Abstract: A portable barrier for a door sill fills a gap between the flooring and the bottom of a respective door to restrict passage of water, air, and pests. The barrier detachably mounts into a door sill on an exterior side of the door. The barrier is height adjustable, so as to enable the dual function of inhibiting passage through the gap beneath the door, and enabling passage of a wheeled vehicle over the barrier. A restriction bar provides the barrier function. The restriction bar has a tapered edge to enable a wheel to roll over it. A mount bar is disposed parallel to the restriction bar for mounting to the flooring. A spring biases the restriction bar towards an extended position for expanding above the door sill. The spring compresses to enable the restriction bar to move towards the mount bar. A bolt passes through and aligns the components.

Abstract: A window includes a vacuum insulating glass (VIG) window unit in a window frame. The window frame includes at least one vacuum insulated structure (VIS) for improving the insulating functionality of the frame, so that the frame can adequately insulate the periphery of the VIG unit. Such windows may be used in residential and/or commercial window applications for buildings. The use of a window frame having at least one VIS is advantageous in that allows for improved window frame thermal performance and a narrow frame design if desired for improved aesthetics.

Abstract: There is provided a method of producing a vacuum sealed component including a sealing layer formed by heating glass powder, an inner side of the sealing layer including a closed space with specific air pressure that is lower than atmospheric pressure. The method includes a binder removal process of decomposing an organic binder by heating paste including the glass power and an organic binder; and a vacuum sintering process of forming the closed space by melting, at a temperature that is higher than a processing temperature of the binder removal process, the glass powder in a decompressed space with the specific air pressure that is lower than the atmospheric pressure. After the binder removal process and prior to the vacuum sintering process, an amount of residual carbon in a residue of the paste is less than or equal to 100 ppm by weight.

Abstract: An insulating glazed element including at least one insulating glazing unit including at least a first glass sheet and a second glass sheet associated together by an intermediate frame that keeps them a certain distance from each other. The intermediate frame includes at least two horizontal spacers and at least two vertical spacers, which are transparent. The horizontal spacers include at least two compartments which are separate and contiguous.

Abstract: Disclosed is an insulated glazed unit for use in a window or door of a building for reducing the transmission of sound energy there through. The insulated glazed unit comprises a plurality of glass panels each with a front face and a rear face and each of a distinct thickness. In a first embodiment at least one substantially uniform gap is disposed between at least two of the glass panels. At least one plastic film is disposed between the front face of a first glass panel and the rear face of a second glass panel forming a laminated unit. The asymmetric thickness laminated unit in combination with the at least one gap and at least one additional glass panel forms an insulated glazed unit capable of reducing the transmission of sound energy.

Abstract: An arrangement for loading a cargo space includes a transfer element as part of the transfer apparatus, which is arranged to move, together with load units to be arranged on top of it, into a cargo space and back out of there leaving the load units in the cargo space and means for forming a protective wall between the structure defining the cargo space and the load units. The forming of the protective wall is synchronized with the movement of the transfer element. In addition, an apparatus is disclosed for forming a protective wall in a cargo space and a method for loading a cargo space.

Abstract: A window blind assembly is disclosed and comprises a blind set, a light modulation device, a pull cord take-up device, and a coil spring control device. The blind set includes a bottom rail, a stopper, leaves, a blind ladder, pull cords, and a headrail. The light modulation device includes a wheel set, a wheel, a cover, an iron bar, a block, and a stick. The pull cord take-up device includes two mounts, a wrapping reel, and iron cores. The coil spring control device includes a bottom plate, a driving gear, a spring shaft, a coil spring, an upper gear cap, an upper cap, and a driven gear. The angle adjustment of the leaves of the blind set is realized by rotating the wrapping reel. When the bottom rail is pulled downwardly, the pull cords are driving the wrapping reel to rotate. The pull cord arranged on the coil spring control device is pulled out and wrapped around the wrapping reel.

Abstract: The disclosure provides roll-up coverings for an architectural opening, and various embodiments of ladder tapes. Embodiments of the roll-up covering include a roller, a first outer elongate tape, a first inner elongate tape and a plurality of slats disposed between the outer and inner elongate tapes. The first inner elongate tape can further defines a plurality of collapsible hinge segments disposed along the length of the first inner elongate tape. The collapsible hinge segments can be configured to collapse in order to decrease the effective length of the first inner elongate tape when the first inner elongate tape is rolled up around the roller. The collapsible hinge segments can further be configured to expand in order to increase the effective length of the first inner elongate tape when the roll-up covering is unrolled from the roller.

