Abstract: An apparatus for determining properties of fluid flowing into a well includes an inflow channel providing a path for fluid to a pipe, a heater arranged to heat at least part of the fluid in the inflow channel, and a temperature sensor arranged to measure the temperature of the fluid in the inflow channel.

Abstract: A bit for drilling a wellbore includes: a shank having a coupling formed at an upper end thereof; a body removably attached to a lower end of the shank and having a blade receptacle formed therethrough; a blade fixed to the body; a plurality of superhard cutters mounted along a leading edge of the fixed blade; a blade disposed in the blade receptacle and longitudinally movable relative to the body between an extended position and a retracted position; a plurality of superhard cutters mounted along a leading edge of the movable blade; and a spring disposed between the shank and the movable blade and biasing the movable blade toward the extended position.

Abstract: Apparatus and methods are disclosed for securing a component, such as a sealing element, to a tubular member, such as a mandrel, of a downhole tool. In at least one example, a retaining ring is used to secure the component to a mandrel. The retaining ring is secured to the mandrel with a plurality of discrete retention segments disposed within a channel at least partially defined by an internal groove on the retaining ring and an external groove on the mandrel. The retention segments are individually insertable into the channel through an access opening on the retaining ring. A compression spring may be provided in the channel to provide compressive engagement of the retention segments. Various closure configurations are also disclosed for closing the access opening once the retention segments have been inserted.

Abstract: An apparatus and method for electromagnetic heating of a hydrocarbon formation. The method involves providing a producer well, which defines a longitudinal axis, between at least a first and second transmission line conductor. At a reference location along the length of the longitudinal axis, the first and second transmission line conductors are laterally spaced from the producer well by a first and second reference distance, respectively. At a second location, the first and second transmission line conductors are laterally spaced from the producer well by a third and fourth distance, respectively. At least one of the third and fourth distances are greater than the first and second reference distances, respectively. Excitation of the transmission line conductors generates an electromagnetic field having a reference shape and a reference position at the reference location and at least one of a more elongated shape and a different position at the second location.

Abstract: A top drive for well operations having a gearbox, a traction motor connected to the gearbox so that a motor shaft of the traction motor extends into the gearbox, a quill extending into the gearbox, a gear train positioned within the gearbox and mechanically connected between the traction motor shaft and the quill, and a connector positioned in the gear train, wherein in a coupled configuration the connector communicates torque through the gear train, and wherein in a decoupled configuration the connector does not communicate torque through the gear train. A method for operating a top drive by applying a first torque to a quill with two traction motors, disconnecting one of the traction motors from the quill, and applying a second torque less than the first torque to the quill with the non-disconnected traction motor.

Abstract: A vibration-damping sub is provided to mitigate shock and other sources of vibration in a tool string. In examples, a tubular damping body is rigidly coupled between a vibration-sensitive tool and a vibration source. The tubular damping body includes a tubular wall defining a plurality of shaped holes configured to dampen the mechanical vibration to below the design threshold for the vibration-sensitive tool. The tubular damping body may also include different portions having different materials and impedances to further disrupt the propagation of mechanical waveforms.

Abstract: Methods, systems, and apparatuses for determining the location or depth in a wellbore of a tubular string or downhole component is provided. One method may include placing a tubular string having a depth measurement module into a wellbore, the wellbore emanating radiation at at least one location along the wellbore and determining the location of the depth measurement module in the wellbore based on a correlation between a wellbore property that is a function of depth and a radiation intensity at at least one location within the wellbore.

Abstract: A shearable sleeve supports a disintegrable plug element in a pipe string, and may include a first portion including a first circumferential end surface, a seat for supporting the disintegrable plug element, a second portion including a second circumferential end surface, and a surface extending axially between the first and second circumferential end surfaces and formed with one or more radial protrusions adapted to shear off from the rest of the sleeve when being exposed to a predefined axial force, and one or more recesses for receiving one or more loading devices for initiating disintegration of the disintegrable plug element upon contact with the plug, wherein one or more radial protrusions is/are axially offset relative to the first circumferential end surface. A plug device, as well as a plug assembly in a pipe string, may include the shearable sleeve.

Abstract: Apparatus, system and method for guiding a gripping tool into a structure to be gripped. In one aspect, the apparatus comprises a nubbin and a guide structure fixed to the nubbin. In a second aspect, the system comprises the apparatus and a target structure to be gripped by the gripping tool. In a third aspect, the method comprises coupling the nubbin to a target structure to be gripped by a gripping tool and moving a leading portion of the gripping tool through the apparatus and into the target structure. In a fourth aspect the apparatus comprises a guide structure configured to be fixed to a nubbin. In a fifth aspect the apparatus comprises coupling the nubbin to a target structure, coupling the guide structure to the nubbin and moving a leading portion of the gripping tool through the apparatus and into the target structure.

Abstract: A multi-expansion packer is deployed in a borehole. The multi-expansion packer includes an outer part and an inner part disposed within the outer part. An outer part pump expands the outer part with a first fluid to engage the outer part with an inner surface of the borehole. A leakage sensor is configured to detect a leakage of the first fluid from the outer part which causes at least a portion of the outer part to disengage from the inner surface. An inner part pump expands the inner part with a second fluid. A controller responds to the detected leakage to control the inner part pump to pump the second fluid into the inner part until at least the disengaging portion of the outer part re-engages the inner surface of the borehole. A method comprises steps performed during operation of the system.

