Abstract: A cement swell packer includes a base tubular that includes at least one end connection; a cement swell assembly configured to mount on the base tubular and including a portion of a dry cementitious material configured to form a hardenable or curable cement when exposed to a fluid in a wellbore, and a mesh configured to hold the portion of the dry cementitious material; and a liquid barrier formed over the dry cementitious material.

Abstract: A well system includes a local controller communicably coupled to a hydraulic diverter configured to control a well shut-in assembly at a well site operable to shut in a wellbore based on a command from the local controller or to shut in or open the wellbore based on a command from a control panel at or in a vicinity of the well site. The well system includes a remote controller located at a location remote from the local controller and the well site and configured to communicate a wireless signal to the local controller to initiate the command from the local controller. The well system includes the hydraulic diverter fluidly coupled to the well shut-in assembly. The hydraulic diverter is configured to, based on the command from the local controller, control the well shut-in assembly to shut in the wellbore and render the command from the control panel irrelevant.

Abstract: A well system includes a local controller communicably coupled to a hydraulic diverter configured to control a well shut-in assembly at a well site operable to shut in a wellbore based on a command from the local controller or to shut in or open the wellbore based on a command from a control panel at or in a vicinity of the well site. The well system includes a remote controller located at a location remote from the local controller and the well site and configured to communicate a wireless signal to the local controller to initiate the command from the local controller. The well system includes the hydraulic diverter fluidly coupled to the well shut-in assembly. The hydraulic diverter is configured to, based on the command from the local controller, control the well shut-in assembly to shut in the wellbore and render the command from the control panel irrelevant.

Abstract: A mud flow measurement system includes a flow pipe, a Coriolis meter, a differential pressure sensor, and a mud flow measurement module. The mud flow measurement module is configured to select a calibration curve corresponding to a drilling mud injected into the well, determine a measured density based on the signal from each of the vibration sensors and the selected calibration curve, determine a differential pressure across the Coriolis meter from the differential pressure sensor, and compute a calculated mass flow rate, Qmass, of the multiphase mud flow using equation Q mass = C d ? A t 1 - ? 4 ? 2 ? ? * ? ? P , where Cd is a calibration constant, At is a cross-sectional area of the measurement tube, ? is a ratio of the internal diameters of the flow pipe the measuring tube, ? is the density of the multiphase mud, and ?P is the differential pressure across the Coriolis meter, where ? is the measured density determined from the Coriolis meter.

Abstract: An apparatus includes a first body, a second body, a shear pin, and a divider. The first body includes a coupling. The second body includes a cutter blade. The shear pin is configured to hold the position of the second body relative to the first body in an open position. The coupling is configured to couple the first body to the second body in a closed position. In the open position, the apparatus defines first and second flow paths for fluids and solids to pass through the apparatus. The first flow path is defined through the first body and through an inner bore of the divider. The second flow path is defined through the first body and through an annulus surrounding the divider. In the closed position, the second flow path is closed, such that solids remain in the annulus surrounding the divider.

Abstract: The present disclosure describes methods and systems, including computer-implemented methods, computer program products, and computer systems, for monitoring the flow of drilling mud from a wellbore by image processing. One method includes: capturing, using a digital imaging device, images of drilling mud at a surface of the wellbore as the drilling mud flows through one or more image capture zones of a circulation system that circulates drilling mud through the wellbore and a wellbore drilling assembly; receiving, by one or more processors of a computer system operatively coupled to the digital imaging device, the images captured by the digital imaging device; and processing, by the one or more processors, the images captured by the digital imaging device to determine a rate of flow of the drilling mud through the one or more image capture zones.

Abstract: Systems include a floating device disposed on a top of a column of drilling fluid in an annulus of a wellbore. The floating device includes a capsule. A transmitter or a reflector may be coupled to the capsule. The floating device may transmit signals to a surface region from the annulus or receive signals from the surface region and reflect at least a portion of the received signals. A receiver in the surface region receives transmitted signals or reflected signals from the floating device and determines a distance between the floating device and a reference point in the surface region. The distance indicates a level of the drilling fluid in the annulus.

Abstract: System and methods for delivering objects formed of a solid material into a circulation fluid of a subterranean well include a volume transfer container. The volume transfer container has an inlet port, an outlet port, and a charge access opening sized to provide for the filling of the volume transfer container with the objects. A discharge line extends from a pump assembly to the volume transfer container. A transfer line extends from the volume transfer container to the drilling assembly, providing a fluid flow path from the volume transfer container to the drilling assembly that is free of any pump.

Abstract: A mud flow measurement system includes a flow pipe, a Coriolis meter, a differential pressure sensor, and a mud flow measurement module. The mud flow measurement module is configured to select a calibration curve corresponding to a drilling mud injected into the well, determine a measured density based on the signal from each of the vibration sensors and the selected calibration curve, determine a differential pressure across the Coriolis meter from the differential pressure sensor, and compute a calculated mass flow rate, Qmass, of the multiphase mud flow using equation Q mass = C d ? A t 1 - ? 4 ? 2 ? ? * ? ? P , where Cd is a calibration constant, At is a cross-sectional area of the measurement tube, ? is a ratio of the internal diameters of the flow pipe the measuring tube, ? is the density of the multiphase mud, and ?P is the differential pressure across the Coriolis meter, where ? is the measured density determined from the Coriolis meter.

