Abstract: A system for monitoring fluid flow conditions on a return flow line including a return flow line in fluid communication with a wellbore, a shaker, and a header box. The system includes a contactless flow sensor facing an interior of the header box or an outlet of the return flow line, a data gathering and analyzing unit coupled to the contactless flow sensor, and a control panel to display data and notify when hazardous conditions occur. A method for monitoring fluid flow conditions on a return flow line including flowing a drilling mud into the header box through the return flow line and monitoring the height of the drilling mud in the header box and/or return flow line to determine the fluid level using the contactless flow sensor. The fluid level is used to determine a fluid flow rate and indicate a current operational or a hazardous operational status.

Abstract: A system including a plug with a first end connected to a lower drill string and a second end connected to an upper drill string. The plug further includes a sealing element configured to seal against a reservoir pressure that is downhole from the plug, and an anchoring element configured to releasably couple the plug to a wellbore to disallow an axial movement of the plug in the wellbore. The plug is configured to couple to a retrieving tool. The retrieving tool includes a first engagement element configured to release the anchoring element, thereby allowing axial movement of the plug and retrieval of the upper drill string in order to shut in the wellbore.

Abstract: A method and a system for reducing the risk of dopped string through the implementation of image processing are disclosed. The method includes obtaining a plurality of images of a rotary table, a lower elevator latching position, and an upper elevator position from a rig and analyzing the plurality of images of the rotary table, the lower elevator latching position, and the upper elevator position with an artificial intelligence (AI) model to detect a type of the elevators and a latching string component. Further, an operability of the elevators and an operability of the latching string component, and a compatibility between the latching string component and the elevators are determined. Additionally, an instruction based on the determined compatibility is generated, the instruction allowing a latching process to continue or initiating an interlock to stop the latching process.

Abstract: An autonomous inflow control device includes a body defining a cavity. An inlet is in fluid communication with the cavity. The inlet receives well fluids. A deflection surface within the cavity deflects the well fluids at an angle based on a predetermined fluid property range of the well fluids. An influx outlet is in fluid communication with the cavity. An actuation device is disposed in the cavity and based on the angle the well fluids deflect off the deflection surface, the actuation device moves between an open position and a closed position. In the closed position, the actuation device covers the influx outlet. In the open position, the actuation device exposes the influx outlet to direct a volume of water from the well fluids out of the cavity. An outlet is in fluid communication with the cavity to direct the well fluids out of the cavity.

Abstract: A method repairing lost circulation conditions during drilling operations, including deploying a deployment tool to a lost circulation zone, charging the deployment tool with eutectic metal alloy pellets, activating a heater to melt the pellets through the deployment tool and out of the crucible onto the targeted zone to form a patch, removing the deployment tool, and milling away excess cooled and cured eutectic metal alloy.

Abstract: Embodiments disclosed herein relate to a conformal multilayer soft shell apparatus and a system to make a downhole connection between an electric power supply, a conformal multilayer soft shell apparatus, and a downhole system requiring power. The conformal multilayer soft shell apparatus may include an innermost layer with one or more electrically conductive materials, a number of middle layers, and a protective outermost layer.

Abstract: An apparatus for downhole electrical connection includes: a heater adapted to convert electric energy to thermal energy to liquefy a piece of electronically conductive material; a first electrical circuitry connected to the heater and a power source; a first assembly in which a first connector is disposed; and a second assembly in which a second connector is disposed. The apparatus is configured to: deploy the first assembly and the second assembly in a tubing in a wellbore; mechanically mate the first connector and the second connector; control the electric energy provided from the first electrical circuitry to the heater; electrically connect the first connector and the second connector by soldering the first connector and the second connector with the piece of electronically conductive material; and electrically disconnect the heater from the first electrical circuitry after the soldering.

Abstract: A system for determining a flow rate of a fluid in a well includes an electrical submersible pump disposed in the well, a motor disposed on the electrical submersible pump, and a downhole sensor module connected to the motor. The electrical submersible pump includes a vertical axis. The system includes a metering module extending from the downhole sensor module including a plurality of dynamic pressure sensors along the vertical axis. The plurality of dynamic pressure sensors are connected to an outer diameter of the metering module. The plurality of dynamic pressure sensors are configured to measure a pressure fluctuation of the fluid. The system includes a processor configured to receive data from the plurality of dynamic pressure sensors and determine the flow rate of the fluid based on the received data.

Abstract: A method for determining a bulk velocity and a mixture speed of sound of a multi-phase fluid flowing in a pipe of a pipeline. The method includes the steps: obtaining a plurality of pressure signals from a plurality of pressure sensors, where each pressure sensor in the plurality of pressure sensors includes a diaphragm for sensing pressure, where the diaphragm of each pressure sensor is aligned with an inner wall of the pipe such that each pressure sensor is flush-mounted on the inner wall of the pipe; determining, using the plurality of pressure signals, a first time-of-flight of one or more flow eddies; determining, using the plurality of pressure signals, a second time-of-flight of one or more sound waves; determining, using the first time-of-flight, the bulk velocity of the multi-phase fluid; and determining, using the bulk velocity and the second time-of-flight, the mixture speed of sound of the multi-phase fluid.

