Abstract: The disclosure describes a system and a method for locating a cement plug within a wellbore. The system includes a signal transmitter mounted to the cement plug, a receiver at the opening to the wellbore, one clock positioned on the cement plug and in communication with the transmitter, a second clock which is synchronized to the first clock and in communication with the receiver, and a controller for triggering the transmittal of the signal.

Abstract: Apparatus and corresponding method for remotely communicating with a device in a wellbore, comprising: an oilfield tubular handling apparatus (200); partial toroidal coil sections (304) integrated with the oilfield tubular handling apparatus, wherein the partial toroidal coil sections form a toroidal coil upon a tubular member (102) with the handling apparatus; and a microcontroller for communicating with the device via at least one of signals transmitted or received through the tubular member using the toroidal coil.

Abstract: Methods and systems are provided for remotely operating a setting tool for a liner hanger (402) independent of a ball seating or dart landing. Operating the setting tool independent of the ball seating or dart landing may allow for a sufficient pressure differential to properly set the liner hanger.

Abstract: Methods and systems are provided for remotely operating a cementing head. Remotely operating a cementing head (202) may allow for continued rotation as well as up or down movements (e.g., of a top drive).

Abstract: A drill bit made according to one embodiment includes a bit body and at least one preloaded sensor in the bit body. In one aspect, the sensor may include a sensor element on a sensor body having a first end and a second end and wherein the sensor is preloaded after placing the sensor body in the bit body. In another aspect, the sensor may be preloaded outside the bit body and then placed in the bit body in a manner that enables the sensor to retain the preloading.

Abstract: A drill bit for drilling subterranean formations includes a bit body bearing at least one gage pad and a shank extending from the bit body. An annular chamber is formed within the shank. A data evaluation module is disposed in the annular chamber and includes a processor, a memory, and a communication port. The data evaluation module estimates a gage pad wear by periodically sampling a tangential accelerometer and a radial accelerometer disposed in the drill bit. A history of the tangential acceleration and the radial acceleration is analyzed to determine a revolution rate, gage-slipping periods, and gage-cutting periods. A change in a gage-pad-wear state is estimated responsive to an analysis of the revolution rate, the at least one gage-cutting period and the at least one gage-slipping period. The determination of the gage-pad-wear state may also include analyzing a formation hardness.

Abstract: A drill bit for drilling a subterranean formation includes a plurality of cutting elements and a shank extending from a bit body. A set of accelerometers disposed in the drill bit include a radial accelerometer and a tangential accelerometer. An annular chamber is formed within the shank. A data evaluation module is disposed in the annular chamber and includes a processor, a memory, and a communication port. The data evaluation module is configured for performing a bit acceleration analysis. The analysis includes sampling acceleration information from the radial accelerometer and the tangential accelerometer over an analysis period and storing the acceleration information in the memory to generate an acceleration history. The acceleration history is analyzed to determine a cutting effectiveness of the cutting elements responsive to changes in the acceleration history. The cutting effectiveness is reported through the communication port.

Abstract: A drill bit made according to one embodiment includes a bit body and at least one preloaded sensor in the bit body. In one aspect, the sensor may include a sensor element on a sensor body having a first end and a second end and wherein the sensor is preloaded after placing the sensor body in the bit body. In another aspect, the sensor may be preloaded outside the bit body and then placed in the bit body in a manner that enables the sensor to retain the preloading.

Abstract: A drill bit for drilling subterranean formations includes a bit body bearing at least one gage pad and a shank extending from the bit body. An annular chamber is formed within the shank. A data evaluation module is disposed in the annular chamber and includes a processor, a memory, and a communication port. The data evaluation module estimates a gage pad wear by periodically sampling a tangential accelerometer and a radial accelerometer disposed in the drill bit. A history of the tangential acceleration and the radial acceleration is analyzed to determine a revolution rate, gage-slipping periods, and gage-cutting periods. A change in a gage-pad-wear state is estimated responsive to an analysis of the revolution rate, the at least one gage-cutting period and the at least one gage-slipping period. The determination of the gage-pad-wear state may also include analyzing a formation hardness.

Abstract: An apparatus for drilling a borehole in an earth formation is disclosed. The apparatus includes: an earth-boring rotary drill bit including a bit body having a plurality of cutters engagable with a subterranean earth formation; a fluid conduit disposed in the bit body, the fluid conduit being in fluid communication with a source of drilling fluid and configured to receive a portion of the drilling fluid; a nozzle extending between the fluid conduit and a surface of the bit body, the nozzle configured to apply a stream of the portion of the drilling fluid to a first location of the surface; and a valve assembly including an actuator and a valve, the actuator configured to move the valve and divert a flow path of the portion of the drilling fluid, thereby diverting at least part of the stream to a second location on the surface.