Abstract: The present invention comprises a foldable platform step ladder having one or more railing sides which are pivotable along a first pivot axis, a first hinge which facilitates the railing sides pivoting along the first pivot axis, a platform step which is pivotable along a second pivot axis; and a second hinge which facilitates the platform step pivoting along the second pivot axis. When the railing sides or the platform step are in a use position, one of the first hinge or the second hinge are in a locked position. When the railing sides or the platform step are in a non-use position, one of the first hinge or the second hinge are in an open position allowing pivoting motion along the first pivot axis and the second pivot axis.

Abstract: Adjustable drill string housings are described for use in the directional drilling of wellbores, e.g. wellbores for hydrocarbon recovery wells. The adjustable drill string housings permit adjustment of a bend angle in the housings without removing the housings from a wellbore. In some exemplary embodiments, the bend angle can be adjusted by changing the internal stresses in a support member carried by the housings. In other embodiments, the bend angle may be adjusted by causing failure of sacrificial support members carried by the housings, and the failure may be caused by delivering chemicals through a chemical delivery system to the sacrificial support members. Methods of operating the adjustable drill string housings include multi-lateral drilling operations wherein the bend angle is adjusted when a casing window has been detected.

Abstract: The present invention relates to a downhole production casing string for insertion in a borehole in a reservoir, the downhole production casing string having a first end nearest a top of the borehole and a second end furthest away from the top, the downhole production casing string extending along a longitudinal axis and comprising at least one opening which during production allows hydrocarbon-containing fluid from the reservoir into the downhole production casing string, a plurality of casing parts having end sections and a base section between the end sections, the base section having an outer diameter, and at least one annular projecting element having an outer face and at least one helical groove arranged in or on the outer face and having an overall outer diameter which is larger than the outer diameter of the base section.

Abstract: Offshore system for delivering geotechnical tools to seafloor is described.

Abstract: A cutter assembly includes a substrate and at least one island. The substrate includes a surface circumscribed by a peripheral edge, a flank surface extending from the peripheral edge, and at least one pocket with an opening on the surface and spaced apart from the peripheral edge. The at least one pocket extends from the opening towards an interior of the substrate. The at least one island is in the at least one pocket, and the at least one island includes a cutting surface that is exposed by the opening of the at least one pocket.

Abstract: A cutting element assembly includes a sleeve, a lining extending a distance axially from an end of the sleeve, and an inner cutter. The inner cutter has a cutting end, wherein the cutting end extends a depth from a cutting face, a side surface, and a body, wherein the body is at least partially disposed within the sleeve, and wherein the side surface of the cutting end interfaces with an interfacing surface of the lining.

Abstract: Embodiments provide a coated apparatus for improved corrosion resistance and associated system and system and method for artificial lift.

Abstract: A wet connection system has pressure compensation operative when running in and thermal effects compensation active in the duration between running in and supporting a bottom hole assembly and hooking up a production string having a mating upper part of the wet connect to the lower part of the wet connect already in the hole. The thermal compensation system is then defeated by locking a floating piston so that applied pressure in a given control line will be used to operate an associated tool connected to that control line. Multiple control lines each similarly compensated are envisioned. The pressure compensation system comes out of the hole with the running tool for the bottom hole assembly.

Abstract: An assembly for use in subsurface drilling includes a downhole downhole probe supported by a centralizer. The centralizer comprises a tubular member that extends around the downhole probe. A wall of the centralizer is fluted to provide inward contact points that support the downhole probe and outward contact points that bear against a bore wall of a section of drill string. The downhole probe may be supported for substantially its entire length.

Abstract: A pipe handler for assembling and deploying a string of threaded tubulars into a wellbore includes a pair of compensating bails and an elevator pivotally connected to the compensating bails. Each compensating bail includes: a first bail segment; a second bail segment; and a compensator connecting the respective first and second bail segments. Each compensator includes a load cylinder connected to the respective first bail segment and a linear actuator disposed in the respective load cylinder and operable to retract the respective second bail segment from a hoisting position to a ready position. Each second bail segment is engaged with the respective load cylinder in the hoisting position. The compensating bails are capable of supporting string weight in the hoisting position.

