Abstract: One example of a downhole self-isolating wellbore drilling system to pulverize formation cuttings includes a cutting grinder tool and an isolation tool. The cutting grinder tool can be attached to a drill string uphole relative to a drill bit attached to a downhole end of the drill string. The cutting grinder tool can receive and pulverize formation cuttings resulting from drilling a formation using the drill bit. The isolation tool can be attached to the drill string uphole relative to the cutting grinder tool. The isolation tool can control flow of the pulverized formation cuttings mixed with a drilling mud uphole through the drill string.

Abstract: One example of a downhole self-isolating wellbore drilling system to pulverize formation cuttings includes a cutting grinder tool and an isolation tool. The cutting grinder tool can be attached to a drill string uphole relative to a drill bit attached to a downhole end of the drill string. The cutting grinder tool can receive and pulverize formation cuttings resulting from drilling a formation using the drill bit. The isolation tool can be attached to the drill string uphole relative to the cutting grinder tool. The isolation tool can control flow of the pulverized formation cuttings mixed with a drilling mud uphole through the drill string.

Abstract: One example of a downhole self-isolating wellbore drilling system to pulverize formation cuttings includes a cutting grinder tool and an isolation tool. The cutting grinder tool can be attached to a drill string uphole relative to a drill bit attached to a downhole end of the drill string. The cutting grinder tool can receive and pulverize formation cuttings resulting from drilling a formation using the drill bit. The isolation tool can be attached to the drill string uphole relative to the cutting grinder tool. The isolation tool can control flow of the pulverized formation cuttings mixed with a drilling mud uphole through the drill string.

Abstract: One example of a downhole self-isolating wellbore drilling system to pulverize formation cuttings includes a cutting grinder tool and an isolation tool. The cutting grinder tool can be attached to a drill string uphole relative to a drill bit attached to a downhole end of the drill string. The cutting grinder tool can receive and pulverize formation cuttings resulting from drilling a formation using the drill bit. The isolation tool can be attached to the drill string uphole relative to the cutting grinder tool. The isolation tool can control flow of the pulverized formation cuttings mixed with a drilling mud uphole through the drill string.

Abstract: A drilling system has a drill string that is made up of tubular segments of coiled tubing joined together by connectors. The connectors can be selectively changed between locked and unlocked configurations. When in the unlocked configuration adjacent tubular segments rotate with respect to one another, and when in the locked configuration the tubular segments are rotationally affixed. The connectors include clutch members coupled to each tubular segment, that axially slide into a slot formed in an adjacent tubular segment to rotationally lock the adjacent segments. A Kelly bushing and rotary table rotate the drill string; and an injector head is used to insert the drill string through the Kelly bushing and rotary table and into a wellbore. While the drill string is inserted through the bushing and table, the connectors are set into the locked configuration so that all tubular segments from the rotary table downward are rotationally affixed.

Abstract: A liner assembly tool includes a base tubular that includes a bore therethrough; a wellbore liner that includes a liner top and is coupled to the base tubular; a pack-off element radially positioned between the base tubular and the wellbore liner to ride on the base tubular; and a wedge positioned to ride on the base tubular and expand the pack-off element to at least partially seal the liner top to a wellbore wall based on a particular fluid pressure supplied through the bore.

Abstract: A downhole tool system includes a base tubular that includes a bore therethrough; a centralizer positioned to ride on the base tubular, the centralizer expandable to contact a wellbore wall and adjust a location of the downhole tool system relative to the wellbore wall based on a first fluid pressure supplied through the bore; and a liner top assembly positioned to ride on the base tubular, the liner top assembly including a wellbore liner and a pack-off element, the pack-off element expandable to at least partially seal a liner top of the wellbore liner to the wellbore wall based on a second fluid pressure supplied through the bore.

Abstract: A lateral wellbore is formed from a high side of a horizontal portion of a primary wellbore with a drill bit assembly that has a selectively extendable pilot bit. The drill bit assembly is mounted on a lower end of a drill string. A bit guide is disposed adjacent the drill bit assembly for urging the drill bit assembly in a lateral direction against the high side of the primary wellbore. Rotating the drill bit assembly while urging the drill bit assembly upward creates a groove in a subterranean formation adjacent the primary wellbore. This forms a ledge at a far end of the groove. The drill string is then drawn back from the groove, and the pilot bit is deployed. Urging the drill bit assembly forward engages the pilot bit with the ledge, providing leverage for retaining the drill bit assembly in an orientation for excavating the lateral wellbore.

Abstract: A wellbore tool centralizer includes a housing that includes a bore to receive a wellbore tubular; an expandable element radially mounted to the housing; and a fluid pathway that extends through the housing to fluidly connect the bore and the expandable element and expose the expandable element to a fluid pressure sufficient to radially expand the expandable element.

Abstract: A downhole tool for use in a multilateral wellbore includes a guide member on one end that selectively projects into a designated wellbore, where the designated wellbore can be a motherbore or a lateral wellbore. Pistons are set radially in a body of the tool that selectively push against an end of the guide member to pivot it into a designated orientation to guide the tool into the designated wellbore. The pistons are hydraulically actuated when probes that are on sides of the tool body extend outward into contact with a lateral wellbore. The probes block hydraulic flow when retracted, but when deployed outward they allow fluid communication to push the pistons against the guide member.

Abstract: A bottom hole assembly carrying an expandable tubular is disposed in a portion of a wellbore having a lost circulation zone, and the tubular is radially expanded to isolate the wellbore from the formation across the lost circulation zone. The expandable tubular is made up of a rolled up sheet like member and mounts along the outer periphery of a portion of the bottom hole assembly. A bladder on the bottom hole assembly is inflated for expanding the tubular radially outward against the wellbore wall. A drill bit and underreamer are included with the bottom hole assembly.

