Abstract: Extracting a core sample from within a wellbore is optimized based on information extracted from acoustic signals that are generated downhole. The acoustic signals provide an indication of the formation being cored, which is used to obtain or adjust designated coring operating parameters for accomplishing an efficient and effective coring procedure. Coring operating parameters that are adjusted include weight on bit and bit rotational speed. Optimizing coring operating parameters reduces wear on the bit and produces samples with less fractures. Generating acoustic signals is done by the operation of coring itself, or contacting the formation with a coring bit. Contacting includes impacting the coring bit radially against the wellbore's sidewall, or moving the bit laterally after coring operations have initiated.

Abstract: A downhole fluid analysis device includes a piezoelectric helm resonator, an optical sensor, and an electromagnetic spectroscopy sensor. The piezoelectric helm resonator includes a strain bar and a pair of electrodes coupled to opposite sides of the strain bar. The piezoelectric helm resonator further includes a pair of tines, in which a first tine of the pair of tines is coupled to opposite ends of the strain bar, the pair of tines each having an arc, and such that strain across a transverse face of the strain bar generates a resonance response from the pair of tines. The optical sensor is positioned centrally with respect to the piezoelectric helm resonator, and the spectroscopy sensor is positioned symmetrically with respect to the piezoelectric helm resonator in at least on direction.

Abstract: A method for determining a wellbore fluid phase includes receiving, from a first sensor, first fluid data for a fluid flowing through a wellbore. The method also includes receiving, from a second sensor, second fluid data for the fluid. The method further includes determining, based at least in part on the first fluid data, a first fluid property. The method also includes determining, based at least in part on the second fluid data, a second fluid property. The method further includes determining a relationship between the first fluid property and the second fluid property, the relationship based at least in part on respective evaluations of the first fluid property with respect to a first threshold and the second fluid property with respect to a second threshold. The method includes determining, based at least in part on the relationship, a phase of the fluid.

Abstract: A resource exploration and recovery system includes a first system, a second system including a tubular string having an inner surface, a connector system provided at the inner surface, a screen component, and a cable extending between the connector system and the control system. The connector system includes at least one connector component and at least one frangible link component. A tractor is deployable into the tubular string. The tractor includes a cable reel having an amount of cable deployable in the tubular string. The tractor is connected to a control system and is operable to configure at least one component in the tubular string including at least one of the connector component, the frangible link component and the screen component.

Abstract: A computer-implemented method includes receiving a plurality of sensor signals, each signal of the plurality of sensor signals being tagged with an associated time and depth. The method also includes selecting a baseline signal. The method further includes comparing a selected sensor signal, of the plurality of sensor signals, to the baseline signal. The method also includes determining a difference between the baseline signal and the selected sensor signal exceeds a threshold. The method includes identifying, based at least in part on the difference, a feature of interest associated with the selected sensor signal.

Abstract: A downhole fluid analysis system includes an optical sensor comprising, which includes a light source configured to emit light comprising a plurality of wavelengths, a light detector, and an optical tip through which at least a portion of the light travels and returns to the detector, wherein the incident angle of the light causes total internal reflection within the optical tip. The system further includes a piezoelectric helm resonator that generates a resonance response in response to an applied current, and an electromagnetic spectroscopy sensor positioned symmetrically with respect to the piezoelectric helm resonator in at least one direction. The light may be reflected in the optical tip at one or more reflection points, and each reflection point may generate an evanescent wave in a medium surrounding the optical tip. The light may be internally reflected in the optical tip at a plurality of reflection points.

Abstract: A method for configuring a wellbore system includes guiding a tractor into a tubular string including an inner surface supporting more or more components to a select one of the plurality of components, deploying an element from the tractor into the tubular string, engaging the selected one of the plurality of components with the tractor, and changing a configuration of the selected one of the plurality of components with the element deployed from the tractor.

