Abstract: Provided herein is an intervention tool and a method for fracturing multiple lateral wellbores in a well system. The intervention tool, in one aspect, includes a radial outer housing, the radial outer housing forming an interior bore configured to flow fluid, and an expansion member coupled proximate an outer surface of the radial outer housing. The intervention tool according to this aspect further includes a sliding sleeve positioned along an interior surface of the radial outer housing and engageable with the expansion member, the sleeve including a collection of slots or catches configured to move the expansion member between a radially retracted position when the sliding sleeve is in a first linear position and a radially expanded position when the sliding sleeve is in a second linear position.

Abstract: A system for monitoring flaring activities on a drill ship includes a plurality of devices in wireless communication with each other on the drill ship. Each of the devices includes a resistive temperature detector configured to determine a temperature within a sensing area of the resistive temperature detector, and a communication device operably connected to the resistive temperature detector, wherein the communication device is configured to receive the temperature data from the resistive temperature detector and send the temperature data to a remote system. The device may also include a global positioning system operably connected to the communication device, the global positioning system configured to identify a location of the drill ship in real-time and send the location data to the communication device, wherein the communication device is configured to send the location data to the remote system.

Abstract: A downhole flow control device is described having a flow control valve and a sensor communication with the flow control valve. The sensor measures a downstream process parameter and the flow control valve is configured to control the fluid flow through the valve to achieve a target downstream process parameter value in response to the measured downstream process parameter. A control system for controlling the downhole flow control device and a method for controlling the downhole flow device are also provided.

Abstract: A system for stimulating a subterranean formation that has a wellbore formed within the subterranean formation; and a tubular disposed within the wellbore. There is a first frac valve disposed within the tubular, the first frac valve having a first sleeve in a closed position, and further configured to move to an open position. There is an at least a second frac valve disposed within the tubular, the second frac valve having a respective sleeve in a respective closed position, and further configured to move to a respective open position. A dart is configured to pass through the first frac valve without moving the first sleeve, and to subsequently engage the second frac valve to move the respective sleeve to the respective open position.

Abstract: A downhole tractor for operational use in well casing of a wellbore. The tractor comprising a tractor body, at least one actuator assembly, and at least one tractor wheel. The actuator assembly is actionable to shift the axis of rotation of the tractor wheel. The at least one tractor wheel includes at least one bifurcated tract having a leading and trailing edge for engaging the well casing. The at least one actuator assembly causes the at least one tractor wheel to switch from traversing a first vertical plane of the well casing to a second vertical plane of the well casing when actuated.

Abstract: One or more remote-operated sleeve valves are placed along a tubular string downhole. The sleeves can be opened and closed wirelessly, and in embodiments over and over again. Differential pressure between wellbore fluid pressure and an accumulator chamber enable repeated shifting. Each sleeve can have a unique actuation code removing constraints regarding sequence of operation and need for well intervention to access the sleeves. Hydraulic fracturing can be achieved without wellbore obstructions, and other operations benefit for reduced expense in service rigs and the ability or selectively shut off problem zones. Remote signals received downhole include those generated by percussive and seismic, distinguishable from background noise including during pumping.

Abstract: An indexing apparatus for use with a downhole tool may include a tubular body and a mandrel. The tubular body may have a first end and a second end. The tubular body may also have a plurality of body detents on the second end of the tubular body and a recess in a surface of the tubular body. The mandrel may include a plurality of mandrel detents on a surface of the mandrel. The mandrel detents may be sized and shaped to engage with the body detents on the second end of the tubular body. The indexing apparatus may also include a cam sized to be received in the recess of the surface of the tubular body and a spring coupled to the first end of the tubular body.

Abstract: An apparatus for dispensing frac balls into a wellhead includes an outer sleeve, an inner sleeve positioned and moveable within an interior of the main body and a ball retention device for retaining a frac ball within an interior of the inner sleeve. A retained frac ball held in the ball retention device is released within the inner sleeve when weight or pressure is applied to the inner sleeve to cause the inner sleeve to slide upwardly within the main sleeve.

