A method of estimating a directional parameter of a downhole component includes deploying a borehole string in a borehole, the borehole string including the downhole component, the downhole component being rotatable, the downhole component including a gyroscope device and a magnetometer device. The method also includes collecting gyroscope measurement data from the gyroscope device and magnetic field measurement data from the magnetometer device during rotation of the downhole component, and estimating, by a processor, the directional parameter of the downhole component, where the estimating includes correcting the gyroscope measurement data based on the magnetic field measurement data.

A method of estimating a directional parameter of a downhole component includes deploying a borehole string in a borehole, the borehole string including the downhole component, the downhole component being rotatable, the downhole component including a gyroscope device and a magnetometer device. The method also includes collecting gyroscope measurement data from the gyroscope device and magnetic field measurement data from the magnetometer device during rotation of the downhole component, and estimating, by a processor, the directional parameter of the downhole component, where the estimating includes correcting the gyroscope measurement data based on the magnetic field measurement data.

A method for causing a desired drilling direction of a steerable subterranean drill in consideration of a contemporaneously detected formation tendency force acting on a drill bit of the steerable subterranean drill. The method includes detecting, utilizing a steering direction setting device, a direction and magnitude of a formation tendency force acting on the drill bit of the steerable subterranean drill. Further the steering direction setting device is configured to contemporaneously cause the drill bit of the steerable subterranean drill to drill in the desired direction, counteracting the formation tendency force based on the detected direction and magnitude of the formation tendency force acting on the drill bit.

The present disclosure provides an earth-boring drill bit including a bit head and a shank. The shank includes a blank and a mandrel. The mandrel is concurrently formed by and secured to the blank by additive manufacturing. The mandrel includes a first region including a first alloy and a second region including a second alloy. The first alloy and the second alloy have a different modulus of elasticity, yield strength, resilience, ductility, hardness, fracture toughness, wear resistance, corrosion resistance, or erosion resistance. The disclosure also provides a mandrel wherein the second region comprises a sensor region or a fluid passageway having a geometry that is not obtainable in a mandrel that is cast, machined, or both. The disclosure additionally provides method of manufacturing such bits and mandrels.

A self-calibration method and system of a solid-state resonator gyroscope, which can realize the separation of the bias error from the angular rate, and fundamentally solve the problem of repeatability errors; this calibration method acquires steady-state signals of key monitoring points in a gyroscope in different working modes in real time by externally feeding excitation signals, and realizes the separation of the bias error from the input angular rate by an algorithm, thus calibrating the repeatability error of the gyroscope. The excitation signals include first and second excitation signals; the first and second excitation signals are respectively combined with demodulated primary mode detection signal D.sub.−x and demodulated secondary mode detection signal D.sub.+y to realize feeding; the key monitoring points include output points of an antinode controller and output points of a node controller, and realize the separation of the bias error from the input angular rate according to the excitation signals and acquired signals of monitoring points. The technical solution provided can be applied to a measurement while drilling system or a navigation system.

The pure mechanical well deviation wireless measure-while-drilling and mud pulse generation device includes an outer cylinder and an inner cylinder coaxially arranged inside the outer cylinder; an inner flow channel is formed inside the inner cylinder, and an outer flow channel is formed between the inner cylinder and the outer cylinder; a flow control valve and a hydraulic turbine are arranged in the inner flow channel, and the flow control valve is located at an upstream section of the hydraulic turbine. The device further includes a signal generation base and a rotary stopper. An overflow hole is formed on the signal generation base and arranged in the annular outer flow channel, and the rotary stopper can periodically shield the overflow hole. The inclinometer includes the pure mechanical well deviation wireless measure-while-drilling and mud pulse generation device, an inclinometer outer cylinder and an eccentric rotary column.

The pure mechanical well deviation wireless measure-while-drilling and mud pulse generation device includes an outer cylinder and an inner cylinder coaxially arranged inside the outer cylinder; an inner flow channel is formed inside the inner cylinder, and an outer flow channel is formed between the inner cylinder and the outer cylinder; a flow control valve and a hydraulic turbine are arranged in the inner flow channel, and the flow control valve is located at an upstream section of the hydraulic turbine. The device further includes a signal generation base and a rotary stopper. An overflow hole is formed on the signal generation base and arranged in the annular outer flow channel, and the rotary stopper can periodically shield the overflow hole. The inclinometer includes the pure mechanical well deviation wireless measure-while-drilling and mud pulse generation device, an inclinometer outer cylinder and an eccentric rotary column.

A method of estimating a directional parameter of a downhole component includes deploying a borehole string in a borehole, the borehole string including the downhole component, the downhole component being rotatable, the downhole component including a gyroscope device and a magnetometer device. The method also includes collecting gyroscope measurement data from the gyroscope device and magnetic field measurement data from the magnetometer device during rotation of the downhole component, and estimating, by a processor, the directional parameter of the downhole component, where the estimating includes correcting the gyroscope measurement data based on the magnetic field measurement data.

A method of estimating a directional parameter of a downhole component includes deploying a borehole string in a borehole, the borehole string including the downhole component, the downhole component being rotatable, the downhole component including a gyroscope device and a magnetometer device. The method also includes collecting gyroscope measurement data from the gyroscope device and magnetic field measurement data from the magnetometer device during rotation of the downhole component, and estimating, by a processor, the directional parameter of the downhole component, where the estimating includes correcting the gyroscope measurement data based on the magnetic field measurement data.

Various implementations described herein may refer to a wellbore survey tool using Coriolis vibratory gyroscopic sensors. In one implementation, a method may include receiving one or more reference values corresponding to the Earth's rotation rate and one or more reference values corresponding to a local latitude of a survey tool disposed in a wellbore. The method may also include receiving rotation rate measurements from one or more quartz Coriolis vibratory gyroscopic (CVG) sensors of the survey tool. The method may further include determining bias-corrected rotation rate measurements using one or more statistical estimation processes and based on the one or more reference values corresponding to the Earth's rotation rate, the one or more reference values corresponding to the local latitude, and the rotation rate measurements. The method may additionally include determining azimuth values of the survey tool based on the bias-corrected rotation rate measurements.