Abstract: Implementations of the present disclosure include a wellbore assembly that includes a wellhead assembly and a plunger. The wellhead assembly is coupled to a wellbore string disposed within a wellbore. The wellhead assembly includes a lubricator, a spring, and a flexible damper. The lubricator defines a tubular housing. The spring is disposed at least partially within and attached to the tubular housing. The spring comprises a first end attached to the tubular housing. The flexible damper is coupled to a second end of the spring opposite the first end. The plunger strikes, as the plunger is lifted from a downhole location of the wellbore to the terranean surface, the flexible damper. The flexible damper deforms, upon impact with the plunger, to dissipate some or all of the kinetic energy of the plunger.

Abstract: A gas vent can include an inner production tube and at least two outer housings. One outer housing is configured to be connected above a tubing anchor, and another outer housing is configured to be connected below the tubing anchor. The inner production tube is configured to extend longitudinally through the tubing anchor. A gas vent system can include an inner production tube which extends longitudinally through a tubing anchor, and an annulus formed between the inner production tube and the tubing anchor. A gas flows through an interior of the tubing anchor via the annulus.

Abstract: Systems and methods for installing a coiled tubing pumping system in a well permit the use of a standard wellhead. A method for installing the coiled tubing pumping system includes the steps of connecting a continuous length of coiled tubing to the coiled tubing pumping system, lowering the coiled tubing pumping system and coiled tubing into the production tubing, and temporarily supporting the weight of the coiled tubing pumping system with an installation kit. The method continues with the steps of cutting the continuous length of coiled tubing to form a coiled tubing segment attached to the coiled tubing pumping system, attaching a deployment assembly to an upper end of the coiled tubing segment connected to the coiled tubing pumping system, and lowering the deployment assembly, the coiled tubing segment and the coiled tubing pumping system into the well until the deployment assembly lands on the seating element.

Abstract: An example control system includes a hydraulic pump disposed in a wellbore, a valve bank disposed in the wellbore, and an unpressurized hydraulic fluid reservoir. The hydraulic pump is fluidically connected with the valve bank. The valve bank is fluidically connected with the unpressurized hydraulic fluid reservoir. The unpressurized hydraulic fluid reservoir is fluidically connected with the hydraulic pump. The control system is configured to flow pressurized hydraulic fluid exiting from the hydraulic pump to the valve bank to be distributed from the valve bank to the wellbore equipment.

Abstract: A hydraulic collapsible rotary stand for a wireline coring underground drill rig includes two main hydraulic supporting posts, at least one hydraulic post erection cylinder, a collapsible stand base, a horizontal rotating base, and a rotary lifting cylinder, where the rotary lifting cylinder drives the collapsible stand base to move up or down; post mounting rods are hinged at a front side of the collapsible stand base; the post mounting rods are respectively connected to the main hydraulic supporting posts; a main post supporting cross-bar is provided between the main hydraulic supporting posts; through the hydraulic post erection cylinder, the main post supporting cross-bar is supported and the main hydraulic supporting post is pushed to be erected or collapsed; a hydraulic gyration supporting beam is provided between the main hydraulic supporting posts; and the hydraulic gyration supporting beam is connected to a lower sliding plate provided with a drill rig.

Abstract: Provided are compositions, methods, and systems that relate to downhole tractor wheels. A downhole tractor system comprising: tubular housing capable of being deployed downhole by wireline; plurality of wheels rotatably mounted to tubular housing, wheels having at least a portion of an outer surface comprising polymeric material. A method for conveying a downhole tool along an inner wall of a wellbore, the method comprising: disposing downhole tool coupled to downhole tractor within wellbore; providing energy to downhole tractor by way of wireline thereby rotating a wheel disposed on downhole tractor; frictionally engaging the inner wall of wellbore with wheel comprising polymeric material disposed on at least a portion of an outer surface of wheel thereby providing a compressive load between the inner wall of the wellbore and polymeric material; allowing downhole tractor to proceed along wellbore wall until downhole tractor reaches desired location; deploying downhole tool for use in wellbore.

