Abstract: A method for calibrating a downhole tool may comprise disposing a downhole tool in a borehole, transmitting a signal from a master module disposed on the first device to a module disposed on the second device, transmitting a return signal from the module to the master module, receiving the return signal with the master module, measuring a tone enabled delay for the signal to travel from the master module to the module, and determining a time delay of a return signal to travel from the module to the master module. A well measurement system may comprise a downhole tool. The downhole tool may further comprise a first device and a master module disposed on the first device, wherein the master module may comprise a master transmitter and a master receiver. In examples, the downhole tool may further comprise a second device and a module disposed on the second device.

Abstract: A method and system for detecting a conductive member in a formation. The method may comprise disposing an electromagnetic induction tool into a wellbore, transmitting the electromagnetic field from the at least one electromagnetic source, energizing the conductive member in a second wellbore, wherein an eddy current is induced in the conductive member, transmitting a second electromagnetic field from the conductive member, wherein the second electromagnetic field is formed by the eddy current, sensing the second electromagnetic field with the receiver, recording an amplitude of the second electromagnetic field as data, and transmitting the data to an information handling system. A system for detecting a conductive member in a formation may comprise an electromagnetic induction tool. The electromagnetic induction tool may comprise at least one electromagnetic source and at least one receiver. The system may further comprise an information handling system.

Abstract: A method for calibrating a downhole tool may comprise disposing a downhole tool in a borehole, transmitting a signal from a master module disposed on the first device to a module disposed on the second device, transmitting a return signal from the module to the master module, receiving the return signal with the master module, measuring a tone enabled delay for the signal to travel from the master module to the module, and determining a time delay of a return signal to travel from the module to the master module. A well measurement system may comprise a downhole tool. The downhole tool may further comprise a first device and a master module disposed on the first device, wherein the master module may comprise a master transmitter and a master receiver. In examples, the downhole tool may further comprise a second device and a module disposed on the second device.

Abstract: A modular downhole logging system includes a transmitter module having a local frequency, wherein the transmitter module transmits interrogation signals into a formation based on the local frequency. The downhole system also includes a receiver module axially-spaced from the transmitter module and that receives response signals corresponding to the interrogation signals, wherein the receiver module includes sampling logic and sync estimation logic. The sync estimation logic is configured to perform sync estimation operations including estimating the local frequency of the transmitter module based on analysis of response signal Fourier transform results corresponding to different frequencies. The sampling logic/clock is configured to sample the response signals based on the estimated local frequency of the transmitter module, wherein a processor derives formation property values using the sampled response signals.

Abstract: A method and system for detecting a conductive member in a formation. The method may comprise disposing an electromagnetic induction tool into a wellbore, transmitting the electromagnetic field from the at least one electromagnetic source, energizing the conductive member in a second wellbore, wherein an eddy current is induced in the conductive member, transmitting a second electromagnetic field from the conductive member, wherein the second electromagnetic field is formed by the eddy current, sensing the second electromagnetic field with the receiver, recording an amplitude of the second electromagnetic field as data, and transmitting the data to an information handling system. A system for detecting a conductive member in a formation may comprise an electromagnetic induction tool. The electromagnetic induction tool may comprise at least one electromagnetic source and at least one receiver. The system may further comprise an information handling system.

Abstract: A method for synchronizing signals among transmitters and receivers of a logging tool positioned in a borehole is provided. Measurement signals generated from operating a transmitter in the borehole are acquired by a receiver. An operating frequency of the receiver is determined by a processing unit. The operating frequency of the receiver is different from an operating frequency of the transmitter. A sampling frequency of the receiver is determined based on the determined operating frequency. A phase delay of the receiver is determined by the processing unit. The acquired measurement signals are adjusted by the processing unit based on the determined sampling frequency and the phase delay of the receiver.

Abstract: A modular downhole logging system includes a transmitter module having a local frequency, wherein the transmitter module transmits interrogation signals into a formation based on the local frequency. The downhole system also includes a receiver module axially-spaced from the transmitter module and that receives response signals corresponding to the interrogation signals, wherein the receiver module includes sampling logic and sync estimation logic. The sync estimation logic is configured to perform sync estimation operations including estimating the local frequency of the transmitter module based on analysis of response signal Fourier transform results corresponding to different frequencies. The sampling logic/clock is configured to sample the response signals based on the estimated local frequency of the transmitter module, wherein a processor derives formation property values using the sampled response signals.

Abstract: An example slip-ring interface may include a first section and a second section rotationally independent from the first section. At least one conductor path between the first section and the second section may be selectively associated with and dedicated to the transmission of signals with a first signal type. At least one conductor path between the first section and the second section may be selectively associated with and dedicated to the transmission of signals with a second signal type. If error conditions occur, the signal types associated with one or more of the conductor paths may be changed so that signals of both the first and second signal types are transmitted across the interface.

Abstract: A method for synchronizing signals among transmitters and receivers of a logging tool positioned in a borehole is provided. Measurement signals generated from operating a transmitter in the borehole are acquired by a receiver. An operating frequency of the receiver is determined by a processing unit. The operating frequency of the receiver is different from an operating frequency of the transmitter. A sampling frequency of the receiver is determined based on the determined operating frequency. A phase delay of the receiver is determined by the processing unit. The acquired measurement signals are adjusted by the processing unit based on the determined sampling frequency and the phase delay of the receiver.