Abstract: The present invention provides a thermally deformable annular packer with pressure relief means for use in oil and gas wells. The annular packer is formed from a stack of component parts, said parts comprising one or more eutectic alloy based ring sections sandwiched between two end sections. At least one of the annular packer component parts has one or more enclosed voids that are configured to become exposed when the packer is subjected to a predetermined pressure or temperature. The exposure of the enclosed voids serves to increase the effective volume within the sealed region formed by the annular packer in the annulus between two coaxial well casing/tubing. The increase in the effective volume serves to reduce the pressure within the sealed region thus preventing a build-up of pressure that might otherwise have damaged the well casing/tubing.

Abstract: A system and method for successively fracking a wellbore at spaced intervals along tubing having therein frac ports each openably closed by a sliding sleeve. The system has at least one actuation member and at least one cylindrical sand screen sub insertable into the tubing. Each actuation member has a collet sleeve with a radially-outwardly biased protuberance of a first profile configured to matingly engage an interior groove profile on at least one of the sliding sleeves and slide the sliding sleeve downhole to open the corresponding port. Each cylindrical sand screen sub has a dissolvable plug member or burst plate disposed on one end thereof allowing for the sand screen to be forced into the well by pressure acting against the plug or plate, and has a resiliently-outwardly biased protuberance configured for engaging a mating profile on the tubing and retaining the sand screen sub in a desired position.

Abstract: A stage cementing tool includes a housing configured to couple to a casing and having a central bore therethrough, a first plurality of ports arranged on a radial surface of the housing and configured to fluidly connect the central bore and an annulus of a wellbore, a second plurality of ports arranged on the radial surface of the housing uphole of the first plurality of ports and configured to fluidly connect the central bore and the annulus of the wellbore, an expandable element coupled to the housing between the first plurality of ports and the second plurality of ports, and a sleeve. The sleeve is moveable from a first position on the housing to a second position on the housing to fluidly disconnect the central bore and the annulus through the first plurality of ports and fluidly connect the central bore and the annulus through the second plurality of ports.

Abstract: A downhole apparatus has a casing string and a degradable plug positioned in the casing string to block flow therethrough. An upper membrane covers an upper end of the degradable plug. The upper membrane is made up of a plurality of separable membranes. A lower membrane covers a lower end of the degradable plug and is comprised of a plurality of separable membranes.

Abstract: A testable indexing plug includes a body having an outer surface, an inner surface defining a flow path, a first end, a second end, and an intermediate portion extending between the first end and the second end. A valve chamber extends from the first end into the intermediate portion. A valve member is arranged in the valve chamber. The valve member includes a first end portion, a second end portion including an opening, and an intermediate section including one or more ports fluidically connected with the opening. An indexing system shifts the valve member between a first position, wherein the one or more ports are arranged in the valve chamber and a second position, wherein the one or more ports are exposed outside of the valve chamber following a defined number of pressure applications to the valve member.

Abstract: A fully electric tool for continuous downhole flow control is described, said tool comprising a body and along the said body, actuating set(s), each actuating set comprising a passage system comprised of shaft(s) radially disposed along said cylindrical body, each of said shaft (s) being actuated with its opposed pair or in an independent way in a well-defined position or not, said shaft(s) being provided of spherical element(s) or sphere(s), provided of at least one window forming piles of sphere(s) in shaft(s), the rotation of said shaft(s)(108) of piles of sphere(s) enabling the opening or total or partial obstruction of holes by the total or partial coincidence of said window(s) of sphere(s) with said bore(s) of said cylindrical body.