Abstract: A resource exploration and recovery system includes a first system, a second system including a tubular string having an inner surface, a connector system provided at the inner surface, a screen component, and a cable extending between the connector system and the control system. The connector system includes at least one connector component and at least one frangible link component. A tractor is deployable into the tubular string. The tractor includes a cable reel having an amount of cable deployable in the tubular string. The tractor is connected to a control system and is operable to configure at least one component in the tubular string including at least one of the connector component, the frangible link component and the screen component.

Abstract: A method of determining a rate of penetration of a downhole tool. The method comprises introducing a downhole tool including a drill bit configured to drill through a subterranean formation in a wellbore, the downhole tool comprising at least one reader configured to communicate with identification tags using electromagnetic radiation. The method includes advancing the wellbore with the drill bit and placing, with a component of a bottomhole assembly of the downhole tool, a first identification tag at a first location proximate the wellbore and at least a second identification tag at a second location proximate the wellbore and separated from the first location by a distance. An interrogation signal is transmitting from the at least one reader toward a wall of the wellbore and response signals from the identification tags are received by the at least one reader to determine proximity of the identification tags to the reader.

Abstract: A downhole fluid analysis tool includes a tool body, a plurality of arms coupled to the tool body and movable between a retracted position and one or more expanded positions away from a central axis of the tool body. The plurality of arms are at an angle with respect to the central axis, the angle being different in each of the one or more expanded positions. The tool further includes a plurality of fluid sensors coupled to the plurality of arms. A fluid sensor of the plurality of the fluid sensors is movably coupled to an arm of the plurality of arms and configured to pivot across a plurality of angles with respect to the arm. The angle of the fluid sensor with respect to the arm is associated with the angle of the arm with respect to the central axis of the tool body.

Abstract: A downhole fluid analysis device includes a piezoelectric helm resonator, an optical sensor, and an electromagnetic spectroscopy sensor. The piezoelectric helm resonator includes a strain bar and a pair of electrodes coupled to opposite sides of the strain bar. The piezoelectric helm resonator further includes a pair of tines, in which a first tine of the pair of tines is coupled to opposite ends of the strain bar, the pair of tines each having an arc, and such that strain across a transverse face of the strain bar generates a resonance response from the pair of tines. The optical sensor is positioned centrally with respect to the piezoelectric helm resonator, and the spectroscopy sensor is positioned symmetrically with respect to the piezoelectric helm resonator in at least on direction.

Abstract: A downhole fluid analysis device includes a piezoelectric helm resonator, a spectroscopy sensor positioned symmetrically with respect to the piezoelectric helm resonator in at least one direction, and a circuit comprising a first terminal and a second terminal electrically coupled to a power supply. The piezoelectric helm resonator and the spectroscopy sensor are electrically coupled in parallel between the first and second terminals. The power supply drives the piezoelectric helm resonator with a voltage of a first polarity and the spectroscopy sensor with a voltage of a second polarity. The circuit includes at least one current flow control device in the circuit configured to prevent both the piezoelectric helm resonator and the spectroscopy sensor from being powered simultaneously.

Abstract: Embodiments of the present disclosure include a method for determining at least one fluid property that includes obtaining electrical admittance data from a downhole tool, the admittance data being associated with a fluid in a wellbore. The method also includes obtaining reference electrical admittance data for air. The method further includes comparing the admittance data to the reference admittance data. The method also includes determining an offset between a first peak of the admittance data and a second peak of the reference admittance data. The method includes determining the at least one fluid property based at least in part on the determined resonance frequency offset.

Abstract: Estimating parameters of interest of a formation, including density, porosity, and fluid saturation. Methods relate to gamma ray energy spectra calibration for a radiation detector including generating a calibration radiation spectrum using measurements of radiation with the detector in a time interval wherein the radiation comprises predominantly gamma rays emitted by decay of radionuclides produced by neutron activation reactions resulting from neutron irradiation, the time interval following a prior time interval corresponding to thermal neutrons produced from the irradiation; making at least one other radiation measurement with the detector outside the time interval; and producing a calibrated radiation measurement from the at least one other radiation measurement using the calibration radiation spectrum. The measurements may be taken in the time interval by conveying the radiation detector in the borehole at high speed and using a background gate of the detector.

