Abstract: An electrical submersible pump (“ESP”) has a seal member that carries a packer. A retainer initially retains the packer in a fixed axial position with the seal member as the ESP is lowered into a well conduit. The retainer is releasable after the packer has been set in the conduit in response to a thermal growth axial force on the seal member, enabling relative axial movement between the seal member and the packer. The seal member has annular seal rings that extend over an axial length on the tubular member that is greater than an axial length of the bore of the packer.

Abstract: Provided are electric safety valves and methods of use. An electric safety valve comprises an electric actuator positioned in an interior chamber of the electric safety valve; the interior chamber comprising a dielectric fluid and being pressure and temperature compensated with a flow passage extending axially through the electric safety valve. The pressure and temperature compensation is performed via a compensating subassembly in pressure communication with the interior chamber thereby providing a section-balanced electric safety valve. The electric safety valve further comprises a protective sleeve separating the interior chamber from the flow passage. The electric safety valve further comprises at least one compression spring rod coupled to a closure member capable of restricting or preventing fluid flow through the flow passage.

Abstract: A method for determining a location of a proppant in a subterranean formation includes obtaining a first set of data in a wellbore using a downhole tool. The proppant is pumped into the wellbore after the first set of data is obtained. The proppant is pumped while or after the subterranean formation is fractured. A second set of data is obtained in the wellbore using the downhole tool after the proppant is pumped into the wellbore. The first set of data and the second set of data include a gravitational field measurement. The first and second sets of data are compared, and in response to the comparison, the location of the proppant in the subterranean formation is determined.

Abstract: Disclosed are pit launched horizontal drilling devices suitable for drilling a substantially horizontal bore hole and laying pipe underground from a surface dug pit. The devices comprise a stationary frame and a carriage component competent to move forward and back along the frame and drill and retrieve an attached drill stem through an aperture in the frame, the device comprising mechanical linear actuator means for moving the carriage along said frame. The devices are compact, light-weight, easy to maneuver and suitable for utility contractor applications exhibiting on the order of about 800-15,000 lbs of push/pull force. Also disclosed herein are improved means and components for easily and quickly breaking drill stem joints, including integrated, positionable collar wrenches and breakout wrenches.

Abstract: A downhole drilling tool and methods for using the tool include a body with a wall that defines an internal volume, and at least one arm attached to the wall, the at least one arm comprising a channel within a body of each arm. The at least one arm provides fluid paths connecting the internal volume to outside the wall, and the at least one arm is displaceable relative to the wall.

Abstract: A method that includes deploying a casing with a multi-electrode configuration over a dielectric layer in a downhole environment. The method also includes collecting electromagnetic (EM) measurements using the multi-electrode configuration, and processing the EM measurements to obtain a characterization of fluids in an annulus between the casing and a borehole wall. A related system includes a casing deployed downhole, the casing having a multi-electrode configuration and a dielectric layer between the casing and the multi-electrode configuration. The system also includes a controller for directing collection of EM measurements using the multi-electrode configuration, and a processor that processes the EM measurements to obtain a characterization of fluids in an annulus between the casing and a borehole wall.

Abstract: A drilling bottom hole assembly for loss circulation mitigation includes a drill bit configured to drill a wellbore in a formation. The drill bit is attached to a drill string. The wellbore includes a high-loss circulation zone into which drilling fluid is lost during drilling the wellbore. An under reamer is attached to the drill string upstring of the drill bit. The under reamer is downhole of the high-loss circulation zone. The under reamer, in response to actuation, is configured to widen a diameter of the high-loss circulation zone. An expansion assembly is connected to the under reamer. The expansion assembly surrounds the drill string upstring of the under reamer. The expansion assembly is configured to cover the high-loss circulation zone after the diameter of the high-loss circulation zone is widened by the under reamer.

Abstract: Apparatus, and methods of use, where the apparatus includes a cylindrical tool main body defining an axial centerline, the main body having a first bladed magnet section having at least one blade extending substantially perpendicular from the axial centerline at a first angle, a second bladed magnet section having at least one blade extending substantially perpendicular from the axial centerline at a second angle, and a hardfaced cylindrical section disposed between the first bladed magnet section and the second bladed magnet section, wherein the outer circumference of the hardfaced cylindrical section defines the outer circumference of the tool main body.

Abstract: A stage tool comprises a body with a tubular wall, defining an outer surface and an inner surface. Fluid ports, such as cement circulation ports, extend through the tubular wall. The stage tool further comprises a primary closing sleeve. The primary closing sleeve may be movable along the outer surface of the tubular wall for closing the ports when the treatment of the wellbore stage ends. A secondary closing sleeve may be movable along the inner surface of the tubular wall for closing the port in case of failure of the primary closing sleeve or for redundancy. The primary closing sleeve may be actuated by an internal member joined to the primary closing sleeve by a crosslink and movable on the inner surface. The internal member and the secondary closing sleeve may move along different surfaces on the internal wall to avoid interference.