Abstract: A completion assembly includes tubing that defines an axis that extends from a distal shoe end to a proximal uphole end where the tubing includes: a washdown shoe; a plug seat configured to receive a plug that hinders flow through the washdown shoe; a screen; a fluid loss control device that permits, in an exterior space, flow of fluid in an uphole direction and that hinders flow of fluid in a downhole direction; a circulation valve that is actuatable to permit flow of fluid from an interior space to the exterior space; a formation isolation valve that is actuatable to form a flow barrier in the interior space; a packer that is actuatable to extend radially outwardly from the tubing to form an annular flow barrier in the exterior space; and a barrier component that is actuatable to form a flow barrier in the interior space of the tubing.

Abstract: A tool for deploying plug balls or frac balls in a borehole utilizing the hydrostatic pressure of fluid in the borehole is disclosed. The tool includes two connected cylinders, the first cylinder with a larger cross-sectional area than the second cylinder. The tool includes two connected pistons, the first piston disposed in sealing engagement within the first cylinder, the second piston disposed in sealing engagement within the second cylinder. The tool includes a ball-holding tube connected to the second cylinder. Application of force to the first piston by exposing the first cylinder to the hydrostatic head of the borehole fluid causes the second piston to move which in turn applies force to the balls in the ball-holding tube which deploys the balls into the borehole by ejecting them from the tube.

Abstract: A new resin blend is disclosed, which may be referred to as a hybrid resin. The resin blend includes an effective amount of benzoxazine resin or benzoxazine derivative mixed with at least one of epoxy resin, phenolic resins and other thermosetting polymers at varying ratios.

Abstract: A well configuration unit configured to connect to a zipper manifold, and comprising a bridge connector header comprising an axial throughbore and a horizontal throughbore. A frac manifold connector is connected to the axial throughbore of the bridge connector header and comprises a mandrel that is axially movable and a hydraulic setting tool configured to move the mandrel from an open position, in which fracturing fluid is allowed to flow from the zipper manifold to a connected frac tree, to a closed position, in which the mandrel and its associated cup tool prevent fracturing fluid from flowing to the connected frac tree. A bridge connector is connected to the horizontal throughbore of the bridge connector header and comprises two bridge spools configured to connect the zipper manifold to the same frac tree.

Abstract: A production system and a frac sleeve assembly of a frac assembly of the production system. The frac sleeve assembly includes a funnel section that reduces in diameter in a direction of an outlet of the frac assembly, a throat section having a selected diameter, and a ball seat at an intersection of the funnel section and the throat section for receiving a ball. When seated in the ball seat, an entire portion of a ball extending into the funnel section is exposed to disintegrating fluid in the funnel section.

Abstract: The invention relates to a blowout preventer stack having at least one blowout preventer, at least one kinetic energy storage device, at least one hydraulic pump, and at least one hydraulic actuator which is disposed outside the kinetic energy storage device and is connected to the hydraulic pump via a hydraulic line and is mechanically connected to the blowout preventer, wherein the kinetic energy storage device is coupled, or couplable, to the hydraulic pump and the hydraulic pump may be driven by the kinetic energy stored in the kinetic energy storage device in such a manner that in case of need the hydraulic pump will pump hydraulic fluid to the hydraulic actuator and thus actuate the blowout preventer.

Abstract: A system is provided, run on a liner, for stimulating one or more stages of a downhole wellbore. The system includes one or more frac valves arranged on the liner; each of the frac valves presenting an identical inside profile, the frac valves being openable for providing fluid communication between in inside of the liner to outside of the wellbore; and at least one dart deployable into the liner, and being adjustable to pass through one or more frac valves without opening said one or more frac valves, and to engage and open one or more other frac valves. Each of the at least one darts is identical to another. A method is further provided for stimulating one or more stages of a downhole wellbore.

Abstract: Degradable downhole tools, tool components, and balls are formed from a polyvinyl alcohol (PVA) compound. The PVA compound exhibits strength and elasticity properties that are comparable to existing degradable downhole polymers and further exhibits degradability properties that are superior to existing degradable downhole polymers. For different components, the PVA compound may include a reinforcing material such as fiberglass. A plug for use in a wellbore conduit may include a sealing element that is formed of PVA compounds of various types.

