Abstract: A lost circulation system and a method for reducing losses of drilling fluid in a lost circulation zone of a wellbore are described. The lost circulation system includes a sheet of lost circulation material and particles of a lost circulation material. The sheet of lost circulation material has a maximum thickness of 1 millimeter, a length of one foot to one thousand feet, and a width of one inch to twenty inches. The method for reducing losses of drilling fluid in a lost circulation zone of a wellbore includes identifying the lost circulation zone, deploying a sheet of a first lost circulation material in the wellbore at the lost circulation zone, and circulating a slurry containing particles of the lost circulation material through the wellbore.

Abstract: A system including one or more hardware processors for automatic evaluation of a cutting element in a wear testing device. The system includes an access module to access cutting element event analysis results from a sensor array. The system further includes a first model trained to classify a cutting element event of the cutting element according to a supervised machine learning algorithm, and output a predicted event type of the cutting element event. The system further includes a second model trained to classify a cutting element event of the cutting element according to an unsupervised machine learning algorithm, and output a predicted behavior of the cutting element event. The system further includes a controller to determine a toughness and a wear resistance of the cutting element. The system also includes an output module to generate and display a work order on a user interface of a client device.

Abstract: A testing device that includes a wear testing device, a sensor array, and a controller. The wear testing device includes a sample rotation element configured to hold and to rotate a sample; and a cutting element holder configured to hold a cutting element and to engage the cutting element with the sample as the sample rotates. The sensor array includes an acoustic emissions (AE) sensor array comprising a plurality of AE sensors, the plurality of AE sensors configured to measure a plurality of acoustic signals generated during engagement between the cutting element and the sample; and a load sensor. The controller is communicably connected to the sensor array and configured to determine a toughness and a wear resistance of the cutting element using the plurality of acoustic signals, the applied load, and a wear state of the cutting element.

Abstract: A testing device that includes a wear testing device, a sensor array, and a controller. The wear testing device includes a sample rotation element configured to hold and to rotate a sample; and a cutting element holder configured to hold a cutting element and to engage the cutting element with the sample as the sample rotates. The sensor array includes an acoustic emissions (AE) sensor configured to measure an acoustic signal generated during engagement between the cutting element and the sample; and a load sensor. The controller is communicably connected to the sensor array and configured to determine a toughness and a wear resistance of the cutting element using the acoustic signal, the applied load, and a wear state of the cutting element.

Abstract: A drilling tool for drilling a wellbore in a formation, where the drilling tool includes: a drill bit comprising a cutting element, a sensor array, and a controller. The sensor array includes: an acoustic emissions (AE) sensor configured to measure an acoustic signal generated during drilling of the formation by the cutting element and a load sensor configured to measure an applied load by the cutting element on the formation. The controller is communicably connected to the sensor array and configured to determine a toughness of the cutting element using the acoustic signal, the applied load, and a wear state.

Abstract: A system includes sensing modules positioned along a length of a drill string. Each sensing module includes a structure arrangement composed of an outer structure body having a cavity and an inner structure body rotatably supported within the cavity. The structure arrangement is coupled to the drill string such that rotation of the drill string produces a relative rotation between the structure bodies. Ball elements are disposed in a gap between the structure bodies and move along a predetermined path defined in the gap in response to relative rotation between the structure bodies. Movable elements are positioned to physically interact with the ball elements as the ball elements move along the predetermined path. Energy harvesters in the sensor modules generate electrical energy from the mechanical energy produced by physical interaction between the ball elements and movable elements. The sensing modules include sensors to measure parameters in the drill string environment.

Abstract: A method of deploying a flexible cable in a wellbore includes carrying, by a tubular assembly, a cable spool cartridge into the wellbore. The cable spool cartridge is attached to an exterior of the tubular assembly and contains the flexible cable. A first end of the flexible cable is attached to a buoyancy device, and the buoyancy device is releasably attached to the cable spool cartridge. A fluid is flowed by the tubular assembly in a downhole direction through an interior of the tubular assembly and in an uphole direction within an annulus at least partially defined by the exterior of the tubular assembly. The fluid has a greater density than the buoyancy device. The buoyancy device is released by the cable spool cartridge, and the buoyancy device is configured to travel after release in the uphole direction with the fluid and thereby pull the flexible cable from the cable spool cartridge and into the annulus.

