Abstract: A downhole deployment and isolation system may be used to deploy a completion string, service the well, and isolate the lower completion string, optionally in a single trip. The lower completion string may be run into the well with a valve in an open condition, such as a ball valve propped open by a mandrel. The mandrel may be operable to both disconnect the work string from the lower completion string and to close the valve upon disconnecting such as by removing the mandrel from the ball. The valve may be remotely reopened with fluid pressure form surface.

Abstract: A fluid control device includes a housing, a fluid channel defined within the housing, the fluid channel having an inlet, and a restriction assembly. The restriction assembly includes a cantilever device disposed within the fluid channel and defining a restricted fluid path, the cantilever device configured to deform to reduce an area of the restricted fluid path and restrict a flow rate of fluid flowing therethrough based on a property of the fluid.

Abstract: A valve assembly for integration within a wellbore string disposed within a subterranean reservoir is provided. The valve assembly includes a valve housing having one or more injection ports for establishing fluid communication between a central passage and the reservoir. The valve assembly includes a valve sleeve operatively mounted within the valve housing and comprising a fluid channel adapted to establish fluid communication between the central passage and the injection ports, and configured to create a fluid flowrate restriction. The valve assembly has a flow adjuster connectable to the valve sleeve, and is selectively arranged to align an opening with the fluid channel and allow fluid to flow from the fluid channel through the opening to the injection port, wherein connecting the flow adjuster to the valve sleeve defines a flow length of the fluid channel to adjust the fluid restriction created by the fluid channel.

Abstract: Ball valves, methods to close a ball valve, and methods to form a well barrier are discussed. A ball valve includes a valve housing and a ball that is rotatably movable from an open position to a closed position. The ball valve also includes an actuation mechanism operable to rotate the ball from the open position to the closed position, where a fluid passage of the ball is not aligned with a fluid passage of the valve housing while the ball is in the closed position. The ball valve further includes a sleeve disposed in the valve housing and operable to shift from a first position to a second position to actuate the actuation mechanism.

Abstract: A flow stopper has an elongated shape for positioning in a tubular cavity of a check valve. The elongated shape has a concave section such that the flow stopper can impact a line running along an inner surface of a housing forming the tubular cavity in a lengthwise direction of the tubular cavity. The concave section allows the flow stopper to impact the housing with a first point of contact and a second point of contact on the line, and the two points of contact are separated by a gap where the flow stopper does not contact the housing. The flow stopper may include a first and a second ball where the balls are connected by a stem. The flow stopper may also include a plurality of balls that are not connected to each other. The flow stopper may include a ball connected to a stem.

Abstract: Fluid flow control devices and downhole floats are presented. A fluid flow control device includes a port and a rotatable component that rotates about an axis in response to fluid flow from the port. The fluid flow control device also includes an outlet port that provides a fluid passageway out of the rotatable component. The fluid flow control device further includes a float positioned within the rotatable component, where the float is shiftable from an open position to a closed position, and where the float restricts fluid flow through the outlet port while the float is in the closed position.

Abstract: A toe valve (1) comprising; a housing (200) having an interior and exterior; a sliding sleeve (8); a counter mechanism (2) comprising a cylinder, a ratchet piston (11, 27) with first and second ends, and a ratchet shaft (14, 28) connected to the second end; a trigger assembly (3) comprising a trigger housing, and a release piston (19), wherein the trigger assembly (3) is arranged between the counter mechanism (2) and the sliding sleeve (8), and wherein the release piston (19) is configured to activate the sliding sleeve (8), and the ratchet shaft (14, 28) is configured to activate the release piston (19), wherein the toe valve (1) further comprises; a closed chamber (15) enclosing the ratchet shaft (14, 28) and defined at least partly by the cylinder comprising a chamber fluid with a chamber pressure (P2); an inlet pressure port (6) configured to be in communication with a wellbore fluid with a wellbore pressure (P1), and wherein the first end of the ratchet piston (11, 27) is in fluid communication with the

Abstract: A work string and method of performing a downhole operation is disclosed. The work string includes a first tool having a first ball seat configured to activate when a first activation pressure is applied to a plug seated at the first ball seat, and a second tool having a second ball seat configured to activate when a second activation pressure is applied to the plug when seated at the second ball seat, wherein the first activation pressure is different than the second activation pressure. A plug is dropped through a string in a wellbore. The first activation pressure is applied when the plug is at the first tool to activate the first tool. The second activation pressure is applied when the plug is at the second tool to activate the second tool.

