Abstract: A downhole pump used for a reciprocating pump system includes a barrel coupling to a tubing string and having a standing valve and includes a plunger coupling to a rod string and having a traveling valve. One or both of the valves can include an assembly comprising a housing, an insert, a ball, and a seat. The insert allowing for flow therethrough defines a ball stop at one end has a ball passage at the other end. The insert positions in flow passage of the housing, and one of the ends engages a shoulder in the passage. The insert is secured in the flow passage with metallic material metallurgically affixed between at least a portion of the insert and the flow passage. For example, brazing material can be brazed at the end of the insert to metallurgically affix the insert in the passage. The ball is positioned in the insert, and the seat is positioned adjacent an end of the insert. The assembly is then incorporated into components of the pump.

Abstract: A surface unit reciprocates a rod string for a downhole pump in a slanted well. The unit has a beam with a bend and pivots at a pivot between the bend and the horsehead of the beam. A post of the unit supports the pivot and is oriented to support the beam's load along the post and reduce bending stress. A crank arm is rotated by a prime mover about a crank point and translates pitman arms to oscillate the beam on the pivot, which reciprocates the rod string at surface along the slanted axis. The unit can be set at various offset distances relative to the intersection of the well so the unit can be used at various inclinations of slanted axis. The horsehead defines a segment with a face to accommodate at least 70% engagement or greater with the rod load for both largest and smallest inclinations.

Abstract: A well tool can include an annular seal and a radial expansion mechanism having radially retracted and radially expanded configurations, the annular seal being longitudinally displaceable relative to the radial expansion mechanism in the radially retracted configuration. A method of setting a well tool can include positioning the well tool in a well, the well tool including an annular seal and a radial expansion mechanism, and then longitudinally displacing the annular seal to a radially outward position relative to the radial expansion mechanism. A well system can include a well tool including an annular seal, a radial expansion mechanism, an inner mandrel assembly and a setting sleeve, and a setting tool that produces a relative longitudinal displacement between the setting sleeve and the inner mandrel assembly, the annular seal radially outwardly overlying the radial expansion mechanism in response to the relative longitudinal displacement.

Abstract: Aspects of the present disclosure relate to automated load cell identification. One example method generally includes sending, from a load cell to a remote processing system, identification information associated with the load cell; and determining whether the load cell is valid for use during makeup of a threaded connection of a first threaded tubular to a second threaded tubular based on the identification information associated with the load cell. The load cell identification information may include a measurement range of torque values supported. The method can include comparing the measurement range of torque values to a job-defined range of torque values associated with the makeup of the threaded connection; and determining that the load cell is valid for use based on the comparison. The identification information can be used to detect the load cell type, range, and calibration data before tubular makeup to ensure data quality and safety at work.

Abstract: A tong includes a gear ring powered by a motor assembly, the gear ring having a plurality of ramps formed on an inner surface thereof and a brake plate rotationally independent of the gear ring, the brake plate having a gripping assembly for interacting with the ramps to grip a tubular. Also included is a brake assembly for preventing rotation of the brake plate, the brake assembly including an adjustable brake band for applying friction to the brake plate and at least one brake pad made of braking material disposed on an outer surface thereof in the area of contact with the brake band for reducing friction between the brake plate and the brake band. In one embodiment, the braking material is bronze.

Abstract: A hydraulic pumping method for use with a subterranean well can include mounting a hydraulic actuator above a wellhead, the hydraulic actuator and the wellhead being axially aligned with each other and inclined relative to vertical The hydraulic actuator can be unsupported by any substructure or guy wires after the mounting. A hydraulic pumping system for use with a subterranean well can include a hydraulic actuator including a piston that displaces in response to pressure in the actuator, a magnet that displaces with the piston, and a magnetic field sensor that detects a presence of the magnet. The hydraulic actuator may be mounted above a wellhead, with the hydraulic actuator and the wellhead being axially aligned with each other and inclined relative to vertical.

Abstract: A float shoe for a downhole tubular or casing includes a housing, a nose, a support, and a valve. The housing is attached to the casing, and the nose having a shell of a millable material (e.g., composite, aluminum, etc.) extends from the housing. A support of cement, fills an internal cavity of the nose's shell and support a valve in the housing. The shell for the nose defines a flow passage communicating with the valve and can have a conical or eccentric shape to facilitate passage of the float shoe in a borehole during run-in. The shell for the nose can also have a port or jet that communicate the flow passage out the side of the nose.

Abstract: A system or apparatus for use in downhole communication or detection comprises a downhole arrangement defining a throughbore and primary and secondary elements. One of the primary and secondary elements is provided on the downhole arrangement and the other of the primary and secondary elements is provided in the throughbore. The primary and secondary elements are configurable for coupling of an electromagnetic field therebetween. The primary or secondary element which is provided in the throughbore may be provided on a tool such as a shifting tool which is deployable through the throughbore. The secondary element may be configured to provide the electromagnetic field coupled between the first and second elements with one or more characteristic features. The system may be configured for use, in particular though not exclusively, for communicating information to and/or from a downhole tool in an oil or gas well.

Abstract: A method of actuating at least one of a plurality of downhole tools connected to at least one hydraulic fluid line is disclosed. The method includes the steps of:— a) providing each of the downhole tools with a control unit comprising a timer which permits fluid communication between the at least one hydraulic fluid line and the downhole tool during a window of time; and b) controlling the pressure in the at least one hydraulic fluid line for at least a sufficient period of time required to at least actuate the said downhole tool, wherein the said sufficient period of time coincides at least partially with the said window of time.

