably mounted to a respective bearing shaft of a respective leg; a row of gage cutters mounted to each roller cone; a row of inner cutters mounted to each roller cone; one or more nose cutters mounted to each roller cone; and a center jet secured in the bore. Each cutter is an insert.

Abstract: A drill head for expanding a pilot bore in order to create a borehole having a borehole wall as a result of loosening rock surrounding the pilot bore in the region of a working face, which extends in a substantially right-angled manner to the pilot bore, including a basic body including a connection element for a pilot bore string including at least two tool holders, in that at least one tool holder is at a greater spacing radially from the basic body than the at least one other tool holder such that there is at least one outer and one inner drilling tool which are movable into engagement with the working face, and the at least one inner drilling tool and the at least one outer drilling tool are each arranged offset at an angle in relation to the working face.

Abstract: Roller cutters comprise a diamond-bonded body joined to an infiltration substrate. An extension is joined to the substrate and includes first section having a diameter sized the same as the substrate, and an integral second section having a diameter smaller than the substrate. The extension is joined to the substrate during an HPHT process. The first section has a thickness greater than that of the infiltration substrate. The second section has an axial length greater than the combined thickness of the substrate and the first section. The extension has a strength and/or toughness greater than the substrate as a result of its material composition, e.g., the amount of binder phase material and/or the size of hard phase material. The roller cutter is rotatably disposed within a pocket internal cavity, wherein the pocket is attached to a drill bit.

Abstract: In an embodiment, a polycrystalline diamond compacts (“PDC”) includes a substrate and a polycrystalline diamond (“PCD”) table bonded to the substrate. The PCD table defines an upper surface and at least one peripheral surface. The PCD table includes a plurality of bonded diamond grains. The PCD table includes a first region adjacent to the substrate that includes a metallic constituent disposed interstitially between the bonded diamond grains thereof, and a leached second region extending inwardly from the upper surface and the at least one peripheral surface that is depleted of the metallic constituent. The leached second region exhibits a leach depth profile having a maximum leach depth that is measured from the upper surface. A leach depth of the leach depth profile decreases with lateral distance from a central axis of the PCD table and toward the at least one peripheral surface.

Abstract: Polycrystalline ultra-hard constructions comprise a polycrystalline ultra-hard material body and two or more support members attached to the body by braze material. The support members include a backside support member and a side support member. The side support member is a one- or two-piece construction, and is positioned circumferentially around and extends axially along the body or both the body and the backside support member such that a working surface of the body remains exposed. The support members can be configured to provide a mechanical attachment or interlocking attachment with the body or another support member. The braze materials used in the construction can be different and selected to enhance the attachment and/or reduce the creation of thermal stress within the construction during assembly. The support members can be selected having different thermal expansion characteristics that also operate to reduce the thermal stress during construction assembly.

Abstract: A thermally stable polycrystalline diamond compact is created by (i) preforming an annular thermally stable polycrystalline from a diamond plate, (ii) preforming a substrate with a projection that has an interfacial mating surface that is a negative topology of the annular thermally stable polycrystalline, (iii) and brazing the two components together. The resulting polycrystalline diamond compact can be made thermally stable because cobalt and other catalysts can be leached out of the thermally stable polycrystalline. The thermally stable polycrystalline can be attached to the substrate by brazing, which due to the topology of the thermally stable polycrystalline and the substrate with a projection will unexpectedly have sufficient blaze shear strength to be used in demanding applications.

Abstract: A tubular anchor spool having a plurality of removably attached, radially extending, support beams removably attached to a BOP stack of a wellbore to provide a temporary support framework for workover equipment such as a snubbing unit. Guywires are attached to the support beams of the temporary framework for support of the workover equipment. The anchor spool is fabricated offsite and delivered to the well site for installation.

Abstract: One example embodiment is an apparatus including a ring assembly and a contact assembly. The ring assembly includes a conductive ring having a conductive ring engagement surface. The contact assembly includes a contact block and a contact element having a contact element engagement surface. The contact element is connected with the contact block. The contact element forms a loop around the conductive ring between the ends of the contact element. The contact element engagement surface is engaged with the conductive ring engagement surface along an electrical contact section of the loop. Another example embodiment is a method for assembling a slip ring.

