Abstract: A stage cementing tool for a wellbore comprises a tool body defining a flow port in a wall thereof. The tool body and wellbore define an annulus therebetween. A setting sleeve compresses a packer element as it moves from the first to the second position. The packer element expands radially outwardly to engage the wellbore as a result of the compression applied by the setting sleeve. A pump-out plug in the tool body is expellable into the annulus upon the application of pressure in the tool body after the packer element engages the wellbore.

Abstract: A connection device, a control box component, and a fracturing apparatus are provided. The connection device includes: a fixation rack, configured to be fixedly connected with a mounting base; a box connection mechanism, configured to be connected with the control box, and drive the control box to move at least from a first position to a second position relative to the fixation rack. In a case that the control box is located at the first position, the control box is located at a side of the transmission component and a distance between the control box and the transmission component is less than a predetermined distance, and during the control box being moved from the first position to the second position, the control box is away from the transmission component to form an operation space for the transmission component at the first position.

Abstract: A downhole tool has a tubular body defining an outer wall. A port is defined in the outer wall and a plug is received in the port. The plug is detachably connected to the outer wall and expellable into an annulus between the tubular body and a wellbore in which the downhole tool is placed upon the application of pressure in an interior of the tubular body.

Abstract: A well system includes a wellhead positionable at a surface of a wellbore. The well system also includes a ball valve for coupling to the wellhead. The ball valve is movable between an open position and a closed position. Further, the well system includes a hollow core electric motor positionable adjacent to the ball valve to move the ball valve between the open position and the closed position. Furthermore, the well system includes a power source that provides electric power to the hollow core electric motor.

Abstract: A sand removal system configured to remove sand from a casing installed within a producing wellbore. The system utilizes a bottom hole assembly comprising a check valve sub and at least one sand removal tool. A swab cup installed within a vertical section the casing is used to create a pressure differential around the bottom hole assembly, causing fluid and sand to flow at a high velocity into the sand removal tool. The sand is caused to flow upstream where is later removed from the wellbore.

Abstract: A rotary percussive hydraulic drill comprises a body; a shank having female coupling splines and male coupling splines; a striking piston configured to strike the shank; a rotation drive device configured to drive the shank in rotation; a front abutment surface against which the shank is configured to come into abutment. The shank has an annular bearing flange which is provided on an outer surface of the shank and which has an annular bearing surface configured to come into abutment against the front abutment surface.

Abstract: A pressure bleed-off system. The system includes a fluid bypass line having an inlet and an opposing outlet, wherein the inlet is in fluid communication with a high pressure frac line for a hydraulic fracturing operation. The system also includes a high pressure transducer located proximate the fluid inlet, a first plug valve residing along the fluid bypass line, and a first electric actuator residing on the first plug valve. The actuator is configured to rotate the first plug valve between close and open positions in response to command signals from a controller. The controller, in turn, sends the command signals in response to control signals delivered by an operator, remotely. Preferably, the command signals are wireless signals sent from outside of the red zone. The system may also include a second plug valve along the bypass line.

Abstract: A latch system including a plurality of rocker latches, a rocker support, supporting the plurality of rocker latches, and a movement restrictor in operative connection with each rocker latch of the plurality of rocker latches, the movement restrictor allowing or restricting movement of each rocker latch of the plurality of rocker latches relative to the rocker support. A downhole tool including a sleeve movable relative to other portions of the tool, the sleeve having a profile at an uphole end thereof, an actuator runnable into contact with the sleeve, the actuator including the latch. A borehole system including a borehole in a subsurface formation, a string in the borehole, and a latch system disposed within or as a part of the string.

Abstract: A hydraulic set packer system includes an outer sleeve and a mandrel extending through the outer sleeve. The mandrel has a setting port extending through a radial wall of the mandrel, and the setting port is configured to provide fluid communication from a central bore of the mandrel to a setting chamber formed between the outer sleeve and the mandrel. The system also includes a piston configured to move axially along the mandrel in response to a setting pressure in the setting chamber. The piston is configured to drive at least one radially actuatable component to actuate in a radial direction to engage a wellbore wall. Further, the system includes a pressure isolation assembly disposed in the setting chamber. The pressure isolation assembly is configured to move axially with respect to the mandrel from a first position to a second position to seal the setting port.

Abstract: A sand collector including a diverter section and a filter section. The diverter section having a tubular portion with at least one aperture extending therethrough and at least one collector extending outwardly therefrom to cooperate with an exterior side of the tubular portion to form a channel in which solids traveling on the exterior side of the tubular portion from the upper end toward the lower end are guided to the aperture. The filter section having a tubular portion with an upper end, a lower end, and a sidewall extending between the upper end and the lower end. The filter section having at least one aperture extending through the sidewall, the upper end of the filter section extending from the lower end of the collector section and the lower end of the filter section being closed and connectable to at least one of another sucker rod and an upper end of a pump assembly.

Abstract: A method of recovering casing in a wellbore using a vibratory casing recovery bottom hole assembly. In a vibratory casing recovery bottom hole assembly having a casing spear, a flow modifier and one or more further elements including a shock sub. The flow modifier produces cyclic variations in fluid flow through the assembly at a first frequency and at least one of the elements is configured to have a natural or resonant frequency when vibrated to be near or at the first frequency. By tuning elements of the bottom hole assembly to be close or at the frequency of the output of the flow modifier, the dynamic amplification factor of the system is maximised and longer lengths of casing can be recovered. A method of recovering casing using the vibratory casing recovery bottom hole assembly is also described. Further embodiments include a casing cutter and a hydraulic jack.

