A downhole cleaning tool (40) adapted for location in bore-lining tubing (22). The tool (40) comprises a tubular body (42) defining an internal bore (48), at least one radially extending cleaning blade (92), and an external axially extending bypass flute (96, 98, 100, 102). The body further defines a fluid flow path from the internal bore (48) to at least one elongated jetting slot (94) extending along an outer surface of the blade (92).

A sucker rod cleaning system includes an inductive heating device, a feed mechanism, a first support and a second support. An electromagnet of inductive heating device includes a wire coil head that is configured to inductively heat a sucker rod positioned within a heating zone. The feed mechanism is configured to feed a sucker rod through the heating zone in a feed direction. The first support is positioned on an upstream side of the wire coil head, and is configured to support a portion of a sucker rod as it is fed through the heating zone by the teed mechanism, The second support is positioned on a downstream side of the wire coil head, and is configured to support a portion of a sucker rod as it is fed through the heating zone by the feed mechanism.

A sucker rod cleaning system includes an inductive heating device, a feed mechanism, a first support and a second support. An electromagnet of inductive heating device includes a wire coil head that is configured to inductively heat a sucker rod positioned within a heating zone. The feed mechanism is configured to feed a sucker rod through the heating zone in a feed direction. The first support is positioned on an upstream side of the wire coil head, and is configured to support a portion of a sucker rod as it is fed through the heating zone by the teed mechanism, The second support is positioned on a downstream side of the wire coil head, and is configured to support a portion of a sucker rod as it is fed through the heating zone by the feed mechanism.

The present invention provides environmentally-friendly compositions and methods for degrading polymers used in fracking operations to enhance the recovery of oil and gas. Specifically, the compositions and methods utilized microorganisms and/or their growth by-products to degrade polymers, such as PGA, PLA and PAM, used in fracking wells.

The present invention provides environmentally-friendly compositions and methods for degrading polymers used in fracking operations to enhance the recovery of oil and gas. Specifically, the compositions and methods utilized microorganisms and/or their growth by-products to degrade polymers, such as PGA, PLA and PAM, used in fracking wells.

A wellbore tool is conditioned between downhole deployments with a substantially continuous application of a conditioning fluid within the tool. Selectively removable caps connect to ends of the tool after its removal from the wellbore. If the tool is part of a downhole string, the caps are added after the tool is decoupled from the remainder of the string. The conditioning fluid is introduced into the tool through a fitting on one of the end caps; and while a fitting on the other end cap is opened to vent fluids resident within the tool. The caps are in sealing contact with a housing of the tool to retain the conditioning fluid inside the tool. A fluid supply system at the well site provides the conditioning fluid. Example conditioning fluids include a fracturing fluid, a completion fluid, a diluent, a solubilizing agent, an anti-scaling agent, a pH buffer, a liquid freezing point depressant, corrosion and oxidation inhibitors, oxygen scavengers, biocides, surfactants, and combinations thereof.

A wellbore tool is conditioned between downhole deployments with a substantially continuous application of a conditioning fluid within the tool. Selectively removable caps connect to ends of the tool after its removal from the wellbore. If the tool is part of a downhole string, the caps are added after the tool is decoupled from the remainder of the string. The conditioning fluid is introduced into the tool through a fitting on one of the end caps; and while a fitting on the other end cap is opened to vent fluids resident within the tool. The caps are in sealing contact with a housing of the tool to retain the conditioning fluid inside the tool. A fluid supply system at the well site provides the conditioning fluid. Example conditioning fluids include a fracturing fluid, a completion fluid, a diluent, a solubilizing agent, an anti-scaling agent, a pH buffer, a liquid freezing point depressant, corrosion and oxidation inhibitors, oxygen scavengers, biocides, surfactants, and combinations thereof.

An apparatus includes a gauge cutter, a lead impression block (LIB), a locking pin, and a locking device. The gauge cutter has a gauge cutter tubular body, a gauge cutter head, and an orifice. The LIB has an LIB body and an LIB head. The LIB is fixed in a first position within the orifice of the gauge cutter by being connected to an inner circumferential surface of the gauge cutter tubular body using a shear pin. The locking pin is disposed around the LIB body. The locking device is disposed around the inner circumferential surface of the gauge cutter tubular body and is configured to mate with the locking pin to hold the LIB in a second position within the gauge cutter. The second position includes a portion of the LIB body located within the orifice and the LIB head located outside of the orifice.

A downhole system includes a lower completion having at least one tubular including a first end and a second end terminating at a shoe. The at least one tubular defining a flow path. A packer is arranged at the first end. A fluid loss control valve (FLCV) is arranged between the packer and the shoe. A screen system is arranged between the FLCV and the shoe. The screen system includes a screen and a non-mechanically operated flow control valve that selectively isolates the flow path from formation fluids passing through the screen. A wellbore clean out string is insertable into the lower completion. The wellbore clean out string includes a selectively activated casing cleaner and a setting tool. The selectively activated casing cleaner is spaced from the setting tool.

A method and apparatus to move an object in an open hole section of a wellbore. A bottom hole assembly including a downhole pulling tool and fishing device is described. The downhole pulling tool includes an open hole anchor to allow location of the downhole pulling tool in the open hole section of the wellbore so as to reduce the operating distance between the downhole pulling tool and the fishing device. An embodiment in which a cut section of tubular is removed from the open hole section is described. A casing cutter may also be located in the bottom hole assembly to cut the tubular on the same trip in the well as removing the cut section of tubular.