Abstract: A vibration damping device for use with downhole electronics may comprise: a device housing mechanically coupled to the downhole electronics and defining a receptacle; and an inertia element movably supported in the receptacle; wherein the volume of the receptacle is greater than the volume of the inertia element so as to define an interstitial volume therebetween and wherein the interstitial volume is occupied by a fluid or an elastomer. A method for tuning a downhole torsional damping device to match a desired downhole electronics may comprise a) calculating a set of natural frequencies and mode shapes for the downhole electronics, b) selecting a desired frequency from the calculated natural frequencies, c) tuning the damping device characteristics to match the selected frequency, d) using the mode shapes to place the damping device. The mode shapes may include antinodes and step d) includes positioning a damping device at an antinode.

Abstract: A method for locating a buried casing stub may include a) identifying a target region, b) providing at each of a plurality of survey points in the target region a casing stub locator that includes a vector magnetometer, c) measuring the magnetic field at each of the survey points using the vector magnetometer so as to generate a plurality of magnetic field measurements, d) using the magnetic field measurements to generate a model of the magnetic field of the target region, e) fitting the model generated in step d) to a selected model of a magnetic anomaly created by the casing stub so as to generate model fit information (MFI), and f) locating the casing stub using the MFI. At each survey point, an expected Earth magnetic field can be subtracted from the measured magnetic field. A total station can measure the position and/or the azimuth of the package.

Abstract: A damping device for use with a downhole tool having a tool axis and an expected operational temperature range, may comprise a device housing mechanically coupled to the tool and including a volume; and an inertia element movably supported in the receptacle and having a volume, a mass, and a non-zero moment of inertia about the tool axis. The inertia element may be supported within the receptacle such that the inertia element can move relative to the device housing and an interface between the device housing and the tool may include an area-altering feature. The device housing has a coefficient of thermal expansion that allows the interface to transmit a predetermined amount of torque and a predetermined amount heat across at expected operational temperatures. The interface may include a thermally conductive material in thermal contact with the device housing and the tool.

Abstract: A magnetic ranging system for use with a drilling assembly in a borehole in a formation, the drilling assembly including a drill string, a drill bit and a bottomhole assembly (BHA) connected to the drill bit, the BHA including a measurement-while-drilling (MWD) system, a bi-directional MWD telemetry interface, and a steerable component, may comprise at least one ranging magnetometer incorporated into the BHA. The ranging magnetometer may be configured to collect ranging measurements from behind the drill bit and the ranging magnetometer may be configured to transmit measurement data. The magnetic ranging system may include at least two ranging magnetometers, with one ranging magnetometer positioned above the MWD system and one ranging magnetometer positioned below the MWD system.

Abstract: The disclosure includes a power section for a bottom hole assembly for use in a wellbore. The power section may include a stator, the stator including a housing, a stator insert, a payload housing and a bent sub having a bend direction. The payload housing may be positioned on an outer surface of the housing, and the payload housing may include a payload pocket. The power section may include a rotor, the rotor rotatable eccentrically within the stator. The payload housing may positioned on the stator housing so as to be always aligned with the bend direction.

Abstract: A method includes providing a Bottom Hole Assembly (BHA) in a wellbore. The BHA includes a rotary steerable system and a downhole attitude correction and control system. The downhole correction and control system includes a first sensor set, the sensors of the first sensor set positioned near ferromagnetic components of a drill string and a second sensor set, the sensors of the second sensor set positioned further from the ferromagnetic components of the drill string than the sensors of the first sensor set. Corrupted data from the first sensor set and reference data from the second sensor set is obtained, the corrupted data including cross-axis magnetometer and accelerometer measurements. The method additionally includes correcting the corrupted sensor data to form corrected sensor measurements and calculating an estimated azimuth from the corrected sensor measurements. The method further includes steering the rotary steerable system based on the estimated azimuth.