Abstract: Implementations of the present invention include drill string components having a thread extending around a body. The leading end of the thread can have a configuration that resists jamming and cross-threading. In particular, the leading end of the thread can include a planar surface normal to the body. The leading end of the thread can provide an abrupt transition to full thread depth that helps reduce or eliminate cross-threading. The leading end of the thread can be oriented at an angle relative to the axis of the drill string component. When mating male and female threads are similarly structured, the mating threads slide together along an interface at the thread start face and are drawn into a fully thread-coupled condition. The thread starts may have full circumference mating with no jamming positions.

Abstract: A field created integral electrically isolated centralizer and swell packer system for wellbore tubulars having in series over the wellbore tubular, a first end ring, a swell packer portion over a first and second primer optionally with cured resin, a second end ring, wherein the end rings inhibit axial movement of the swell packer portion. Integral with the swell packer portion an electrically isolating centralizer; a cured resin bonded to the wellbore tubular filling all hollow spaces of the centralizer portion integrally forming a high strength bond, while excluding bonding to the first and second end rings, the cured resin configured to cure to a hardness of at least 50 shore A and withstand temperatures and pressures within a wellbore for at least twenty-four hours without melting, while specifically excluding a sand screen.

Abstract: A drill rod clamping system for securing a drill rod in a selected position. The drill rod clamping system has a hollow spindle with an upper portion that defines axial slots and a base portion that defines at least one radial opening. A plurality of jaws are moveable radially inwardly to a drill rod gripping position and radially outwardly to a drill rod releasing position. Each jaw is received within a respective axial slot of the hollow spindle. An actuator moves the plurality of jaws between the drill rod gripping position and the drill rod releasing position. A compressed gas spring assembly exerts force on the actuator to close the jaws. A hydraulic operator exerts force on the actuator to overcome the force of the compressed gas spring assembly to open the jaws. The radial openings of the base portion of the spindle permit flushing of material flowing within the spindle.

Abstract: An exit side pipe handling and vise tool. The tool may be suspended from an arm of a hydraulic machine and rotated and pivoted relative to the arm. The tool comprises two retainer assemblies, two vise assemblies, and a roller assembly each suspended from a linear frame. Each of the retainer assemblies is movable relative to the frame in a direction transverse to a length of the frame. The vise assemblies are in side-by-side configuration to break a connection between adjacent pipe segments. The roller assembly defines rollers having a spiral ramp disposed on an external surface to encourage axial movement of a pipe segment during rotation thereof.

Abstract: The disclosed embodiments relate to a system that includes a manifold assembly having a first drilling fluid flow path configured to enable operation of a first drilling technique for a mineral extraction system, where the first drilling fluid flow path has a first inlet and one or more first outlets and a second drilling fluid flow path configured to enable operation of a second drilling technique for the mineral extraction system, different from the first drilling technique, where the second drilling fluid flow path has a second inlet and one or more second outlets, and where the first drilling fluid flow path and the second drilling fluid flow path are different from one another.

Abstract: This disclosure is generally drawn to systems, devices, apparatus, and/or methods related to shaker/filtration systems for drilling environments. Specifically, the disclosed systems, devices, apparatus, and/or methods relate to extended handles on screens used in shaker/filtration systems for drilling environments. In some examples, extended screen handle(s) may include a fastening portion and a handling portion. The fastening portion may be adapted to be coupled to a screen along a side of the screen, and the handling portion may be coupled to the fastening portion. The handling portion may extend above the screen and extend about 25-100% of the length of the side of the screen.

Abstract: An apparatus for switching off and deviating a circulating liquid flow without water hammering, comprising an apparatus body (10) including an inlet channel (11) which is split into two outlet channels (12, 13) in which respective flow valves (14, 15) are arranged; said apparatus body comprises moreover a discharging channel (16) coupled to said outlet channels through respective discharging valves (17, 18); said outlet channels being moreover coupled to respective pressure measuring chambers (19, 20); a balancing valve (21) communicating two middle zones (22, 23) respectively formed in the outlet channels.