Abstract: A frac plug with a flapper, wherein the flapper is configured to set and unset based on a pressure differential and/or fluid flow associated with the frac plug.

Abstract: An operating system for a barrier valve or safety valve is responsive to increments in annulus or tubing pressure. An indexing device controls valves that selectively direct pressure applied to one side of an operating piston or the other for attaining the open and closed positions of the barrier valve. One such indexing device can be a j-slot. Other devices that operate a pair of hydraulic valves in tandem for pressure direction to one side of an actuation piston or another are contemplated. The system needs no electric power and there are no control lines needed to run below the production packer in the case of using annulus pressure to actuate the piston or at all if access to tubing pressure is provided from the vicinity of the barrier valve components.

Abstract: The invention relates to a fluid control device (500) for treating a well, to expand a liner (100) radially outward, said device comprising a piston (550) translatably mounted in said chamber (320), and degradable immobilization means (590), secured in translation with the piston (550), wherein the degradable immobilization means (590) are movable in translation in a cavity (700), wherein the device comprises protection means (800) isolating the cavity (700) from a discharge pipe (810) configured to introduce fluid degrading the pin (590) in said cavity (700), such that, in the initial state, the protection means (800) protect said degradable immobilization means (590), the protection means (800) being configured to break when the pressure in the cavity reaches a threshold pressure gap (?Ps) allowing degradation of the degradable immobilization means (900).

Abstract: The present disclosure relates to a method of forming an energy absorbing three dimensional (3D) structure. The method involves forming an outer shell for the 3D structure from a shell material, the outer shell having a void forming a core volume. The method also involves filling the core volume with a transformative liquid. When the 3D structure is fully formed, the transformative liquid is encapsulated within the outer shell and provides enhanced energy absorbing properties to the 3D structure.

Abstract: A flow control apparatus includes a housing having a bore extending and a port formed through a wall of the housing; and a port sleeve disposed in the housing and having a port in communication with the port of the housing. The apparatus also includes a first sleeve releasably attached to the housing, wherein the first sleeve is movable from a first position preventing axial movement of the port sleeve relative to the housing to a second position allowing axial movement of the port sleeve relative to the housing. The apparatus further includes a second sleeve releasably attached to the port sleeve, wherein the second sleeve is movable from a first position blocking fluid communication through the port of housing and the port of the port sleeve to a second position allowing fluid communication through the ports.

Abstract: A method of manufacturing a safety valve chamber housing can include depositing a chamber housing material, and thereby gradually building up the chamber housing and forming a chamber in the chamber housing enclosed by the chamber housing material, the chamber being bounded by only a single solid structure of the chamber housing. A safety valve can include a piston, and a chamber housing having a piston bore and a chamber formed therein, the piston bore being in communication with the chamber, the chamber being enclosed by only a single chamber housing material. A well system can include a safety valve connected in a tubular string, the safety valve including a chamber housing with a chamber in communication with a control line, inner and outer walls of the chamber housing being made of a continuous chamber housing material.

Abstract: A plug for well drilling includes a mandrel and at least one diametrically expandable annular rubber member and at least one slip disposed on an outer circumferential surface orthogonal to an axial direction of the mandrel; (i) the mandrel being formed from a degradable material; and (ii) the at least one diametrically expandable annular rubber member being formed from a degradable rubber material having a rate of decrease of not less than 5% in 50% strain compressive stress after immersion in water at a temperature of 150° C. for 24 hours relative to the compressive stress before immersion; and/or having a rate of loss of mass of from 5 to 100% after immersion in water at a temperature of 150° C. for 72 hours relative to the mass before immersion. A well drilling method includes a step of isolating a borehole using the plug for well drilling, part or all of the plug being degraded thereafter.

Abstract: There is described a method of removing equipment from a section of a wellbore, and related apparatus. In embodiments of the invention a tool string (10) is provided having a tractor (15) and a GS-pulling tool (14). The tool string (10) is run into the wellbore using the tractor (15), at least one section of the tractor being positioned ahead of the GS-pulling tool (14) within the tool string (10), and the GS-pulling tool (14) is used to couple the equipment (12) to the tool string (10), for allowing the equipment (12) to be removed.

