Abstract: A method, drill string, bottomhole assembly, drill bit, and insert are for extending a borehole for a relief well in a subsurface. The rotary drill string is provided in the borehole and includes a bottomhole assembly. The bottomhole assembly includes a drill bit. Current is provided into the subsurface using at least one electrode on the drill string, thereby generating current in a casing of a mother well located a distance away from the borehole of the relief well. At least one component of a magnetic field associated with the current generated in the casing is detected using at least one sensor disposed on the drill string. Data is obtained from the sensor for determining either or both the proximity and direction to the mother well. The drill string is advanced into the subsurface based upon the obtained data to extend the borehole.

Abstract: This disclosure presents methods and systems for positioning a magnetic fluid conditioner in a well. One or more magnetic fluid conditioners are attached to a coupling mandrel operable to engage with the tubing of a well, either with an existing completion component or directly with the tubing. The coupling mandrel includes a locking mechanism, such as keys or dogs, for setting the mandrel to the profile nipple. The coupling mandrel further includes a packing stack or an expandable element that seals with the completion component or the tubing. The seal directs oil through the mandrel and thus, through the magnetic fluid conditioners. In some embodiments, multiple magnetic fluid conditioners are attached in tandem for more effective conditioning operations. The magnetic fluid conditioners can condition the oil to inhibit the formation of paraffin therein.

Abstract: An excavating machine includes an actuation unit for moving the excavator, a main winch and secondary winch for lifting and lowering the actuation unit. A closed hydraulic circuit or an electric circuit drives the main winch. An open hydraulic circuit drives the secondary winch. A first pressure or current sensor measures fluid pressure or, electric current intensity in the hydraulic or electric driving circuit. A second pressure sensor measures fluid pressure in the open hydraulic circuit. A pressure regulator regulates fluid pressure in the open hydraulic circuit. A control unit executes a combined operating condition with the winches applying a force simultaneously and based on values sensed, controls the pressure regulator so the fluid pressure in the open hydraulic circuit, during the combined operating condition, has a target value that is a function of: the fluid pressure in the closed hydraulic circuit or the current in the electric circuit.

Abstract: A cable head line cutter tool comprising an internal mandrel anchored to a line and releasably held in an initial position by a locking mechanism disposed within an outer housing of the cable head cutter tool. When a tensile load is applied to the line sufficient to overcome a mechanical resistance acting upon the locking mechanism, and maintained for a duration sufficient to overcome a hydraulic resistance acting upon the locking mechanism, the internal mandrel may become released from the locking mechanism and allowed to travel within the outer housing free of the locking mechanism. In embodiments, the cable head line cutter tool may comprise one or more such locking mechanisms acting independently or in coordination. If the tensile load applied to the line is sufficient to release the mandrel from each of the one or more locking mechanisms and maintained for sufficient duration, the mandrel may cause a line cutter device disposed within the cable head line cutter tool to cut the line.

Abstract: A system including a spinner assembly that includes a spinner subassembly which includes a spinner configured to engage a tubular, and a drive gear coupled to the spinner, with the drive gear configured to drive rotation of the spinner, and the encoder configured to count teeth of the drive gear as the drive gear rotates. A controller configured to determine a number of revolutions of a tubular that are needed to thread the tubular to a tubular string based on data from the encoder. The controller is also configured to determine when the tubular is unthreaded from the tubular string based on data from the encoder.

Abstract: A method includes deploying a cementing assembly within a wellbore that is at least partially open hole. The method also includes setting the cementing assembly at a target zone of the wellbore by setting a first packer of the cementing assembly downhole of the target zone. The method also includes flowing, through the wellbore string and through the cementing assembly, cement to an annulus at the target zone. The annulus is defined between an exterior surface of the cementing assembly and a wall of the wellbore. The method also includes setting, with the wellbore string, a second packer of the cementing assembly. The second packer is disposed uphole of the first packer and uphole of the target zone.

