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.

An apparatus including a rotating segment having a first radial surface, a non-rotating segment having a second radial surface, a housing disposed around the first and second radial surfaces, and one or more rolling elements disposed between and in contact with the first and second radial surfaces for transferring the non-rotating segment in an axial direction upon rotation of the rotating segment. The non-rotating element may be a second rotating element that rotates at a different rotational rate than the rotating element. Each rolling element moves 360 degrees along a circular path relative to the first radial surface and the second radial surface. The first or second radial surface has a tapered section. A downhole apparatus includes a power mandrel having a first end connected to a power section member and a second end having a rotating cam surface; a rotating element engaging the rotating cam surface; an anvil sub attached to a workstring, with the anvil sub having a stationary cam surface configured to engage with the rotating cam surface. Rotation of the rotating cam surface moves the anvil sub and the workstring axially within the wellbore.

An apparatus including a rotating segment having a first radial surface, a non-rotating segment having a second radial surface, a housing disposed around the first and second radial surfaces, and one or more rolling elements disposed between and in contact with the first and second radial surfaces for transferring the non-rotating segment in an axial direction upon rotation of the rotating segment. The non-rotating element may be a second rotating element that rotates at a different rotational rate than the rotating element. Each rolling element moves 360 degrees along a circular path relative to the first radial surface and the second radial surface. The first or second radial surface has a tapered section. A downhole apparatus includes a power mandrel having a first end connected to a power section member and a second end having a rotating cam surface; a rotating element engaging the rotating cam surface; an anvil sub attached to a workstring, with the anvil sub having a stationary cam surface configured to engage with the rotating cam surface. Rotation of the rotating cam surface moves the anvil sub and the workstring axially within the wellbore.

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 fluid pulse apparatus for down hole drilling having a turbine assembly actuated by a flow of drilling fluid. The apparatus has a narrowed fluid flow section that cooperates with a piston that moves between an open a fluid flow restricting position. The apparatus has a turbine assembly that rotates in response to a flow of drilling fluid. The turbine apparatus has upper and lower cam followers that cooperate with fixed cam surface such that rotation of the turbine assembly and cam action between the cam followers and the fixed cam surface causes the turbine assembly to reciprocate axially. The piston is fixed to either of the upper or the lower turbine surface such that as the turbine assembly reciprocates axially, the piston moves between the open and the flow restricting positions to create a pulsed fluid flow.

A fluid pulse apparatus for down hole drilling having a turbine assembly actuated by a flow of drilling fluid. The apparatus has a narrowed fluid flow section that cooperates with a piston that moves between an open a fluid flow restricting position. The apparatus has a turbine assembly that rotates in response to a flow of drilling fluid. The turbine apparatus has upper and lower cam followers that cooperate with fixed cam surface such that rotation of the turbine assembly and cam action between the cam followers and the fixed cam surface causes the turbine assembly to reciprocate axially. The piston is fixed to either of the upper or the lower turbine surface such that as the turbine assembly reciprocates axially, the piston moves between the open and the flow restricting positions to create a pulsed fluid flow.

A rock drilling machine, rock drilling rig and method of measuring physical features during rock drilling is provided. The rock drilling machine includes one or more sensing devices, which are arranged in connection with a bendable sensing cord. The sensing cord is fed via a feed passage to a flushing passage of a drilling tool.