Abstract: A method of hydraulically actuating downhole equipment includes supplying pressure P(z) to a downhole network comprising tools T(n), tool T(x), control lines C(z), and control lines Y(z), wherein n and z are integers, and x=n+1, wherein a pressure P(z) is applied to tool T(n) using at least one control line C(z) in hydraulic communication with tool T(n); applying pressure P(z) to a hydraulically movable portion of tool T(n), wherein pressure P(z) to tool T(n) is not high enough to independently activate tool T(x); and applying each pressure P(z) to a hydraulically movable portion of tool T(x), wherein tool T(x) is only activated when all of pressures P(z) are simultaneously applied to the hydraulically movable portion of tool T(x), and wherein tool T(x) is only activated when each pressure P(z) is at least at a preset value PV(z).

Abstract: Counter-flow heat exchanger is constructed with plenums at either end that separate the opposing fluids, the channels of which are arrayed in a checkerboard patterns, such that any given channel is surrounded by channels of opposing streams on four sides—laterally on both sides and vertically above and below.

Abstract: A pressure compensated sensing system and methods for using the same are provided. The system can include a housing, a seal, an incompressible fluid, and sensing elements. The seal can be positioned within a housing cavity and divide the cavity into two portions. A first cavity portion can be sealed from the fluid environment by the seal and contain the sensing elements and the incompressible fluid. A second cavity portion can be in fluid communication with the fluid environment. The fluid environment can apply an external pressure to the seal that is opposed by an internal pressure of the sealed cavity applied to the seal by the incompressible fluid. When the internal pressure and the external pressure are different, the seal can move in a manner that changes the volume of the sealed cavity by an amount sufficient to equalize the internal pressure with the external pressure.

Abstract: A method for use in well drilling, development, completion, and production, including supplying hydraulic pressure to a tubing spider having at least one actuating component, generating position data from a position sensor based on the position of the actuating component, generating pressure data from a pressure sensor based on the pressure supplied to the spider, and automatically handling tubing with the spider by actuating the actuating component by adjusting pressure supplied to the spider based on the position data, the pressure data, and a prescribed control algorithm. The method may be implemented as part of a system including a tubing spider having at least one actuating component, sensors detecting hydraulic pressure supplied to the spider and the position of the actuating component, and a programmable logic controller capable of generating spider control data to control the spider based on data from the sensors and a prescribed control algorithm.

Abstract: A downhole tool subassembly has an outer sleeve with a first set of apertures extending from an inner bore of the outer sleeve. An intermediate sleeve positioned is within the outer sleeve and defines an intermediate flow path extending from an inner bore of the intermediate sleeve to a cavity formed between the uphole portion of the outer sleeve and the downhole portion of the intermediate sleeve. An inner sleeve is positioned within the intermediate sleeve and has an external sealing portion that restricts flow across the intermediate flow path when the downhole tool is in a first configuration.

Abstract: Embodiments described herein relate to injecting steam into a wellbore using a device. The device includes a body having a bore configured to communicate steam through the body. The device also includes a sleeve movable in the bore of the body between a first position and a second position, wherein the sleeve in the first position blocks steam from exiting an opening of the body and the sleeve in the second position allows steam to exit the opening of the body. The device can be activated by an activation device conveyed down a tubing string and can include a seat on which the activation device. The seat is expandable to allow the activation device to pass.

Abstract: A downhole tool and method of operation thereof is provided. The downhole tool may be configured to permit fluid communication between a combined flowbore of the casing string and the downhole tool and the subterranean formation or wellbore, or both, after a pressure test has been completed, a second threshold pressure is reached or applied, and a third threshold pressure has been applied to the downhole tool.