Abstract: A magnetic ranging system for use with a drilling assembly in a borehole in a formation, the drilling assembly including a drill string, a drill bit and a bottomhole assembly (BHA) connected to the drill bit, the BHA including a measurement-while-drilling (MWD) system, a bi-directional MWD telemetry interface, and a steerable component, may comprise at least one ranging magnetometer incorporated into the BHA. The ranging magnetometer may be configured to collect ranging measurements from behind the drill bit and the ranging magnetometer may be configured to transmit measurement data. The magnetic ranging system may include at least two ranging magnetometers, with one ranging magnetometer positioned above the MWD system and one ranging magnetometer positioned below the MWD system.

Abstract: A damping device for use with a downhole tool having a tool axis and an expected operational temperature range, may comprise a device housing mechanically coupled to the tool and including a volume; and an inertia element movably supported in the receptacle and having a volume, a mass, and a non-zero moment of inertia about the tool axis. The inertia element may be supported within the receptacle such that the inertia element can move relative to the device housing and an interface between the device housing and the tool may include an area-altering feature. The device housing has a coefficient of thermal expansion that allows the interface to transmit a predetermined amount of torque and a predetermined amount heat across at expected operational temperatures. The interface may include a thermally conductive material in thermal contact with the device housing and the tool.

Abstract: An apparatus for use in acoustically assessing a wellbore, comprises a tubular body, an acoustic transmitter supported on the body, first and second acoustic receivers supported on the body with the second receiver being farther from the transmitter, wherein at least one of the inner and outer body surfaces includes a helical groove between the acoustic transmitter and the first acoustic receiver and the helical groove is filled with a composite material. The body may include a second helical groove that has the same pitch as the first helical groove and is diametrically opposite the first helical groove and may further include a third helical groove between the first and second receivers. At least one of the grooves may an opening width that is less than the maximum groove width and may have a cross-sectional area that includes a neck. The composite material may comprise tungsten particles in rubber.

Abstract: A vibration damping device for use with a downhole tool having a tool axis and a drill string component (DSC), may comprise an inertia ring rotatably mounted on the DSC and including at least one cutout defining a chamber therein such that the DSC forms an end wall of the chamber, and a leaf spring disposed in the chamber, the leaf spring having first and second spring ends, the first end being attached to the inertia ring or the DSC such that relative rotation between the inertia ring and the DSC distorts the leaf spring. The second spring end may engage the other of the inertia ring or the DSC. A fluid may be included in the chamber and the spring may divide the chamber into two portions, so that relative rotation between the inertia ring and the DSC distorts the leaf spring and varies the volumes of the portions.

Abstract: An extended dipole antenna for an uplink transmitter positioned in a wellbore includes an electromagnetic telemetry system interface sub, wired or lined drill pipe segment, and upper dipole terminating sub. The electromagnetic telemetry interface sub includes an outer tubular in electrical contact with a negative output of the uplink transmitter and an inner conductor in electric contact with a positive output of the uplink transmitter. The wired or lined drill pipe segment includes an outer tubular in electrical contact with the outer tubular of the electromagnetic telemetry interface sub and an inner conductor in electric contact with the inner conductor of the electromagnetic telemetry system interface sub. The upper dipole terminating sub including an outer tubular at least partially in electric contact with the outer tubular of the wired or lined drill pipe segment and an inner conductor in electric contact with the inner conductor of the wired or lined drill pipe segment.

Abstract: A vibration damping device for use with a downhole tool having a tool axis may comprise a body coupled to a drill string component. The body may include a longitudinal bore therethrough and at least one lateral bore, the lateral bore having a bore opening and an end wall; an inertial mass slidably disposed in the lateral bore; and a cap mechanically coupled to the lateral bore. The lateral bore may be orthogonal to a radius of the body and may lie in a plane normal to the tool axis. The body may include a plurality of lateral bores, which may be in a co-planar arrangement. Each lateral bore may be blind hole positioned in the body so that it does not intersect the longitudinal bore or another lateral bore. A cap may enclose a lateral bore and fluid may be contained in the bore by the cap.

Abstract: A method may include providing a drill string including a measurement tool. The drill string may be positioned in a wellbore. The method may include taking a measurement with the measurement tool at a first location. The method may include coupling a pipe stand including a first selected number of tubular segments to the drill string, the first selected number being two or more. The method may include lowering or advancing the drill string into the wellbore the length of the pipe stand. The method may include taking a measurement with the measurement tool at a second location. The method may include raising the drill string the length of a tubular segment. The method may include removing a second selected number of tubular segments from the drill string, the second selected number different from the first selected number. The method may include taking a measurement with the measurement tool at a third location.