Abstract: A lateral wellbore is formed from a high side of a horizontal portion of a primary wellbore with a drill bit assembly that has a selectively extendable pilot bit. The drill bit assembly is mounted on a lower end of a drill string. A bit guide is disposed adjacent the drill bit assembly for urging the drill bit assembly in a lateral direction against the high side of the primary wellbore. Rotating the drill bit assembly while urging the drill bit assembly upward creates a groove in a subterranean formation adjacent the primary wellbore. This forms a ledge at a far end of the groove. The drill string is then drawn back from the groove, and the pilot bit is deployed. Urging the drill bit assembly forward engages the pilot bit with the ledge, providing leverage for retaining the drill bit assembly in an orientation for excavating the lateral wellbore.

Abstract: A production system for use in a wellbore having a main bore with an axis, a lower lateral bore, and an upper lateral bore, includes a hollow whipstock with a central bore. The hollow whipstock is secured to the main bore between the lower lateral bore and the upper lateral bore. A sleeve assembly has a moveable inner sleeve with an outer diameter smaller than an inner diameter of the central bore of the hollow whipstock, and a moveable outer sleeve with an outer diameter larger than the inner diameter of the central bore of the hollow whipstock. A flow control valve is located in the main bore above the upper lateral bore. The flow control valve has an inner tubing member in selective fluid communication with the lower lateral bore and an annular conduit in selective fluid communication with the upper lateral bore.

Abstract: A downhole tool in a drill string for mitigating hazards of a blockage in an annulus of the drill string. The downhole tool can sense blockages and selectively recirculate flow from within the annulus back to surface. Further, the downhole tool is made up of segments that are selectively detachable from one another, so that the segments above the point of detachment are removable from a wellbore. The bypass assembly includes a sleeve in the downhole tool with openings in its side; when the annulus reaches a set pressure, the sleeve slides to a position so the openings register with ports formed through a side of the tool to allow bypass flow. A processor in the downhole tool senses movement of the string, and when the string is axially stationary more than a designated period of time, the processor emits signals to detach the segments.

Abstract: A loss mitigation bottom hole assembly for use in a wellbore to isolate a severe loss zone of a formation, including a drill bit for drilling a well bore, and a dual wall drill string connecting the drill bit to a fluid source, and having a first fluid passage for delivering fluid to a drill bit, and a separate second fluid passage for returning the fluid away from the drill bit. The assembly further includes a drilling liner circumscribing and attached to a bottom portion of the dual wall drill string, and surrounding the drill bit, the drilling liner having an end adjacent the drill bit to contain the fluid exiting the drill bit and prevent the fluid from entering the severe loss zone of the formation.

Abstract: A well test assembly sized for use in a slim-hole of a subterranean well includes an inner moveable sleeve having an inner circulation port and an inner fluid passage port. An outer housing has a first outer circulation port, an outer fluid passage port, and a second outer circulation port. A middle sleeve has: a middle circulation port aligned with the inner circulation port and the first outer circulation port when the assembly is in a lowering position; a middle fluid passage aligned with the inner fluid passage port and the outer fluid passage port when the assembly is in a collection position; and a fluid injection port aligned with the second outer circulation port when the assembly is in a retrieval position. A packer assembly seals an annulus between the middle sleeve and an inner diameter of the slim-hole when the assembly is in a setting position.

Abstract: A production system for use in a wellbore having a main bore with an axis, a lower lateral bore, and an upper lateral bore, includes a hollow whipstock with a central bore. The hollow whipstock is secured to the main bore between the lower lateral bore and the upper lateral bore. A sleeve assembly has a moveable inner sleeve with an outer diameter smaller than an inner diameter of the central bore of the hollow whipstock, and a moveable outer sleeve with an outer diameter larger than the inner diameter of the central bore of the hollow whipstock. A flow control valve is located in the main bore above the upper lateral bore. The flow control valve has an inner tubing member in selective fluid communication with the lower lateral bore and an annular conduit in selective fluid communication with the upper lateral bore.

Abstract: Methods and systems for automatic classification of images of internal structures of human and animal bodies. A method includes receiving a magnetic resonance (MR) image testing model and determining a testing volume of the testing model that includes areas of the testing model to be classified as bone or cartilage. The method includes modifying the testing model so that the testing volume corresponds to a mean shape and a shape variation space of an active shape model and producing an initial classification of the testing volume by fitting the testing volume to the mean shape and the shape variation space. The method includes producing a refined classification of the testing volume into bone areas and cartilage areas by refining the boundaries of the testing volume with respect to the active shape model and segmenting the MR image testing model into different areas corresponding to bone areas and cartilage areas.

Abstract: A drill bit for use in drilling a wellbore and that can be used for fracturing the subterranean formation surrounding the wellbore. Included on the bit body is a packer for sealing against the wellbore wall during fracturing. A chamber in the drill bit houses a valve assembly for selectively diverting fluid between use in drilling and for use in fracturing. The fluid is delivered through a drill string that attaches to an upper end of the bit. The valve assembly can be shuttled between drilling and fracturing configurations by selectively adjusting an amount and/or pressure of the fluid flowing in the drill string.

Abstract: A multi-zone well test system, that can flow test multiple zones within a subterranean formation and without the use of a rig. The system includes an inflow control tool that is ball actuated, a top diverter sub, a zonal isolation packer, a bottom diverter sub, and a dual-conduit tubing system. An advantage of the test system is that the subs and packers can be individually actuated without a surface operated control system.