Abstract: A crossover tool for use in a wellbore includes: a tubular housing having a bypass port; a mandrel having a bore therethrough and a mandrel port in fluid communication with the mandrel bore, the mandrel movable relative to the tubular housing between a first position where the mandrel port is isolated from the bypass port and a second position where the mandrel port is aligned with the bypass port; and an actuator operable to move the mandrel between the first position and the second position. The actuator includes a first piston connected to the mandrel and a second piston operable in response to the first piston.

Abstract: Salt or acid solution is stored inside a frac sleeve instead of being pumped from a surface location. A mechanically-actuated valve releases the stored salt or acid solution into the borehole to electrochemically degrade the frac ball and allow it to pass through the seat. The stored fluid can be immediately released upon mechanical actuation or released after a specified delay using an integrated timer. In multiple sleeve applications a first ball shifts a first sleeve to open treatment ports and a second ball shifts a second sleeve to close the treatment port and open screened production ports while releasing the stored material either between the seated objects or above one of the seated objects to initiate the disintegration that will allow objects on both seats to disintegrate and pass through.

Abstract: A system to monitor the retrieval of a well tool from a wellbore comprises a deployment member coupled to the well tool to retrievably insert the well tool in the wellbore. At least one first identification transducer is coupled to a top end of the well tool to transmit an identification signal during retrieval of the well tool. At least one second identification transducer is located at at least one axial location along a surface pressure control assembly to detect the identification signal. A controller is in data communication with the at least one second identification transducer to determine the position of the well tool relative to the pressure control assembly, and to output at least one command related to the position of the well tool relative to the pressure control assembly.

Abstract: A technique facilitates pressure containment with a retrievable cement bushing. The retrievable cement bushing includes a body and an engagement lug that cooperates with a sleeve. The engagement lug is mounted on the body and is movable to a radially outward position for engagement with a corresponding portion of a surrounding wall, e.g an internal packer wall. The sleeve is sized to receive a slick joint therethrough and is secured to a radially inward position relative to the engagement lug via a retention member movably mounted on the sleeve, so as to hold the engagement lug in the radially outward position. The sleeve protects the slick joint from inwardly directed loading via the engagement lug when the retrievable cement bushing is subjected to differential pressures.

Abstract: An autonomous valve includes a fluid-sensitive actuator operable to automatically actuate the valve in response to being exposed to a target fluid. The target fluid may be a fluid whose presence is generally undesirable in a production fluid, such as water, and the valve may be actuated to stop flow from an interval within a wellbore that is no longer expected to produce hydrocarbon-bearing fluids. The valve further includes a protective layer disposed between the fluid inlet and the fluid-sensitive actuator, the protective layer being insoluble in the target fluid. The fluid-sensitive actuator may include a swellable piston that swells to actuate the valve in the presence of the target fluid, a soluble plug that isolates a hydraulic, closing piston until the soluble plug is dissolved into the target fluid, and an electromechanical actuator that closes the valve in response to detecting the target fluid using an electronic sensor.

Abstract: The present disclosure relates generally to data communication in subsea oil and gas drilling and production operations. In particular, data communication from sensors located on a piece of subsea oil and gas drilling and/or production equipment to a remote location, such as to a demodulation system, is disclosed. The data communication system can include sensors for measuring various characteristics of the subsea equipment, for coding the measured data into a signal, for transmitting the signal, and for ultimately decoding the signal. The signal is transmitted along the structures which provide the containment for existing hydraulic fluid lines associated with the subsea equipment by a variety of methods, such as by pulse position modulation and/or reverse time pulse position modulation. The communication system can further include a local power generator assembly to power associated sensors and transmitters.