Abstract: A latching assembly for use in a well system is provided. The latching assembly can include an outer mandrel and a running tool coupling assembly coupled to a first longitudinal end of the outer mandrel. The running tool coupling assembly can be operable to couple to a running tool that includes a drill string component. The latching assembly can be controllable using the running tool. The latching assembly can also include a bearing coupling assembly coupled to a second longitudinal end of the outer mandrel that is opposite longitudinally with respect to the first longitudinal end. The bearing coupling assembly can be operable to couple to a bearing assembly. The latching assembly can further include a rotating control device (RCD) coupling assembly coupled to the side of the outer mandrel. The RCD coupling assembly can be operable to couple to an RCD positioned in the well system.

Abstract: A plug is engageable with a ball for seating in a tubular having an internal profile. The plug's body has a bore with a seat. Blocks disposed on the body are temporarily held in a retracted condition, but the blocks are biased outward to an expanded condition for engaging inside the tubular. The plug sets in the tubular with the blocks released from the retracted condition to the expanded condition. With the ball dropped downhole, the seat engages the ball so that fluid pressure is sealed from uphole to downhole through the bore. With applied fluid pressure against the seated ball, the plug can move through the tubular until the blocks seat in the internal profile of the tubing, sliding sleeve, or other component. A seal on the plug can then seal inside the tubular while the blocks seat in the profile and applied pressure pushes on the seated ball on the plug's mandrel.

Abstract: A sensor transportation apparatus to convey a sensor assembly through a wellbore. The apparatus comprising has an engagement structure to connect the sensor transportation apparatus to the sensor assembly, and one or more wheels arranged to rotate about an axis of rotation substantially perpendicular to a longitudinal axis of the sensor assembly when the transportation apparatus is connected to the sensor assembly. An orientation structure defining a form having a transverse outline which has a rotational center, wherein the rotational center is offset from a centroidal axis of the elongate sensor assembly.

Abstract: The present application discloses the use of the pre-stressed steel strand in, the procedure of multi-angle core drilling. Using the properties of high strength and toughness of pre-stressed steel strand material, the core internal pipe is pushed inside the drill rod without deformation and damage. The rolling wheel is designed to rapidly take out and put back the pre-stressed steel strand to finish the extracting of the core, without taking out and putting back the drill rod. Without altering the original structure of the drilling machine, the technology of 360° core drilling is realized. Problems of tedious and arduous operations and a low efficiency in multi-angle drilling are resolved completely. The use of the pre-stressed steel strand not only can significantly improve the drilling-in efficiency, but also is beneficial to guarantee the quality of the rock mineral coring, reduce the cost of drilling, lower the labor intensity notably.

Abstract: An apparatus that is usable with a well includes a first component and a second component. The first component is adapted to dissolve at a first rate, and the second component is adapted to contact the first component to perform a downhole operation and dissolve at a second rate that is different from the first rate.

Abstract: A downhole assembly includes a downhole tool including a degradable-on-demand material and a triggering system. The degradable-on-demand material includes a matrix material and an energetic material configured to generate energy upon activation to facilitate the degradation of the downhole tool. The triggering system includes an igniter arranged to ignite the downhole tool, an electrical circuit, and a pre-set timer. In an open condition of the circuit the igniter is not activated, and in a closed condition of the circuit the igniter is activated. The pre-set timer is operable to close the electrical circuit after a pre-set time period.

Abstract: A downhole assembly includes a downhole tool including a degradable-on-demand material including: a matrix material; and, an energetic material configured to generate energy upon activation to facilitate the degradation of the downhole tool; and, a triggering system including: an electrical circuit having an open condition and a closed condition, the electrical circuit configured to be in the closed condition after movement of an object downhole that engages directly or indirectly with the triggering system; and, an igniter within the electrical circuit, the igniter arranged to ignite the downhole tool in the closed condition of the electrical circuit. In the open condition of the electrical circuit the igniter is inactive, and in the closed condition of the electrical circuit the igniter is activated.

Abstract: A downhole assembly arranged within a borehole includes a downhole tool including a degradable-on-demand material, the degradable-on-demand material including: a matrix material; and, an energetic material configured to generate energy upon activation to facilitate the degradation of the downhole tool; and, a triggering system including: an electrical circuit; an igniter in the electrical circuit arranged to ignite the energetic material; a sensor configured to sense a target event or parameter within the borehole; and, a control unit arranged to receive sensed signals from the sensor and to deliver a start signal to the electrical circuit in response to the sensed signals indicating an occurrence of the target event or parameter; wherein, after the start signal is delivered from the control unit, the electrical circuit is closed and the igniter is initiated.

