Abstract: A single-cord control device for roller blind comprises a front base comprising a space covered by a lid for setting a winding element which has a winding channel, an abutting block, and a space for locating a spiral spring, and a rear base comprising a step hole and several blocks. A second shaft inserted into the step hole comprises two tubular sections and two elastic elements covering the tubular sections and an inner and an outer shaft sheath. A first shaft is inserted into the center of the lid and one tubular section, and a curtain torque rod is assembled into a through-hole of the second shaft. The outer shaft sheath comprises a path for the abutting block moving. Therefore, the roller blind is controlled by the single-cord to roll up and down, which cord is wound around the winding element to prevent child from being wound around neck.

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 comprises 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 and/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 retractable deer stand ladder system for providing a ladder that is efficiently concealed from wildlife. The retractable deer stand ladder system generally includes a support member having an elongated structure, an upper end and a lower end, a plurality of first steps pivotally attached to a first side of the support member, and a plurality of second steps pivotally attached to a second side of the support member. The first steps and the second steps each have an extended state where the steps extend outwardly from the support member for a user to climb upon. The first steps and the second steps also have a refracted state where the steps extend substantially parallel with respect to the support member for concealment.

Abstract: A tether system for a safety line has an elongate guide track and stay elements arranged to move along the guide track and be carried at spaced positions along the length of a tether line. The system is typically employed in a fall arrest or protection system mounted to a structure, having an ascent/descent ladder fixed to the structure, the system including a self-retracting safety line device including a safety line, mounted at height.

Abstract: A ladder stabiliser for use with a ladder comprising two stiles positioned against a wall, the ladder stabiliser comprising a body, a securing mechanism for releasably securing the body to the ladder and two or more feet for engagement with a surface wherein the securing mechanism and feet are configured such that in use the feet are located on the surface at points which are distant from the point at which the axes of the stiles intersect the surface. A line between the feet of the stabiliser and the top of the ladder stiles is at an angle of about 55 to 65° to the ground and the ladder is at an angle of 70 to 80° to the ground.

Abstract: A house clamp assembly having a fixed jaw and a slide bar mounted movable jaw, the fixed jaw opposing the movable jaw. A one-way drive means, by operation of a trigger handle grip, releasably engages the slide bar and advances the movable jaw towards the fixed jaw. The one-way drive means is incapable of moving the slide bar and movable jaw away from the fixed jaw. A return motion of the movable jaw (separating) is accomplished manually when the one-way drive means is disengaged. A braking lever, which is biased to bind the slide bar, prevents reverse motion of the slideable jaw away from the fixed jaw, except when the first lever is disengaged from the slide bar.

Abstract: A downhole motor for a drillstring has a housing with upper and lower portions coupled to one another. A rotor in the lower portion has an outward tapered receptacle at one end. An extension is coupled to the rotor and is disposed relative to a seat in the housing. An outer body of the extension has an external shoulder to engage the seat with separation of the upper and lower housing portions. An end of this outer body is disposed in the outward tapered receptacle of the rotor and defines an internal taper tapering inward in an internal passage of the body. An inner body is inserted into the internal passage of the outer body. An end of the inner body wedges the internal inward taper at the end of the outer body into the outward tapered receptacle on the rotor to hold the extension on the rotor. Should the lower housing portion separate from the upper housing portion, the shoulder on the extension can engage the seat so that the motor does not fully separate.

Abstract: A drilling system includes a drilling assembly and a control assembly. The control assembly is operably connected to the drilling assembly such that simultaneous movement of multiple portions of the drilling assembly is enabled.

Abstract: An apparatus for drilling curved and straight sections of a wellbore is disclosed that in one non-limiting embodiment includes a drilling assembly configured to include a drill bit at an end thereof that can be rotated by a drive in the drilling assembly and by the rotation of the drilling assembly, and wherein the drilling assembly includes: a deflection device that (i) tilts a section of the drilling assembly within a selected plane when the drilling assembly is substantially rotationally stationary to allow drilling of a curved section of the wellbore by rotating the drill bit by the drive; and (ii) straightens the section of the drilling assembly when the drilling assembly is rotated to allow drilling of a straight section of the wellbore.