Abstract: Variable flow, internally adjustable choke (100) configured to be incorporated into a production tubing (200) of a subterranean well (300). The internally adjustable choke (100) includes a cylindrical choke body (102) having a longitudinal centerline (104); a cylindrical flow adjustment sleeve (110) concentrically and interiorly located with respect to the body (102); a plurality of fluid inlets (120) into the body (102) that establish fluid communication from outside the body (102) to an inlet annular reservoir (122) within the body (102); a pair of cylindrical, longitudinally aligned annular rings (130, 132), each ring (130, 132) having a plurality of longitudinally oriented flow ports 140 therethrough; an outlet annular reservoir (160) within the body (102); and a plurality of open ports (170) through the sleeve (110), each at least partially radially aligned with the outlet annular reservoir (160) and open thereto for fluid communication therewith.

Abstract: A downhole actuator (30) comprises a tubular housing (34) which includes an indexing profile (42) on an inner surface thereof, and an indexing sleeve (46) mounted within the housing (34). The indexing sleeve (46) comprises an engaging arrangement including first and second axially spaced engagement members (52, 54) which cooperate with the indexing profile (42) of the housing (34) to be sequentially engaged by an actuation object (48) passing through a central bore (50) of the indexing sleeve (46) to drive the indexing sleeve (46) one discrete step of movement through the housing (34) towards an actuation site.

Abstract: A well treatment fluid uses ingredients that include an aqueous base, a non-associative, ionic, synthetic polymer, and optionally, at least one metal crosslinker. The polymer contains a backbone and a functional group that hinders hydrolysis of the backbone. The functional group is distributed at intervals on the backbone. A well treatment method includes forming a well treatment fluid by combining ingredients including a non-associative, ionic, synthetic polymer and a first aqueous base. The first fluid exhibits a first viscosity greater than a viscosity of the first aqueous base. The method includes treating a well during a stage using the first fluid exhibiting the first viscosity. A second well treatment fluid is formed by combining ingredients including the polymer, a second aqueous base, and at least one crosslinker and by crosslinking the synthetic polymer. The method includes treating the well during another stage using the second fluid exhibiting the second viscosity.

Abstract: A tubing string assembly for fluid treatment of a wellbore includes substantially pressure holding closures spaced along the tubing string, which each close at least one port through the tubing string wall. The closures are openable by a sleeve drivable through the tubing string inner bore.

Abstract: Disclosed are wellbore flow control devices that allow on-site field adjustments to flow characteristics. One disclosed well system includes a base pipe defining one or more flow ports and an interior, a first end ring and a second end ring each arranged about the base pipe, the second end ring being axially-offset from the first end ring such that a fluid compartment is defined therebetween, an autonomous inflow control device (AICD) arranged within the fluid compartment and having at least one fluid inlet and an outlet in fluid communication with the one or more flow ports, and a sleeve removably coupled to the first and second end rings and configured to be removed to provide access to the fluid compartment and the AICD in order to make on-site fluid flow adjustments to the AICD.

Abstract: A downhole tool, such as a toe sleeve, has an insert movably disposed in the housing's bore and sealably enclosing a second part of the communication path from a first port. A barrier disposed between the first and second parts of the communication path is breachable in response to a level of the applied pressure in the housing's bore. At least one retainer is engaged between the insert and the housing and at least temporarily retains the insert toward a closed position. The at least one retainer is at least partially composed of a dissolvable material and at least partially dissolves in response to the applied pressure communicated through the communication path to the second part. The at least one retainer when at least partially dissolved permits the applied pressure to initiate movement of the insert, such as from a closed position toward an opened position.

Abstract: A system and method for successively fracking a wellbore at spaced intervals along tubing having therein frac ports each openably closed by a sliding sleeve. The system has at least one actuation member and at least one cylindrical sand screen sub insertable into the tubing. Each actuation member has a collet sleeve with a radially-outwardly biased protuberance of a first profile configured to matingly engage an interior groove profile on at least one of the sliding sleeves and slide the sliding sleeve downhole to open the corresponding port. Each cylindrical sand screen sub has a dissolvable plug member or burst plate disposed on one end thereof allowing for the sand screen to be forced into the well by pressure acting against the plug or plate, and has a resiliently-outwardly biased protuberance configured for engaging a mating profile on the tubing and retaining the sand screen sub in a desired position.