Abstract: A method of installing a coiled tubing string having a plurality of external assemblies includes injecting the coiled tubing string into a well with a coiled tubing injector, when a first external assembly on the coiled tubing string reaches the coiled tubing injector, transferring support of the coiled tubing from the coiled tubing injector to a coiled tubing snubber located below the coiled tubing injector, opening the coiled tubing injector to an extent sufficient to allow passage of the first external assembly thereby, and actuating the coiled tubing snubber to move the first external assembly past the coiled tubing injector. The first external assembly has an outside diameter that is larger than an outside diameter of the coiled tubing string.

Abstract: A spooling system for deploying cable, hose, and/or umbilical connections may include a drum, an air motor, a sheave having one or more sensor, and an electronic control unit coupled to an electro-pneumatic drive for controlling the system. The sensors may provide information to the electronic control unit, such as a measured line tension and/or a length of cable, hose or umbilical connection that has been deployed, and the information may be displayed on the electronic control unit. The electronic control unit also may allow an operator to rotate the reel, stop rotation of the reel, increase or decrease the speed of rotation of the reel, increase or decrease pressure and/or line tension, and/or select between a normal mode of operation and a tensioning mode of operation.

Abstract: A system and method for separating two or more materials, such as a solid from a liquid, or a solid from a slurry, are provided. An exemplary system and method for separating drill cuttings from drilling fluids are provided, as well as a system and method of processing such separated drill cuttings. In another implementation, a system and method is provided for separating gold (or another mineral, element, or solid) from a slurry or liquid that includes mining cuttings.

Abstract: An apparatus for generating pressure pulses in a drilling fluid flowing through a bore of a downhole tubular. A housing containing a rotor is located in the bore. Drilling fluid flowing through the housing actuates rotation of the rotor relative to the housing, which in turn drives movement of an actuator valve assembly to vary flow of drilling fluid between the bore and an actuator chamber defined by the actuator valve assembly and the housing. The resulting variation in drilling fluid pressure within the actuator chamber actuates a pulse valve assembly to vary flow of drilling fluid through the housing and into the bore. The varying drilling fluid pressure may be used to induce a percussive effect in a drill bit assembly coupled to the downhole tubular.

Abstract: A flow diverter including a bypass element to divert at least a first portion of drilling fluid from a drill string to the borehole annulus. The first portion of fluid, or bypass flow, may be provided to the borehole annulus to clear cuttings generated by a drill bit of a BHA. The remaining fluid flow, or BHA flow, may be expelled through the bottom of the BHA. The fluid discharged through the BHA may enter the annulus and flow upward with the fluid flow diverted through the flow diverter to aid in clearing cuttings. The flow diverter also includes a choke housing disposed concentrically within a drill collar and containing a plurality of chokes to regulate bypass flow. An actuation system may be coupled to the flow diverter to control opening/closing of the chokes and to measure flow rate of the first portion of fluid and/or the remaining fluid.

Abstract: A method for maneuvering and operating a tool within a wellbore of a subterranean well includes providing a tractor assembly having a fluid chamber with a port extending through a sidewall of the fluid chamber. The port is moved to the open position to allow a well fluid of the subterranean well to flow into the fluid chamber. The port is moved to the closed position to prevent the well fluid from flowing between the interior of the fluid chamber and the exterior of the fluid chamber. A heating laser beam is generated with a laser and directed towards the fluid chamber to increase the temperature of the well fluid within the fluid chamber. The port is moved to the open position to allow the high heat well fluid to flow out of the fluid chamber to accelerate the tractor assembly within the wellbore.

Abstract: An activation method and a mechanism in which a pressure or flow sensor senses the pressure or flow rate of the treatment fluid being pumped through the drill string. A controller powered by a power source monitors the sensed pressure or flow rate within a first time window and via a suitable activator activates a first downhole tool or operation mode thereof if the sensed pressure or flow rate is stable with that time window. The controller monitors the sensed pressure or flow rate within a second time window and activates a second downhole tool or second operation mode of the first downhole tool if the sensed pressure or flow rate is stable with that time window. In one embodiment, the sensed pressure is combined with a rotation sensor sensing the rotation of the drill string. The controller logs the starting time for the pumping and the rotation.