Abstract: A helical displacement well with preassembled segments includes a preassembled shaft-forming penetrator tube including helical plates mounted to its exterior that may be rotated to propel the casing into the ground. A hydraulic drill motor rotates the penetrator tube as it moves deeper into the ground. Extension tubes may be added to and coupled to the penetrator tube. A bolt including a threaded stem sized to engage the threaded bolt opening of the male connector and a cap of larger breadth than the threaded stem and sized to fit within the unthreaded tension bolt opening of the female connector for connecting the female connector about the male connector.

Abstract: A top surface drilling device has a core bit and a drill head disposed in the core bit. The drill head has a smaller diameter than that of the core bit, and the core bit and the drill head can be driven at different angular speeds.

Abstract: The invention concerns a seal assembly (1) for sealing between a fixed member (10) and a rotatable member (3) adapted for rotating around an axis in relation to said fixed member. The seal assembly comprises a first ring member (4) adapted for being fitted in or on said fixed member circumferentially around said axis and having a first surface (34); a second ring member (6) adapted for being fitted circumferentially in or on said rotatable member and having a second surface (36) facing said first surface along a length; and a third ring member (7) between said second and said first surface, the distance between said second surface and said first surface being larger at the middle of said length and becoming smaller towards the extremities thereof.

Abstract: A drilling device for a down-the-hole drilling apparatus. The drilling device includes in a guide, a drilling member and a flushing mechanism configured to flush drilling waste. The drilling mechanism includes first and second drilling bit arrangements that are movable with respect to the drilling device and that are arranged to be expanded to drill a hole having a greater cross-sectional surface area than an end of the casing and arranged to be reduced to a size smaller than the end of the casing. Bit pieces of the second drill bit arrangement expand and reduce the second drill bit arrangement. The bit pieces expand the second drill bit arrangement by moving in a radial direction outwards in slide grooves, by rotating the guide in a drilling direction, and move in the radial direction inwards in the slide grooves, by rotating the guide in an opposite direction.

Abstract: Expandable reamers for enlarging a borehole in a subterranean formation include a tubular body, at least one curved blade track carried by the tubular body, and at least one blade engaged with the at least one blade track and configured to slide along the curved blade track along a curved path between a first retracted blade position and a second expanded blade position. To form such an expandable reamer, a tubular body having at least one curved blade track carried by the tubular body may be formed, and at least one blade may be engaged with the blade track. The blade and blade track may be configured such that the blade slides along the blade track along a curved path between a retracted position and an expanded position. Such expandable reamers may be used to enlarge boreholes in subterranean formations.

Abstract: A multi-layer downhole drilling tool designed for drilling a wellbore including a plurality of formations is disclosed. The drilling tool includes a bit body and a plurality of primary blades and secondary blades with respective leading surfaces on exterior portions of the bit body. The drilling tool further includes a plurality of first layer cutting elements and second layer cutting elements located on the leading surfaces of the primary blades and secondary blades, respectively. Each second layer cutting element is under exposed with respect to the corresponding first layer cutting element. The amount of under-exposure is selected according to each second layer cutting element having an initial critical depth of cut greater than an actual depth of cut for a first drilling distance and a critical depth of cut equal to zero at a target drilling depth.

Abstract: Continuous fiber-reinforced hard composites may be useful in mitigating crack propagation in downhole tools. In some instances, a wellbore tool may be formed at least in part by a continuous fiber-reinforced hard composite portion that includes a binder material continuous phase with reinforcing particles and continuous fibers contained therein, wherein the continuous fibers have an aspect ratio at least 15 times greater than a critical aspect ratio (Ac), wherein Ac=?f/(2Tc, ?f is an ultimate tensile strength of the continuous fibers, and Tc is a lower of (1) an interfacial shear bond strength between the continuous fibers and the binder material and (2) a yield stress of the binder material.

Abstract: A cutting element for an earth-boring tool includes at least one volume of superabrasive material on a substrate. The volume of superabrasive material includes a first planar surface and a second planar surface oriented at an angle relative to the first planar surface and intersecting the first planar surface along an apex. The first planar surface has a circular or oval shape having a first maximum diameter, and the second planar surface has a circular or oval shape having a second maximum diameter. The apex has a length less than the first maximum diameter and the second maximum diameter. Earth-boring tools include such a cutting element attached to a body. Methods of forming earth-boring tools include the attachment of such a cutting element to a body of an earth-boring tool.

