Abstract: The present disclosure provide techniques and apparatus for magnetic flux leakage (MFL) testing for casing inspection and coiled tubing inspection. An example technique includes operating an inspection tool including at least one sensor arranged in proximity to a coiled tubing. A first set of MFL measurements associated with a first liftoff distance of the sensor with respect to a surface of the coiled tubing is obtained using the inspection tool. A second set of MFL measurements associated with a second liftoff distance of the sensor with respect to the surface of the coiled tubing is generated, based on performing a filtering operation on the first set of MFL measurements. The second liftoff distance is less than the first liftoff distance. At least one defect of the coiled tubing is determined based on the second set of MFL measurements.

Abstract: A method includes receiving raw measurements of a well, receiving thickness measurements from a well completion file of the well, receiving computed thickness measurements of the well, clustering the raw measurements into a first plurality of clusters, wherein each cluster of the first plurality of clusters corresponds to a particular range of depths, obtaining a corrected phase thickness using the first plurality of clusters, the signals, and the computed thickness measurements, clustering the thickness measurements from the well completion file into a second plurality of clusters, obtaining a corrected well thickness using the second plurality of clusters, the well completion file, and the computed thickness measurements, and identifying corrections in the computed thicknesses from corrected raw measurement thickness and corrected well completion thickness based on differences between each of the corrected raw measurement thickness, the corrected well completion thickness, and the computed thickness measure

Abstract: Techniques and systems for determining eccentering in concentric pipes. A device includes a data acquisition tool to generate measurements related to eccentering characteristics of a first pipe concentrically surrounding the tool and second eccentering characteristics of a second pipe concentrically surrounding the tool and the first pipe. The tool includes a transmitter to generate at least one first time-varying magnetic field at a first frequency and at least one second time-varying magnetic field at a second frequency, a first receiver disposed at a first distance from the transmitter along the tool to measure a first change in voltage in the first pipe in response to the at least one first time-varying magnetic field, and a second receiver disposed at a second distance from the transmitter along the tool to measure a second change in voltage in the second pipe in response to the at least one second time-varying magnetic field.

Abstract: The present disclosure provide techniques and apparatus for magnetic flux leakage (MFL) testing for casing inspection and coiled tubing inspection. An example technique includes operating an inspection tool including at least one sensor arranged in proximity to a coiled tubing. A first set of MFL measurements associated with a first liftoff distance of the sensor with respect to a surface of the coiled tubing is obtained using the inspection tool. A second set of MFL measurements associated with a second liftoff distance of the sensor with respect to the surface of the coiled tubing is generated, based on performing a filtering operation on the first set of MFL measurements. The second liftoff distance is less than the first liftoff distance. At least one defect of the coiled tubing is determined based on the second set of MFL measurements.

Abstract: An inversion-based method has been developed to evaluate up to 5 or 6 nested casings by utilizing complementary sensitivities from time-domain collocated (relatively shallow) and multi-frequency, multi-spacing non-collocated (both relatively shallow and relatively deeper) pulsed eddy current measurements. Stand-alone inversion-based techniques are also disclosed to process time-domain collocated sensor measurements, which may come from single or multiple sensors of different lengths.

Abstract: Techniques and apparatus for determining quadrant-based locations of casing defects based on multi-frequency, non-collocated, induction measurements are described. An electromagnetic (EM) inspection tool is operated inside of a well including multiple casings. The EM inspection tool includes a triaxial transmitter and multiple triaxial receivers, each being located at a different spacing from the triaxial transmitter. The triaxial transmitter is configured to emit primary time-varying magnetic field signals in a radial direction, a tangential direction, and an axial direction. Each respective primary time-varying magnetic field signal induces corresponding secondary time-varying magnetic field signal(s) in the radial direction, the tangential direction, and the axial direction that are detected by one or more of the triaxial receivers.

