Abstract: A system for inspecting a tubular may comprise an electromagnetic (EM) logging tool and information handling system. The EM logging tool may further include a mandrel, one or more sensor pads attached to the mandrel by one or more extendable arms, and one or more partial saturation eddy current sensors disposed on each of the one or more sensor pads.

Abstract: A system for inspecting a tubular may comprise an electromagnetic (EM) logging tool and information handling system. The EM logging tool may further include a mandrel, one or more sensor pads attached to the mandrel by one or more extendable arms, and one or more partial saturation eddy current sensors disposed on each of the one or more sensor pads.

Abstract: A method for estimating a pipe property for a plurality of nested tubulars. The method may comprise disposing an electromagnetic (EM) logging tool in a wellbore. The electromagnetic logging tool may comprise a transmitter disposed on the electromagnetic logging tool and a receiver disposed on the electromagnetic logging tool. The method may further comprise transmitting an electromagnetic field from the transmitter into one or more tubulars, measuring the eddy current in the pipe string with the receiver on at least one channel to obtain a plurality of measurements, forming an EM log from the plurality of measurements, extracting data and distinct features from the EM log, forming a relationship between the EM log data and a database, wherein the database is formed from one or more high-resolution measurements, and producing a mapping function between the EM log and the database.

Abstract: A system may include an electromagnetic (EM) logging tool for inspecting downhole tubulars. The EM logging tool may include a mandrel, at least one low-frequency transmitter coil disposed on the mandrel, at least one-low frequency receiver coil disposed on the mandrel, and at least one-high frequency sensor configured to measure one or more electromagnetic properties of a tubular.

Abstract: A system for inspecting a tubular may comprise an electromagnetic (EM) logging tool and information handling system. The EM logging tool may further include a mandrel, one or more sensor pads attached to the mandrel by one or more extendable arms, and one or more partial saturation eddy current sensors disposed on each of the one or more sensor pads.

Abstract: A system may include an electromagnetic (EM) logging tool for inspecting downhole tubulars. The EM logging tool may include a mandrel, at least one low-frequency transmitter coil disposed on the mandrel, at least one-low frequency receiver coil disposed on the mandrel, and at least one-high frequency sensor configured to measure one or more electromagnetic properties of a tubular.

Abstract: The disclosure provides a method of evaluating wellbore casing integrity for a wellbore casing configuration. In one example, the method includes providing one or more electromagnetic signals to at least one casing of the wellbore casing configuration, receiving an electromagnetic response measurement that is based on the one or more electromagnetic signals from a selected circumferential portion of the at least one casing of the wellbore casing configuration, and processing the electromagnetic response measurement to produce a metal loss calculation for the selected circumferential portion of the at least one casing of the wellbore casing configuration. A wellbore casing integrity tool and a wellbore casing integrity computing device for evaluating wellbore casing integrity are also provided.

Abstract: Disclosed are systems and methods for receiving, by at least one processor, a first indication to transition from a powered-off state to a low power standby state, in response to the first indication, obtaining, by the at least one processor, from at least one sensor at least one sensor measurement comprising data corresponding to a downhole environment, determining, by the at least one processor, that the at least one sensor measurement exceeds a particular threshold comprising a second indication and transitioning from the low power standby state to a logging state, in response to the second indication, capturing, by the at least one processor, the data corresponding to the downhole environment, and storing, by the at least one processor, the data corresponding to the downhole environment.

Abstract: A method for estimating a pipe property for a plurality of nested tubulars. The method may comprise disposing an electromagnetic (EM) logging tool in a wellbore. The electromagnetic logging tool may comprise a transmitter disposed on the electromagnetic logging tool and a receiver disposed on the electromagnetic logging tool. The method may further comprise transmitting an electromagnetic field from the transmitter into one or more tubulars, measuring the eddy current in the pipe string with the receiver on at least one channel to obtain a plurality of measurements, forming an EM log from the plurality of measurements, extracting data and distinct features from the EM log, forming a relationship between the EM log data and a database, wherein the database is formed from one or more high-resolution measurements, and producing a mapping function between the EM log and the database.

Abstract: A method and system for identifying a deformation. The method may comprise disposing an electromagnetic logging tool in a pipe string, performing a logging operation with the electromagnetic logging tool, transmitting an electromagnetic field from a transmitter, energizing the casing string with the electromagnetic field to produce an eddy current, measuring the eddy current with at least one receiver, processing the measurements of the eddy current to find a point-wise eccentricity between the casing string and the pipe string, identifying a zone with the deformation based at least in part on the point-wise eccentricity, determining at least one characteristic of the deformation, and making a wellbore decision related to an integrity of the casing string based on the at least one characteristic of the deformation or the point-wise eccentricity. The system may comprise an electromagnetic logging tool which may comprise a transmitter and at least one receiver.