Abstract: A threaded joint is constructed of a pin and a box. The pin includes a shoulder surface, a seal surface, and a male threaded portion. The box includes a shoulder surface, a seal surface, and a female threaded portion. The male threaded portion and the female threaded portion are each a tapered threaded portion including threads having a trapezoidal profile. The male threaded portion has a width of the threads that gradually decreases along the thread helix and a width of grooves that gradually increases along the thread helix. The female threaded portion has a width of grooves that gradually decreases along the thread helix and a width of the threads that gradually increases along the thread helix. With this, it is possible to inhibit galling during make-up while maintaining high sealing ability as well as to achieve ease of manufacturing.

Abstract: A metal-to-metal sealing system connecting first and second tubular members includes a first seal configuration on the first tubular member and a second seal configuration on the second tubular member. The first seal configuration includes a first annular groove and a first annular tooth, and the second seal configuration includes a second annular groove and a second annular tooth. The second annular tooth is positioned within the first annular groove with the second annular tooth face engaging the first annular shoulder face to define a first shoulder. The first annular tooth is positioned within the second annular groove with the first annular tooth face engaging the second annular shoulder face to define a second shoulder. Locations of primary sealing contact of surfaces of the members are spaced axially away from the first and second shoulders.

Abstract: A well tool has an inner and outer component arranged to move relative to one another and defining a shear juncture therebetween. A shear member spans the shear juncture. The shear member has first portion with a different cross-sectional area than a second portion. A cam surface is associated with the inner or outer component and abuts the shear member. The cam surface moves the shear member as the inner and outer components move relative to one another and changes the shear member from having the first portion aligned with the shear juncture to having the second portion aligned with the shear juncture.

Abstract: An oilfield assembly including a pump in fluid communication with a string of coiled tubing on a tubing reel through a coiled tubing swivel assembly, includes a fluid inlet segment coupled to a swivel body having a central axis, and a rotatable hollow shaft having a portion that extends axially within the swivel body, wherein the fluid inlet segment, swivel body and hollow rotatable shaft form a conduit for passage of a pumped substance to the tubing reel from the pump. The rotatable shaft includes a first end attachable to the tubing reel, and a distal second end, at least part of which is configured to engage a corresponding indentation in the body, thereby preventing direct contact between the distal end of the shaft and the pumped substance.

Abstract: A subsea removable flex joint laydown tool is described herein. The tool can include a body having a first portion and a second portion hingedly coupled to the first portion. The tool can also include a flex joint coupling feature disposed on an inner surface of the first portion and the second portion toward a proximal end of the body, where the flex joint coupling feature is configured to couple with a first laydown tool coupling feature of a flex joint. The tool can further include a riser coupling feature disposed on the inner surface of the first portion and the second portion toward a distal end of the body, where the riser coupling feature is configured to couple with a second laydown tool coupling feature of a riser. The tool can also include at least one laydown tool coupling feature movably coupled to the first portion.

Abstract: A device for handling oil pipes and a method for workover includes a base, which includes an oil pipe bearing area extending in a longitudinal direction, the oil pipe bearing area being provided therein with at least one positioning member arranged in a transverse direction perpendicular to the longitudinal direction of the base, for positioning an oil pipe; and a movable oil pipe grasping assembly, which is located above the base and configured to grasp the oil pipe and place the oil pipe in the oil pipe bearing area, or grasp the oil pipe from the oil pipe bearing area and place the oil pipe in an area outside the oil pipe bearing area. The device for handling oil pipes provided by the present disclosure is able to achieve automatic handling of oil pipes, thereby decreasing labor intensity of operators, and improving working efficiency and safety factors of the work.

Abstract: Present embodiments are directed to a gripping device configured to couple with a pipe element. A housing of the gripping device is configured to extend over and at least partially around a distal end of the pipe element. Torsional clamp devices are configured to engage an outer circumferential surface of the pipe element with frictional engagement features that extend radially inward from the housing. A sealing mechanism is configured to shift a pipe seal relative to the housing and into engagement with the distal end of the pipe element and to facilitate fluid flow through the gripping device into the pipe element.

Abstract: Apparatus having a base, a separator housing movably connected with the base, the separator housing including a top having an inlet chute, a bottom having a liquid discharge chute, a cylindrical sidewall defining an axial centerline and having a discharge spout, and at least one screen mounted within the separator housing. A vacuum system proximate the at least one screen may also be incorporated. The apparatus further includes at least one circular force generator (CFG) disposed on the separator housing, and at least one sensor positioned on the apparatus for measuring an operating function associated with and enabled by the vibration profile, and a controller in electronic communication with the sensor and with the at least one CFG. The difference between the measured operating function and the prescribed operating function is reduced. The apparatus may also include at least one CFG having a plurality of imbalanced masses which rotate in a plane parallel the axial centerline.

