Systems and methods for drilling a subterranean well with a drill bit include a drill bit body with a central bore. A plurality of ports extend through the nose end of the drill bit body from the central bore to an outside of the drill bit body. A blocked nozzle is located within one of the plurality of ports. The blocked nozzle has a nozzle bore end and a nozzle nose end opposite the nozzle bore end. A bore end disk is located at the nozzle bore end of the blocked nozzle, preventing a flow of fluids through the blocked nozzle past the bore end disk. A nose end disk is located at the nozzle nose end of the blocked nozzle, preventing the flow of fluids through the blocked nozzle past the nose end disk. The nose end disk and the bore end disk are removable.

Systems and methods for drilling a subterranean well with a drill bit include a drill bit body with a central bore. A plurality of ports extend through the nose end of the drill bit body from the central bore to an outside of the drill bit body. A blocked nozzle is located within one of the plurality of ports. The blocked nozzle has a nozzle bore end and a nozzle nose end opposite the nozzle bore end. A bore end disk is located at the nozzle bore end of the blocked nozzle, preventing a flow of fluids through the blocked nozzle past the bore end disk. A nose end disk is located at the nozzle nose end of the blocked nozzle, preventing the flow of fluids through the blocked nozzle past the nose end disk. The nose end disk and the bore end disk are removable.

Rotatable elements for use with earth-boring tools include a movable element and a stationary element. The rotatable element may include a void within the support structure and at least one pin protruding from the void through an exterior side of the support structure. The rotatable element may further include at least one aperture configured to provide a vent to the void. The rotatable element may be disposed at least partially within a cavity of the stationary element. The stationary element may further include a track configured to interact with the at least one pin.

Rotatable elements for use with earth-boring tools include a movable element and a stationary element. The rotatable element may include a void within the support structure and at least one pin protruding from the void through an exterior side of the support structure. The rotatable element may further include at least one aperture configured to provide a vent to the void. The rotatable element may be disposed at least partially within a cavity of the stationary element. The stationary element may further include a track configured to interact with the at least one pin.

An earth boring bit with sealed cutter bearings has a dual function pressure compensator for a lubricant reservoir. The earth boring bit has a bit body and downwardly extending legs which include bearing shafts that extend inward and downward for mounting rotary cutters, and seals are provided between the bearing shafts and the cutters. Lubricant flow passages extend from an interior cavity of the bit body, through the legs and the bearing shafts, and into the spaces located between the bearing shafts and the cutters. The pressure compensator extends between the cavity and the flow passages and has a movable piston. The compensator may be operated in a sealed lubricant system mode when the piston is locked in place or an air flow bypass mode by removing a locking member from securing the piston in place prior to securing the earth boring bit to a drill string.

An earth boring bit with sealed cutter bearings has a dual function pressure compensator for a lubricant reservoir. The earth boring bit has a bit body and downwardly extending legs which include bearing shafts that extend inward and downward for mounting rotary cutters, and seals are provided between the bearing shafts and the cutters. Lubricant flow passages extend from an interior cavity of the bit body, through the legs and the bearing shafts, and into the spaces located between the bearing shafts and the cutters. The pressure compensator extends between the cavity and the flow passages and has a movable piston. The compensator may be operated in a sealed lubricant system mode when the piston is locked in place or an air flow bypass mode by removing a locking member from securing the piston in place prior to securing the earth boring bit to a drill string.

A wellbore drill bit includes a body that defines an inner volume and includes a top sub-assembly, and a plurality of cutting cones along a longitudinal axis of the body. The wellbore drill bit includes a chamber positioned in the inner volume of the body to form an annulus between the chamber and the body; a first set of nozzles positioned in the plurality of cutting cones, each nozzle of the first set of nozzles including a fluid entry that is fluidly coupled to a primary drilling fluid flow path, and a fluid exit oriented toward the second longitudinal end of the body; and a second set of nozzles positioned in the body. Each nozzle of the second set of nozzles includes a fluid entry that is fluidly coupled to the annulus, and a fluid exit oriented toward the first longitudinal end of the body.

A wellbore drill bit includes a body that defines an inner volume and includes a top sub-assembly, and a plurality of cutting cones along a longitudinal axis of the body. The wellbore drill bit includes a chamber positioned in the inner volume of the body to form an annulus between the chamber and the body; a first set of nozzles positioned in the plurality of cutting cones, each nozzle of the first set of nozzles including a fluid entry that is fluidly coupled to a primary drilling fluid flow path, and a fluid exit oriented toward the second longitudinal end of the body; and a second set of nozzles positioned in the body. Each nozzle of the second set of nozzles includes a fluid entry that is fluidly coupled to the annulus, and a fluid exit oriented toward the first longitudinal end of the body.

A drill bit includes a bit body with high and low fluid pressure bodies. The low-pressure bit body includes a fixed cutting structure, and the high-pressure bit body includes at least one high-pressure fluid channel and nozzle capable of withstanding fluid pressures greater than 40 kpsi (276 MPa). A bottomhole assembly includes a drill bit with a bit body having fixed cutter and fluid jetting portions. Low and high-pressure channels in the bit body exit in the fixed cutter and fluid jetting portions. A high-pressure nozzle is coupled to the fluid jetting portion and the high-pressure fluid channel, and a plurality of fixed cutting elements are coupled to the fixed cutter portion. A pressure intensifier is coupled to the drill bit and is configured to increase a pressure of a fluid supplied to the high-pressure fluid channel in the bit body.

A drill bit includes a bit body with high and low fluid pressure bodies. The low-pressure bit body includes a fixed cutting structure, and the high-pressure bit body includes at least one high-pressure fluid channel and nozzle capable of withstanding fluid pressures greater than 40 kpsi (276 MPa). A bottomhole assembly includes a drill bit with a bit body having fixed cutter and fluid jetting portions. Low and high-pressure channels in the bit body exit in the fixed cutter and fluid jetting portions. A high-pressure nozzle is coupled to the fluid jetting portion and the high-pressure fluid channel, and a plurality of fixed cutting elements are coupled to the fixed cutter portion. A pressure intensifier is coupled to the drill bit and is configured to increase a pressure of a fluid supplied to the high-pressure fluid channel in the bit body.