Abstract: An adjustable flow control device. In one aspect, the flow control device comprises a base pipe having one or more openings extending from an exterior to an interior of the base pipe; and a movable sleeve positioned along the interior of the base pipe, the movable sleeve having one or more associated openings extending from an exterior to an interior of the movable sleeve, and configured to rotate to a first position that aligns a first of the base pipe openings with a first of the movable sleeve openings.

Abstract: Provided is a fluid loss device, a well system, and a method for fracturing a well system. The fluid loss device, in this aspect, includes a dissolvable member coupled to an opening sleeve, the dissolvable member operable to fix the opening sleeve in a first opening sleeve position when an internal prop sleeve is in the first prop sleeve position and for a period of time after the internal prop sleeve moves to the second prop sleeve position, and then dissolve triggering the opening sleeve to move from the first opening sleeve position to the second opening sleeve position.

Abstract: A method of improving production in a steam assisted gravity drainage operation, the method including positioning a tubular system within a borehole, the tubular system including a plurality of inflow control devices; injecting steam into a formation to assist in drainage of targeted resources from the formation; receiving fluids at an inlet of the inflow control devices; and regulating thermal conformance in the formation by choking liquids at the inflow control devices when the liquids have a subcool lower than a predetermined subcool at a selected drawdown pressure.

Abstract: Stimulation sleeve (1) for well intervention in a subterranean wellbore, comprising: a housing (10) having a through channel (11) with a first end (11a) and a second end (11b), and one or more flow ports (14), and a sliding sleeve (13) disposed axially movable within the housing (10) to open or close said flow ports (14). Said sliding sleeve (13) is equipped with at least a first obturator seat (15) for receipt of a obturator (17) to partially or fully close fluid communication in the through channel (11) of the housing (10), and a time delay mechanism (20) to allow the sliding sleeve (13) to axially travel in the housing (10) at a predetermined speed to open or close said flow ports (14). The invention also discloses a method for well completion in a subterranean wellbore using a sliding sleeve (1).

Abstract: An apparatus and method for controlling the flow of a fluid from a subterranean well zone to a pipe located within a bore in the well zone. The apparatus comprises an elongate tubular body having an interior passage and a valve passage extending between an exterior of the tubular body and the interior passage with a sliding sleeve adapted to selectably cover and uncover the valve passage. A chamber is formed on one end of the sliding sleeve with an elongate narrow passage extending thereto from the exterior of the tubular body, wherein a pressure drop of the fluid through the elongate narrow passage is adapted to move the sliding sleeve between a closed and an open position. A flow restrictor between the chamber and the interior passage of the tubular body has a pressure drop dependent only upon a flow rate of the fluid therethrough.

Abstract: A tubular for downhole use including a wall defining an inner bore; a fluidic passageway formed within the wall that is fluidically isolated from the inner bore; a portion of the wall being located between the inner bore and the fluid passageway and configured to maintain fluidic isolation between the inner bore and the fluid passageway until an opening is formed through the portion.

Abstract: A system and method directed to performing a single trip cementing operation at spaced out locations within a hydrocarbon zone during the construction of a wellbore using a wellbore fluid communication tool. In an embodiment, the tool is deployed on a tubular string above the hydrocarbon zone and comprises a housing including at least one radial port, a seal assembly, an outer sleeve assembly having a door assembly operable to translate across the seal assembly while closed, an inner mandrel and a seat assembly. The tool facilitates the placement of cement within a wellbore annulus from an uphole position in lieu of at the bottom of the wellbore thereby minimizing the pressure required to perform cementing job. At the same time, the ability for the door assembly to translate across the seal assembly while closed ensures the seal is not damaged from repetitive opening and closing of the door assembly.

Abstract: A downhole catcher device comprises a catching mechanism which is configured to be transferable between a first mode and a second mode. The catching mechanism is further configured for passing by a first operation element if the catching mechanism is in the first mode and for catching a second operation element if the catching mechanism is in the second mode. The transfer between the first and the second mode is triggered (or effected) by a downhole tool which is operated by the second operation element.

Abstract: A gravel pack flow path used to flow slurry fluids during a gravel pack phase may be closed or at least limited with a swellable metallic material prior to a production phase. An example apparatus may include a base pipe, a screen disposed about the base pipe, an inflow control device having an ICD flow path in fluid communication with an outer annulus between the screen and base pipe. The gravel pack flow path defined in part by perforations in a base pipe or by a secondary housing. A swellable metallic material is activated to close the gravel pack flow path in response to a reactive fluid.

