A wellbore tool includes a body having a longitudinal axis and an outer circumferential surface. The wellbore tool includes moveable arms, housings, actuators, a temperature sensor, a pressure sensor, and a heat source, such as a microwave source. Each moveable arm is coupled to a respective actuator and a respective housing. Each actuator is configured to move the respective moveable arm. The temperature sensor is configured to measure a temperature of the subterranean formation. The pressure sensor is configured to measure a pressure of the subterranean formation. The microwave source is configured to generate microwave radiation. Methods of analyzing acquired transient temperature and transient pressure data for formation evaluation are also described.

A drilling system includes a drill string for connecting with a drill bit for drilling a borehole, a fixed stabilizer fixed on the drill string, and an active stabilizer including a body and actuators connecting the body and the drill string. The actuators are capable of driving the drill string away from a center of the borehole with a displacement. The body has an outer surface for contacting a wall of the borehole, an inner surface facing the drill string, and at least one guiding portion projecting from the inner surface and each defining at least one groove. The drill string includes at least one sliding portion slidable within the at least one groove respectively to constrain movement between the drill string and the active stabilizer along an axial direction of the drill string and guide movement between the drill string and the active stabilizer perpendicular to the axial direction.

A production logging tool (1) to analyze at least one property of a multiphase fluid mixture (MF) flowing in a hydrocarbon well (2) has an elongated cylindrical housing (10, 12, 13, 14) shape and comprises a central pressure-resistant rigid housing (10, 12, 13, 14) carrying a centralizer arrangement (11) comprising multiple external centralizer arms (15, 16) circumferentially distributed about said housing (10, 12, 13, 14) and adapted for contact with a production pipe wall (6) of a hydrocarbon well (2) and operable from a retracted configuration into a radially extended configuration, the centralizer arms (15, 16) being coupled at a first side to the housing (10, 12, 13, 14) and at a second side to a first sliding sleeve (21) and a first spring (24). The production logging tool (1) further comprises a deploying arrangement (30) nested within the centralizer arrangement (11), the deploying arrangement (30) comprising: a plurality of deploying arms (31, 32) circumferentially distributed about said housing (10, 12, 13, 14) and being coupled at a first side to the housing (10, 12, 13, 14) and at a second side to the centralizer arrangement (11) by means of at least one second sliding sleeve (36) such that each deploying arm (31, 32) is circumferentially positioned between two centralizer arms (15, 16) whatever the retracted or radially extended configuration of the centralizer arrangement (11), at least one downhole fluid properties analysis probe (55, 55A-55H) being secured on each deploying arm (31, 32) such as to expose a tip (51) of said, at least one, probe to the multiphase fluid mixture (MF) flowing in the hydrocarbon well (2).

The second sliding sleeve (36) comprises a mechanical coupler (39) coupled to the first sliding sleeve (21) such that the deploying arrangement (30) follows radial movements imposed by the centralizer arrangement (11) to radially and/or angularly position the tip (51) of said, at least one, probe (55, 55A-55H) associated with each deploying arm (31, 32) in a first circumferential zone (CZ1) of a hydrocarbon well section substantially perpendicular to a longitudinal axis (XX′) of said well (2).

A downhole sensor deployment assembly includes a body attachable to a completion string and one or more arms pivotably coupled to the body. A sensor pad is coupled to each arm and movable from a retracted position, where the sensor pad is stowed adjacent the completion string, and an actuated position, where the sensor pad is extended radially away from the completion string. One or more actuators are pivotably coupled to the body at a first end and pivotably coupled to a corresponding one of the one or more arms at a second end, the one or more actuators being operable to move the sensor pad to the actuated position. One or more sensor devices are coupled to the sensor pad for determining a resistivity of a formation, the one or more sensor devices comprising at least one of a sensing electrode, a transceiver, and a transmitter.

A well tool for sensing seismic activity at a downhole location has an anchoring mechanism for mechanically coupling the tool to a formation by contact engagement with a wall of a subterranean cavity in which the well tool is located. The anchoring mechanism is deployable by a pressure-triggered hydraulic actuator incorporated in the tool. The actuator is configured for pressure-triggered activation and for hydraulic actuation by agency of borehole fluids (e.g., drilling mud). The actuator can provide a persistent contacting force urging the anchoring mechanism into contact with the cavity wall, to promote firm coupling with the formation for seismic sensoring purposes.

Systems and methods include an extreme range anchor, having extending assemblies configured to engage a wellbore, for providing a self-centering, reusable anchor location within a wellbore. The extending assemblies include a first set of arms connected to a first brace, a second set of arms connected to a second brace, and a set of footplates. Each footplate in the set of footplates is connected to the first set of arms and the second set of arms. Each footplate includes a fixator coupled to a radially external face and configured to securely engage the wellbore. The system also includes a pull rod rigidly coupled to the first brace and slidably connected to the second brace. Forcing the pull rod in an axial direction shortens a distance between the first brace and the second brace and forces the set of footplates to move in a radial direction toward the wellbore.

A modular anti-rotation device for preventing rotation with respect to the central axis of a drilling tool in a borehole and for producing a notch in a borehole surface. The anti-rotation device includes an upper fixture portion and a lower fixture portion in axial alignment. The upper fixture portion and the lower fixture portion are connected by yoke assemblies. Each yoke assembly is connected to the fixture portion and fixture portion at one end, and forming an articulated joint of the upper yoke assembly and the lower yoke assembly at a distal end opposite the first end. A roller is connected at each joint, connecting the upper and lower yoke assemblies. The rollers engage vertically with a borehole surface, the rollers travelling axially, as a drill shaft penetrates into the borehole, the rollers simultaneously preventing radial movement of the anti-rotation device and prevent rotation with respect to the central axis of the borehole.

The invention discloses systems for improving performance and operational efficiency of wireline tractors. A cooling system improves power capabilities of electrical motors mounted in wheels, which are mounted on a linkage pivotably connected to an arm extended from a tractor tool body, in an in-line arm configuration. The linkage and arm mechanism significantly improve the tractor's ability to traverse wellbore obstructions. The hydraulic system of the tractor ensures adequate wellbore centralization.

A body defines a feedthrough passage. Bow springs surround and connect to an outer periphery of the body. The bow springs extend radially outward from the body. An internal coil spring is arranged to actuate axially within the body. A mandrel abuts an end of the coiled spring. The mandrel is arranged to move within the body, the mandrel having sufficient inertia to dampen vibrations.

A centralizing perforating gun for perforating a tubular in a wellbore include a gun housing, perforating charges positioned within the gun housing and detonatable to perforate the tubular, and a centralizing system. The centralizing system includes an extendable member configured to move between a retracted position and an extended position. The extendable member is configured to engage a surface of the tubular in the extended position, thereby biasing the centralizing perforating gun away from the surface of the tubular.