Abstract: A downhole tool assembly includes a downhole tool and an anchor. The anchor is positionable at a downhole work site and includes a wet-connect port for engaging a battery pack. The tool operates until the battery runs low on power, when a low battery power alert is activated. The tool may be anchored at the work site while the battery is disconnected and retrieved to the surface for replacement. One or more charged batteries are then deployed and connected to the tool without having to remove the tool from the worksite or reposition the tool. The tool may be coupled to a wireline cable or a slickline cable or coiled tubing having a conductive wire for delivering low-voltage power to the tool. While the low-voltage power may not be adequate to operate the tool at full load, the power may be used to charge the tool during downtime.

Abstract: Various tools for locking components in place within a wellhead housing are provided. In one embodiment, a system includes a lockdown tool (32) having an inner body (40), an outer body (42) coupled to the inner body, and a locking mechanism (44) carried by the inner body. The locking mechanism can be selectively engaged by moving the outer body with respect to the inner body to secure the lockdown tool to the wellhead housing (60). Additional systems, devices, and methods are also disclosed.

Abstract: The disclosure provides a downhole anchoring apparatus for use in a downhole tool. An example downhole anchoring apparatus may include a housing with a hub provided within the housing. The hub may be arranged to rotate in a bidirectional fashion about a longitudinal axis. The downhole anchoring apparatus may also include a deployment linkage. The deployment linkage may be coupled to the hub by a hinge so that when the hub is rotated in a first direction, a distal end of the deployment linkage is extended radially outward from the central axis, and when the hub is rotated in a second direction, the distal end of the deployment linkage is retracted toward the central axis.

Abstract: A compaction and/or hydro fracture generation device (10) comprises a compression device (11), a vibration generator device (12) arranged to generate vibrations in the ultrasonic frequency range, and a power source connected to the vibration generator.

Abstract: It is sometimes necessary to sever a downhole tubular structure in the course of conducting subterranean operations. Detonation of an explosive material may be used to sever a tubular structure in some instances. Downhole severing tools may comprise: a housing; a two-stage energizing material within the housing, the two-stage energizing material comprising a high explosive and a reactive energizing material; at least one initiator coupled to the two-stage energizing material at least at a first location; and a detonator coupled to the at least one initiator; wherein upon detonation of the two-stage energizing material, the high explosive undergoes a primary reaction that propagates a secondary reaction of the reactive energizing material.

Abstract: A degradable rubber member for a downhole tool formed from a rubber material containing from 0.1 to 20 parts by mass of a degradation accelerator relative to 100 parts by mass of a degradable rubber (optionally containing other rubber materials and/or reinforcing materials), of which, preferably, the decrease rate of the mass or the 50% strain compressive stress after immersion for 24 hours in 150° C. water is not less than 5%, and/or the mass loss rate after immersion for 72 hours in 150° C. water is from 5 to 100%, and further, as desired, the tensile fracture strain at 66° C. is not less than 50%, the 70% strain compressive stress is not less than 10 MPa, and the compressive fracture strain is not less than 50%; a degradable seal member or a protecting member for downhole tools comprising such a rubber member; and a downhole tool such as a plug for well drilling, and a method for well drilling.

Abstract: There are provided high power laser systems for performing decommissioning of structures in land based boreholes, and wells, offshore, and other remote and hazardous locations, and using those system to perform decommissioning operations. In particular embodiments the laser system is a Class I system and reduces emission of materials created during laser cutting operations. The laser systems can include lifting and removal equipment for removing laser sectioned material.

Abstract: An electromagnetic jarring tool and related systems and methods provide for the use of an electromagnetic system to generate jarring forces within a wellbore. The electromagnetic jarring tool includes a chamber having a first end and a second end, a magnetic hammer disposed within the chamber, and an electromagnet operable to generate an electromagnetic field across at least a portion of the chamber. The magnetic hammer is operable to move toward the second end of the chamber in response to the electromagnetic field to deliver an impact. One or more electromagnets may be included to enhance operation of the tool, and the tool may be actuated by a surface controller that selectively delivers electrical power or a control signal to the tool to specify a mode of operation of the electromagnetic jarring tool.

