Abstract: A hydraulic set packer system includes an outer sleeve and a mandrel extending through the outer sleeve. The mandrel has a setting port extending through a radial wall of the mandrel, and the setting port is configured to provide fluid communication from a central bore of the mandrel to a setting chamber formed between the outer sleeve and the mandrel. The system also includes a piston configured to move axially along the mandrel in response to a setting pressure in the setting chamber. The piston is configured to drive at least one radially actuatable component to actuate in a radial direction to engage a wellbore wall. Further, the system includes a pressure isolation assembly disposed in the setting chamber. The pressure isolation assembly is configured to move axially with respect to the mandrel from a first position to a second position to seal the setting port.

Abstract: A well sealing tool may include a hydraulic setting mechanism wherein a setting chamber is isolated after setting a sealing element in engagement with a wellbore. In one example, a setting mechanism includes a setting chamber housing positionable about a mandrel to define at least a portion of a setting chamber between the mandrel and the setting chamber housing. A setting port fluidically couples a through bore of the mandrel with the setting chamber. A valve element is biased toward a closed position within the setting port. A guide sleeve is disposed about the mandrel in a first position that props the valve element to an open position. The guide sleeve is moveable to a second position in response to a threshold pressure applied to the setting chamber to release the valve element to the closed position.

Abstract: A hydraulic set packer system includes an outer sleeve and a mandrel extending through the outer sleeve. The mandrel has a setting port extending through a radial wall of the mandrel, and the setting port is configured to provide fluid communication from a central bore of the mandrel to a setting chamber formed between the outer sleeve and the mandrel. The system also includes a piston configured to move axially along the mandrel in response to a setting pressure in the setting chamber. The piston is configured to drive at least one radially actuatable component to actuate in a radial direction to engage a wellbore wall. Further, the system includes a pressure isolation assembly disposed in the setting chamber. The pressure isolation assembly is configured to move axially with respect to the mandrel from a first position to a second position to seal the setting port.

Abstract: A well sealing tool may include a hydraulic setting mechanism wherein a setting chamber is isolated after setting a sealing element in engagement with a wellbore. In one example, a setting mechanism includes a setting chamber housing positionable about a mandrel to define at least a portion of a setting chamber between the mandrel and the setting chamber housing. A setting port fluidically couples a through bore of the mandrel with the setting chamber. A valve element is biased toward a closed position within the setting port. A guide sleeve is disposed about the mandrel in a first position that props the valve element to an open position. The guide sleeve is moveable to a second position in response to a threshold pressure applied to the setting chamber to release the valve element to the closed position.

Abstract: A control line pinching mechanism can include a pinching sleeve, a clamping sleeve, a tubing, a control line, and a pinching block. The clamping sleeve can have a slot. A control line can extend between the tubing and the slot of the clamping sleeve. A pinching block can be disposed within the slot of the clamping sleeve. The pinching sleeve can be movable relative to the slot from a released position to a pinching position in which the pinching sleeve contacts and radially compresses the pinching block against the control line to pinch the control line against the tubing.

Abstract: A tubular control conduit is disposed in a wellbore having a retractable segment and an abandonable segment, each having an inner bore. Upon retraction of the retractable segment an obstruction member is actuated to form a seal thereby preventing the flow of fluid past the obstruction member in the inner bore of the abandoned segment. Cement is then poured into the wellbore thereby covering the abandoned segment of the tubular control conduit.

Abstract: A control line pinching mechanism can include a pinching sleeve, a clamping sleeve, a tubing, a control line, and a pinching block. The clamping sleeve can have a slot. A control line can extend between the tubing and the slot of the clamping sleeve. A pinching block can be disposed within the slot of the clamping sleeve. The pinching sleeve can be movable relative to the slot from a released position to a pinching position in which the pinching sleeve contacts and radially compresses the pinching block against the control line to pinch the control line against the tubing.

Abstract: A control line pinching mechanism can include a pinching sleeve, a clamping sleeve, a tubing, a control line, and a pinching block. The clamping sleeve can have a slot. A control line can extend between the tubing and the slot of the clamping sleeve. A pinching block can be disposed within the slot of the clamping sleeve. The pinching sleeve can be movable relative to the slot from a released position to a pinching position in which the pinching sleeve contacts and radially compresses the pinching block against the control line to pinch the control line against the tubing.

Abstract: A control line pinching mechanism can include a pinching sleeve, a clamping sleeve, a tubing, a control line, and a pinching block. The clamping sleeve can have a slot. A control line can extend between the tubing and the slot of the clamping sleeve. A pinching block can be disposed within the slot of the clamping sleeve. The pinching sleeve can be movable relative to the slot from a released position to a pinching position in which the pinching sleeve contacts and radially compresses the pinching block against the control line to pinch the control line against the tubing.

Abstract: Method and apparatus for generating fluid pulses in a fluid column, such as within a downhole well, are disclosed. A described example fluid pulse generator utilizes a moveable flow conduit through which at least a portion of a downwardly flowing fluid column will pass. The moveable flow conduit can be moved, such as by pivoting, in and out of registry with other components defining the fluid flow path to provide resistance to flow of a selected duration and pattern, and thereby to generate pressure pulses within the fluid column detectable at the surface. In some examples, magnetic actuators will be used to perform the described pivoting of the moveable flow conduit.

Abstract: Method and apparatus for generating fluid pulses in a fluid column, such as within a downhole well, are disclosed. A described example fluid pulse generator utilizes a moveable flow conduit through which at least a portion of a downwardly flowing fluid column will pass. The moveable flow conduit can be moved, such as by pivoting, in and out of registry with other components defining the fluid flow path to provide resistance to flow of a selected duration and pattern, and thereby to generate pressure pulses within the fluid column detectable at the surface. In some examples, magnetic actuators will be used to perform the described pivoting of the moveable flow conduit.