Abstract: Embodiments of the present disclosure generally relate to apparatus and methods for counterbalancing a pumping unit. One embodiment of the present disclosure provides a method for operation a pumping unit. The method includes measuring an orientation of a component and one or more parameters of the pumping unit while running the pumping unit, and determining an imbalance of the pumping unit according to the measured orientation and one or more parameters.

Abstract: A valve assembly can include a flow passage extending between an uphole end and a downhole end of the valve assembly, a flapper that pivots between an open position and a closed position, and a pump operable to pivot the flapper, the pump being positioned between the flapper and the downhole end. A method of testing a completion tubing string can include increasing pressure in the completion tubing string while a closure member of a valve assembly is in a closed position, thereby testing a pressure integrity of the completion tubing string on an uphole side of the closure member, and transmitting a pressure signal via a flow passage to a pressure sensor of the valve assembly, thereby causing the closure member to displace to an open position, the pressure sensor being connected to an electronic circuit positioned on a downhole side of the closure member.

Abstract: A connection assembly for a tube having a first pin attached to the tube, the first pin having a first sealing member; a second pin attached to a jumper tube, the second pin having a second sealing member; and a movable sleeve configured to sealingly engage the first sealing member and the second sealing member.

Abstract: A wet mate connection can include two connector assemblies, each connector assembly including at least one connector and a protective barrier displaceable between closed and open positions, and one connector assembly including an engagement device that displaces the protective barrier of the other connector assembly from the closed position to the open position in response to engagement between the connector assemblies. A method of making a connection between lines in a well can include installing a connector assembly, then installing another connector assembly, each connector assembly including a connector and an alignment profile, then axially compressing the connector assemblies, thereby opening protective barriers for the respective connectors, operatively connecting the connectors, and engaging the alignment profiles, thereby maintaining rotational alignment of the connectors.

Abstract: A tubular handling assembly includes a mandrel; a plurality of gripping elements for gripping a tubular, the plurality of gripping elements coupled to and rotatable with the mandrel; one or more accumulators; a first actuator configured to supply fluid to the one or more accumulators; and a second actuator configured to receive fluid from at least one of the one or more accumulators and to actuate the plurality of gripping elements.

Abstract: An oil or gas well actuator (1) assembly comprising a fixed member (10), an actuating member (30) being moveable axially with respect to the fixed member, with open-ended recesses containing canted coil springs (40) on e.g. the fixed member and a radially extending shoulder (30s) on the actuating member which adapted to engage a canted coil spring within a recess (20). A support member (50) is adapted to cover open ends of the recesses and moves into different axial positions with respect to the recesses to uncover open ends of different recesses in the different axial positions of the support member. Expansion of a canted coil spring (40) from an open end of a recess engages with the shoulder (30s) to restrict movement of the actuating member (30) at indexed positions. When the actuating member (30) moves relative to the support member direction, the support member (50) retains its position relative to the canted coil spring.

Abstract: A top drive unit including a top drive housing, a drive stem disposed in the top drive housing, a carrier configured to axially move the drive stem relative to the top drive housing, and a drive mechanism for rotating the drive stem.

Abstract: Embodiments of the present disclosure relate to apparatus and methods for making up and evaluating tubular threaded connections. A tong assembly may be used for making up threaded connections. A threaded connection may be made up automatically by controlling the rotation speed of the tong assembly according to measurements of torque, turns, and/or time. After a threaded connection is made up, measurements of time, torque, and/or turns may be corrected based on operating parameters. The corrected measurements may be evaluated for indications of failure, such as discontinuity, torque spikes, and torque drops. The threaded connection is then accepted or rejected based on the evaluation.

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 making a connection between a first tubular and a second tubular includes gripping the first tubular using a power tong; gripping the second tubular using a backup tong; applying a torque to the first tubular using a power tong; and moving the power tong at a predetermined speed to compensate for a weight of the power tong.

Abstract: A load cell for use with a tong assembly includes a body; a chamber formed in the body; and a strain gauge disposed in the chamber. The load cell also includes a first eye for pivotal coupling to the tong assembly, and a second eye for pivotal coupling to the tong assembly. An optional biasing member is disposed around the second eye for biasing the body relative to the tong assembly.

Abstract: Angular position readings are obtained during rotation of an apparatus in a borehole, and angular rate readings are obtained over time of the rotation. The angular rate readings are adjusted based at least on the angular position readings. The angular position measurement does not require calibrated magnetometers or accelerometers to function. Additionally, a dynamic scale factor calculation for an angular rate gyroscope (ARG) allows the ARG to be used over a much wider operating range than without such a calculation. Finally, an integrated angular rate from the ARG calibrated for bias and scale factor fills in positional information between the magnetometers' zero crossings to deliver a high resolution hybrid angular position system capable of measuring precise angular position at high and irregular downhole rotation rates.