Abstract: A method for minimizing over pressurization during a pressure test of a fluid distribution system comprises a plurality of pumping units in fluid communication with a wellhead via a manifold. The method comprises pressurizing the fluid distribution system with a fluid using an initial number of pumping units to an initial predetermined pressure, and further pressurizing the fluid distribution system with the fluid using a final number of pumping units to a final predetermined pressure. The final number of pumping units is less than the initial number of pumping units.

Abstract: A downhole tool assembly is configured for repeated and selective hydraulic activation and deactivation. A spring member biases the indexing control section 210 towards a first axial position while drilling fluid pressure in the tool body urges the indexing control section 210 towards other axial positions. Downhole tool activation and deactivation may repeatedly be controlled from the surface by cycling the drilling fluid pressure.

Abstract: A guide assembly including a guide nose, a body supporting the guide nose, and a torque limiter having a configuration to connect the guide nose and the body to a separate structure. A method for negotiating a restriction in a borehole including running a guide assembly into the borehole, encountering a restriction with the guide nose, limiting torque on the guide nose while encountering the restriction, longitudinally unloading the guide nose, incrementing an incrementing feature of the guide assembly to thereby rotate the guide nose. A wellbore system including a borehole in a subsurface formation, a string in the borehole, a guide assembly disposed within or as a part of the string.

Abstract: A downhole tool may include an anchor coupled to a first portion of the downhole tool and configured to engage with a feature of a wellbore to affix the first portion to the feature. The downhole tool may also include a linear actuator coupled to the first portion and to a second portion of the downhole tool, where the linear actuator is configured to move the second portion relative to the first portion and the feature. The downhole tool may further include a cutting head coupled to the second portion and including one or more cutters configured to engage with the feature. The downhole tool may also include a control system configured to obtain remote commands to control the anchor, the linear actuator, the cutting head, or a combination thereof.

Abstract: An inflow control device configured to switch between an open and a closed state, includes: an inlet; an outlet; a housing; a first body and second body arranged within the housing. The second body is moveable relative to the first body. In an electrically energised state, the first body is operative to magnetically attract or repel the second body. In the open state, the first and second body are located at respective open positions and define a continuous path with the housing, through which fluid can flow from the inlet to the outlet. In the closed state, the first and second body are located at respective closed positions and are contiguous, thereby blocking the continuous path. The inflow control device is operative to switch between the open and closed states by electrically energising or de-energising the first body.

Abstract: A well system includes a service rig positioned above a wellbore including a primary wellbore and a lateral wellbore extending from the primary wellbore, a string of casing lining a portion of the primary wellbore and having an inner surface coated with a first reactive material, a liner lining a portion of the lateral wellbore and having an inner surface coated with a second reactive material, a downhole tool conveyable into the wellbore to discharge a corrosive fluid reactable with the reactive materials and generate a reacted solution including a reaction product indicative of the first or second reactive material, and a fluid analyzer to analyze the reacted solution and identify the reaction product entrained in the reacted solution, wherein identifying the reaction product with the fluid analyzer provides a positive indication of a location of the downhole tool within the wellbore.

Abstract: A system includes a tubing hanger configured to be positioned in a wellhead assembly, the tubing hanger configured to support a tubing string, the tubing hanger including: a bore extending at least partially through the tubing hanger; and a valve disposed along the bore of the tubing hanger, wherein the valve is configured to control the flow of a fluid medium through the bore, and wherein the valve includes: an electrical actuator, wherein the electrical actuator is disposed at least partially within the tubing hanger, and wherein the electrical actuator is configured to selectively open or close the valve in response to one or more electrical signals.