Abstract: A method for drilling a wellbore includes disposing a tubular string in the wellbore, wherein the tubular string includes a drill bit disposed at a bottom and a flow sub disposed on a top; injecting drilling fluid through a bore valve in the flow sub to rotate the drill bit; moving a sleeve in the flow sub to engage and close the bore valve; moving the sleeve independently from the bore valve to expose a flow port formed through a wall of the flow sub; and injecting the drilling fluid into the flow port while adding a stand to the top of the tubular string, wherein injection of drilling fluid into the tubular string is continuously maintained between drilling and adding the stand to the tubular string.

Abstract: A downhole tool assembly for use in a drilling string includes a motor, a flow head, and a flow restrictor. The flow head is coupled to the motor and comprises a plurality of ports permitting fluid communication therethrough. The flow restrictor is in fluid communication with the flow head and comprises a plurality of ports permitting fluid communication therethrough. The flow restrictor is stationary with respect to the flow head, which rotates. As the flow head rotates, one or more of the plurality of ports of the flow head enters into and out of alignment with one or more of the plurality of ports of the flow restrictor such that fluid flow through the ports of the flow head and the flow restrictor is constrained to a cyclic, polyrhythmic pattern optionally including at least one interval where the fluid flow is substantially blocked by the flow restrictor.

Abstract: A gripper assembly for anchoring a tool within a downhole passage and for possibly assisting movement of the tool within the passage. The gripper assembly includes an elongated mandrel and flexible toes that can be radially displaced to grip onto the surface of the passage. The toes are displaced by the interaction of a driver slidable on the mandrel and a driver interaction element on the toes. In one embodiment, the toes are displaced by the interaction of rollers and ramps that are longitudinally movable with respect to one another. In another embodiment, the toes are displaced by the interaction of toggles that rotate with respect to the toes.

Abstract: An improved rope socket for downhole operations, capable of separating within the wellbore to permit removal of upper components and attached wireline, while lower components including an uphole-facing fishing neck remain attached to a tool string or fish within the wellbore. Also, an improved drop bar for actuating a release mechanism of the improved rope socket. The improved drop bar includes wheel assemblies having integrated axles to provide a stronger axle capable of offset placement along the circumference of the drop bar.

Abstract: A pressure compensator for a subsea device is provided. The pressure compensator provides pressure balancing between a chamber of the subsea device and the surrounding environment when the subsea device is installed at a subsea location. The pressure compensator includes an intermediate compensation chamber that is provided by a compensator enclosure. The compensator enclosure is sealed against the subsea environment. The compensator enclosure includes a bellows portion that is deformable to change the volume of the intermediate compensation chamber. The pressure compensator further includes a flexible hose disposed inside the intermediate compensation chamber. A volume inside the flexible hose provides a main compensation chamber.

Abstract: A subsea termination head assembly adapted for both communicating and controlled load earning connection via a termination head to a subsea structure to be installed on the seabed, is described. The termination head allows a subsea cable, a power cable, a power umbilical or an umbilical, to be connected to the subsea structure before lowering them as a unit from a vessel and into the sea. The termination head assembly and subsea structure are to be lowered together while concurrently paying out the cable all the way to the seabed. The termination head is arranged to be hingedly connected relative to the subsea structure, which allows the termination head to pivot about a pivot axis in order to let the subsea cable adopt a natural catenary curvature in the sea during lowering thereof. The cable extends in a pigtail loop from the termination head and into the subsea structure. The pigtail loop is able to perform a “rolling motion” during such pivotal movement of the termination head.

Abstract: Embodiments may include methods that include emplacing a degradable material into a wellbore, wherein the degradable material includes a thermoplastic elastomer; contacting the degradable material with an aqueous fluid downhole; and allowing the degradable material to at least partially degrade. In another aspect, methods may include emplacing into a wellbore a tool containing a sealing element thereon, wherein the sealing element contains a degradable material; engaging the sealing element with a downhole surface to establish a seal; contacting the sealing element with an aqueous fluid; and allowing the sealing element to at least partially degrade, thereby disrupting the established seal.