Abstract: There is provided a system and method for temporarily locking a wellhead component while cementing it in place within a mineral extraction system. As cement is pumped into the wellhead, its temperature may be increased, leading to thermal expansion of the cement and movement of wellhead components. Disclosed embodiments include a hold-down ring configured to cooperate with tie-down screws to temporarily lock a running tool in place within the wellhead during cementing. In another embodiment, the tie-down screws may cooperate directly with the running tool. The locked running tool then blocks other wellhead components, such as a hanger run into the wellhead by the running tool, from upward axial movement due to thermal expansion of the cement during the cementing process. After the hanger is cemented in place, the running tool may be unlocked and retrieved from the wellhead.

Abstract: Subsea well assembly having a Xmas tree (107, 207) and wellhead (103). From a tubing hanger (113) a tubing extends into the well. A part of a production flow passage extends vertically from the tubing hanger (113) in a vertical bore (111) of the Xmas tree. A fail close production master valve (PMV) (117) is arranged in the production flow passage. The tubing hanger (113) is arranged below the Xmas tree (107), such as in the wellhead (103). The Xmas tree (107) exhibits a branch (115) that deviates from the vertical bore (111), which branch constitutes part of the production flow passage. The fail close type production master valve (PMV) (117) is arranged in the branch (115).

Abstract: A wellhead stack assembly is provided that includes pressure restriction devices. The pressure restriction devices are staged such that each pressure restriction device is coupled to another pressure restriction device for cascading pressure differentials across the pressure restriction devices. Each pressure restriction device includes an active element positionable about a drill pipe for controlling a gap between the drill pipe and the active element.

Abstract: A method for setting a barrier within a wellbore comprises deploying a first plug assembly (16) into a wellbore on a running string, wherein the first plug assembly comprises an extendable arrangement (24), and then setting the first plug assembly within the wellbore by extending the extendable arrangement. A settable medium is injected via the running string into the wellbore above the first plug assembly. To be accompanied, when published, with FIG.

Abstract: A method of cementing an oil or gas well for abandonment comprises cutting the production tubing 6 above the production packer 8, setting a tubing plug 9 in the tubing and then cutting the tubing. A bridge plug may be installed at the level of the cut, which spans the full diameter of the well casing 3. An agitator assembly 20 comprising an agitator 24, packer 21 and burst sub 23, with a running tool fitted to the top, is run down the tubing on wire line. Cement is then injected into the tubing 6, which flows through the agitator assembly and causes the tubing to vibrate. The cement fills the tubing but also flows back up the A annulus between the casing and production tubing. Vibration of the tubing assists the formation of a good quality cement plug extending all around the annulus over a substantial length of the well.

Abstract: An apparatus and method for activating a downhole tool of a production system is disclosed. The apparatus includes a first component, a first magnetic member coupled to the first component, a second component of movable with respect to the first component, and a second magnetic member attached to the second component. The first component is generally stationary with respect a work string of the production system. An electric current activates at least one of the first magnetic member and the second magnetic member to create a magnetic force between the first magnetic member and the second magnetic member, thereby moving the movable component with respect to the stationary component to perform the action downhole. The produced motion of the movable component activates the downhole tool.

Abstract: In accordance with some embodiments of the present disclosure, a method of modeling a downhole drilling tool is disclosed. The method may include identifying a location for each of a plurality of cutlets associated with each of a plurality of cutting elements. The method may further include calculating a depth of cut for each cutlet based on the location of the cutlet and a three dimensional model of a borehole bottom. Additionally, the method may include generating a three dimensional model of a rock chip for each cutting element, in response to at least one depth of cut being greater than a critical depth of cut, each three dimensional model including a two dimensional model of a rock chip associated with each cutlet. The method may also include updating the three dimensional model of the borehole bottom by removing each three dimensional model of a rock chip.

Abstract: An apparatus for generating of vibrations for enhancing of forming at least one fracture having a required width r and length L in the formation surrounding a wellbore in the regime of resonance by means of applying vibrations to the formation which is undergoing pressurizing exceeding the fracture gradient pressure of the formation.

Abstract: A long offset gas condensate production system comprising: a subsea production well; a subsea separator; and a subsea cooler.

