Abstract: A tool for use within a subterranean well extending from a wellhead to a subterranean location, wherein the wellhead resides at a first temperature and the subterranean well increases in temperature in a direction from the wellhead to the subterranean location, increasing from the first temperature to a higher second temperature, includes a component including a meltable material. The meltable material is configured to have a solid first state while the meltable material is at the first temperature. The meltable material in the first state has one or more mechanical properties sufficient to avoid mechanical failure of the component and is configured to have a second state when the meltable material is at the second temperature. The meltable material in the second state is lacking the one or more mechanical properties necessary to avoid mechanical failure.

Abstract: Self-winding power generating device, system, and method are disclosed. The device includes a mechanical winding knob for receiving mechanical energy from a downhole environment, a gear train including a plurality of gears engaged with each other, wherein a first gear in the gear train is operatively connected to the mechanical winding knob, and configured to receive mechanical energy from the mechanical winding knob and transfer the mechanical energy to a second gear in the gear train, a spiral spring attached to one of the gears in the gear train, the spiral spring configured to self-wind and store the mechanical energy upon receiving the mechanical energy from the first gear, and a power generation unit configured to receive the mechanical energy from a last of the plurality of gears and convert the mechanical energy into electrical energy.

Abstract: An intervention system is provided. The intervention system comprises a cable being configured to be lowered into a wellbore, said cable having an inner tube enclosing one or more electrical conductors, and an outer tube surrounding the inner tube. The intervention system further comprises a downhole tool being connected to a distal end of the cable and being configured to pull the cable into the wellbore.

Abstract: Aspects of the subject technology relate to a sensor container for a downhole tool. The sensor container can be mountable in a receiver space on a carrier that is insertable into a wellbore. The sensor container can comprise a container body having a receiving space to which a shock-sensitive sensor is couplable. Further, the sensor container can comprise a shock absorber positioned at a lateral side thereof. The shock absorber can be configured to buffer shock forces and vibration forces acting thereupon.

Abstract: A well cleaning tool includes a positioning device configured to control a position of the well cleaning tool within a well, a rotatable brush assembly configured to scrape a wall of the well, a capture device configured to catch debris dislodged from the wall by the rotatable brush assembly, and a fluid delivery assembly configured to deliver a cleaning fluid to the well.

Abstract: The present invention relates to the field of natural gas production, and discloses a well structure for natural gas hydrate production, which comprises: a natural gas production well (12); an injection well (4) capable of extending into a geothermal reservoir and injecting a heat-carrying fluid; a curved connecting well (7), the inlet end of the curved connecting well (7) is connected to the outlet end of the injection well (4); a hydrate production horizontal well (10), which may be arranged in a shallow hydrate reservoir (9), the curved connecting well (7) and the hydrate production horizontal well (10) are connected by an ascending well section (8). With the above technical scheme, the high curvature connected well connecting the horizontal well and the vertical well can be located in the bottom layer below the hydrate reservoir, enhancing the stability and production efficiency of the gas hydrate production well.

Abstract: An imaging device (124), laser(s) (190, 192), lag calculation, and/or volume calculations are used to determine cuttings volume per unit depth. A projected or theoretical volume can be calculated based on parameters of the borehole being drilled. At the surface of the borehole, cuttings can be captured in a shaker screen (108). The volume of the cuttings can then be directly measured on the shaker screen. Deviations from a projected volume can be logged and notifications can be communicated on and/or offsite of the borehole. Additionally, size and shape of cuttings can be logged. Deviations from projected size and shape can also be logged. Various hydrocarbon recover}? operations can be altered based on results of the cuttings analysis and other indicators of improper hole cleaning. For instance, the drilling can be stopped, or a direction of the borehole can be altered.

Abstract: A well livening system to reduce an accumulation in a wellbore includes a chemical skid, the chemical skid includes a chemical storage tank configured to contain the dosing chemical, a dosing pump configured to transfer an amount of the dosing chemical from the chemical storage tank to a wellbore, a skid line, and a dosing check valve configured to allow flow of the amount of dosing chemical, a controller system configured to determine the amount of dosing chemical to be transferred to the wellbore based on downhole data, the connection line configured to transport the amount of dosing chemical from the chemical skid, an injection spool, a hanger configured to support the chemical injection string and to isolate the wellbore from the surface, the chemical injection string configured to deliver the amount of dosing chemical to the wellbore, and a data acquisition system configured to collect downhole data.

Abstract: A telescopic drill rod has at least two rod members disposed coaxially to one another, with the inner rod member being axially slidable relative to the outer rod member in a telescoping manner between an extended position and a retracted position. Both the inner rod member and outer rod member are equipped with joints at each end for connection to a drill head and/or another section of drill pipe. The joints also lock the inner and outer rod members in either the extended or retracted positions, and this is accomplished with a unique frusto-conical threaded engagement that is well-suited for transmitting pressure forces.

Abstract: A system for stimulating a subterranean formation that has a wellbore formed within the subterranean formation; and a tubular disposed within the wellbore. There is a first frac valve disposed within the tubular, the first frac valve having a first sleeve in a closed position, and further configured to move to an open position. There is an at least a second frac valve disposed within the tubular, the second frac valve having a respective sleeve in a respective closed position, and further configured to move to a respective open position. A dart is configured to pass through the first frac valve without moving the first sleeve, and to subsequently engage the second frac valve to move the respective sleeve to the respective open position.