Abstract: The present invention relates to a plug (1) comprising at least two discrete glass discs (2), wherein there is provided between the glass discs a liquid (3) which contributes to load uptake and load distribution, and a pin-/claw device (4) is arranged to be pressed in a radial direction into at least one of the glass discs (2). A distinctive feature of the plug is that it does not include a functional drainage system, and the pin-/claw device (4) is arranged such that on activation there occurs a pressure leakage through the glass disc (2). Also suggested according to the invention is a volume compensator/constant pressure regulator (20, 21, 22; 23; 24).

Abstract: Provided herein are embodiments of sealing assemblies for packers and wellbore assemblies for use in the injection of steam into a formation. Usage of one or more of these items may increase recovery of hydrocarbon from the formation.

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 retrievable downhole tool has a mandrel, an upper radially expandable slip carried by the mandrel, a lower radially expandable slip carried by the mandrel, a rubber element disposed between the upper radially expandable slip and the lower radially expandable slip, an upper backup disposed between the upper radially expandable slip and the rubber element, and a lower backup disposed between the rubber element and the lower radially expandable slip. At least one of the upper radially expandable slip, the lower radially expandable slip, the upper backup, and the lower backup comprises a soluble material.

Abstract: A method for reverse circulation cementing of a liner in a wellbore extending through a subterranean formation is presented. A running tool with expansion cone, annular isolation device, and reverse circulation assembly is run-in with a liner. The annular isolation device is set against the casing. A valve, such as a dropped-ball valve, opens reverse circulation ports for the cementing operation. The liner annulus is cemented using reverse circulation. An expandable liner hanger, if present, is expanded into engagement with the casing. The running tool is released and pulled from the hole.

Abstract: A system and associated method for monitoring pressure of water at a sub-surface water location. The system includes a chamber, enclosing a fluid, and a fluid line. The system includes a differential pressure sensor with first and second fluid pressure inputs connected to the chamber and the fluid line, respectively. The system includes a first valve configured to have a first position in which the chamber is in fluid communication with the fluid line through the first valve and configured to have a second position in which the chamber is blocked from fluid communication with the line. The system includes a second valve configured to have a first position in which the fluid line is blocked from fluid communication with the water at the sub-surface location and is configured to have a second position in which the line is in fluid communication with the water through the second valve.

Abstract: An example ball valve includes a body defining a first valve port and a second valve port circumferentially offset from each other on the body by 180°. A valve member is positioned within the body and defines an inlet port and first and second outlet ports extending perpendicularly from the inlet port in opposing directions. First and second sealing elements are mounted on the valve member within corresponding first and second annular grooves, the first and second sealing elements being circumferentially offset from each other on the valve member by 180° and circumferentially offset from the first and second outlet ports by 90°. First and second seal systems are positioned within the first and second valve ports, respectively, and each include a valve seat engageable with the first and second sealing elements, a boost piston, and a bias spring.

Abstract: A technique facilitates valve operations in many applications including well related applications. A valve utilizes a piston which moves along an arc. The valve has an outer housing and an inner housing spaced to create an arcuate pressure chamber which extends along the arc. A piston is mounted in the arcuate pressure chamber for movement along the arc. A hydraulic force or other force may be selectively applied directly against an end of the arcuate piston to shift the arcuate piston along the arc. In some applications, the piston comprises a cutting edge oriented to enable performance of a cutting operation.

Abstract: A technique facilitates controlled injection of a chemical injection fluid at a desired downhole location. A chemical injection valve is mounted along a well tubing and is disposed externally of an internal flow passage through the well tubing. The chemical injection valve is operated via hydraulic pressure which is applied to actuate the chemical injection valve between closed flow and open flow positions. The chemical injection valve controls flow of the chemical injection fluid to at least one injection port. The at least one injection port may be positioned to inject the chemical injection fluid into the internal flow passage of the well tubing.

Abstract: Fracking ports are initially obstructed with respective biased sleeves that have an associated release device responsive to a unique signal. The signal can be electronic or magnetic and delivered in a ball or dart that is dropped or pumped past a sensor associated with each release device. Each sensor is responsive to a unique signal. When the signal is received the release device allows the bias to shift the sleeve to open the fracture port and to let a flapper get biased onto an associated seat. The flapper and seat are preferably made from a material that eventually disappears leaving an unobstructed flow path in the passage. The method calls for repeating the process in an uphole direction until the entire zone is fractured. The flapper and seat can dissolve or otherwise disappear with well fluids, thermal effects, or added fluids to the well.