Abstract: A completion assembly defines a throughbore and comprises an isolation valve configurable between an open state (permitting fluid to flow through the throughbore) and a closed state (preventing fluid from flowing through the throughbore). A method for use in installing the assembly into a wellbore in a single trip comprises running the assembly into the wellbore with the valve in the open state until a downhole end of the assembly reaches a target position; injecting a fluid through the throughbore and the valve when the valve is in the open state; configuring the valve into the closed state; and performing a pressure integrity test of the throughbore above the valve. The valve is configurable between the open and closed states without any requirement for the valve to be mechanically engaged by an activation member or a tool whilst the valve receives power from a power source.

Abstract: A flow control apparatus is provided comprising: a housing including a port; a housing passage disposed within the housing; a flow control member, displaceable, relative to the port, for effecting opening of the port; and a co-operating member. The flow control member and the co-operating member are co-operatively configured such that displacement of the flow control member, relative to the port, is with effect that a force is applied by the flow control member to the co-operating member, with effect that a seating surface is obtained for receiving a flow communication interference body that is being conducted through the housing passage. The seating surface is obtained in response to a deformation effected by the applied force.

Abstract: A counter including a housing disposed about a tubular creating a space therebetween, a piston disposed in the space and responsive to pressure up events in the tubular to compress a transfer chamber, a supply chamber fluidly attached to the transfer chamber; a trigger chamber fluidly attached to the transfer chamber wherein sequential pressure events cause the piston to move fluid from the supply chamber to the trigger chamber. A counter including a fluid incrementing configuration, an activation member in fluid force communication with the fluid incrementing configuration, the activation member having a first position where a fluid port is blocked and a second position where the fluid port is unblocked, the fluid port being fluid pressure connected to a tool to be actuated when the activation member is in the second position.

Abstract: A frac sleeve assembly and method of operation. The frac sleeve assembly includes a ball seat that retains a frac ball. The ball seat moves within a sleeve. The sleeve includes a profile that separates the first half and the second half to allow passage of the frac ball through the ball seat when the ball seat moves within the sleeve. Alternatively, the ball seat has a ring for receiving the frac ball and the sleeve has a protrusion that selectively engages a shifting pin to move the ring with respect to a ridge to release the ball from the ball seat when the ball seat moves within the sleeve.

Abstract: A suspended fluid sampling and monitoring system includes a BOP, the BOP attached to a wellhead. The BOP is positioned above a wellbore. The suspended fluid sampling and monitoring system further includes a TEC, the TEC connected to a sensor package. The TEC and sensor package extend through the BOP into the wellbore. The suspended fluid sampling and monitoring system also includes a fluid sample line, the fluid sample line extending through the BOP into the wellbore. The suspended fluid sampling and monitoring system also includes a fluid sample intake and filtration device, the fluid sample intake and filtration device mechanically coupled to the fluid sample line within the wellbore.

Abstract: An actuation device may include a plurality of actuation units disposed about an axis. Each actuation unit of the plurality of actuation units may include a shape memory alloy component, an auxetic material component operationally coupled to the shape memory alloy component, and a power source operationally coupled to the shape memory alloy component. Additionally, the actuation device may include a control system operationally coupled to the power source, the control system is configured to actuate the shape memory alloy component through the power source. Further, when actuated, the shape memory alloy component moves in a direction outward from the axis to pull the auxetic material component, and the auxetic material component expands in a direction perpendicular to the movement direction of the shape memory alloy component.

Abstract: A technique facilitates wellbore operations and utilization of wellbore equipment, e.g. equipment comprising actuation devices for downhole tools. According to an embodiment, the system comprises a pump solution for an electrically control device, e.g. an electrically controlled valve. The system may comprise hydraulic circuitry which utilizes bellows to effectively enclose the hydraulic circuitry. Consequently, the system enables an electrically control downhole system having components hydraulically actuated via a closed loop hydraulic system.

Abstract: Flow control systems are described for variably resisting flow of a fluid composition dependent on the surface energy of the fluid composition. Surface energy is a measure of the wettability of a surface with a particular the fluid. Surface energy dependent flow resistors of the present disclosure include a support structure extending across and/or filling a control passageway such that the surface area exposed to a fluid may be maximized. The flow control systems described may autonomously distinguish between fluid compositions having high and low proportions of a desired fluid component even when the fluid compositions have substantially equal viscosities. Flow control valves are described which may be employed in downhole production and injection equipment.