Abstract: Techniques and apparatus for evaluating sensor placement and frequency selection for an electromagnetic inspection tool, and determining casing count and casing sizes in a multi-casing well are described. The electromagnetic inspection tool includes a transmitter and multiple receivers configured to operate at one or more frequencies. Each receiver is located at a different spacing from the transmitter. At least one of a casing count for a well or a respective size of each casing in the well is determined using multi-frequency, non-collocated induction measurements obtained via the electromagnetic inspection tool. The size of an innermost casing may be determined based on slope(s) of high frequency response(s) at spacings in a direct coupling zone of an electromagnetic field distribution. Each size of an outer casing(s) may be determined based in part on null frequency locations within the frequency domain responses at spacings in the transition zone of the electromagnetic field distribution.

Abstract: Systems and methods to determine a thickness profile of nested metallic pipes can include processing long sections (windows) of induction multi spacing and multi frequency noncollocated sensor measurements (attenuation and phase). The systems and methods also include using an inversion based process to deconvolve the tool transfer function from the surrounding pipe structure and its anomalies by running an axisymmetric finite element method (FEM modeling solver with a model in an inversion loop.

Abstract: The present disclosure provide techniques and apparatus for magnetic flux leakage (MFL) testing for casing inspection and coiled tubing inspection. An example technique includes operating an inspection tool including at least one sensor arranged in proximity to a coiled tubing. A first set of MFL measurements associated with a first liftoff distance of the sensor with respect to a surface of the coiled tubing is obtained using the inspection tool. A second set of MFL measurements associated with a second liftoff distance of the sensor with respect to the surface of the coiled tubing is generated, based on performing a filtering operation on the first set of MFL measurements. The second liftoff distance is less than the first liftoff distance. At least one defect of the coiled tubing is determined based on the second set of MFL measurements.

Abstract: Embodiments presented provide for a method for providing look-ahead measurements ahead of a drill bit in hydrocarbon recovery operations. Embodiments use a pixel-based inversion workflow to produce real time prediction in horizontal and high-angle wells. The method includes obtaining data related to geological properties, performing a one dimensional look around inversion of the data to achieve one dimensional results, performing a two dimensional look ahead pixel based inversion wherein the generated results for the one dimensional look around inversion are used as a starting model to obtain a second set of results, and displaying the second set of results.

Abstract: A system and apparatus are described for measuring magnetic flux in a wellbore casing. In an example, the apparatus includes a primary magnet and a sensor for measuring magnetic flux in the wellbore casing created by the primary magnet. The primary magnet can have magnetic pole pieces at either end that help guide the magnetic flux into the wellbore casing. Focusing magnets can be placed on both ends of the primary magnet so that the focusing magnets are separated from the primary magnet by the magnetic pole pieces. The magnetic flux created by the focusing magnets reduces dispersion of the primary magnet's magnetic flux by forcing magnetic flux from the primary magnet that would otherwise disperse to flow toward the sensor. The sensor can output a signal with magnetic flux readings. A computing device can receive the signal and detect discontinuities in the wellbore casing.

Abstract: A system and apparatus are described for measuring magnetic flux in a wellbore casing. In an example, the apparatus includes a primary magnet and a sensor for measuring magnetic flux in the wellbore casing created by the primary magnet. The primary magnet can have magnetic pole pieces at either end that help guide the magnetic flux into the wellbore casing. Focusing magnets can be placed on both ends of the primary magnet so that the focusing magnets are separated from the primary magnet by the magnetic pole pieces. The magnetic flux created by the focusing magnets reduces dispersion of the primary magnet's magnetic flux by forcing magnetic flux from the primary magnet that would otherwise disperse to flow toward the sensor. The sensor can output a signal with magnetic flux readings. A computing device can receive the signal and detect discontinuities in the wellbore casing.

Abstract: Embodiments presented provide for a method for providing look-ahead measurements ahead of a drill bit in hydrocarbon recovery operations. Embodiments use a pixel-based inversion workflow to produce real time prediction in horizontal and high-angle wells. The method includes obtaining data related to geological properties, performing a one dimensional look around inversion of the data to achieve one dimensional results, performing a two dimensional look ahead pixel based inversion wherein the generated results for the one dimensional look around inversion are used as a starting model to obtain a second set of results, and displaying the second set of results.