Abstract: A section mill including a housing, a cutter pivotally connected to the housing, a drive piston operably connected to the cutter to radially expand or retract the cutter depending upon longitudinal position of the drive piston relative to the housing, and a limit configuration in operable contact with the drive piston to limit drive piston stroke responsive to hydraulic pressure on the drive piston. A method for cutting casing including determining condition of a structure radially outward of a casing to be cut, selecting an amount of expansion of a cutter based upon the determining, and cutting the casing. A borehole system including a borehole in a subsurface formation, a string in the borehole, and a section mill as in any prior embodiment disposed in the borehole.

Abstract: Embodiments described herein provide an expanding and collapsing apparatus and methods of use. The apparatus includes a plurality of elements assembled together to form a ring structure about a longitudinal axis. The ring structure is operable to be moved between an expanded condition and a collapsed condition by movement of the plurality of elements. At least one set of structural elements are operable to move between the expanded condition and the collapsed condition by movement of a first end in an axial direction, and by movement of a second end in a radial dimension. In certain embodiments, the plurality of elements includes at least one set of structural elements extending longitudinally on the apparatus and operable to slide with respect to one another. Applications of the embodiments described herein include oilfield devices, including anti-extrusion rings, plugs, packers, locks, patching tools, connection systems, and variable diameter tools run in a wellbore.

Abstract: An instrumented cutter including a polycrystalline diamond table bonded to a substrate with a sensor, for monitoring the condition of the polycrystalline compact diamond table, embedded in the substrate. Further the instrumented cutter includes a wireless transmitter equipped with a power supply to power to the wireless transmitter.

Abstract: A method for creating a weep hole is disclosed. The weep hole is drilled in an uncured, concrete, hollow core structural component having one or more external surfaces and one or more internal surfaces. The weep hole is drilled using a drilling apparatus comprising a drill, a rotating drill bit with an internal fluid passageway, a power source, and a pressurized fluid source. Loose, uncured concrete material deposited near the weep hole on the one or more internal surface as a result of drilling the weep hole is removed by releasing pressurized fluid which flows from the pressurized fluid source, through the drill and the rotating drill bit.

Abstract: Examples described herein include systems and methods associated with a mechanical service tool. In one example, the service tool includes a power jar, an accelerator, and a linear actuator. The accelerator can be coupled to the power jar and provide assistance to the power jar. The linear actuator can be coupled to the accelerator and configured such to pull the accelerator spring within the accelerator with a force sufficient to fire the power jar. When the power jar is in a released state, the linear actuator can also be used to push or pull the entire accelerator and power jar assembly, which in turn can push or pull the target object within the wellbore. The linear actuator can also be used to move the power jar from a released state to a set state.

Abstract: A system for establishing a bypass flow path includes a plug assembly having bypass ports extending from the exterior to the interior; a wiper dart to engage and seal the first flow path and bypass flow path, and initiate release of the plug assembly from a first position, the plug assembly having a dart nose attached to the dart body; once the plug has moved to a second position, pressure applied through the bypass ports communicates to the dart nose to cause detachment of the dart nose from the dart body; a first flow path extends through the central bore of the plug assembly when the wiper dart is not present; and a second flow path extends through the bypass ports on the plug assembly below the dart body to the detachable dart nose, once detached, the bypass flow path is established thru the bore below the dart body.

Abstract: An illustrative modular manifold system includes, among other things, two or more modular pump manifolds, a low-pressure header, and a main high-pressure manifold. Modular pump manifolds may include a low-pressure manifold for supplying fracturing fluid or water to pumps, a high-pressure manifold for supplying fracturing fluid or water to one or more wells and a bleed-off/prime-up manifold. Each modular pump manifold of the modular manifold system is configured to be fluidly isolatable from the other modular pump manifolds. Each isolated modular pump manifold is configured to be flushed with water, bled off and primed up independently of the other modular pump manifolds. After the bleed off, maintenance procedures may be performed on pumps associated with the isolated modular pump manifold. The modular pump manifolds that are not isolated may continue in active fracing stage operations while a modular pump manifold is isolated.

Abstract: Systems include a floating device disposed on a top of a column of drilling fluid in an annulus of a wellbore. The floating device includes a capsule. A transmitter or a reflector may be coupled to the capsule. The floating device may transmit signals to a surface region from the annulus or receive signals from the surface region and reflect at least a portion of the received signals. A receiver in the surface region receives transmitted signals or reflected signals from the floating device and determines a distance between the floating device and a reference point in the surface region. The distance indicates a level of the drilling fluid in the annulus.

Abstract: An electrical submersible well pump assembly has a SAW (surface acoustic wave) sensor on a motor shaft. A SAW electronic circuit mounts to the motor housing. The SAW electronic circuit has an antenna closely spaced to the SAW sensor for monitoring torque on the motor shaft. A controller at an upper end of the well supplies power to the motor. A motor gauge unit mounted to a lower end of the motor transmits signals to the controller. A signal line extends from the SAW electronic circuit to the motor gauge unit for transmitting signals from the SAW electronic circuit to the motor gauge unit, and from the motor gauge unit to the controller.