Abstract: A wellbore system includes a wellbore tubular with local inner diameter variation. The system includes a wellbore tubular that is positionable in a wellbore for producing hydrocarbon fluid. The wellbore tubular includes at least one portion of an inner wall with a greater inner diameter than other portions of the inner wall of the wellbore tubular. The system includes a fiber optic cable of a fiber optic sensing system that is positionable in the wellbore for measuring flow disturbance of production fluid at the at least one portion of the inner wall to monitor hydrocarbon production flow.

Abstract: A method for controlling a flow of one or more fluids from a formation into a production tubing, includes measuring fluid properties of the one or more fluids passing through one or more fluidic oscillators of a flowmeter device disposed on the production tubing, adjusting the flow in a flow area based on the fluid properties through an inflow control device coupled to the production tubing and is in fluid communication with the flow meter device, and controlling, in response to change in the fluid properties, actuation of the inflow control device to adjust the flow by a controller coupled to the inflow control device.

Abstract: A method of monitoring a marine animal in a marine environment, implemented by an interrogator unit and a sensing attached to the interrogator, the method comprises deploying the sensing cable within a water column, interrogating, using the interrogator unit, the sensing cable, receiving acoustic data comprising acoustic signals generated by the marine animal, and processing, by a processor coupled to the interrogator unit, the acoustic data to detect a presence of the marine animal.

Abstract: A method of monitoring a marine animal in a marine environment, implemented by an interrogator unit and a sensing attached to the interrogator, the method comprises deploying the sensing cable within a water column, interrogating, using the interrogator unit, the sensing cable, receiving acoustic data comprising acoustic signals generated by the marine animal, and processing, by a processor coupled to the interrogator unit, the acoustic data to detect a presence of the marine animal.

Abstract: The way in which a fiber optic cable is wrapped around a casing string in a wellbore can be modeled using information from downhole sensor devices. For example, a system can include a fiber optic cable located along a length of a wellbore. The system can also include sensor devices located near the fiber optic cable at various depths to transmit acoustic signals indicating depths and orientations of segments of the fiber optic cable. The system can build a model describing how the fiber optic cable is positioned around the casing string based on the acoustic signals transmitted from the sensor devices. The system can also determine a target position for a perforating gun to perform a perforation operation through the casing string that avoids damaging the fiber optic cable. The system can output the target position for the perforating gun to an electronic device to facilitate the perforation operation.

Abstract: A system may include a sensing fiber that can receive interrogation data via a coil of reference fiber, the coil of reference fiber configurable to be of a same type of fiber as the sensing fiber, and the sensing fiber configurable to be coupled in series with the coil of reference fiber. A known temperature and a known strain can be received from the coil of reference fiber. The known temperature, the known strain, and the interrogation data can be outputted for calibrating a measurement of the interrogation data.

Abstract: A method includes deploying an optical fiber attached to a distributed acoustic sensing (DAS) interrogator in a wellbore, pre-setting gauge length of the DAS interrogator based on an expected measurement signal, interrogating the optical fiber using the DAS interrogator, receiving reflected DAS signals along a length of the optical fiber using the pre-set gauge length, performing an analysis to estimate a location and a magnitude of a strain source associated with the reflected DAS signals, and dynamically adjusting the gauge length for at least a portion of the optical fiber within a pre-defined limit of the DAS interrogator as a function of the estimated location and magnitude of the strain source to enhance sensitivity and to optimize signal-to-noise ratio.

Abstract: A distributed acoustic sensing (DAS) system for determining an acoustic event may include an interferometer and an acoustic event detection processing device. The interferometer may measure DAS data from sensed signals from a sensing fiber deployed in a wellbore. The acoustic event detection processing device may determine an acoustic event in the wellbore from an out-of-band signal using the DAS data by performing operations. The operations can include determining a first acoustic event and a second acoustic event from the DAS data. The operations can include determining a first set of aliased frequencies from the first acoustic event and a second set of aliased frequencies form the second acoustic event. The operations can include determining, using an intersection of the first set of aliased frequencies and the second set of aliased frequencies, a frequency or amplitude of out-of-band signals that are usable to determine the at least one acoustic event.

Abstract: A partially dissolvable plug is to be deployed in a position in a wellbore formed in a subsurface formation. The partially dissolvable plug comprises a first portion comprising a dissolvable material that is to dissolve over time after exposure to a downhole ambient environment in the wellbore and a second portion comprising a non-dissolvable material that is to create a flow restriction as the flow of fluid passes through the partially dissolvable plug. The first portion is to prevent a flow of fluid from downhole to a surface of the wellbore until at least a portion of the dissolvable material is dissolved. A flow rate is to be determined based on a detected change in a downhole attribute that is to change in response to the flow of fluid passing through the partially dissolvable plug after at least a portion of the partially dissolvable plug is dissolved.

Abstract: Some embodiments of the inventive subject matter improve techniques for measuring downhole attributes. A method for determining a flow rate of a fluid includes positioning a tubular within a wellbore formed in a subsurface formation, wherein a flow of fluid is to move through the tubular. An orifice plate is positioned in the tubular. The orifice plate is movable between a first position and a second position to alter a flow area of the flow of fluid moving through the tubular. The method includes detecting a change in a downhole attribute that changes in response to the alteration of the flow area of the flow of fluid. Sensors positioned within or in communication with an interior of the tubular can detect the change in the downhole attribute. The method further includes determining a flow rate of the flow of fluid based on the detected change in the downhole attribute.