Abstract: A method and a system to perform a wellhead maintenance process are disclosed. The wellhead maintenance process includes digitizing data records of wellhead valve greasing operations, automatic well and wellhead valve data recognition and verification, automatic generation of greasing operation volume recommendations, and generating advanced greasing operation analytics. A portable microcontroller device is used for geolocating and timestamping the digital maintenance records of the wellhead valve greasing operation to improve operation efficiency and automation as well as compliance audit verification.

Abstract: A system includes a retrieving tool component with a first engagement element disposed at a first radial distance from a retrieving tool centerline. The system includes an uphole component comprising a second engagement element. The system includes a downhole component coupled to the uphole component and releasably connected to a wellbore. The retrieving tool component is configured to retrieve the uphole component and the downhole component from the wellbore using a connection component to release an axial lock thereby allowing an axial movement of the downhole component out of the wellbore.

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 chemical dispenser system includes a Y-tool secured to a toolstring via a Y-block, the Y-tool comprising a bypass line and a pump line, where the bypass line and the pump line are fluidly connected to the toolstring at an upper end of the Y-block and where the pump line and the bypass line are arranged parallel to each other. The chemical dispenser system further includes an electrical submersible pump provided in the pump line, inhibitor chemicals held within one or more pressure retaining chambers in the bypass line, and a blanking plug landed in the bypass line.

Abstract: A drilling tractor tool in a drill string includes a rotating mandrel having an engagement part configured to rotate with the drill string; and a static sleeve disposed on the rotating mandrel configured to remain stationary during rotation of the rotating mandrel. The static sleeve includes a plurality of pockets that form a pathway from an interior of the static sleeve to an exterior of the static sleeve. The drilling tractor tool includes a plurality of force applicators each disposed in a respective pocket of the plurality of pockets of the static sleeve. The plurality of force applicators configured to extend through the respective pocket and apply a forward thrust to the drill string when extended. The engagement part of the rotating mandrel is configured to contact and cause to extend each of the plurality of force applicators respectively as the rotating mandrel rotates.

Abstract: A mechanical autonomous pipe cutting system for cutting a pipe in a wellbore includes a locking unit that prevents the system from moving within the pipe when engaged to an inner surface of the pipe, a punching unit that moves a plurality of punching elements radially relative to an axis of the system, and a cutting unit that is designed to sever the pipe. The locking unit, the punching unit, and the cutting unit are attached to a body of the mechanical autonomous pipe cutting system. The body includes a motor that rotates the cutting unit. The mechanical autonomous pipe cutting system further includes a sensor module that detects interactions between the pipe and walls of the wellbore and a control unit in electronic communication with the sensor module, the locking unit, and the punching unit.

Abstract: A test fixture includes a cylindrical main body extending in a longitudinal direction that receives a test piece. The main body includes a cylindrical screen filter with a mesh surface that extends in along a longitudinal axis coincident with an axis of the main body. The mesh surface generates a filter cake when particle-entrained fluid is supplied through the mesh surface and the particulate is retained on the mesh surface. The main body also includes an offset shaft that extends in the longitudinal direction along an offset axis that is offset from the axis of the main body, and the test piece extends through the offset shaft and the interior of the screen filter. The main body further includes a bearing that decouples rotational motion of the offset shaft from the end cap.

Abstract: A solids trap module for an electrical submersible pump (ESP) of a wellbore is provided. The module includes a solids buffer and a fluid passage, the fluid passage having a first segment configured to redirect a fluid in a first angular direction relative to an axial axis, and a second segment configured to redirect at least a portion of the redirected fluid flow in a second angular direction different than the first angular direction. The first segment, the second segment, and the solids buffer are configured to cooperate to cause settling of solids entrained by the fluid flowing through the solids trap module during a period when the ESP does not operate and to re-entrain settled solids into the fluid flowing through the solids trap module when the ESP is operating.

Abstract: A drilling tractor tool in a drill string includes a rotating mandrel having an engagement part configured to rotate with the drill string; and a static sleeve disposed on the rotating mandrel configured to remain stationary during rotation of the rotating mandrel. The static sleeve includes a plurality of pockets that form a pathway from an interior of the static sleeve to an exterior of the static sleeve. The drilling tractor tool includes a plurality of force applicators each disposed in a respective pocket of the plurality of pockets of the static sleeve. The plurality of force applicators configured to extend through the respective pocket and apply a forward thrust to the drill string when extended. The engagement part of the rotating mandrel is configured to contact and cause to extend each of the plurality of force applicators respectively as the rotating mandrel rotates.

Abstract: An oil slinger apparatus includes a metal disc having a center annulus and an outer annulus disposed on a motor. The center annulus comprises a space between an inner diameter and an outer diameter with at least one feed hole in the space. The oil slinger apparatus includes an impeller imprint on the outer annulus with a vane around each of the at least one feed hole; and a keyway disposed on the metal disc configured to fit a key for aligning the oil slinger to the motor.

Abstract: A method for determining flow rates and phase fractions within a throughbore is disclosed. The method includes providing a mixture of one or more fluids through a fluid flow path in a throughbore at a flow rate, reducing the flow rate, slidably moving a first and second sleeve along the throughbore to a first position of a plurality of positions, measuring a first and second differential pressure at the first position, calculating a first loss pressure ratio from the first and second differential pressure. The method further includes slidably moving the first sleeve and second sleeve to each of the others of the plurality of positions in succession after the first position, measuring a plurality of differential pressures and calculating a loss pressure ratio at each of the plurality of positions, and calculating a plurality of flow rates phase fractions of the fluids flowing through the fluid flow path.