Abstract: In at least some embodiments, a high-voltage drilling system includes a a power supply to output high-voltage power to an electrical conductor, a bit that extends a borehole based on the high-voltage power, and a hybrid drillstring that transports a fluid flow from the bit to convey detached formation material out of the borehole. At least part of the electrical conductor resides within the hybrid drillstring to convey power to the bit. The hybrid drillstring includes a coiled tubing section and a jointed pipe section.

Abstract: According to aspects of the present disclosure, systems and methods for controlling the speed of a fluid-controlled drive mechanism are described herein. An example system may include a housing, a variable flow fluid pathway disposed within the housing, an electromagnet coupled to the housing, a fluid-controlled drive mechanism in fluid communication with the variable flow fluid pathway, and a load-generating assembly coupled to the fluid-controlled drive mechanism. An example method may include altering a variable flow fluid pathway disposed within a housing, wherein the variable flow fluid pathway is in fluid communication with a fluid-controlled drive mechanism, and generating an electrical current through an electromagnet, wherein the electromagnet is coupled to the housing.

Abstract: A method for performing ranging measurements within a formation includes transmitting an asymmetric time-varying signal from a transmitter (114) disposed within a borehole (106) in the formation. The asymmetric time-varying signal may have a signal characteristic that is based at least in part on a downhole characteristic. A (receiver 110) disposed within the borehole (106) may measure a magnetic field induced on an object (103) within the formation by the asymmetric time-varying signal. A direction to the object (103) from the borehole (106) may be determined based at least in part on the measurement of the induced magnetic field.

Abstract: In at least some embodiments, a high-voltage drilling system includes a a power supply to output high-voltage power to an electrical conductor, a bit that extends a borehole based on the high-voltage power, and a hybrid drillstring that transports a fluid flow from the bit to convey detached formation material out of the borehole. At least part of the electrical conductor resides within the hybrid drillstring to convey power to the bit. The hybrid drillstring includes a coiled tubing section and a jointed pipe section.

Abstract: In some embodiments, an apparatus and a system, as well as a method and an article, may operate to retrieve a parsing instructions file and a binary configuration file stored in a housing, parse the binary configuration file according to the parsing instructions file to determine configuration information, display at least some of the configuration information as part of a graphical user interface, receive a selection of some of the configuration information and corresponding changed parameter values of the configuration information, transform the binary configuration file into a transformed version of the binary configuration file, and transmit the transformed version of the binary configuration file to the housing as a replacement for the binary configuration file. Additional apparatus, systems, and methods are described.

Abstract: In one example of rotational ranging in a wellbore in which a wellbore component having an axis of rotation is disposed, a wellbore ranging sensor is disposed on a circumferential area surrounding the axis of rotation. The sensor is moved on the circumferential area to multiple distinct sensing positions. At each sensing position, a magnetic field from another wellbore that is apart from the wellbore is measured resulting in multiple magnetic field measurements at the multiple distinct sensing positions. The multiple magnetic field measurements are provided to determine a position of the wellbore relative to the other wellbore using at least a subset of the multiple magnetic field measurements.

Abstract: A rotationally independent wellbore ranging system includes a housing which is attached to a rotary component positioned in a first wellbore and remains substantially stationary relative to the first wellbore when the rotary component rotates in the first wellbore. Multiple sensors affixed to the housing are operable to receive multiple ranging signals from a second wellbore while the rotary component rotates in the first wellbore, and provide the multiple ranging signals to a processor to determine a position of the first wellbore relative to the second wellbore.

Abstract: An example slip-ring interface may include a first section and a second section rotationally independent from the first section. At least one conductor path between the first section and the second section may be selectively associated with and dedicated to the transmission of signals with a first signal type. At least one conductor path between the first section and the second section may be selectively associated with and dedicated to the transmission of signals with a second signal type. If error conditions occur, the signal types associated with one or more of the conductor paths may be changed so that signals of both the first and second signal types are transmitted across the interface.

Abstract: In one example of rotational ranging in a wellbore in which a wellbore component having an axis of rotation is disposed, a wellbore ranging sensor is disposed on a circumferential area surrounding the axis of rotation. The sensor is moved on the circumferential area to multiple distinct sensing positions. At each sensing position, a magnetic field from another wellbore that is apart from the wellbore is measured resulting in multiple magnetic field measurements at the multiple distinct sensing positions. The multiple magnetic field measurements are provided to determine a position of the wellbore relative to the other wellbore using at least a subset of the multiple magnetic field measurements.

Abstract: Methods and systems that compensate for magnetic interference in azimuthal tool measurements. At least some method embodiments include a downhole logging method that includes taking measurements as a function of orientation from inside a borehole. The measurements are associated with different azimuthal bins, and an azimuthal direction is determined for each azimuthal bin. Because the tool rotates at a constant rate, the relative number of measurements associated which the different bins can be used to measure the effective sizes of the different bins and to redetermine the effective angles of the bins in the presence of magnetic interference. The tool measurements may include, but are not limited to, formation resistivity, magnetic field, and formation density.

Abstract: A method for performing ranging measurements within a formation includes transmitting an asymmetric time-varying signal from a transmitter (114) disposed within a borehole (106) in the formation. The asymmetric time-varying signal may have a signal characteristic that is based at least in part on a downhole characteristic. A (receiver 110) disposed within the borehole (106) may measure a magnetic field induced on an object (103) within the formation by the asymmetric time-varying signal. A direction to the object (103) from the borehole (106) may be determined based at least in part on the measurement of the induced magnetic field.