Abstract: An ultra-high expansion downhole packer includes an anchor, a primary expansion cone, and a central tube. The anchor is provided with a first tapered through-hole having a large end sleeved at a small end of the primary expansion cone. The anchor is radially expandable to anchor with an inner wall of a wellbore. The primary expansion cone is provided with a second tapered through-hole, and the second tapered through-hole has a large end sleeved at a small end of the central tube. The primary expansion cone is a radially expandable structure, and the primary expansion cone supports the anchor after an expansion. The primary expansion cone is provided between the anchor and the central tube. The primary expansion cone is first driven into the anchor to make the anchor radially expand, and then the central tube is driven into the primary expansion cone to make the anchor radially expand again.

Abstract: An open tip downhole expansion tool incudes a frustoconical member having a base and a tip, the member having a radially outer zone and a radially inner zone and having an axial length extending from the base to the tip; an outer compliance area in a material of the member along a length of the radially outer zone; and an inner compliance area in a material of the member along a length of the radially inner zone, the outer and inner compliance areas being located at different positions along the axial length of the frustoconical member, the outer and inner compliance areas each causing the frustoconical member to present a first resistance to deformation when the compliance areas are in a first condition and a higher resistance to deformation of the frustoconical member when the compliance areas are in a second condition.

Abstract: A flexible coupling for coupling sections of a downhole tubing string is provided. The flexible coupling has a central section with first and second ends, each end having a contact surface and a first part of a pivoting connector, the contact surface extending radially outward relative to the first part of the pivoting connector. The flexible coupling also has first and second coupling sections pivotally coupled to the first and second ends of the central section. Each of the first and second coupling sections have a tubing string attachment at a first end, a second part of the pivoting connector at a second end, and a contact surface at the second end, the contact surface extending radially outward relative to the second part of the pivoting connector. Pivotal movement of the first and second coupling sections relative to the central section is limited by engagement between the contact surfaces.

Abstract: Methods for producing hydrocarbons from subterranean reservoirs utilize a production well having a plurality of individually-actuatable fluid-inlet components that are spaced apart to define a plurality of production-well fluid-inlet zones. An injection fluid including a non-condensable gas (NCG) is injected into the reservoir, such that a drainage fluid including at least a portion of the NCG occupies the production-well fluid-inlet zones. The gas phase:liquid phase ratio of a production fluid is modulated by identifying at least one of the production-well fluid-inlet zones as having a gas content above a threshold and thus being a higher-gas zone, and actuating variations in pump speed and the flow states of the plurality of fluid-inlet components adjacent and corresponding to the higher-gas zone to prioritize hydraulic communication with a subset of the plurality of production-well fluid-inlet zones spaced apart from the higher-gas zone.

Abstract: The disclosure includes a power section for a bottom hole assembly for use in a wellbore. The power section may include a stator, the stator including a housing, a stator insert, a payload housing and a bent sub having a bend direction. The payload housing may be positioned on an outer surface of the housing, and the payload housing may include a payload pocket. The power section may include a rotor, the rotor rotatable eccentrically within the stator. The payload housing may positioned on the stator housing so as to be always aligned with the bend direction.

Abstract: An integrated well logging system includes an elongated stem portion configured to lower the well logging system into a hydrocarbon well, a multi-finger calipers for measuring the internal diameter of the annulus of the hydrocarbon well, the multi-finger calipers comprising a plurality of measuring arms, a first crossover configured to connect the stem portion to the multi-finger calipers, a static bottom hole pressure survey configured to measure the pressure at a location within the hydrocarbon well, the static bottom hole pressure survey comprising a plurality of memory gauges, and a second crossover configured to connect the multi-finger calipers to the static bottom hole pressure survey.

Abstract: A method and an assembly for heating and evaluating a formation of the Earth while drilling a wellbore filled with drilling mud are described. A first drilling mud temperature at a depth in the wellbore is received from a first sensor by a controller. The formation proximal to the depth is heated by a heat source mounted to the assembly to a temperature greater than a formation temperature as the drilling assembly drills the wellbore. A second drilling mud temperature is received from a second sensor by the controller. The heat source is positioned in between the first sensor and the second sensor. A difference between the first drilling mud temperature and the second drilling mud temperature is compared to a threshold drilling mud temperature difference value by the controller. Based on a result of the comparison, the drilling assembly is controlled and directed in the formation.

Abstract: A downhole tool suitable for use in a wellbore, the tool having a cone mandrel having a dual-cone outer surface. The downhole tool includes a carrier ring disposed around one end of the cone mandrel, and a seal element disposed around the carrier ring. There is a slip disposed around or proximate to an other end of the cone mandrel.

Abstract: A liner hanger is used for deploying a liner into a wellbore. The liner hanger includes a tubular body having a first end and a second end. The first end can include a connection to a liner. The second end can include a sealed connection to an operational pipe. The sealed connection can be releasable. An expansion tool attached to a work string can be used for suspending the liner hanger into the wellbore. At least a portion of the expandable pipe is radially expanded using the expansion tool. The radial expansion of the expandable pipe can cause compression of at least one seal member against a base casing.

Abstract: A packer assembly includes a mandrel and a packing element disposed about the mandrel. Upper and lower recovery sleeves are disposed about the mandrel and extend between the mandrel and respective upper and lower ends of the packing element. The upper and lower recovery sleeves each have a recovery profile embedded within the packing element. Upper and lower backup assemblies are movably disposed about the respective upper and lower recovery sleeves, adjacent to the respective upper and lower ends of the packing element. The packer assembly includes at least one release mechanism. When setting the packer assembly in a bore, the packing element is axially compressed between the upper and lower backup assemblies to contact the bore wall, and the upper and lower backup assemblies splay outwards. Upon release, the packing element and backup assemblies retract, thereby facilitating retrieval of the packer assembly from the bore.