Abstract: A female portion arranged to form part of a thread joint for a percussive drilling tool includes a mounting sleeve, wherein the mounting sleeve has at least one substantially cylindrical internally threaded section having a length, L1, a thread entrance located towards an axial end and a thread exit located towards the axial inner wall. The threaded section has a thread form including crests, roots, contact flanks, and non-contact flanks, a pitch length, L4, located between two axially neighboring crests and an inner diameter, D2 disposed radially between the roots. A thread clearance section is positioned between the axial inner wall and the thread exit and has a length L2 and a diameter D1. A guiding section is positioned between the thread entrance and the axial end of the sleeve and has a length, L3. The pitch length, L4, is between 12.8-14.5 mm.

Abstract: A drill speeder. The drill speeder is used for increasing the rotating speed of a drill bit in drilling operation and comprises: an upper joint (1) connected to a drill tool (200) in the drilling operation; a lower joint connected to the drill bit (300); and three wing plates (9) arranged on the outer surface of a gear sleeve (10) of the drill speeder in an equal division mode, and closely attached to pistons embedded on the gear sleeve (10). When the drill bit (300) conducts a speed increasing operation, a drilling slurry column in the drill speeder jacks up the pistons (8) on the gear sleeve (10), and the wing plates (9) are opened and attached to the well wall. The drill speeder further comprises a sun shaft (12) and planetary gears (4).

Abstract: Drill bit (230) for a drilling tool (1) comprising a drill bit member (231) which delimits a through-channel (231C) for the passage of the fluid flow and comprising an external surface (232), from which there extend a plurality of drilling members (233) which are uniformly distributed over the external surface (232), each drilling member (233) comprising a fin (233A) which extends from the external surface (232) and a plurality of drilling teeth (233B) which extend from the fin (233A) and which each comprise a base (233B1) and a cutting element (233B2) which is arranged at the end of the base (233B1), the drill bit comprising a high-voltage electrode (232C) which is arranged at the centre of the central facial opening (231A1) and each drilling member (233) comprising an earth electrode (233C) which is positioned at the end of the fin (233A), at the high-voltage electrode (232C), so as to at least partially extend in line with the central facial opening (231A1).

Abstract: A setting kit for connecting a plug to a setting tool includes a collet connecting part configured to be attached to an internal sleeve of the setting tool; and a collet configured to be attached with a first end to the collet connecting part and with a second end to the plug. The second end automatically connects to the plug by only pushing the second end onto the plug.

Abstract: A tubular running tool equipped with a mandrel having an elongated body with a longitudinal axis. The mandrel is configured with a plurality of offset stepped ramps. A plurality of slips are disposed on the mandrel with stepped ramps configured for complementary engagement with the mandrel offset ramps. The mandrel is configured for actuation to urge the slips radially outward for engagement of a gripping portion on the slips with an inner surface of a tubular. A method using the tool for running a tubular and providing a makeup torque.

Abstract: A retention system for attaching a collar to a pipe. The collar has an internally-disposed groove configured for placement of a ring. The ring is sized such that in one orientation, it can enter the collar between torque-transmitting features into the internally-disposed groove. Once in the groove, the ring may be adjusted such that its aperture is generally aligned with the axis of the collar. In this orientation, the features retain the ring within the groove. A bolt and a pipe may then be placed within the collar from opposite sides. The bolt is attached to the pipe through the ring. Once joined, the collar is joined to the pipe, forming its box end. Such a retention system may be used to join a series of inner pipe members of a dual-member pipe assembly, as in horizontal directional drilling.

Abstract: A subsurface safety valve includes an outer housing, a flapper valve disposed within the outer housing, and a motor that pivotally displaces the flapper valve. The subsurface safety valve also includes a battery that powers the motor, a turbine that charges the battery and a wireless receiver that, responsive to a received signal, transmits a signal to the motor to pivotally displace the flapper valve. A related method includes: providing a subsurface safety valve having an outer housing; disposing a flapper valve within the outer housing; providing a motor, a battery, a turbine and a wireless receiver; charging the battery with the turbine; powering the motor with the battery; receiving a signal at the wireless receiver; and responsive to the received signal, transmitting a signal to the motor to pivotally displace the flapper valve.