Abstract: An oilfield band cutter is useful for removing a band from a tubing string structure as the tubing string structure is being pulled up from the well. The oilfield band cutter includes a base frame with a central hole, an axis extending vertically and centrally through the frame coaxial with the central hole. A tubing follower member is coupled to the base frame and is positioned against an outer surface of the tubing string structure. A cutter is coupled to the tubing follower member, the cutter including an underside having a cutting edge. The cutting edge is positioned to engage against and cut bands on the tubing string structure.

Abstract: A wellhead system includes a first position casing hanger and a second position casing hanger, arranged within a wellbore. The second position casing hanger is positioned axially higher and stacked on the first position casing hanger, and a weight of the second position casing hanger is supported, at least in part but less than entirely, by the first position casing hanger and, at least in part but less than entirely, by an actuated load shoulder transferring the force into a high pressure housing. The actuated load shoulder includes a load ring having a hanger side profile and a housing side profile, the load ring is adapted to engage a hanger profile formed in the second position casing hanger and a housing profile formed in the high pressure housing upon activation via the first position casing hanger.

Abstract: A system and method to controlling fluid flow to/from multiple intervals in a lateral wellbore. The system and method can include a unitary multibranch inflow control (MIC) junction assembly (a primary passageway through a primary leg and a lateral passageway through a lateral leg) installed at an intersection of main and lateral wellbores. An upper energy transfer mechanism (ETM) can be mounted along the primary passageway, and control lines 100 can provide communication between the upper ETM 214 and lower completion assembly equipment. A lower ETM can be mounted along the lateral passageway, with the upper ETM in communication with the lower ETM via the control lines. A tubing string can be extended through the primary passageway to access lower completion assembly equipment. The upper ETM can communicate with a tubing string ETM to receive/transmit control, data, and/or power signals from/to lower completion equipment in the lateral wellbores.

Abstract: Apparatus and operational methods thereof, including a top drive, a rotation sensor, and a processing device. The top drive connects with an upper end of a drill string. The rotation sensor facilitates rotational distance measurements indicative of rotational distance achieved by the top drive. The processing device causes the top drive to impart rotational oscillations alternatingly in opposing directions to the upper end of the drill string while maintaining a downhole toolface orientation during a slide drilling operation, such that each rotational oscillation rotates the upper end of the drill string through a base rotational distance. The processing device also causes the top drive to change the downhole toolface orientation by an offset rotational distance by adding the offset rotational distance and an overshoot rotational distance to the base rotational distance of an instance of the rotational oscillations.

Abstract: A downhole chemical reactor can be placed in a downhole environment to generate gas in-situ. This gas can pressurize an inner pressure chamber of the downhole chemical reactor to create a pressure-on-demand source or to maintain a constant pressure reservoir, depending on the configuration of a reactor controller coupled to an inlet of the inner pressure chamber. The inner pressure chamber contains one or more desired chemical reactants and the reactor controller operates to permit well fluid to flow from the wellbore and into the inner pressure chamber. The well fluid reacts with the desired chemical reactants and generates one or more gases such as hydrogen or carbon dioxide. The generated gases pressurize the inner pressure chamber and a pressure regulator coupled to the inner pressure chamber maintains a maximum pressurization of the inner pressure chamber. For a constant pressure reservoir, the reactor controller repeats this cycle indefinitely.

Abstract: A walking system for a workover rig or completion rig mounted on a motor vehicle. The walking system includes a main platform having ramps and tracks for the motor vehicle to drive up onto and a base beam extending perpendicularly on both sides of the main platform to act as outriggers for stability. The system further includes a workstring platform for storing tubulars that make up the workstring, which is elevated above a wellhead. The main platform and base beam have walking assemblies for lifting the rig and moving it laterally so that it can be positioned over the wellhead for workover or completion operations.

Abstract: A repairable seal assembly for deployment at a wellbore includes an elongate body, a first seal carried by the elongate body and configured to seal against an adjacent surface, and a transitional component carried by the elongate body. The transitional component is adjustable from a first configuration in which the transitional component defines a gap between the transitional component and the adjacent surface to a second configuration in which the transitional component contacts the adjacent surface to form a second seal at the adjacent surface.

Abstract: A formation tester tool assembly includes a seal member mounted on rigid stabilizer that contacts a borehole wall separately from the seal member, so that seal exposure to a stabilization load that presses the tool against the borehole wall is limited or reduced by contact engagement of the stabilizer with the borehole wall. The stabilizer is provided by a hydraulically actuated probe piston reciprocally movable relative to a tool body on which it is mounted. The seal member is in some embodiments movable relative to the probe piston, for example being configured for hydraulic actuation to sealingly engage the borehole wall while the tool body is stabilized by action of the probe piston.

Abstract: An apparatus and method for placing a member in a wellbore. The apparatus includes member conveyable downhole, a component of the member configured to perform an action in the wellbore, a potential energy source, a locking device and a heat source. The potential energy source is capable of activating the component. The locking device constrains the potential energy source from activating the component when the locking device is in a first state. The heat source changes the locking device from the first state to a second state in which the locking device allows the potential energy source to activate the component.

Abstract: A downhole cutting tool includes a tool body with a cutting element or cutting element pocket thereon. At least a portion of the tool body or an attachment thereto is a metal matrix composite formed from metal carbide particles dispersed in a continuous metal matrix. The metal carbide particles make up less than 45 wt % of the metal matrix composite and/or less than 30 vol % of the metal matrix composite. The continuous metal matrix may also be formed from a metal or metal alloy other than Ni—Si—B and/or have a transverse rupture strength greater than 150 ksi and a fracture toughness over 22 ksi*in0.5.