This hydraulic drilling apparatus including a casing comprising a front part, a shank including a fluid injection conduit and intended to be coupled to at least one drill rod equipped with a tool, the shank, a striking piston slidably mounted inside the casing along a striking axis (A) and configured to strike the shank, an extraction piston disposed around the shank and comprising an extraction portion configured to cooperate with the shank, and a cartridge removably mounted on the front part and disposed around the shank, the cartridge including an injection part configured to fluidly connect the fluid injection conduit to a fluid delivery conduit. The cartridge delimits a receiving housing in which the extraction piston is slidably mounted.

This hydraulic drilling apparatus including a casing comprising a front part, a shank including a fluid injection conduit and intended to be coupled to at least one drill rod equipped with a tool, the shank, a striking piston slidably mounted inside the casing along a striking axis (A) and configured to strike the shank, an extraction piston disposed around the shank and comprising an extraction portion configured to cooperate with the shank, and a cartridge removably mounted on the front part and disposed around the shank, the cartridge including an injection part configured to fluidly connect the fluid injection conduit to a fluid delivery conduit. The cartridge delimits a receiving housing in which the extraction piston is slidably mounted.

A down-the-hole hammer drill bit retaining assembly is arranged to releasably retain a drill bit at a hammer arrangement of a percussion drilling apparatus. The retaining assembly includes a drive sub and a retainer ring. The drive sub has at least one indent to provide a fluid communication pathway for a flushing fluid extending over a radially outward facing surface of the retainer ring and into an internal region of the drive sub in contact with inwardly projecting splines.

A method for automated control of a drilling operation of a blast hole drilling machine using a down-the-hole drill bit mounted on a drill string is disclosed. The method may include: receiving input data from a user input including information of the drill bit, drill string weight, and desired hole settings; receiving a command from the user to initiate an automatic down-the-hole operation; identifying a location of the down-the-hole drill bit; and using the received input data and based on the location of the down-the-hole drill bit, automatically initiating the steps of: collaring a hole; drilling the hole; and retracting the drill when the hole is drilled.

A method for automated control of a drilling operation of a blast hole drilling machine using a down-the-hole drill bit mounted on a drill string is disclosed. The method may include: receiving input data from a user input including information of the drill bit, drill string weight, and desired hole settings; receiving a command from the user to initiate an automatic down-the-hole operation; identifying a location of the down-the-hole drill bit; and using the received input data and based on the location of the down-the-hole drill bit, automatically initiating the steps of: collaring a hole; drilling the hole; and retracting the drill when the hole is drilled.

An apparatus for boring a wellbore, including a bit body having a first end, an inner cavity, and a second end. The first end is connected to a workstring that is configured to deliver a rotational force to the bit body. The inner cavity contains a profile having a first radial cam surface. The second end includes a working face containing a cutting member. The apparatus also includes a pilot bit rotatively connected within the inner cavity. A second radial cam surface is contained on a first end of the pilot bit. The first and second radial cam surfaces are operatively configured to deliver a hammering force. A second end of the pilot bit may include an engaging surface configured to engage a formation surrounding the wellbore. The bit body rotates relative to the pilot bit.

An apparatus for boring a wellbore, including a bit body having a first end, an inner cavity, and a second end. The first end is connected to a workstring that is configured to deliver a rotational force to the bit body. The inner cavity contains a profile having a first radial cam surface. The second end includes a working face containing a cutting member. The apparatus also includes a pilot bit rotatively connected within the inner cavity. A second radial cam surface is contained on a first end of the pilot bit. The first and second radial cam surfaces are operatively configured to deliver a hammering force. A second end of the pilot bit may include an engaging surface configured to engage a formation surrounding the wellbore. The bit body rotates relative to the pilot bit.

The present invention discloses a drilling speed improvement device capable of producing both hydraulic pulse and impact vibration. The device has a pressure transfer rod that is arranged at an upper end of a lower joint. A spring chamber is formed among a drill body, the pressure transfer rod and the lower joint. A spring is arranged in the spring chamber. A communicating hole is formed in the drill body. A piston is arranged at an upper end of the pressure transfer rod. A pressure bearing head is arranged at an upper end of the piston. A pressure bearing base is arranged on the inner side of an upper joint. Drill bit impact loads and drilling fluid pulse jets are modulated by the longitudinal vibration energy of a drill stem, the rock breaking efficiency of a drill bit is improved by both dynamic and static loads, and harm caused by vibration of the drill stem is reduced.

The present invention discloses a drilling speed improvement device capable of producing both hydraulic pulse and impact vibration. The device has a pressure transfer rod that is arranged at an upper end of a lower joint. A spring chamber is formed among a drill body, the pressure transfer rod and the lower joint. A spring is arranged in the spring chamber. A communicating hole is formed in the drill body. A piston is arranged at an upper end of the pressure transfer rod. A pressure bearing head is arranged at an upper end of the piston. A pressure bearing base is arranged on the inner side of an upper joint. Drill bit impact loads and drilling fluid pulse jets are modulated by the longitudinal vibration energy of a drill stem, the rock breaking efficiency of a drill bit is improved by both dynamic and static loads, and harm caused by vibration of the drill stem is reduced.

A directional drilling apparatus using a water hammer unit according to the present invention includes a hammer body in which a bit unit configured to perform boring work is installed to be movable upward and downward at an end portion of the hammer body, a piston slidably installed on the hammer body and including an operating fluid discharge part formed in a longitudinal direction, a drive unit installed between the hammer body and the piston to support an upper portion of the piston and configured to move the piston upward and downward using water supplied through a rod connected to the hammer body, a hammer unit including a rotary shaft coupled to a bit by a first coupling part so as to transmit a rotational force in a state in which the hammer unit passes through the piston installed on the hammer body and is moved upward or downward by the bit, and a mud motor unit coupled to the hammer body and configured to rotate the rotary shaft.