Abstract: An isolation valve for use with a tubular string includes a tubular housing for connection with the tubular string; a closure member disposed in the housing and movable between an open position and a closed position; a flow tube longitudinally movable relative to the housing for opening the closure member; a piston for moving the flow tube; a fluid chamber formed between the flow tube and the housing and receiving the piston; a first fluid passage for fluid communication between a first portion of the chamber and a control line and for moving the piston in a first direction; and a second fluid passage for fluid communication between a second portion of the chamber and a bore of the tubular string and for moving the piston in a second direction. A single control line may be used to operate the isolation valve between an open position and a closed position.

Abstract: A system and method for selectively locking open or close a gravel pack-circulating sleeve is disclosed. The sleeve is movably coupled to a first chamber containing a fluid. The first chamber is fluidly connected to a second chamber through a fluid flow controller. Shifting of the sleeve between open and closed positions is resisted by a the fluid flow controller. The resistance to fluid flow can reduce or eliminate inadvertent shifting of the sleeve due to short bumps and small loads upon the sleeve. To overcome the resistance to fluid flow and to shift the sleeve, a continuous load can be applied to the sleeve.

Abstract: An adjustable fluid injection tool for use in a wellbore may be used to provide steam to a wellbore annulus. The tool may be adjusted immediately before being positioned in a well. Fluid may exit an inner space of the tool into an accumulation chamber, after which the fluid may exit the tool through one or more adjustable valves. An adjustable valve may be formed between a valve seat of a shroud and a valve plug of a plug sleeve. The plug sleeve may be positioned around a tubular of the tool and able to translate linearly with respect to the shroud by rotating the plug sleeve, thus adjusting the adjustable valve and controlling fluid flow out of the tool.

Abstract: An internal completion string is anchored within a closed casing valve of a production liner in a wellbore. The internal completion string comprises a packer and a shifting tool. The production liner comprises a casing valve having a port and a moveable member. The annulus defined between the production liner and the internal completion string is sealed, and the shifting tool is remotely operated to move the moveable member away from the port, thereby opening the casing valve.

Abstract: An ice preventing system for a flow passage of a well or pipe line includes a fluid tank holding an ice prohibiting fluid and a pressure inducer positioned in the flow passage. The fluid tank is fluidically connected to the flow passage at an upstream location from the pressure inducer by an inlet pressure line. And the fluid tank is fluidically connected to the flow passage at a downstream location from the pressure inducer by a fluid injection line. A normally closed valve is disposed across the fluid injection line that is opened by a pressure differential across the pressure induce by ice accumulation in the flow passage, thereby allowing injection of the ice prohibiting fluid into the flow passage from the tank. Once the pressure differential lowers by removing the ice accumulation, the valve once again closes, and fluid injection stops.

Abstract: An apparatus for maintaining a gas or oil well, including: a first opening proximate a first end; a second opening proximate a second end; a wall connecting the first and second ends; a protrusion extending from the wall in a radial direction; a space enclosed by the wall and continuous with the first and second openings; and a seal element. The apparatus is arranged to be placed into production tubing for a gas or oil well. The seal element arranged to seal the wall with respect to the production tubing. The protrusion is arranged to contact a nipple in the production tubing to block movement of the apparatus past the nipple. The first opening is arranged to receive compressed air. The space is arranged to channel the compressed air through the second opening to an area of the oil or gas well deeper than a position of the apparatus in the production tubing.

Abstract: Provided herein are embodiments of flow control devices, static mixers, and wellbore assemblies for use in the injection of steam into a formation. Usage of one or more of these items may increase recovery of hydrocarbon from the formation.

Abstract: The disclosed embodiments include a method, apparatus, and computer program product for determining optimal flow control device (FCD) properties that would yield to a prescribed shape of the injection flow rate profile. For example, in one embodiment, a computer implemented method is configured to perform the steps of: determining a reference location along a production length of the injection well; determining a reference value equal to the injection flow rate profile at the reference location along the production length of the injection well; defining a target injection profile using the reference value; determining a pressure distribution along the production length of the injection well based on the target injection profile; determining a FCD distribution profile using the target injection profile and the pressure distribution; and determining FCD properties that yields the target injection profile based on the FCD distribution profile.