The invention concerns a method for cleaning control particles in a wellbore of a subterranean formation to improve the recovery of formation fluids and/or gases, said wellbore comprising a wall defining a borehole, at least one control equipment arranged into said borehole and a plurality of control particles arranged between said control equipment and said wall, said method comprising the steps of generating at least one shock wave nearby said control equipment and propagating said at least one shock wave through said control equipment toward said control particles for cleaning said control particles.

The invention concerns a method for cleaning control particles in a wellbore of a subterranean formation to improve the recovery of formation fluids and/or gases, said wellbore comprising a wall defining a borehole, at least one control equipment arranged into said borehole and a plurality of control particles arranged between said control equipment and said wall, said method comprising the steps of generating at least one shock wave nearby said control equipment and propagating said at least one shock wave through said control equipment toward said control particles for cleaning said control particles.

A system provides for the remote activation and deactivation of a downhole tool such as an agitator tool. The downhole tool uses a dart-catching section configured with a profile that engages with a corresponding key section of a dart. Different tools in the string may have different profiles, allowing darts to pass through tools to reach a tool with a matching profile further downhole. The dart includes a removable nozzle that can be detached by a object dropped from the surface, after which a second dart may be dropped to engage with the first dart to change operating parameters of the tool.

A method to induce pressure transients in fluids for use in hydrocarbon recovery operations by inducing the pressure transients in a fluid by a collision process. The collision process employs a moving object (103,203,303,403) that collides outside the fluid with a body (102,202,302,402) that is in contact with the fluid inside a partly enclosed space (101,201,301,401). Furthermore, the pressure transients must be allowed to propagate in the fluid. The fluid may be one or more of the following group: primarily water, consolidation fluid, treatment fluid, cleaning fluid, drilling fluid, fracturing fluid and cement.

A method to induce pressure transients in fluids for use in hydrocarbon recovery operations by inducing the pressure transients in a fluid by a collision process. The collision process employs a moving object (103,203,303,403) that collides outside the fluid with a body (102,202,302,402) that is in contact with the fluid inside a partly enclosed space (101,201,301,401). Furthermore, the pressure transients must be allowed to propagate in the fluid. The fluid may be one or more of the following group: primarily water, consolidation fluid, treatment fluid, cleaning fluid, drilling fluid, fracturing fluid and cement.

A vibratory tool for use in a tubular string to prevent sticking or to release a stuck string features a fluid operated dart valve working in conjunction with an impact sleeve to deliver continuous axial jarring blows in opposed directions as long as flow is maintained. Movement of one of those components axially in opposed directions opens and closes access to opposed lateral ports so that a lateral vibration is also established as flow cyclically occurs and stops sequentially at opposed lateral outlets.

A vibratory tool for use in a tubular string to prevent sticking or to release a stuck string features a fluid operated dart valve working in conjunction with an impact sleeve to deliver continuous axial jarring blows in opposed directions as long as flow is maintained. Movement of one of those components axially in opposed directions opens and closes access to opposed lateral ports so that a lateral vibration is also established as flow cyclically occurs and stops sequentially at opposed lateral outlets.

Embodiments of the modular fracking ball assembly can include, but are not limited to, a measurement assembly, a shock absorbing layer, and an outer shell. The shock absorbing layer can encase the measurement assembly and the outer shell can encase the shock absorbing layer and the measurement assembly. The outer shell of the modular fracking ball assembly can be replaced with another outer shell when a change in parameters of the modular fracking ball assembly is needed. For instance, an overall diameter or a specific gravity of the modular fracking ball assembly can be changed by swapping outer shells.

Embodiments of the modular fracking ball assembly can include, but are not limited to, a measurement assembly, a shock absorbing layer, and an outer shell. The shock absorbing layer can encase the measurement assembly and the outer shell can encase the shock absorbing layer and the measurement assembly. The outer shell of the modular fracking ball assembly can be replaced with another outer shell when a change in parameters of the modular fracking ball assembly is needed. For instance, an overall diameter or a specific gravity of the modular fracking ball assembly can be changed by swapping outer shells.

A method for determining along relatively uniformly spaced apart parallel first and second wellbores situated in an underground hydrocarbon-containing formation, regions within the formation, including in particular regions between such wellbores, to inject a fluid at a pressure above formation dilation pressure, to stimulate production of oil into the second of the two wellbores, and subsequently injecting fluid at pressures above formation dilation pressures at the discrete regions along such wellbores determined to be in need. An initial information-gathering procedure is conducted, wherein fluid is supplied under a pressure less than formation dilation or fracture pressure, to discrete intervals along a first wellbore, and sensors in the second wellbore measure and data is recorded regarding the ease of penetration of such fluid into the various regions of the formation intermediate the two wellbores. Regions of the formation exhibiting poor ease of fluid penetration are thereafter selected for subsequent dilation, at pressures above formation dilation pressures. Where initial fluid pressures and/or formation dilation pressures are provided in cyclic pulses, a downhole tool is disclosed for such purpose.