Abstract: A downhole tool includes a choke, a controller, a communication and power element, instrumentation, and a stabilizer. The choke is configured to vary an annular well pressure. The choke includes an expandable element having an expanded position, an expanding position, and an unexpanded position. The controller is connected to the choke and is configured to place the choke in the expanded position, the expanding position, and the unexpanded position. The communication and power element is electronically connected to the controller. Power and instructions are sent to the controller from the communication and power element. The instrumentation is electronically connected to the communication and power element. The instrumentation comprises sensors configured to obtain downhole data and the downhole data is sent to the communication and power element. The stabilizer is configured to centralize the choke within the casing string.

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: A system for monitoring an annular fluid level may include a floating element disposed on a surface of a drilling fluid within an annulus of the well, during mud cap drilling operations. The system may also include an antenna disposed above the floating element. The antenna may be configured to transmit a first signal to the floating element, and to receive a second signal from the floating element in response to the first signal. The system may also include a processor configured to determine a time value that measures a time between a transmittal, by the antenna, of the first signal and a receipt, by the antenna, of the second signal. The processor may also determine a state of a drilling fluid level within the annulus based on the time value, and update a drilling program for the well based on the state of the drilling fluid level.

Abstract: A testing apparatus for testing a fluid and a loss control material (LCM) is provided. The testing apparatus includes a testing chamber having an upstream end, a downstream end, a device central axis, and a general flow direction. The testing chamber includes a chamber body having an upstream cap, a downstream cap, a first chamber wall, and a second chamber wall. The first chamber wall has a first diameter and in part defines a first chamber interior, the second chamber wall has a second diameter, the first diameter is less than the second diameter, and both the first chamber wall and the second chamber wall are positioned relative to one another such that an annulus is defined in part in between. The traversal of the fluid and the LCM along the fluid flow path is restricted by a flow restriction.

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: A method, and related apparatus, involves providing one or more drill pipe segments and disposing a quantity of lost circulation material objects within the one or more drill pipe segments. A retention element is provided to retain the lost circulation material objects within the one or more drill pipe segments. The one or more drill pipe segments are connected to a drill string at a wellbore, and drilling fluid is flowed through the drill string. The flowing of drilling fluid through the drill string causes the retention element to release the lost circulation material objects to propagate further.

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: A testing apparatus for testing a fluid and a loss control material (LCM) is provided. The testing apparatus includes a testing chamber having an upstream end, a downstream end, a device central axis, and a general flow direction. The testing chamber includes a chamber body having an upstream cap, a downstream cap, a first chamber wall, and a second chamber wall. The first chamber wall has a first diameter and in part defines a first chamber interior, the second chamber wall has a second diameter, the first diameter is less than the second diameter, and both the first chamber wall and the second chamber wall are positioned relative to one another such that an annulus is defined in part in between. The traversal of the fluid and the LCM along the fluid flow path is restricted by a flow restriction.

Abstract: Systems and methods for moving a tubular string within a subterranean well include a downhole assembly. The downhole assembly includes a torque disconnecting member and a shock generating member. During normal drilling activities, both components are inactive. When a stuck pipe event occurs, first the torque disconnecting member is activated while the shock generating member is still inactive. Once the torque disconnecting member is activated, then the shock generating member is activated. A laterally-protruding shock pad of the activated shock generating member produces shocks against the proximate side of a wellbore wall while the shock generating member is rotating. Systems and methods for moving a tubular string within a subterranean well include a fishing assembly. The fishing assembly includes a fishing member, a swivel member, and an imbalanced member.

Abstract: Systems and methods for moving a tubular string within a subterranean well include a downhole assembly. The downhole assembly includes a torque disconnecting member and a shock generating member. During normal drilling activities, both components are inactive. When a stuck pipe event occurs, first the torque disconnecting member is activated while the shock generating member is still inactive. Once the torque disconnecting member is activated, then the shock generating member is activated. A laterally-protruding shock pad of the activated shock generating member produces shocks against the proximate side of a wellbore wall while the shock generating member is rotating. Systems and methods for moving a tubular string within a subterranean well include a fishing assembly. The fishing assembly includes a fishing member, a swivel member, and an imbalanced member.

Abstract: Systems and methods for moving a tubular string within a subterranean well include a downhole assembly. The downhole assembly includes a torque disconnecting member and a shock generating member. During normal drilling activities, both components are inactive. When a stuck pipe event occurs, first the torque disconnecting member is activated while the shock generating member is still inactive. Once the torque disconnecting member is activated, then the shock generating member is activated. A laterally-protruding shock pad of the activated shock generating member produces shocks against the proximate side of a wellbore wall while the shock generating member is rotating. Systems and methods for moving a tubular string within a subterranean well include a fishing assembly. The fishing assembly includes a fishing member, a swivel member, and an imbalanced member.

Abstract: Systems and methods for moving a tubular string within a subterranean well include a downhole assembly. The downhole assembly includes a torque disconnecting member and a shock generating member. During normal drilling activities, both components are inactive. When a stuck pipe event occurs, first the torque disconnecting member is activated while the shock generating member is still inactive. Once the torque disconnecting member is activated, then the shock generating member is activated. A laterally-protruding shock pad of the activated shock generating member produces shocks against the proximate side of a wellbore wall while the shock generating member is rotating. Systems and methods for moving a tubular string within a subterranean well include a fishing assembly. The fishing assembly includes a fishing member, a swivel member, and an imbalanced member.