Abstract: A method of installing a sealing ring onto a wire wrap screen comprising: providing the sealing ring, wherein the sealing ring has an initial inner diameter greater than the outer diameter of an end of the wire wrap screen; reducing the inner diameter of the sealing ring, wherein the reduced inner diameter of the sealing ring is less than the outer diameter of the end of the wire wrap screen; heating the sealing ring; positioning the heated sealing ring over the end of the wire wrap screen; and allowing the sealing ring to decrease in temperature. Another method comprises positioning at least two sealing rings adjacent to a cut-out section of the wire wrap screen.

Abstract: A downhole gas separator apparatus for separating gas from liquids during extraction of oil from the ground is disclosed. The apparatus can be used for high angle or horizontal wells, as well as low angle or vertical wells. The dimensions can vary to be used for extra heavy oil as well as light crude oil.

Abstract: In order to address the above noted problems, embodiments of the present invention use distributed acoustic sensing to monitor the fluid level in an ESP activated well so as to monitor the condition and performance of the ESP. Embodiments of the invention use the ESP as an acoustic source in order to monitor the annulus fluid level within the well and to monitor the frequency of the ESP. Additionally, embodiments of the present invention may use distributed acoustic sensing to monitor the flow rates of the production fluid above and below the ESP to determine the pump's efficiency. In particular, some embodiments utilise one or more optical fibers to measure the acoustic waves generated by the ESP, wherein the fiber cabling has already been deployed along the length of the well. As such, the present invention is a non-invasive, in-situ method for monitoring the condition and performance of an ESP.

Abstract: Techniques and apparatus are provided for improved diagnostics of downhole dynamometer data for control and troubleshooting of reciprocating rod lift systems. A method for pump fillage determination for a reciprocating rod lift system is provided. The method generally includes measuring downhole data during a pump cycle, wherein the downhole data comprises a first plurality of data points associated with an upstroke of the pump cycle and a second plurality of data points associated with a downstroke of the pump cycle, each data point comprising a rod position value and an associated rod load value; converting the data points to non-dimensional data points, calculating non-dimensional slope values between non-dimensional data points; and determining pump fillage based, at least part, on the calculated non-dimensional slope values.

Abstract: The present invention provides a system and method for detecting underground tunnels by using bentonite-slurry.

Abstract: In accordance with some embodiments of the present disclosure, a method of modeling for one-dimensional temperature distribution calculations in a wellbore is disclosed. The method may include estimating a pressure gradient of a fluid in a wellbore. The method may further include calculating a pressure of the fluid in the wellbore based on the pressure gradient of the fluid. Additionally, the method may include computing a velocity of the fluid in the wellbore. The method may also include determining a temperature of the fluid in the wellbore based on the pressure of the fluid in the wellbore and the velocity of the fluid in the wellbore. The method further includes using the temperature of the fluid to model a fluid property. The method includes selecting parameters for a stimulation operation based on the fluid property.

Abstract: A downhole ultrasonic transducer (10) used to transmit and/or receive ultrasonic waves in a hydrocarbon well where a fluid is present comprises: a metal housing (11) defining an internal cavity (12) isolated from the fluid of the hydrocarbon well (100) by a membrane wall (13) made of metal or metal alloy; a piezoelectric element (14) mounted inside the internal cavity (12), the piezoelectric element (14) having a front side (20) mechanically coupled on the membrane wall (13); wherein: the internal cavity (12) is at a pressure unrelated to a hydrocarbon well pressure; a back side (21) of the piezoelectric element (14) is arranged to be free to oscillate in the internal cavity (12) so as to generate a high acoustic impedance mismatch between the piezoelectric element (14) and the internal cavity (12) at the back side (21) and to maximize acoustic transmission at the front side (20); and a thickness (ei) of the membrane wall (13) is such that there is a common resonance between the membrane wall and th

Abstract: An assembly can include a casing string with an outer surface. The assembly can also include an antenna for wirelessly communicating data by generating a surface wave that propagates along an interface surface. The antenna can be positioned coaxially around the casing string. The antenna can include a cylindrically shaped conductor that is positionable coaxially around an outer surface of a casing string for generating a magnetic field component of the surface wave that is non-transverse to a direction of propagation of the surface wave along the interface surface. The antenna can also include a pair of conductive plates positioned at an angle to the cylindrically shaped conductor for generating an electric field component of the surface wave.