Abstract: An apparatus includes an outer structure body having a cavity and an inner structure body rotatably supported within the cavity. The inner structure body has a central bore. Movable elements are positioned along the inner surface and movably coupled to the outer structure body. Ball elements are positioned along the outer surface and coupled to the inner structure body for movement with the inner structure body. The ball elements are positioned to releasably contact and impart motion to the movable elements in response to relative motion between the inner structure body and the outer structure body. A plurality of triboelectric energy harvesters are positioned to generate electrical charges when motion is imparted to the movable elements by the ball elements.

Abstract: A wellbore fluid monitoring system can implement a method while drilling a wellbore using a drilling assembly that includes a drill string, a rotary table and a bell nipple below the rotary table. Air flowing in a downhole direction through a portion of an annulus within the bell nipple below the rotary table responsive to a decrease in a liquid level in the portion of the annulus is sensed. The annulus is formed by the drill string and an inner wall of the wellbore. In response to sensing the air flowing in the downhole direction, a flow rate of the air flowing in the downhole direction over a period of time is measured. Based on the flow rate and the period of time, a volume of air flowed in the downhole direction over the period of time is determined. A liquid level relative to the rotary table is determined based on the volume of air flowed in the downhole direction over the period of time.

Abstract: Tools and methods are described to measure dimensions of wellbores. Downhole caliper tools include: a downhole collar; an uphole collar; and a caliper sensor assembly disposed between the downhole collar and the uphole collar. The caliper sensor assembly include: an annular sensor module defining a plurality of radially extending tracks; and a caliper including: a plurality of linear slide arms, each linear slide arm at least partially disposed in the annular sensor module in one of the plurality of radially extending tracks and radially moveable relative to the annular sensor module, each linear slide arm extending from a first end within the annular sensor module to a second end outside the annular sensor module, and a cover extending from the downhole collar to the uphole collar. The annular sensor module can measure the radial position of the plurality of linear slide arms relative to the annular sensor module.

Abstract: Tools and methods are described to measure dimensions of wellbores. Downhole caliper tools include a downhole collar and an uphole collar having a running position and a sensing position. The uphole collar is farther from the downhole collar in the running position than in the sensing position. A caliper sensor assembly includes: a sensor module defining tracks extending parallel to an axis of the caliper tool, the sensor module positioned towards an uphole end of the caliper tool relative to the uphole collar; and a caliper disposed between the downhole collar and the uphole collar including: a flexible mesh extending from the downhole collar to the uphole collar. Movement of the uphole collar from the running position to the sensing position axially compresses and radially expands the flexible mesh. The annular sensor module can measure dimensions of the flexible mesh relative to the axis of the caliper tool.

Abstract: A method includes utilizing a charging and communication interface and a sensor system to gather downhole measurements. The method further includes charging and activating the sensor system using the charging and communication interface, installing the sensor system into a nozzle of a drill bit, running the drill bit into a wellbore, conducting measurements using the sensor system, pulling the drill bit out of the wellbore, and contacting the charging and communication interface with the sensor system to retrieve the measurements from the sensor system.

Abstract: A system for gathering downhole measurements includes a drill bit, at least one nozzle receptacle located on the drill bit, and a sensor system. The sensor system has a sensor housing, a flow path extending through the sensor housing, wherein the flow path allows fluid to flow through the sensor housing, and an internal cavity provided within the sensor housing separate from the flow path. The internal cavity contains components that include at least one sensor for gathering data about drill bit conditions and downhole conditions, a powering unit, a printed circuit board, and an electrical conductor, wherein the sensor housing is installed in the at least one nozzle receptacle.