Abstract: A method for locating a buried casing stub may comprise a) identifying a target region, b) providing at each of a plurality of survey points in the target region a casing stub locator that includes a vector magnetometer, c) measuring the magnetic field at each of the survey points using the vector magnetometer so as to generate a plurality of magnetic field measurements, d) using the magnetic field measurements to generate a model of the magnetic field of the target region, e) fitting the model generated in step d) to a selected model of a magnetic anomaly created by the casing stub so as to generate model fit information (MFI), and f) locating the casing stub using the MFI. At each survey point, an expected Earth magnetic field can be subtracted from the measured magnetic field. A total station can measure the position and/or the azimuth of the package.

Abstract: A method for adjusting a gain of a gamma detector comprises detecting gamma radiation using the detector, recording the detected radiation as count rates in channels, wherein the last channel accumulates all counts above the maximum recorded energy; comparing the last channel count rate (LCCR) to a threshold X and, if LCCR>X, decreasing the gain by a preset amount Y. If LCCR?X, establishing a first estimate of a needed voltage HV1 using tool temperature and a temperature lookup table, and establishing a second estimate of a needed voltage HV2 using a backscatter peak value and a backscatter lookup table; comparing |HV1?HV2| to a threshold Z; if |HV1?HV2|<Z, adjusting the gain of the gamma detector by HV2 or, if |HV1?HV2|?Z, adjusting the gain of the gamma detector by HV1.

Abstract: A vibration damping device for use with a downhole tool having a tool axis may comprise a device housing mechanically coupled to the downhole tool, wherein the device housing defines a receptacle having a volume and an inner surface; an inertia element movably supported in the receptacle and having a volume, a mass, and a non-zero moment of inertia about the tool axis; wherein the inertia element volume is greater than the receptacle volume and an interstitial volume is defined between the inertia element and the receptacle, and wherein the interstitial volume is occupied by a fluid or an elastomer. The device may include a longitudinal bearing and/or a radial bearing between the inertia element and the receptacle. The device may also include a pressure compensation device in fluid communication with the receptacle and positioned within or an integral part of the device housing.

Abstract: A method comprises a) positioning a passive magnetic ranging (PMR) tool in a drilling well that is near a target well that includes a ferromagnetic casing, b) measuring with each of the magnetometers a local magnetic anomaly created by the ferromagnetic casing of the target well so as to generate a plurality of magnetometer readings corresponding to the positions of the magnetometers; c) receiving the plurality of magnetometer readings with the controller; and d) using the received measurements to calculate ranging information, the ranging information including the range and direction from the PMR tool to the target well. The PMR tool may include a ranging collar, a longitudinal array of magnetometers extending along the length of the ranging collar, and a controller, the controller operatively connected to the plurality of magnetometers. The PMR tool may further comprise a radial array of magnetometers positioned radially about the ranging collar.

Abstract: A heading transfer unit may be used to transfer a heading from a surface base to a MWD tool. The surface base may have a master north finder to determine a heading. The heading may be transferred to the heading transfer unit, which is in turn transferred to the MWD unit. The heading on the heading transfer unit is transferred to the MWD tool.

Abstract: An integrated logging tool includes an outer housing and an insert, the insert positioned within the outer housing. The integrated logging tool further includes a gamma sensor within the insert.

Abstract: A method includes providing a Bottom Hole Assembly (BHA) in a wellbore. The BHA includes a rotary steerable system and a downhole attitude correction and control system. The downhole correction and control system includes a first sensor set, the sensors of the first sensor set positioned near ferromagnetic components of a drill string and a second sensor set, the sensors of the second sensor set positioned further from the ferromagnetic components of the drill string than the sensors of the first sensor set. Corrupted data from the first sensor set and reference data from the second sensor set is obtained, the corrupted data including cross-axis magnetometer and accelerometer measurements. The method additionally includes correcting the corrupted sensor data to form corrected sensor measurements and calculating an estimated azimuth from the corrected sensor measurements. The method further includes steering the rotary steerable system based on the estimated azimuth.