Abstract: A port sub comprises one or more standard flow ports, each having a low-pressure port assembly positioned therein to, and at least one control flow port having a high-pressure port assembly positioned therein. The low-pressure port assembly comprises an inner layer having a first rupture pressure and an outer layer configured to remain intact upon the rupturing of the inner layer. The high-pressure port assembly comprises an inner layer having a second rupture pressure that is greater than the first rupture pressure. The high-pressure port assembly is configured to be broken through upon the rupturing of its inner layer to allow fluid flow through the at least one control flow port, thereby allowing a dissolve fluid to flow therethrough to facilitate the disintegration of the outer layer of the low-pressure port assembly to open the one or more standard flow ports.

Abstract: A ball-in-place plug configured to isolate formation zones within a wellbore includes an anchoring subassembly configured to secure the ball-in-place plug in the wellbore and a flow control subassembly configured to control the flow of fluid through the plug. The flow control subassembly is configured to allow bidirectional flow of fluid through the ball-in-place plug before the ball-in-place plug is activated, and wherein the flow control subassembly is configured to permit only unidirectional flow of fluid through the ball-in-place plug after the ball-in-place plug is activated.

Abstract: In well bores with included tubulars, it is often desirable to segregate a portion of the wellbore's pressure-driven fluid flowpath in the conduit portion formed by included tubulars to permit work to be completed in a pressure-controlled portion of that flowpath. The subassembly and included frangible device provided here does so with minimal exposure of seals to well fluid environments, and provides a field-adjustable variability to the pressure differentials required to open the conduit by removal of the frangible sealing device from the flowpath into which the subassembly is installed or included.

Abstract: A washover tool including an inner housing and an outer housing forming an enclosed annulus. The washover tool includes a rod member coupled to the outer housing, the rod member configured to supply a fluid to the annulus. The washover tool includes a front face plate having a plurality of openings in fluid communication with the annulus. The annulus of the washover tool is configured to receive a fluid through the rod member and configured to eject the fluid through the plurality of openings of the front face plate to washover a pipe embedded in a ground.

Abstract: A top drive system for wellbore related activities involving a drilling tubulars string. The system includes a frame structure and a top drive device with one or more top drive motors, a transmission housing, a floating quill system with a hollow vertical floating quill shaft. The top drive device has a thrust bearing housing arranged below the transmission housing and suspended via said first and second vertical frame members from the top frame member. A hollow vertical outer main shaft is suspended from the thrust bearing housing and a hollow vertical inner main shaft is arranged vertically mobile within the outer main shaft.

Abstract: A well tool for milling a tubular includes a well tubing disposed in a wellbore and including a circulation fluid pathway through an interior of the well tubing, a first milling tool coupled to the well tubing at a first longitudinal end of the well tubing, a second milling tool coupled to the well tubing at a location longitudinally uphole from the first milling tool, and a third milling tool coupled to the well tubing at a location longitudinally uphole from the second milling tool. Each of the milling tools include a mill bit and a circulation sub fluidly connected to the circulation fluid pathway. The first milling tool mills a first portion of the tubular, the second milling tool mills a second portion of the tubular, and the third milling tool mills a third portion of the tubular.

Abstract: A system for conducting a subterranean operation can include a retention feature in a drill floor with the retention feature configured to suspend a tubular string from the drill floor via engagement of the retention feature with the tubular string, an imaging system configured to capture images of a visible feature on a portion of the tubular string that extends above the drill floor; and a processor configured to detect a change in a position of the visible feature while the tubular string is engaged with the retention feature, and the processor being configured to calculate a wear status of the retention feature based upon the change in the position of the tubular string.

Abstract: A well system includes a tubular string comprising a plurality of tubular segments and positioned in a wellbore drilled into a subterranean zone, and a landing sub connected to a bottom end of one of the plurality of tubular segments. The landing sub includes a landing sub central bore and a landing sub locking profile on an inner surface of the landing sub central bore. The well system also includes a valve assembly configured to be pumped down the tubular string by fluid flowing in a downhole direction through the tubular string and to land within the landing sub central bore. The valve assembly includes a main body with a valve central bore and a flapper configured to pivot between an open position and a closed position. In the closed positon the flapper seals against a flapper seat and blocks fluid from flowing in an uphole direction through the valve central bore.