Abstract: A mobile cutting tool is for cutting a subsea tubular structure and has i) a tool body for receiving the subsea tubular structure in an enclosure thereof; ii) an actuator mounted on the tool body at one side of the enclosure; iii) a non-rotatable cutting element provided on the actuator, the actuator with the cutting element for carrying out a translational cutting movement through the enclosure including the subsea tubular structure, and iv) a reaction member mounted at an opposite side of the enclosure of the tool body opposite to the cutting element for applying a reaction force on the subsea tubular structure during cutting. A method is for cutting a subsea tubular structure, wherein a non-rotating translation cutting movement is used for cutting.

Abstract: A hydraulic jar for delivering impacts downhole. The jarring mechanism includes a cup-type piston that moves through a seal bore. The cup is deformable in response to fluid pressure so that it expands each time it moves through the seal bore to compensate for wear on the lip. Since only minimum interference is required between the piston and seal bore, less material may be used. This reduces the force required to reset the tool, which is particularly advantageous in horizontal wells. The seal bore may be slightly wider at the exit; the cup expands to this exit diameter, ensuring an interference fit as the cup travels back through the smaller diameter entry section. The entry end of the seal bore may include longitudinal grooves. This prevents the piston cup from rupturing by preventing a fluid seal around the lip until the most of cup is inside the seal bore.

Abstract: A system for coupling to equipment at a well includes a connector and/or an outer sleeve sub engageable with the connector, each including an internal bore. An isolation sleeve includes a seal and is positioned at least partially within the internal bore, in which the seal is axially movable with respect to the internal bore so as to be positionable to seal against the equipment.

Abstract: A method for anchoring a casing string within a wellbore is disclosed. The method includes providing a casing string, where the casing string being generally tubular, and coupling a swellable elastomeric material on at least a portion of the exterior of the casing string. In addition, the method includes positioning the casing string within a wellbore, exposing the swellable elastomeric material to a swelling fluid, and sealing the swellable elastomeric material to the wellbore.

Abstract: A collapsible baffle sub installable within a casing string of a hydrocarbon well. The collapsible baffle sub includes a movable sleeve and a collapsible baffle. By moving the sleeve from a first to a second position using a setting tool, the collapsible baffle is permitted to collapse within the collapsible baffle sub. Once collapsed, the collapsible baffle may receive an untethered object, such as a ball, forming a seal between the untethered object and the collapsible baffle and isolating sections of the wellbore for treatment.

Abstract: The present invention relates to an annular barrier to be expanded in an annulus between a well tubular structure and an inside wall of a borehole downhole. The annular barrier comprises a tubular part for mounting as part of the well tubular structure, an expandable sleeve surrounding the tubular part and having an inner face facing the tubular part, each end of the expandable sleeve being connected with a connection part which is connected with the tubular part, a space between the inner face of the sleeve and the tubular part, and an element arranged in connection with the sleeve, the element having a first part and a second part both of which extend around the inner face, the first part of the element being fastened to the inner face.

Abstract: This invention relates to a sealing apparatus, system and method for use in a well pipe. The apparatus has a mandrel arranged around a center axis through the apparatus, a radially movable gripping device arranged around the mandrel, a radially movable packer element arranged around the mandrel, and an axially movable activation device designed to set up axial forces for activating the apparatus. The apparatus also includes a radially movable centralizer arranged around the mandrel for centring the apparatus. The activation device being operatively connected to the gripping device, the packer element and the centralizer for the respective activation and radial movement of each, via power transmission of axial forces, between retracted, passive positions and expanded, active positions relative to the center axis of the apparatus.

Abstract: A packer is used for setting downhole in tubing subject to downhole flow at a high flow rate. The packer includes a setting element, a slip element, and a packing element. The setting element is disposed on the packer toward an uphole end and is activated hydraulically to move in a downhole direction toward a downhole end of the packer. The slip element is disposed toward the downhole end and is moveable outward toward the tubing in a first stage in response to the movement of the setting element. The packing element is disposed on the other elements and is at least partially carried by the setting element. The packing element is compressible outward toward the tubing in a second stage, after the first stage, in response to the movement of the setting element. Additionally, a choke ring or other element disposed on the packer at least downhole of the packing element can move outward toward the tubing in response to the setting movement to restrict the downhole flow in the annulus to a lower flow rate.