Abstract: A sealing device includes a tubular body having a bore; a collet seat having a plurality of collets; a frangible sealing element disposed in the collet seat and blocking fluid communication through the bore; and a releasable sleeve releasably attached to the tubular body and retaining the collet seat against the tubular body. In one embodiment, the plurality of the collets includes threads mated with threads on the tubular body. In another embodiment, the plurality of the collets is attached to the sleeve.

Abstract: The invention provides a method and system for maximizing production of a well with a gas assisted plunger lift. The method comprises obtaining a plurality of measurements associated with operation of the well from sensors associated with various components of the well. The method further comprises determining set points for operation of the production valve and the injection valve based on one or more of the plurality of measurements. The set points may be determined by the controller or by a SCADA system. Optionally, one or more of the set points may be modified according to a comparison of current and optimal values of plunger velocity and gas and liquid production. In addition, the method comprises coordinating the operation of the production valve and the injection valve is coordinated based on the set points and the stage in operation cycle by the controller.

Abstract: A mast assembly for a mobile drilling machine may comprise: a mast frame including a back, a first side, and a second side, the first side and the second side diverging from the back to form an open front along substantially an entire length of the mast frame; a drill motor assembly movably attached to the mast frame, wherein the drill motor assembly is configured to rotate a drill pipe; and a drill drive assembly configured to drive the motor assembly up and down along a length of the mast frame, the drill drive assembly including: a sheave assembly comprising a plurality of sheaves, wherein the plurality of sheaves include a first sheave aligned generally parallel to the first side of the mast frame and a second sheave aligned generally parallel to the second side of the mast frame.

Abstract: The present invention corresponds to a check valve with an inertial mass that is installed in the bottom of the production tubing and above the progressive cavity pump (PCP) of an oil well, which prevents that the hydrostatic column that is inside of the production tubing go down in the moment where the artificial lift of the column stops for the detention of the PCP pump. If we prevent that this phenomenon to happen, the PCP pump will not rotate in the opposite direction of its normal operation and it will not be clogged by any particulate material that is contained in it.

Abstract: A device, system and method are provided for using a seal sub to isolate a well. The seal sub generally has a primary channel extending through the seal sub and seat positioned within the primary channel. As a ball setting tool passes through the seal sub and the seat, a ball connected to the setting tool with a shear pin contacts the seat and selectively connects to the seal sub. A predetermined force can be applied to the ball setting tool to break the shear pin, which leaves the seal ball in place, and the seal sub and the seal ball isolate the downhole pressures and contents from the uphole pressures and contents.

Abstract: A temporary seal within a wellbore. More specifically, a temporary seal within casing that limits the flow of fluid through the casing until the temporary seal is released.

Abstract: In one embodiment, a sealing device includes a tubular body having a bore; a collet seat having a plurality of collets; a frangible sealing element disposed in the collet seat and blocking fluid communication through the bore; and a releasable sleeve releasably attached to the tubular body and retaining the collet seat against the tubular body.

Abstract: A screw drill bypass valve comprising a valve body, the valve body is internally provided with a first-level valve core and a second-level valve core, a first-level spring is arranged between the first-level valve core and the second-level valve core, a second-level spring is arranged between the second-level valve core and a valve seat, and a rigidity of the second-level spring is greater than that of the first-level spring; the first-level valve core is provided with an inner bypass hole, the valve body is provided with an outer bypass hole, and the inner bypass hole is conducted with the outer bypass hole when a flowing pressure within a fluid channel of drilling fluid disappears; the second-level valve core is provided with an inner diversion hole, the valve body is provided with an outer diversion hole.

Abstract: An elevator system that supports a tubular member includes an elevator movable between a first elevator position and a second elevator position. A mechanical signal mechanism is coupled to the elevator. A valve is coupled to the mechanical signal mechanism. The mechanical signal mechanism is configured to transmit a mechanical signal by a mechanical control cable to move the valve into a valve position to send a valve signal that the elevator is in the second elevator position.

Abstract: The invention relates to a connecting assembly to be plugged into a mating receptacle in a wellbore, comprising a first sleeve including a second sleeve and having a top connecting end and a bottom connecting end, characterized in that: —the first sleeve comprises the bottom end and has a top end opposite to said bottom connecting end, said bottom connecting end being provided with an end cap for preventing entrance of materials and capable of being opened; —said second sleeve comprises said top connecting end located outside of the first sleeve and has a bottom end opposed to said top connecting end; —said connecting assembly comprises a locking mechanism adapted to lock said second sleeve in a position relative to said first sleeve such that the bottom end of the second sleeve is inside said first sleeve, and —the dimensions of the first sleeve and second sleeve are adapted such that when said locking mechanism is unlocked, said second sleeve is allowed to move relative to said first sleeve to impinge and o

Abstract: A centralizer for downhole OCTG having a storage space capable of housing downhole electronics and other downhole devices, compositions and elements is disclosed. The storage space is located within an inner cavity formed in one or more of the blades making up the centralizer. A capsule is provided for protecting the contents of the items being stored within the inner cavity. The capsule may be hermetically sealed to protect the contents from the damaging effects of downhole fluids. Ports may be provided within the capsule to allow downhole electronics to be connected to sensors and other devices and components residing outside of the capsule.