A hydraulic breaking hammer and method of supporting a percussion piston is provided. The breaking hammer includes a percussion device provided with a reciprocating piston. The piston is supported on a frame at its end portions by a first piston bearing element and a second piston bearing element. The second piston bearing element includes a collar sealing element facing towards a working collar of the piston. The piston bearing elements are easily mountable and dismountable separate components.

A hydraulic breaking hammer and method of supporting a percussion piston is provided. The breaking hammer includes a percussion device provided with a reciprocating piston. The piston is supported on a frame at its end portions by a first piston bearing element and a second piston bearing element. The second piston bearing element includes a collar sealing element facing towards a working collar of the piston. The piston bearing elements are easily mountable and dismountable separate components.

Disclosed is a fluid driven pulsating, hammering tool operational when pressurized fluid is pumped into the tool's upper sub, having a poppet valve which can seal the upper end of a slidable outer valve assembly when closed; an inner valve assembly slidable within the outer valve assembly; wherein the inner and outer valve assemblies remain in selective fluid communication with the poppet valve even when the poppet valve is closed, wherein interruption of said fluid communication occurs from movement of the inner and/or outer valve assemblies to particular positions along their sliding paths; and further including a lower valve which is preferably a Tesla valve having channels which are also in fluid communication with the poppet valve.

A device for generating pressure waves in a well or a wellbore. The device includes a housing containing an impact-generating mechanism for generating the pressure waves and a connector for connecting the housing to a conveyor for transporting the device to any desired location within the well or the wellbore. The device may be used for a number of downhole applications such as cleaning perforations, fracturing processes, vibration of a casing to prevent fluid flow in a cemented annulus, hydraulic jar operations for freeing stuck downhole objects, generating data to optimize pumping parameters and as an enhancement to percussion drilling techniques.

A down-the-hole drilling assembly activated by fluid under pressure includes a casing having an axially rearward and forward end, a piston arranged movably inside the casing, a plurality of fluid passages for feeding and discharging pressurized fluid into and out of a working chamber for generating reciprocating movement of the piston, a drill bit at the forward end and provided with an anvil facing towards the piston for receiving impacts therefrom and an annular drive sub surrounding at least a portion of a shank and cooperating with the bit to form fluid passages extending length-wise along the shank. The drive sub has a concave arcuate groove extending circumferentially to form a chamber for collecting fluid from the hammer exhaust and redistributing a volume of the collected fluid from channels formed between complimentary splines of the drive sub and splines of the bit to flushing holes arranged in the bit.

A down-the-hole drilling assembly activated by fluid under pressure includes a casing having an axially rearward and forward end, a piston arranged movably inside the casing, a plurality of fluid passages for feeding and discharging pressurized fluid into and out of a working chamber for generating reciprocating movement of the piston, a drill bit at the forward end and provided with an anvil facing towards the piston for receiving impacts therefrom and an annular drive sub surrounding at least a portion of a shank and cooperating with the bit to form fluid passages extending length-wise along the shank. The drive sub has a concave arcuate groove extending circumferentially to form a chamber for collecting fluid from the hammer exhaust and redistributing a volume of the collected fluid from channels formed between complimentary splines of the drive sub and splines of the bit to flushing holes arranged in the bit.

A down the hole drilling assembly having a drill tube adapter, an elongate casing, a fluid powered piston, a top working chamber, a bottom working chamber, a top sub and an exhaust system, wherein the exhaust system is moveable with respect to the drill string. The top sub includes an exhaust valve arranged for opening and closing the connection between the at least one exhaust passage and the at least one exhaust port.

A down the hole drilling assembly having a drill tube adapter, an elongate casing, a fluid powered piston, a top working chamber, a bottom working chamber, a top sub and an exhaust system, wherein the exhaust system is moveable with respect to the drill string. The top sub includes an exhaust valve arranged for opening and closing the connection between the at least one exhaust passage and the at least one exhaust port.

Disclosed is a drillable adaptive turbine guide shoe, including an adaptive booster component and a power casing shoe component; the adaptive booster component includes a supercharging hollow shaft, a supercharging shell, a disc spring group, a shunt head, a jet oscillator and a semi-cylindrical ring, the supercharging hollow shaft is slidably connected to the supercharging shell, one end of the supercharging hollow shaft is a liquid inlet end and the other end is closed, a cavity is formed between the supercharging hollow shaft and the supercharging shell, and the disc spring group is built in the cavity, the jet oscillator and the semi-cylindrical ring are mounted on the inner wall of the supercharging shell, and one side of the jet oscillator and the semi-cylindrical ring abuts against the shunt head, the shunt head is sleeved on the outer wall of the supercharging hollow shaft; this disclosure solves the problem that the casing cannot be effectively run when the wellbore has sand bridges or wellbore necking.

A drill string rotation controller includes an anti-torque balance module, a TC bearing retaining ring, an upper TC bearing, an upper thrust ball bearing, an upper Haval ring, a middle seal retaining ring, an upper mandrel, an upper shell, a rotary control cylinder, an upper spring, a spline shell, a spline sleeve, a spline mandrel, a lower shell, a spring push sleeve, a lower spring, a floating piston, a lower mandrel, a bulkhead, a lower thrust ball bearing, a lower Haval ring, a lower TC bearing, a conversion joint, an anti-drop joint, a lower joint, and a control pin. The rotary control cylinder causes the spline sleeve to switch the transmission relationship between the spline mandrel and shell. Therefore, the drill string rotation controller controls the conversion between the composite drilling mode and the directional drilling mode.