Abstract: A method and a system for determining metal loss in a layered system. The method may comprise disposing an EM metal loss tool downhole, broadcasting an electromagnetic field from the one or more transmitters of the EM metal loss tool into the layered system, recording the altered electromagnetic field with the one or more receivers, processing the signal with an information handling system, and determining metal loss in the layered system. A system may comprise an EM metal loss tool. The EM electromagnetic metal loss tool may comprise at least one transmitter and at least one receiver. The system may further comprise a conveyance, wherein the conveyance is attached to the electromagnetic metal loss tool, and an information handling system, wherein the information handling system is configured to process the altered electromagnetic field and determine metal loss in the layered system.

Abstract: The disclosure provides a method of evaluating wellbore casing integrity for a wellbore casing configuration. In one example, the method includes providing one or more electromagnetic signals to at least one casing of the wellbore casing configuration, receiving an electromagnetic response measurement that is based on the one or more electromagnetic signals from a selected circumferential portion of the at least one casing of the wellbore casing configuration, and processing the electromagnetic response measurement to produce a metal loss calculation for the selected circumferential portion of the at least one casing of the wellbore casing configuration. A wellbore casing integrity tool and a wellbore casing integrity computing device for evaluating wellbore casing integrity are also provided.

Abstract: A method and a system for determining metal loss in a layered system. The method may comprise disposing an EM metal loss tool downhole, broadcasting an electromagnetic field from the one or more transmitters of the EM metal loss tool into the layered system, recording the altered electromagnetic field with the one or more receivers, processing the signal with an information handling system, and determining metal loss in the layered system. A system may comprise an EM metal loss tool. The EM electromagnetic metal loss tool may comprise at least one transmitter and at least one receiver. The system may further comprise a conveyance, wherein the conveyance is attached to the electromagnetic metal loss tool, and an information handling system, wherein the information handling system is configured to process the altered electromagnetic field and determine metal loss in the layered system.

Abstract: A method for measuring fluid flow including disposing a measurement device within a fluidic channel, the measurement device including a hydrodynamic central body, a plurality of arms coupled with and operable to extend from and retract to the hydrodynamic central body, and a plurality of sensors disposed within the hydrodynamic central body and distributed along the length of each of the plurality of arms; triggering, via an actuator, the plurality of arms to expand from the hydrodynamic central body until a portion of each of the plurality of arms abut a sidewall of the fluidic channel; collecting, via the plurality of sensors, measurements relating to one or more fluid flow parameters within the fluidic channel; triggering, via the actuator, the plurality of arms to contract inwards to the hydrodynamic central body; and retracting the measurement device from the fluidic channel.

Abstract: A method for measuring fluid flow including disposing a measurement device within a fluidic channel, the measurement device including a hydrodynamic central body, a plurality of arms coupled with and operable to extend from and retract to the hydrodynamic central body, and a plurality of sensors disposed within the hydrodynamic central body and distributed along the length of each of the plurality of arms; triggering, via an actuator, the plurality of arms to expand from the hydrodynamic central body until a portion of each of the plurality of arms abut a sidewall of the fluidic channel; collecting, via the plurality of sensors, measurements relating to one or more fluid flow parameters within the fluidic channel; triggering, via the actuator, the plurality of arms to contract inwards to the hydrodynamic central body; and retracting the measurement device from the fluidic channel.

Abstract: A method and system for identifying a deformation. The method may comprise disposing an electromagnetic logging tool in a pipe string, performing a logging operation with the electromagnetic logging tool, transmitting an electromagnetic field from a transmitter, energizing the casing string with the electromagnetic field to produce an eddy current, measuring the eddy current with at least one receiver, processing the measurements of the eddy current to find a point-wise eccentricity between the casing string and the pipe string, identifying a zone with the deformation based at least in part on the point-wise eccentricity, determining at least one characteristic of the deformation, and making a wellbore decision related to an integrity of the casing string based on the at least one characteristic of the deformation or the point-wise eccentricity. The system may comprise an electromagnetic logging tool which may comprise a transmitter and at least one receiver.

Abstract: Disclosed are systems and methods for receiving, by at least one processor, a first indication to transition from a powered-off state to a low power standby state, in response to the first indication, obtaining, by the at least one processor, from at least one sensor at least one sensor measurement comprising data corresponding to a downhole environment, determining, by the at least one processor, that the at least one sensor measurement exceeds a particular threshold comprising a second indication and transitioning from the low power standby state to a logging state, in response to the second indication, capturing, by the at least one processor, the data corresponding to the downhole environment, and storing, by the at least one processor, the data corresponding to the downhole environment.