Abstract: A method includes receiving, by a computer system, a video of a visible state of a component of a generator, the generator powering at least a portion of a rig equipment system at a wellsite. The computer system can determine an operational parameter based on the visible state of the component of the generator imaged in the video, and can transmit the operational parameter to an output device.

Abstract: Analysis of drilling slurry solids by image processing includes receiving images of a solid slurry including a mixture of wellbore drilling mud and solid objects found in the wellbore while drilling the wellbore through a subterranean zone. The solid objects include drill cuttings and non-drilled solids. By implementing image processing techniques on the images, the solids in the solid slurry are classified a drill cutting or as a non-drilled solid.

Abstract: System and methods for delivering objects formed of a solid material into a circulation fluid of a subterranean well include a volume transfer container. The volume transfer container has an inlet port, an outlet port, and a charge access opening sized to provide for the filling of the volume transfer container with the objects. A discharge line extends from a pump assembly to the volume transfer container. A transfer line extends from the volume transfer container to the drilling assembly, providing a fluid flow path from the volume transfer container to the drilling assembly that is free of any pump.

Abstract: An apparatus includes a first body, a second body, a shear pin, and a divider. The first body includes a coupling. The second body includes a cutter blade. The shear pin is configured to hold the position of the second body relative to the first body in an open position. The coupling is configured to couple the first body to the second body in a closed position. In the open position, the apparatus defines first and second flow paths for fluids and solids to pass through the apparatus. The first flow path is defined through the first body and through an inner bore of the divider. The second flow path is defined through the first body and through an annulus surrounding the divider. In the closed position, the second flow path is closed, such that solids remain in the annulus surrounding the divider.

Abstract: One or more images of a tubular being run into a well are captured. The one or more images can be captured by an image sensor. The tubular includes a first tubular section and a second tubular section connected together by a connection. An onsite edge gateway local to the image sensor is configured to perform various operations. Based on the captured one or more images, an elevation of the connection relative to a reference elevation of the well is determined. Based on the determined elevation, an operating condition is determined. It is determined whether the operating condition is included in an automation rule. In response to determining that the automation rule includes the operating condition, a signal is transmitted to drive a controllable device.

Abstract: A method for determining a slips status during a drilling operation of a subterranean formation. The method includes capturing, using one or multiple camera devices mounted on a drilling rig of the drilling operation, a plurality of images, each of the plurality of images comprising a portion that corresponds to a slips device of the drilling rig, generating, using a sensor device of the drilling rig, a plurality of parameters of the drilling rig, wherein the plurality of parameters are synchronized with the plurality of images, providing, by a computer processor, the plurality of parameters as input to a machine learning model of the drilling rig, and analyzing, by the computer processor and based on the machine learning model, the plurality of images to generate the slips status.

Abstract: A monitoring system includes an image sensor positioned about a rig, the image sensor directed at a drill string component positioned on the rig, and an onsite gateway communicably coupled to the image sensor and disposed proximate to the rig. The onsite gateway includes one or more processors, and a non-transitory computer-readable storage medium coupled to the one or more processors and storing programming instructions for execution by the one or more processors. The programming instructions instruct the one or more processors to receive an image stream of the drill string component from the image sensor, identify an operating parameter of the drill string component, generate an operating condition of the drill string component, determine that the generated operating condition meets a failure threshold of the drill string component, and send an instruction to drive a controllable device.

Abstract: Disclosed are methods, systems, and computer-readable medium to perform operations including: capturing, using an image sensor directed at a drilling system, an image feed of movement of a component of the drilling system with respect to a vertical reference line; converting the image feed into a digital representation of the movement of the component, the digital representation including a number of offset pixels from the component to the vertical reference line in the image feed; converting the digital representation into a machine learning (ML), the ML representation including a plurality of vectors each including the number of offset pixels from the component to the vertical reference line at a respective time; training a ML model using the ML representation to characterize the movement of the component as normal or abnormal; and using the trained ML model to characterize the movement of the component in real-time as normal or abnormal.

Abstract: Systems and methods for determining rheology characteristics of a drilling fluid include a drop-in unit sized to fit within a flowline of a drilling fluid circulation system upstream of a mud shaker. The drop-in unit has an entry funnel having an end plate with an opening through the end plate. The entrance of the entry funnel has an outer diameter that is larger than a diameter of the opening through the end plate. An instrumentation tubular is an elongated member with an inner bore that is in fluid communication with the opening through the end plate. The instrumentation tubular includes a downstream sensor and an upstream sensor. The upstream and downstream sensors are operable to sense a parameter of the drilling fluid traveling through the instrumentation tubular for calculating a change of viscosity of the drilling fluid within the flowline between a first time and a second time.

Abstract: A fast-acting managed pressure drilling rig is disclosed. A main valve configured as an alternative for a conventional rotating control device is provided to control drilling of a wellbore. A second valve is configured to trap pressure in the wellbore. A choke valve maintains well bottomhole pressure within specified limits by trapping pressure or by releasing trapped pressure within the wellbore. A pressure relief choke is configured to provide fine pressure stability control within the well and to act as a pressure relief valve in response to wellbore overpressure. A controller is configured with at least one processor to affect operation of the main valve, the second ratio valve, the choke valve, and the pressure relief choke in response to information received by the controller representing operation of the managed pressure drilling rig.

Abstract: A method includes receiving, by a computer system, a video of a visible state of a component of a generator, the generator powering at least a portion of a rig equipment system at a wellsite. The computer system can determine an operational parameter based on the visible state of the component of the generator imaged in the video, and can transmit the operational parameter to an output device.