Abstract: A completion assembly to aid in gravel packing a wellbore which assembly includes a plurality of interconnected sand screen assemblies, each sand screen assembly having a wireless adjustable electronic flow control node disposed along the sand screen base pipe to control flow of a gravel packing slurry from the base pipe into the wellbore annulus. Each electronic flow control node includes a valve that can be adjusted by an electric actuator powered by a power harvesting mechanism disposed in a flow path of the completion assembly. A wireless transmitter receives a control signal to control the electric actuator. The control signal may be transmitted sequentially from a distal most sand screen assembly to a proximal sand screen assembly in order to sequentially build the gravel pack.

Abstract: A downhole oil level detection device includes a mounting housing (1) and a balance cylinder (2) installed on the mounting housing (1). The balance cylinder (2) includes a cylinder body (25) and a moving piston (21), a piston tension spring (22), a moving rod (23), a moving rod compression spring (24) and a displacement sensor (3) installed in the cylinder body (25). One end of the piston tension spring (22) is fixed to one end of the cylinder body (25), the other end thereof is connected to one side of the moving piston (21); one side of the moving piston (21) is also connected to one end of the moving rod compression spring (24), the other end of the moving rod compression spring (24) is connected to one end of the moving rod (23), the other end of the moving rod (23) is provided with the displacement sensor (3).

Abstract: A gravel pack system includes a liner assembly and a deployment assembly. The liner assembly includes a sand control screen. The deployment assembly facilitates rotation of the liner assembly and circulation through the liner assembly while running the liner assembly into a wellbore using a work string. The deployment assembly includes a crossover tool that is operated to facilitate gravel packing without manipulation of the work string. The deployment assembly also includes a setting tool for setting a packer and/or a sand barrier at the top of the liner assembly.

Abstract: The present disclosure relates to mechanical packer systems. More particularly, the present disclosure relates to devices, tools, and methods for controlling fluid flow with one or more mechanical packer assemblies. A mechanical packer system may be used in vertical, inclined, or horizontal casings, pipes, boreholes, cartridges, or similar conduits. The mechanical packer system may be applied in casings below a ground surface (e.g., groundwater contamination assessments, groundwater resource investigations, or oil and gas exploration) or used in casings above a ground surface (e.g., water or gas lines, drainage pipes, or horizontal borings in tunnels). The mechanical packers described in the present disclosure are generally considered retrievable and useful for other purposes; however, the systems could also be dedicated to a specific application and considered permanent.

Abstract: Apparatus can have a separable housing having a longitudinal length extending along a longitudinal axis with an upper portion and a lower portion. One or more tubular control conduits can be disposed within the separable housing and extend along the longitudinal axis. The one or more tubular control conduits can have an inner bore formed therein. One or more actuation elements can be coupled with the separable housing and be operable to separate the upper portion and the lower portion of the separable housing. The one or more actuation elements can also be operable to separate the one or more tubular control conduits, thereby interrupting the inner bore of the one or more tubular control conduits.

Abstract: A downhole tool including a mandrel having a first surface, and opposing second surface defining a flow path, a lock support zone provided one of the first and second surfaces, and a passage extending between the flow path and the first surface. A tool is supported on one of the first and second surfaces. A sleeve is selectively shiftable on the one of the first and second surfaces into engagement with the tool. The sleeve includes a first surface portion and a second surface portion. The second surface portion includes a latch section. A lock system is arranged between the first surface and the second surface portion in the lock support zone. The lock system includes a lock member selectively supporting a lock element in the latch section. The lock element constrains movement of the sleeve.

Abstract: Methods and systems for controlling fluids in a wellbore are described. The methods and systems include running a production string into the wellbore, the production string includes production tubing and completion components with a first packer with a first control line and a backup packer with a second control line; setting the first packer in the wellbore in response to a signal on the first control line; producing hydrocarbons from the wellbore with the first packer set and the backup packer unset; and setting the backup packer in the wellbore in response to a signal on the second control line.

Abstract: A well barrier can include an inner mandrel, a flow passage, and a releasably secured plug. The plug blocks fluid flow through the flow passage, and includes a shoulder that prevents the plug from displacing completely through the inner mandrel. A method of treating a subterranean well can include treating a deeper zone, setting a well barrier in the well between the deeper zone and a shallower zone, then treating the shallower zone, and then applying a pressure differential from the deeper to the shallower zone, thereby displacing a plug out of the well barrier. A well treatment system can include a well barrier with a plug releasably secured to an inner mandrel. The plug is released by application of a pressure differential in a longitudinal direction, and fluid communication is unblocked by application of a pressure differential in an opposite longitudinal direction.

Abstract: A plugging tool includes an elongated inner housing allowing a first fluid to flow through a hollow interior of the inner housing, a retractable plunger positioned within the inner housing and operable to obstruct the flow of the first fluid into a discharge chamber and resume the flow of the first fluid into the discharge chamber based on a pressure exerted by the first fluid on the retractable plunger, and at least one pressure release valve (PRV) operable to open and release at least a portion of the first fluid from the inner housing based on a pressure exerted by the first fluid on the at least one PRV, wherein operation of the retractable plunger and the at least one PRV generates pulses of the first fluid used to deposit a sealing plug at a target interval of a wellbore.

Abstract: A method of determining a presence of a leak in a wall of a production tubing string includes positioning an electrical submersible pump is positioned at the string's downhole end. Based on measurements from a pressure sensor positioned at a downhole location at a discharge end of the electrical submersible pump, it is determined that a discharge pressure has decreased over a specified time period. Based on measurements from a pressure sensor within a wellhead of the well, it is determined that a pressure within the production tubing string at the surface has decreased over the specified time period. Based on measurements from a flow-rate sensor at an uphole end of the production tubing string, it is determined the flow rate has decreased relative to a calculated expected flow rate. Based on a pressure integrity test initiated in response to these determinations, the presence of the leak is determined.