Abstract: Extracting a core sample from within a wellbore is optimized based on information extracted from acoustic signals that are generated downhole. The acoustic signals provide an indication of the formation being cored, which is used to obtain or adjust designated coring operating parameters for accomplishing an efficient and effective coring procedure. Coring operating parameters that are adjusted include weight on bit and bit rotational speed. Optimizing coring operating parameters reduces wear on the bit and produces samples with less fractures. Generating acoustic signals is done by the operation of coring itself, or contacting the formation with a coring bit. Contacting includes impacting the coring bit radially against the wellbore's sidewall, or moving the bit laterally after coring operations have initiated.

Abstract: A method and system for transmitting data through a transmission medium between surface and subsurface transceivers. A surface transceiver and a subsurface transceiver are each configured to selectively transmit over a plurality of transmission channels, each transmission channel having a range of frequencies within the total frequency bandwidth. The surface transceiver is adapted to initialize a channel to determine at least one parameter affecting the current maximum data rate for transmission of information through the channel using a given transmission methodology. At least one of the channels uses carrierless phase/amplitude (CAP) modulation for its transmission methodology. The surface transceiver and the subsurface transceiver adapt to cooperatively periodically test a channel by transmission of a calibration signal from the subsurface transceiver to the surface transceiver.

Abstract: A method of determining a rate of penetration of a drill bit using acoustic technology. The method comprises providing a drill string including a drill bit configured to drill through a subterranean formation in a wellbore and operably coupling an array of acoustic transducers to a member of the drill string. Acoustic waves are emitted toward a wall of the wellbore with at least one acoustic transducer and a frequency of the acoustic waves reflected from the wall of the wellbore are measured with at least one acoustic transducer. The array of acoustic transducers is operably coupled to a controller comprising a memory and a processor to determine a frequency shift between the emitted acoustic waves and the reflected acoustic waves. A rate of penetration of the drill bit is determined with the processor based at least in part on the frequency shift. Downhole acoustic systems for determining a rate of penetration of a drill string are also disclosed.

Abstract: A method of determining a rate of penetration of a downhole tool. The method comprises introducing a downhole tool including a drill bit configured to drill through a subterranean formation in a wellbore, the downhole tool comprising at least one reader configured to communicate with identification tags using electromagnetic radiation. The method includes advancing the wellbore with the drill bit and placing, with a component of a bottomhole assembly of the downhole tool, a first identification tag at a first location proximate the wellbore and at least a second identification tag at a second location proximate the wellbore and separated from the first location by a distance. An interrogation signal is transmitting from the at least one reader toward a wall of the wellbore and response signals from the identification tags are received by the at least one reader to determine proximity of the identification tags to the reader.

Abstract: Methods, systems, devices, and products for estimating at least one parameter of interest of a volume of interest of an earth formation using nuclear radiation based measurements. Logging tools include a limited aperture collimated radiation beam source, detectors, and at least one processor configured to take measurements. The source is configured to emit a beam of radiation radially from the logging tool into an elongated volume of interest outside the wellbore such that the beam penetrates a plurality of zones of the volume of interest. Each zone represents a range of radial depths corresponding to a respective infrastructure component associated with the wellbore, such as nested tubulars. Each detector has a unique angle of detection and is configured to generate measurement information in response to spatially coherent backscattered gamma rays. Each detector is associated with scattering events at one of the plurality of zones.

Abstract: Estimating parameters of interest of a formation, including density, porosity, and fluid saturation. Methods relate to gamma ray energy spectra calibration for a radiation detector including generating a calibration radiation spectrum using measurements of radiation with the detector in a time interval wherein the radiation comprises predominantly gamma rays emitted by decay of radionuclides produced by neutron activation reactions resulting from neutron irradiation, the time interval following a prior time interval corresponding to thermal neutrons produced from the irradiation; making at least one other radiation measurement with the detector outside the time interval; and producing a calibrated radiation measurement from the at least one other radiation measurement using the calibration radiation spectrum. The measurements may be taken in the time interval by conveying the radiation detector in the borehole at high speed and using a background gate of the detector.