Abstract: A mechanically-set packer system for use in a wellbore may include a packer assembly. The packer assembly may include a first ring and a second ring. The packer assembly may also include a packing element positioned between the first ring and the second ring. The packer system may include a mandrel having an interior and an exterior. The packer assembly may be configured to slide onto the exterior of the mandrel. The packer system may further include a line configured to run between the exterior of the mandrel and an interior of the packing element.

Abstract: Degradable downhole tools, tool components, and balls are formed from a polyvinyl alcohol (PVA) compound. The PVA compound exhibits strength and elasticity properties that are comparable to existing degradable downhole polymers and further exhibits degradability properties that are superior to existing degradable downhole polymers. For different components, the PVA compound may include a reinforcing material such as fiberglass. Usage of tools, tool components, and balls formed from the disclosed materials eliminates the requirement that such equipment be drilled out after use as the PVA compound quickly degrades in standard downhole fluids.

Abstract: Methods including experimentally determining a salt creep profile for a single salt or intercalated salts in a subterranean formation, designing a proposed cement slurry based on the salt creep profile, experimentally determining whether the proposed cement slurry is capable of forming a wellbore load resistant cement sheath based on actual thermal and thermo-mechanical properties of the proposed cement slurry, theoretically determining whether the proposed cement slurry is capable of forming the wellbore load resistant cement sheath by designing an electronic, cross-section geometric model of the subterranean salt formation and simulating a condition of the wellbore loads on the cured proposed cement slurry using the geometric model, establishing a final cement slurry capable of forming the wellbore load resistant cement sheath, and performing a final cementing operation with the final cement slurry in the subterranean salt formation.

Abstract: A system for cementing a tubular in a wellbore that includes a sleeve made up of an annular housing with a cement seal on outer surface of the housing. The sleeve further includes a sliding block, a stationary block, an arm attached to the sliding block, and a passage formed through a sidewall of the housing, and that receives a free end of the arm. When the sleeve inner bore is pressurized, the arm moves to move the sliding block into an open space in the stationary block. Inserting the sliding block into the open space forms a seal on the outer periphery of the sleeve which forms a barrier to cement flowing in an annulus between the sleeve and inner surface of the wellbore. Lost circulation material can be deposited in the annulus and which settles along an interface between the seal and wellbore wall.

Abstract: A system, including a wellhead system, and a flow control system coupled to the wellhead system, wherein the flow control system comprises, a flow control device including a housing, a flow path through the housing from an inlet to an outlet, and a flow control element disposed in the housing along the flow path, and an actuator mounting assembly coupled to the flow control device, wherein the actuator mounting assembly is configured to selectively mount one of a manual actuator and a powered actuator to actuate the flow control element of the flow control device, without taking the flow control system offline.

Abstract: A downhole fluid flow control system includes a fluid control module having an upstream side, a downstream side and a main fluid pathway in parallel with a secondary fluid pathway each extending between the upstream and downstream sides. A valve element disposed within the main fluid pathway has open and closed positions. A viscosity discriminator including a viscosity sensitive channel forms at least a portion of the secondary fluid pathway. A differential pressure switch operable to open and close the valve element includes a first pressure signal from the upstream side, a second pressure signal from the downstream side and a third pressure signal from the secondary fluid pathway. The magnitude of the third signal is dependent upon the viscosity of the fluid flowing through the secondary fluid pathway such that the viscosity of the fluid operates the differential pressure switch, thereby controlling fluid flow through the main fluid pathway.

Abstract: An apparatus and method for displacing a sleeve within a downhole tool wherein the apparatus comprises an outer mandrel, and a sleeve extending between first and second ends slidably located within the outer mandrel wherein the sleeve and mandrel form first, second and third annular chambers therebetween. The first annular chamber is in fluidic communication with an interior of the sleeve. The second annular chamber is in fluidic communication with an exterior of the mandrel. The third annular chamber is substantially sealed. The method comprises pressurizing the second chamber through bores extending through the sleeve and releasing the pressure within the second chamber so as to permit a vacuum within a third sealed chamber and a pressure from an exterior of the mandrel to pressurize a first chamber to draw the sleeve towards a second end of the outer mandrel thereby uncovering the valve openings.