Abstract: Bottom hole assemblies for deploying fabric can include: a body configured to be attached to a drill pipe; a control tube disposed inside the body at a position controlled by engagement of a cam with a continuous guide path; a set tube, the set tube and the body together defining a pressure chamber with the body defining an inlet port extending between the interior cavity and pressure chamber, the set tube movable between a rolling position and a reaming position; a reamer assembly with at least one first articulated arm with extending between first attachment point on the body and the set tube; and a roller assembly with: at least one second articulated arm extending between the set tube and a second attachment point on the body; and a roller positioned at a joint of each second articulated arm.

Abstract: A wellbore fluid monitoring system includes a housing, a first sealing element, a second sealing element and a sealing unit. The housing is configured to be securely disposed in a portion of an annulus within a bell nipple below a rotary table of a wellbore drilling assembly. The annulus is formed by a drill string of the wellbore drilling assembly and an inner wall of a wellbore being drilled by the wellbore drilling assembly. The housing includes a first open end and a second open end. The housing is configured to house an air flow sensor disposed within the housing. The first sealing element is attached to the first open end of the housing. The first sealing element is configured to seal and unseal the first open end. The second sealing element is attached to the second open end of the housing. The second sealing element is configured to seal and unseal the second open end. The sealing unit is disposed in the portion of the annulus.

Abstract: Systems and methods for managing a loss circulation zone in a subterranean well include a tool housing located on a surface of a tubular member with a tool cavity that is an interior open space within the tool housing. An electromechanical system is located within the tool cavity and has a printed circuit board, a microprocessor, a sensor system, a power source, and a communication port assembly. A release system can move a deployment door of a deployment opening of the tool housing between a closed position and an open position. The deployment opening can provide a flow path between the tool cavity and an outside of the tool housing. The release system is actuable autonomously by the electromechanical system. A releasable product is located within the tool cavity and can travel through the deployment opening when the deployment door is in the open position.

Abstract: Systems, methods, and apparatuses for deploying a lost circulation fabric (LCF) to seal a lost circulation zone during a drilling operation. The LCF may be contained within a lost circulation fabric deployment system (LCFDS) that is coupled to a tubular of a drilling string. The LCFDS may include a controller and sensors to detect the presence of a lost circulation zone and deploy the LCF upon detection of the lost circulation zone. In some implementations, a plurality of LCFDSs may be disposed on the tubular and work in cooperation to deploy a plurality of LCFs to form a seal along the lost circulation zone.

Abstract: A drill bit having a rotatable ball bit includes a first bit head and a second bit head, a first set of cutters on the first bit head, and a second set of cutters on the second bit head. The rotatable ball bit is configured to rotate between a first position and a second position, wherein the first bit head is distal to the second bit head in the first position, and wherein the second bit head is distal to the first bit head in the second position. A method of operating a rotatable ball bit includes orienting the rotatable ball bit in a first position, wherein a first bit head is oriented distally, rotating the rotatable ball bit about a longitudinal axis, orienting the rotatable ball bit in a second position, wherein a second bit head is oriented distally, and rotating the rotatable ball bit about the longitudinal axis.

Abstract: An apparatus includes an outer structure body having a cavity and an inner structure body rotatably supported within the cavity. The inner structure body has a central bore. Movable elements are positioned along the inner surface and movably coupled to the outer structure body. Ball elements are positioned along the outer surface and coupled to the inner structure body for movement with the inner structure body. The ball elements are positioned to releasably contact and impart motion to the movable elements in response to relative motion between the inner structure body and the outer structure body. A plurality of triboelectric energy harvesters are positioned to generate electrical charges when motion is imparted to the movable elements by the ball elements.

Abstract: A system includes sensing modules positioned along a length of a drill string. Each sensing module includes a structure arrangement composed of an outer structure body having a cavity and an inner structure body rotatably supported within the cavity. The structure arrangement is coupled to the drill string such that rotation of the drill string produces a relative rotation between the structure bodies. Ball elements are disposed in a gap between the structure bodies and move along a predetermined path defined in the gap in response to relative rotation between the structure bodies. Movable elements are positioned to physically interact with the ball elements as the ball elements move along the predetermined path. Energy harvesters in the sensor modules generate electrical energy from the mechanical energy produced by physical interaction between the ball elements and movable elements. The sensing modules include sensors to measure parameters in the drill string environment.