A pump down intervention tool may be pumped downhole through a work string after an installation of the work string. The pump down intervention tool may include a downhole tool that includes but is not limited to an agitator tool, including but not limited to a fluidic pulsation device, or a check valve. The pump down intervention tool may be pumped downhole in the work string, for example but not limited to in a coiled tubing or jointed pipes. The pump down intervention tool may be landed at a desired location along a length of the work string. The pump down intervention tool can allow for the addition of a downhole tool after the work string's initial deployment, providing a desired functionality downhole at time after the initial deployment of the work string downhole.

Systems and methods for oscillating a string within a subterranean well include a motor assembly having an output shaft extending along a central axis. A translation coupling is in mechanical communication with the output shaft. An inertia sleeve is in mechanical communication with the translation coupling. The translation coupling is operable to translate a rotation of the output shaft to an oscillating movement of the inertia sleeve. A spring assembly is in mechanical communication with the inertia sleeve. The spring assembly is positioned along the central axis.

A method of recovering casing in a wellbore using a vibratory casing recover), bottom hole assembly. In a vibratory casing recover), bottom hole assembly having a casing spear, a flow modifier and one or more further elements including a shock sub. The flow modifier produces cyclic variations in fluid flow through the assembly at a first frequency and at least one of the elements is configured to have a natural or resonant frequency when vibrated to be near or at the first frequency. By tuning elements of the bottom hole assembly to be close or at the frequency of the output of the flow modifier, the dynamic amplification factor of the system is maximised and longer lengths of casing can be recovered. A method of recovering casing using the vibratory casing recover), bottom hole assembly is also described. Further embodiments include a casing cutter and a hydraulic jack.

A vibratory casing recovery bottom hole assembly and a method of recovering casing in a wellbore. The vibratory casing recovery bottom hole assembly includes a casing spear, a flow modifier and a dynamic amplification tool. The flow modifier produces cyclic variations in fluid pressure through the assembly at a first frequency and the bottom hole assembly is configured to have a natural or resonant frequency when vibrated to be near or at the first frequency. The dynamic amplification tool induces vibration in the bottom hole assembly while ensuring the dynamic amplification factor of the system is greater than one so as to transmit maximum vibration to the casing at the casing spear. Embodiments of dynamic amplification tools are described.

A lateral oscillation tool for using in a drill string performing a drilling operation includes a fluid driven, positive displacement motor and a rotating mandrel coupled to the positive displacement motor. At least one unbalanced mass is coupled to the rotating mandrel to generate lateral oscillation of the lateral oscillation tool. The unbalanced mass may include a plurality of tuning channels into which a high-density material may be selectively introduced to alter the positional mass of the unbalanced mass. When paired with the or variable electric drive motor turbine powered, lateral impact forces may be adjusted real-time and through the downhole adaptive learning software.

A method and system for downhole pulse generation determines an optimal frequency and, in some embodiments, amplitude of axial pressure pulses to maximize the rate of penetration. Specifically, one or more sensors may be disposed on or near an axial oscillation tool that provides near real-time raw sensor data relating to speed, velocity, and acceleration of the tool. With this sensor data, an optimal set of parameters, namely an optimal frequency and, in some embodiments, amplitude may be determined based on the hydraulic conditions and frictional forces of the actual drilling environment. An optimizing control system may directly communicate these parameters to the axial oscillation tool or pass the parameters to an axial oscillation tool control system that controls the operation of the tool. Advantageously, frictional forces may be substantially reduced, the rate of penetration may be substantially enhanced, and power consumption may be intelligently managed.

Provided is a downhole vibrating tool comprising an interconnected power section, axial shock assembly and lateral vibration assembly wherein the power section comprising a rotor and a stator, the rotor comprising a plurality of lobes and the stator comprising a second plurality of recesses adapted to receive the plurality of lobes, the number of recesses greater than the number of lobes; the axial shock assembly comprising a valve assembly, the axial shock assembly adapted to vary fluid flow therethrough; and the lateral vibration assembly comprising an eccentric mass; wherein the power section, the axial shock assembly and the lateral vibration assembly are aligned linearly.

A downhole tool includes a main body configured to be disposed by a conveyance member within a tubing string disposed in a wellbore drilled into a subterranean zone, and a plurality of hammers disposed about a central axis of the main body, each of the plurality of hammers configured to reciprocate radially with respect to the central axis. The tool also includes a plurality of electric motors, each of the plurality of electric motors configured to drive the reciprocation of a respective one of the plurality of hammers, such that each of the electric motors can cause a respective hammer to repetitively strike an interior surface of the tubing string and thereby impart vibration in the tubing string.

A downhole drag reducing apparatus 18 comprises a mandrel 20 and a bearing sleeve 24 mounted on the mandrel 20, such that the mandrel 20 and bearing sleeve 24 are rotatable relative to each other. The bearing sleeve 24 defines a bore wall engaging surface. The apparatus 18 comprises a reciprocating piston 23 mounted within a piston housing 25 to define a piston chamber 27. The apparatus 18 further comprises a rotary valve assembly 29 operated by relative rotation between the mandrel 20 and the bearing sleeve 24 to cyclically pressurise and depressurise the piston chamber 27 to provide reciprocating movement of the reciprocating piston 23 and the generation of vibration within the apparatus 18.

Systems and methods for oscillating a string within a subterranean well include a motor assembly having an output shaft extending along a central axis. A translation coupling is in mechanical communication with the output shaft. An inertia sleeve is in mechanical communication with the translation coupling. The translation coupling is operable to translate a rotation of the output shaft to an oscillating movement of the inertia sleeve. A spring assembly is in mechanical communication with the inertia sleeve. The spring assembly is positioned along the central axis.