Abstract: A system includes a sliding sleeve, a ball landing seat, a plurality of microchips, a hydraulic piston, and a ball catcher. The sliding sleeve is installed within a tubular body having an exit groove. The ball landing seat is formed by the sliding sleeve. The plurality of microchips are housed in a microchip ring installed within the sliding sleeve. The hydraulic piston is installed within the microchip ring and triggered by reception of a ball in the ball landing seat. The ball reduces a cross sectional area of a flow path while in the ball landing seat. The hydraulic piston releases the plurality of microchips through the exit groove and into the well to gather data. The ball catcher is configured to receive and hold the ball after the plurality of microchips are released into the well. The ball catcher and the ball are made of a dissolvable material.

Abstract: Contamination estimation of a mud filtrate or reservoir sample requires a robust handle on the properties of mud filtrate at downhole conditions. Coupling acquired data with downhole measured data provides a robust estimation of contamination by encompassing the entire available data. Downhole density of the mud filtrate sample may be estimated based on a characteristic of the mud filtrate sample. A density of a formation fluid of the reservoir may be determined using a formation tester tool. The contamination of the formation fluid may be estimated based on the clean fluid density and the estimated mud filtrate density by, for example, using a material balance equation or ratio. An estimated pump-out time for the formation fluid may be determined based on the estimated contamination and a trend of the estimated contamination of the formation fluid.

Abstract: A severing apparatus is used for severing a conduit. The apparatus includes a main body section having an upper portion, a lower portion, and an intermediate portion. A combustible charge is located in the intermediate portion, and an ignition mechanism is coupled to the upper portion for igniting the combustible charge. A nozzle head is located in the lower portion and includes an internal cavity and a nozzle portion having apertures at spaced apart positions for providing passages from the internal cavity to outside of the nozzle head. The ignition mechanism is configured to ignite the combustible charge to create a flame and combustion products and pressure in the internal cavity for moving the nozzle head relative to the lower portion so that the nozzle portion protrudes out of the lower portion for passage of the flame and hot combustion products out of the apertures to sever the conduit.

Abstract: Apparatus, methods, and systems are provided to count one or more magnetically permeable objects that have passed by a magnetic sensor and determine a direction thereof. The apparatus comprises a first permanent magnet; a second permanent magnet; a magnetic field sensor disposed between opposing poles of the first permanent magnet and the second permanent magnet; and a circuit connected to the magnetic field sensor, the circuit configured to count one or more magnetically permeable objects that have passed by the magnetic field sensor, and determine direction of the one or more magnetically permeable objects based on an output of the magnetic field sensor.

Abstract: A sonic tooling handling apparatus includes a gantry support structure with a base frame structure and an overhead frame structure operatively coupled to the base frame structure. The overhead frame structure has a pair of longitudinal beams and a transverse beam coupled to the pair of longitudinal beams. The transverse beam is movable along each of the pair of longitudinal beams. The gantry support structure includes a lifting device coupled to the transverse beam and is movable along part of the transverse beam. The lifting device includes a sonic tooling clamp. The lifting device may raise or lower sonic tooling held by the sonic tooling clamp. The sonic tooling apparatus further includes a removable sonic tooling holding rack having a plurality of stanchions creating at least one sonic tooling holding space for holding sonic tooling. A method of handling sonic tooling and a pipe tong is also disclosed.

Abstract: Provided is a downhole tool. The downhole tool, in one aspect, includes an isolation system for placement at a junction between a first wellbore and a secondary wellbore. In at least one aspect, the isolation system includes an elongated tubular, the elongated tubular having an opening connecting an interior of the elongated tubular and an exterior of the elongated tubular; and a slot located in the elongated tubular, the slot spanning the opening. In at least one aspect, the isolation system further includes an isolation sleeve located within the isolation system, the isolation sleeve configured to slide within the slot to either isolate the interior of the elongated tubular from the exterior of the elongated tubular or provide access between the interior of the elongated tubular and the exterior of the elongated tubular, and an I-shaped seal located in an annulus between the elongated tubular and the isolation sleeve.