Abstract: The present disclosure relates to a method that includes receiving ultra-deep azimuthal resistivity (UDAR) measurements from a downhole tool within a geological formation. The method also includes determining a data processing window based on a relative location of a transmitter of the downhole tool with respect to a location of one or more components of the downhole tool. Further, the method includes performing a three-dimensional (3D) inversion of the UDAR measurements based on the relative location of the transmitter. Further still, the method includes generating an anisotropic resistivity distribution and relative formation dip output based on the 3D inversion.

Abstract: An inversion-based method has been developed to evaluate up to 5 or 6 nested casings by utilizing complementary sensitivities from time-domain collocated (relatively shallow) and multi-frequency, multi-spacing non-collocated (both relatively shallow and relatively deeper) pulsed eddy current measurements. Stand-alone inversion-based techniques are also disclosed to process time-domain collocated sensor measurements, which may come from single or multiple sensors of different lengths.

Abstract: Embodiments included herein are directed towards a system and method for analyzing an oilfield casing using an apparent thickness approach. Embodiments may include providing an induction instrument having at least one of a transmitter and a receiver configured to operate at one or more frequencies. Embodiments may further include generating, using data acquired by the induction instrument, one or more apparent thickness transforms for at least one of a measured attenuation and a phase response associated with an oilfield casing, wherein generating includes assuming a proportionate increase in all casing thicknesses.

Abstract: A ranging workflow to interpret the ultradeep harmonic anisotropic attenuation (UHAA) measurements and estimate the distance and orientation of the existing cased well from the well being drilled is presented herein. The ranging workflow applies to scenarios in which the wells are near parallel to each other and performs reasonably well in boreholes which are more or less perpendicular to the formation layers. The ranging workflow generally includes deploying a deep directional resistivity (DDR) tool into a new wellbore; collecting UHAA data via the DDR tool; determining resistivity values based at least in part on the UHAA data; and determining a distance of the DDR tool from a casing of an existing wellbore proximate the new wellbore based at least in part on the resistivity values and a UHAA response table for the DDR tool.

Abstract: Embodiments included herein are directed towards a system and method for analyzing an oilfield casing using an apparent thickness approach. Embodiments may include providing an induction instrument having at least one of a transmitter and a receiver configured to operate at one or more frequencies. Embodiments may further include generating, using data acquired by the induction instrument, one or more apparent thickness transforms for at least one of a measured attenuation and a phase response associated with an oilfield casing, wherein generating includes assuming a proportionate increase in all casing thicknesses.

Abstract: Methods and apparatus for analyzing nested tubulars via electromagnetic (EM) logging. An example method includes operating an EM logging tool within tubulars nested within a wellbore. The EM logging tool includes an EM transmitter and multiple EM receivers. Data obtained via the EM receivers is utilized to estimate an individual thickness of each tubular at each of multiple depths within the wellbore. The estimated individual thicknesses are utilized to estimate a cumulative thickness of the tubulars at each depth. Local variations of the estimated cumulative thicknesses are utilized to distinguish between actual and spurious indications of differences between the estimated individual thicknesses at neighboring depths.

Abstract: Methods and apparatus for analyzing nested tubulars via electromagnetic (EM) logging. An example method includes operating an EM logging tool within tubulars nested within a wellbore. The EM logging tool includes an EM transmitter and multiple EM receivers. Data obtained via the EM receivers is utilized to estimate an individual thickness of each tubular at each of multiple depths within the wellbore. The estimated individual thicknesses are utilized to estimate a cumulative thickness of the tubulars at each depth. Local variations of the estimated cumulative thicknesses are utilized to distinguish between actual and spurious indications of differences between the estimated individual thicknesses at neighboring depths.