Abstract: A wellbore optical fiber measurement system for measuring data in a lateral wellbore that includes a flexible optical fiber. The optical fiber includes a waveguide coated with a coating, wherein the optical fiber has an effective density ?efffiber and an effective axial Young modulus Eefffiber and wherein the product ( ? eff f ? i ? b ? e ? r E eff f ? i ? b ? e ? r ) · ( 1 - ? w ? a ? t ? e ? r ? eff f ? i ? b ? e ? r ) is greater than 50 kg/m3/GPa. The system also includes a data acquisition unit with a processor operable to obtain strain measurement data of the wellbore from the optical fiber.

Abstract: A system for downhole measurements. The system may comprise a fiber optic cable that further comprises a transmission fiber and a return fiber. Additionally, the system may comprise a passive optical device optically connected to the transmission fiber and the return fiber, a first wavelength division multiplexer (WDM) optically connected to the transmission fiber, and a second WDM optically connected to the return fiber. The system may further comprise a transmitter and a first Raman pump optically connected to the first WDM and a receiver and a second Raman pump optically connected to the second WDM.

Abstract: A method is provided. Sensor data regarding a wellbore is received from at least one of a distributed fiber optic sensing line positioned along the wellbore and a plurality of subsurface and surface sensors. Flow models are generated based on the sensor data to optimize production flow. Flow profiles are generated based on the flow models and the sensor data to adjust at least one gas lift valve.

Abstract: Aspects of the subject technology relate to systems and methods for optimizing production flow monitoring by utilizing data driven in-situ injection. Systems and methods are provided for receiving sensor data from at least one of a distributed fiber optic sensing line positioned along a wellbore and a plurality of subsurface and surface sensors, generating flow models based on the sensor data received from the at least one of the distributed fiber optic sensing line and the plurality of subsurface and surface sensors to optimize production flow, and generating flow profiles based on the flow models and the sensor data received from the at least one of the distributed fiber optic sensing line and the plurality of subsurface and surface sensors to adjust zonal inflow device.

Abstract: A wellbore system includes a wellbore tubular with local inner diameter variation. The system includes a wellbore tubular that is positionable in a wellbore for producing hydrocarbon fluid. The wellbore tubular includes at least one portion of an inner wall with a greater inner diameter than other portions of the inner wall of the wellbore tubular. The system includes a fiber optic cable of a fiber optic sensing system that is positionable in the wellbore for measuring flow disturbance of production fluid at the at least one portion of the inner wall to monitor hydrocarbon production flow.

Abstract: The way in which a fiber optic cable is wrapped around a casing string in a wellbore can be modeled using information from downhole sensor devices. For example, a system can include a fiber optic cable located along a length of a wellbore. The system can also include sensor devices located near the fiber optic cable at various depths to transmit acoustic signals indicating depths and orientations of segments of the fiber optic cable. The system can build a model describing how the fiber optic cable is positioned around the casing string based on the acoustic signals transmitted from the sensor devices. The system can also determine a target position for a perforating gun to perform a perforation operation through the casing string that avoids damaging the fiber optic cable. The system can output the target position for the perforating gun to an electronic device to facilitate the perforation operation.

Abstract: A method for determining a flow rate of a fluid includes positioning a tubular within a wellbore formed in a subsurface formation, wherein a flow of fluid is to move through the tubular. An orifice plate is positioned in the tubular. The orifice plate is movable between a first position and a second position to alter a flow area of the flow of fluid moving through the tubular. The method includes detecting a change in a downhole attribute that changes in response to the alteration of the flow area of the flow of fluid. Sensors positioned within or in communication with an interior of the tubular can detect the change in the downhole attribute. The method further includes determining a flow rate of the flow of fluid based on the detected change in the downhole attribute. The flow of fluid may be single phase or multiphase.

Abstract: A partially dissolvable plug is to be deployed in a position in a wellbore formed in a subsurface formation. The partially dissolvable plug comprises a first portion comprising a dissolvable material that is to dissolve over time after exposure to a downhole ambient environment in the wellbore and a second portion comprising a non-dissolvable material that is to create a flow restriction as the flow of fluid passes through the partially dissolvable plug. The first portion is to prevent a flow of fluid from downhole to a surface of the wellbore until at least a portion of the dissolvable material is dissolved. A flow rate is to be determined based on a detected change in a downhole attribute that is to change in response to the flow of fluid passing through the partially dissolvable plug after at least a portion of the partially dissolvable plug is dissolved.

Abstract: A distributed fiber sensing system and method of use. The system may comprise an interrogator configured to receive a Brillouin backscattered light from a first sensing region and a second sensing region, a first fiber optic cable optically connected to the interrogator, a proximal circulator, and a distal circulator, and a second fiber optic cable optically connected to the interrogator, the proximal circulator, and the distal circulator. The system may further comprise a downhole fiber optically connected to the first fiber optic cable and the second fiber optic cable and wherein the first sensing region and the second sensing region are disposed on the downhole fiber. The method may comprise generating and launching a light pulse from an interrogator and through a first fiber optic cable to a downhole fiber and receiving a Brillouin backscattered light from a first sensing region and a second sensing region.