Abstract: A method of plugging a well includes lowering a solid body into a wellbore by wireline; and filling the space around the solid body with a liquid plugging material. The solid body and the liquid plugging material together form a plug after the liquid plugging material is set.

Abstract: A temporary well isolation device which has an axial passage that comprises a temporary housing having an internal cavity containing a chemical material and a temporary barrier or plug member that can be actuated by an external mechanism to allow fluid to flow into the internal chamber and contact the chemical material in the internal chamber. When the chemical material is exposed to fluid, the chemical material causes the temporary housing to corrode, dissolve, and/or degrade.

Abstract: A completion assembly includes an upper liner and a lower liner, a wellbore completion component that interposes the upper and lower liners, a dissolvable pipe plug secured within an aperture defined in the wellbore completion component, and a dissolvable projectile seat arranged adjacent the wellbore completion component.

Abstract: A system for controlling tubing member assembly diameter includes a control unit, a computing device, a tubing member assembly, and an elastomer member. The tubing member assembly includes an outer pipe member that defines a static diameter and an inner pipe member having an outer surface and defining a dynamic diameter that changes from a first inner pipe member value to a second inner pipe member value. The elastomer member is disposed between the outer pipe member and the inner pipe member such that an inner area of the elastomer member is disposed on the outer surface of the inner pipe member. The elastomer member expands from a first position to a second position to constrict the dynamic diameter from the first inner pipe member value to the second inner pipe member value responsive to receiving an electrical signal from the control unit.

Abstract: An apparatus for activating chambers of downhole hydraulic screens. The apparatus comprises an outer sleeve, an inner sleeve, and a flow path. The outer sleeve is coupled to one hydraulic screen on one end and another hydraulic screen on another end. The inner sleeve couples to base pipe at both ends. The flow path is an annulus defined between the outer diameter of the inner sleeve and the inner diameter of the outer sleeve. Hydraulic seals are formed at the interfaces between the inner sleeve and base pipe and the outer sleeve and hydraulic screens. In practice, the assembled apparatus and hydraulic screens are ran downhole to a production zone using production tubing and a running tool. Fluid from the surface is pumped into the production tubing, diverted therefrom, and into chambers of the hydraulic screens using the flow path to conduct fluid between the hydraulic screens.

Abstract: A method of selectively expanding a wall of a tubular includes assembling an expansion tool comprising a plurality of bi-directional boosters, arranging a predetermined number of explosive pellets a serially-arranged column between the bi-directional boosters, positioning a duel end firing explosive column tool within the tubular, and detonating the bi-directional boosters to simultaneously ignite opposing ends of the serially-arranged column to form two shock waves. The shock waves collide to create an amplified shock wave that travels radially outward to impact the tubular and expand a portion of the tubular wall radially outward, without perforating or cutting through the portion of the wall, to form a protrusion of the tubular at the portion of the wall. The protrusion extends into an annulus adjacent an outer surface of the wall of the tubular.

Abstract: A modular downhole packer includes a valve body, which includes a threaded coupler adapted to couple to a tubular and a valve assembly. The packer includes a packer element assembly, which includes a first end coupler, the first end coupler mechanically coupled to the valve body; a packer element; and a second end coupler. The packer includes a floating seal element mechanically coupled to the second end coupler, the floating seal element including a seal extension. The packer includes a floating end anchor. The floating end anchor includes a compression seal housing, the compression seal housing including an outer sealing surface positioned within the seal extension of the second end coupler; a compression seal positioned within a seal pocket formed in the compression seal housing; and an anchor body, the anchor body threadedly coupled to the seal pocket of the compression seal housing, the anchor body abutting the compression seal.

Abstract: A well tool device includes a housing having an axial through bore; a sleeve section axially displaceable relative to the housing; a fluid flow preventing frangible disc; and an axial fluid passage bypassing the frangible disc when the well tool device is in an initial state, thereby allowing a fluid flow between a first location above the frangible disc and a second location below the frangible disc. The sleeve section includes an axial through bore aligned with the axial through bore of the housing. The axial fluid passage is closed when the well tool device is in a intermediate state. The fluid flow preventing frangible disc is provided in the bore of the sleeve section in sealing engagement with the sleeve section. The well tool device further includes a disc supporting device for supporting the frangible disc in relation to the sleeve section. The disc supporting device is releasably connected inside the sleeve section by a releasable connection device.

Abstract: The well system includes a casing and production tubing and a control unit that can receive measurements of temperature and pressure of fluid in the tubing-casing annulus (TCA). A subsurface safety valve (SSSV) connected to the tubing can switch to an open or closed state in response to a change in pressure of the fluid. An expected thermal expansion or contraction of the TCA fluid is calculated based on the received measurements, and the control unit determines, based on the expected thermal expansion or contraction and on a calculated TCA volume, a volume necessary to be added to or released from the TCA to maintain the fluid within an optimal pressure range. The control unit can also receive an indication of an emergency condition and transmit a signal to activate a release valve to release from the TCA a volume of fluid sufficient to cause the SSSV to close.

Abstract: Systems and methods include a method for using a smart retrievable service packer for pressure testing operations. A service packer is installed to a depth in a well. The service packer includes one or more radio frequency identification devices (RFIDs) positioned above and below a packer element of the service packer. A determination is made, by analyzing information received from the one or more RFIDs, that a pressure leak has occurred across the service packer. The pressure leak is reported to a surface receiver system at a surface of the well.