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.

Abstract: Downhole electrical energy harvesting and communication in systems for well installations having metallic structure carrying electric current, for example CP current. In some instances there is a harvesting module (4) electrically connected to the metallic structure (2) at a first location and to a second location spaced from the first location, the first and second locations being chosen such that, in use, there is a potential difference therebetween due to the electric current flowing in the structure (2); and the harvesting module (4) being arranged to harvest electrical energy from the electric current. In addition or alternatively, there may be communication apparatus (4, 5, 6) for communication by modulation of the current, for example CP current, in the metallic structure (2).

Abstract: A drilling control mechanism of a core drilling rig has a tooth drill and a core drilling rig. The core drilling rig is inside the tooth drill and engages with the drill in a sliding manner. A locking recess is formed at an inner wall of the tooth drill. A locking latch recess is formed at an outer wall of the core drilling rig and has a locking latch therein. The locking latch has a spring. When the locking recess is directly opposite the locking latch recess, the spring extends and the locking latch partially enters the locking recess. The core drilling rig has a central rod, a fluid channel activation module, an outer barrel, and outer barrel unlocking module and a flow diverging module. The central rod passes through the inner cavities of the fluid channel activation module, the outer barrel unlocking module and the flow diverging module.

Abstract: A method for performing a subterranean operation that can include operations of engaging a tubular with a pipe handler, calculating, via a processor, an internal volume of the tubular, determining, via the processor, a number of pump strokes required to fill at least a percentage of the internal volume with fluid, pumping the fluid to the tubular by running a pump the number of pump strokes, and filling the internal volume of the tubular to at least the percentage of the internal volume with the fluid.

Abstract: A polycrystalline element includes a table formed of polycrystalline diamond. The table includes a first surface; a second surface spaced apart from the first surface; and at least one side extending between the first surface and the second surface. The table also includes a plurality of extensions also formed of polycrystalline diamond, wherein at least one extension of the plurality of extensions extends away from at least one of the first surface and the at least one side. Optionally, the polycrystalline diamond of at least one extension of the plurality of extensions is contiguous with the polycrystalline diamond of the table. The polycrystalline element may be used in downhole tools for boring and well drilling, machine tools, and bearings.

Abstract: A lateral isolator (200) has a tubular body with an upstream end and a downstream end. The lateral isolator (200) also includes an inner member (210) having a pivot ring (220) disposed within the tubular body. A first elastomeric package (236) is disposed between the tubular body and the inner member (210) longitudinally between the pivot ring (220) and the upstream end. A second elastomeric package (236) is disposed between the tubular body and the inner member (210) longitudinally between the pivot ring (220) and the downstream end.

Abstract: An object includes a housing, a cone received in the housing, a piston body attached to the cone, a gas evolution compound disposed in the object, an interface between the housing and the piston body, an interface feed fluidly connecting the gas evolution compound with the interface, and a trigger to evolve gas from the compound at a selected circumstance. A method for moving a tool including running an object into a borehole, counting features in the borehole using a sensor in the object, evolving gas from the gas evolution compound at a selected count, pressurizing the interface with the evolved gas, driving the piston body, and moving a shoulder member toward a larger diameter end of the cone. A borehole system including a borehole in a subsurface formation, a string disposed in the borehole, and an object disposed within or as a part of the string.

Abstract: A hydraulic fracturing spread system has modular high-pressure fracturing fluid manifold assemblies which couple to form a large trunk line for collecting and conveying high pressure fracturing fluid toward the well bore. Oil-hydraulic intensifier pump units integrated with the modular manifold assemblies increase the fracturing fluid pressure into the trunk line. The manifold assemblies may be configured differently from one to the other and coupleable horizontally and/or vertically.

Abstract: A plug assembly for a cementing operation in a well includes a bottom wiper plug configured to land in or near the toe of a well and receive a cement slurry therethrough, a top wiper plug releasably coupled to the bottom wiper plug and configured to land on the bottom wiper plug after the cement slurry is received through the bottom wiper plug, a bridge plug coupled to the top wiper plug and configured to move toward the bottom wiper plug with the top wiper plug after the bottom wiper plug is landed in or near the toe of the well, and a sensor sub coupled to the bridge plug and configured to detect a gate in the well.

Abstract: A method may include monitoring, for a well head of a hydraulic fracturing system, an operation or a state of one or more subsystems of the hydraulic fracturing system. The hydraulic fracturing system may include one or more fracturing rigs, one or more blending equipment, and one or more power sources electrically connected to a first subset of the one or more fracturing rigs, or one or more fuel sources fluidly connected to a second subset of the one or more fracturing rigs. The hydraulic fracturing system may further include one or more missile valves, one or more zipper valves, one or more well head valves, and one or more well heads. The method may further include controlling, based on an operation schedule for the hydraulic fracturing system and based on monitoring the operation or the state, the state or equipment changes.

Abstract: A control unit includes a rotatable tubular body that rotates around a spindle. A torque transfer unit may be attached to the tubular body and the spindle. A force applied to the torque transfer unit by a biasing element may control a first torque applied by the tubular body to the spindle. The first torque is independent of a rotational velocity of the tubular body. A second torque is applied to the spindle with a torque generator, the second torque controlling the net torque. Controlling the net torque allows the absolute orientation of the control unit to be controlled.