Abstract: A drilling choke is controlled in a controlled pressure system. Pressure and position of the drilling choke are monitored. An adjustment to the position of the choke is determined based on the monitored pressure to control the drilling pressures. An actuation is produced of an actuator operably coupled to the choke to implement the determined adjustment. Rather than directly transferring, the actuation of the actuator is transferred with a transfer mechanism to motion of the choke in a non-linear relationship relative to the position of the choke. Generally, motion of the choke's internal trim (e.g., gate, ball, flapper, disc, etc.) is made quicker when near a fully opened position and is made slower when near a fully closed position. This reduces the need for strict precision for the motion. In the end, the monitored pressure is altered in response to the implemented choke adjustment.

Abstract: Apparatus and methods are for coupling a drive unit to a tool adapter. A drive unit includes a drive stem; a plurality of sliding coupling members; a retainer; a torque profile; a plurality of drive stem ports; a coupling collar; coupling recesses; a plurality of transmission units; and/or first portions of a hydraulic coupling unit. A tool adapter includes a tool stem; a tool stem sleeve; coupling recesses; a torque profile; a plurality of sliding coupling members; and/or second portions of the hydraulic coupling unit. A method of coupling a drive unit to a tool adapter includes positioning the tool adapter below the drive unit; stabbing a drive stem into an interior of a tool stem sleeve; coupling torque between the drive unit and the tool adapter; and coupling load between the drive unit and the tool adapter by engaging a plurality of sliding coupling members.

Abstract: A stage cementing system includes a stage cementing assembly having a stage tool. The stage tool has an outer mandrel, an inner mandrel coupled to and disposed inside of the outer mandrel, an annular chamber between the outer mandrel and the inner mandrel, a first outer port through the outer mandrel, and longitudinally spaced first and second inner ports through the inner mandrel. The stage cementing system further includes an inner string assembly configured to be located inside the inner mandrel. The inner string assembly has a tubular body having a central throughbore and longitudinally spaced first and second side ports, a lower external seal element below the first and second side ports, a middle external seal element between the first and second side ports, and an upper external seal element above the first and second side ports.

Abstract: A gas migration prevention module can include a housing, control line connections configured to connect the housing between control line sections, spaced apart pistons sealingly received in the housing, and a fluid volume defined between the pistons. A control line system can include an upper control line section, a lower control line section in fluid communication with a downhole tool, and a gas migration prevention module connected between the upper and lower control line sections, the lower control line section providing fluid communication between the gas migration prevention module and the downhole tool, and the gas migration prevention module comprising spaced apart pistons and a fluid volume defined between the pistons, the fluid volume being in fluid communication with an exterior of the gas migration prevention module.

Abstract: Methods and systems for controlling a set of tools for hydrocarbon recovery are presented. One example system generally includes a first tool and a first control device mounted on the first tool and configured to operate the first tool. The first control device includes an explosion-proof housing and a processor disposed in the housing. The system further includes a second tool and a second control device mounted on the second tool and configured to operate the second tool. The second control device includes an explosion-proof housing and a processor disposed in the housing.

Abstract: A well tool can include a downhole anchor with at least one outwardly extendable slip including longitudinally spaced apart grip structures, and a longitudinally extending beam which connects the grip structures to each other. The beam has a radial thickness which is greater than a lateral width of the beam. A slip retainer retains the slip, and a spring inwardly biases the slip relative to the slip retainer. The spring surrounds the slip and the slip retainer. An area moment of inertia of the beam with respect to a lateral axis through a centroid of the beam is greater than an area moment of inertia of the beam with respect to a radial axis through the centroid of the beam.

Abstract: A completion apparatus for a wellbore includes several flow tools and an actuation mechanism. The flow tools have a piston defining first and second chambers with a housing. The chambers communicate with hydraulics so the piston are movable in response to the communicated hydraulics. A sleeve disposed in the housing is movable with the piston between first, second, and third positions. The sleeve can have a seat movable between two conditions for passing/engaging plugs. The sleeve in the first position closes off communication through the first and second ports, and the sleeve in the second position permits communication through the first port and closes off communication through the second port. The sleeve in the third position closes off communication through the first port and permits communication through the second port. The actuation mechanism is operable to communicate the hydraulics respectively with the chambers of the flow tools.

Abstract: A hydraulic pumping system can include a hydraulic actuator with a magnet that displaces with a piston, and a sensor that continuously detects a position of the magnet. A ferromagnetic wall of the hydraulic actuator is positioned between the magnet and the sensor. A hydraulic pumping method can include incrementally lowering a lower stroke extent of a rod string reciprocation over multiple reciprocation cycles of the rod string, and automatically varying the lower stroke extent or an upper stroke extent of the rod string reciprocation, in response to a measured vibration. Another hydraulic pumping method can include solving a wave equation in the rod string, and automatically varying a reciprocation speed of the rod string in response to a change in work performed during reciprocation cycles of the hydraulic actuator or a change in detected force versus displacement in different reciprocation cycles of the hydraulic actuator.