Abstract: A wellbore assembly includes a conveyance member including at least one of a continuous spooled rod, a wireline, and a slickline; an accumulator system connected to the conveyance member; and a setting tool connected to the accumulator system. The accumulator system may be configured to supply a fluid pressure to actuate the setting tool. A method of operating a wellbore tool includes lowering a wellbore assembly into a wellbore using a conveyance member including at least one of a continuous spooled rod, a wireline, and a slickline, wherein the wellbore assembly includes an accumulator system and a setting tool. The method includes actuating the accumulator system to provide a fluid pressure to the setting tool. The method also includes actuating the setting tool using the fluid pressure.

Abstract: A downhole tool coupling system, comprising a drive stem, a sleeve, and a plurality of locking clamps. The sleeve is longitudinally movable relative to the drive stem. The locking clamps are at least partially encompassed by the sleeve. The locking clamps are adjustable between an open position and a locked position. The sleeve is oriented relative to the locking clamps to adjust the locking clamps from the open position to the locked position as the sleeve moves longitudinally from an upper position to a lower position. Each locking clamp has an interior recessed region configured to clamp the drive stem to a tool stem when in the locked position.

Abstract: A method and apparatus for supplying non-hydraulic power to a tool unit during well operation. A top drive supplies power to a power consumer of the tool unit with a non-hydraulic power supply: a mechanical power coupling from the top drive to the tool unit, a wireless power coupling from the top drive to the tool unit, a local power supply on the tool unit, and/or combinations thereof. The non-hydraulic power supply may be capable of supplying at least 2 kW for at least 10 s. The system may include a fixed gear coupled to the top drive, a slewing ring meshed to the fixed gear, and a revolving gear meshed with the slewing ring and coupled to the tool unit. The slewing ring is configured to transfer rotational force from the fixed gear to the revolving gear, and may be rotated by rotating a torque shaft or actuating the fixed gear.

Abstract: A diversion connector is used for a downhole pump having a plunger and a barrel in a well. The diversion connector is useful in a sandy well having particulates. The plunger has an interior and is reciprocated by a rod relative to the barrel. The connector includes one or more bodies, such as a mandrel, attaching the rod to the plunger. The mandrel has a first exterior surface and defines a fluid passage communicating with the interior of the plunger. A sleeve is disposed on the first exterior surface and has an interior surface floating relative to the first exterior surface. The floating sleeve at least partially prevents particulate uphole of the plunger from passing in a gap between the plunger and the barrel.

Abstract: Systems and methods for predicting an accurate in-situ stress field in a wellbore in a formation are disclosed. The in-situ stress field is calculated using an optimizing process that takes into account parameters relating to induced tensile fracture that are derived from wellbore image logs and other input data relating to the wellbore. Once values for the in-situ stress field are predicted, those values can be used to generate synthetic image logs and fracturing data which can then be compared to the original image logs and fracturing data to determine the accuracy of the results and if needed repeat the operation to obtain more accurate results.

Abstract: A shifting tool can include an inner mandrel, engagement members engageable with a well tool component, and a detent device that prevents relative displacement between the inner mandrel and the engagement members, but permits such relative displacement in response to a predetermined longitudinal force. A method of operating a shifting tool can include engaging engagement members with a component of a well tool, and disengaging the engagement members from the component by applying a predetermined longitudinal force, thereby causing the engagement members to retract out of engagement with the component and then extend in the well. Another shifting tool can include a retraction sleeve, engagement members that engage a well tool component, and a detent device that prevents relative displacement between the retraction sleeve and the engagement members, but permits such relative displacement in response to a predetermined longitudinal force.

Abstract: A choke controlling fluid flow in a well has a conduit with an inlet and an outlet, and a flow restrictor comprising first and second choke members, one of which rotates relative to the other to choke or promote flow. The first and second choke members are axially spaced from one another, and have mating faces that are optionally planar, and are axially stacked in the choke. The choke is operated by a shifting tool, which grips the inner surface of the rotating choke member, and rotates it relative to the other, in order to vary the flow.

Abstract: A system for isolating a wellbore having a fluid flow passage extending from surface to a subterranean location has a first, downhole, valve and a second, uphole, valve. The downhole valve is located in the wellbore at a first subterranean location and the uphole valve is located in the wellbore at a second subterranean location spaced from the first valve. Downhole valve is operable between a first configuration permitting access through the flow passage and a second, well isolation, configuration isolating the flow passage below the valve. Uphole valve is operable between a first configuration permitting access therethrough and a second, isolation, configuration providing an isolated or isolatable volume between the first and second valves. A pressure sensor disposed in the isolated volume between the downhole valve and the uphole valve and, in use, permits a pressure in the isolated volume to be measured and/or communicated to a remote location.

Abstract: An assembly for forming a lateral wellbore includes a mill having a bore and a plurality of blades; a whipstock having an inclined surface for guiding movement of the mill, the mill releasably connected to the whipstock; and a tubing disposed in the bore of the mill and the whipstock. In one example, at least one of the plurality of blades is disposed in a slot formed in the whipstock.

Abstract: A method and apparatus for an anchor for use downhole. In one embodiment, the anchor includes an upper portion and a lower portion. In a run-in position, the anchor has a smaller outer diameter and in a set position, the anchor has a larger outer diameter. A slip assembly includes at least one slip, the slip having a longitudinal axis parallel to the longitudinal axis of the anchor and rotatable relative to the anchor along its longitudinal axis.

Abstract: The present disclosure generally relates to a method for making up a tubular joint. The method includes rotating a first tubular relative to a second tubular to engage the first and second tubulars while measuring a torque between the first and second tubulars, calculating a set point of a relative rotational speed between the first and second tubulars using the measured torque, and using the calculated set point with a closed-loop controller to control the relative rotational speed between the first and second tubulars.