Abstract: A downhole gravel packing apparatus, comprising: a tubular assembly for being arranged within a wellbore to define an annulus between said tubular assembly and a wall of the wellbore; and a control valve provided within the tubular assembly to control flow of a gravel pack carrier fluid between external and internal regions of the tubular assembly, the control valve comprising a fluid reactant arrangement which reacts with a first fluid to reconfigure the control valve from a first configuration in which flow through the control valve is permitted during a gravel packing operation, and a second configuration in which flow through the control valve is restricted.

Abstract: A shunt tube entry device comprises one or more inlet ports, a shroud disposed at least partially about a wellbore tubular, and a shunt tube in fluid communication with the chamber. The shroud defines a chamber between the shroud and the wellbore tubular, and the chamber is in fluid communication with the one or more entry ports.

Abstract: A method and apparatus for a locking system for a downhole tool. The locking system includes a first portion having a plurality of displaceable members, a second portion disposed around the first portion; a locked position wherein axial movement between the members is prevented; and an unlocked position wherein axial movement between the members is permitted.

Abstract: Downhole electrical energy harvesting and communication in systems for well installations having metallic structure carrying electric current, for example CP current. In some instances there is a harvesting module (4) electrically connected to the metallic structure (2) at a first location and to a second location spaced from the first location, the first and second locations being chosen such that, in use, there is a potential difference therebetween due to the electric current flowing in the structure (2); and the harvesting module (4) being arranged to harvest electrical energy from the electric current. In addition or alternatively, there may be communication apparatus (4, 5, 6) for communication by modulation of the current, for example CP current, in the metallic structure (2).

Abstract: An apparatus includes a cylindrical housing having a hinge, a flapper attached to the hinge, and a slidable element is within the cylindrical housing, wherein the flapper can rotate from a first flapper position to a second flapper position. The slidable element is slidable from a first position to a second position and engages with the flapper at the first position to prevent the flapper from moving to the second flapper position. The flapper is movable to the second flapper position when the slidable element is disengaged from the flapper. The apparatus also includes a latching mechanism attached to the slidable element movable from a first latching mechanism position to a second latching mechanism position. The slidable element is at the first position when the latching mechanism is at the first latching mechanism position and at the second position when the latching mechanism is at the second latching mechanism position.

Abstract: A frac plug system downhole tool and method of securing a frac plug system in a wellbore. A mandrel extending from a first end to a second end. A setting assembly is on the first end of the mandrel and is movable along the mandrel. An anchor is at the second end of the mandrel and is expandable to engage the wellbore. A gas generates a pressure to move the setting assembly along the mandrel to expand the anchor at the second end of the mandrel.

Abstract: A gas migration prevention module can include a housing, control line connections configured to connect the housing between control line sections, spaced apart pistons sealingly received in the housing, and a fluid volume defined between the pistons. A control line system can include an upper control line section, a lower control line section in fluid communication with a downhole tool, and a gas migration prevention module connected between the upper and lower control line sections, the lower control line section providing fluid communication between the gas migration prevention module and the downhole tool, and the gas migration prevention module comprising spaced apart pistons and a fluid volume defined between the pistons, the fluid volume being in fluid communication with an exterior of the gas migration prevention module.

Abstract: A directional drilling device for drilling a borehole having a borehole wall, the device including an outer housing and a driveshaft selectively rotatable with respect to the housing and including an axial flow bore and a through port formed in the driveshaft wall. The device also includes one or more borehole engagement members rotatable with and radially moveable with respect to the outer housing toward engagement with the borehole wall to urge the directional drilling device in a radial direction with respect to the borehole. The device further includes a mud pressure actuation system. The mud pressure actuation system controls fluid flow through the through port to control hydraulic pressure on a piston device and thus movement of the borehole engagement members into engagement with the borehole wall to maintain a rotational position of the outer housing and the corresponding radial direction in which the device is being urged.

Abstract: Methods and systems for producing hydrocarbons in a subterranean well with a completion system include landing an isolation valve completion within the subterranean well. The isolation valve completion is landed within an observation wellbore and downhole of a junction with a production wellbore. The isolation valve completion includes an isolation valve. A production tubing is delivered into the subterranean well. The production tubing has a downhole end located uphole of the junction with the production wellbore. An annulus defined between an outer diameter surface of the production tubing and an inner diameter surface of the subterranean well is sealed with a production packer that circumscribes the production tubing.

Abstract: A circulation sub assembly for circulating fluids in a subterranean well includes a circulation sub body that is a generally tubular shaped member with a sub central bore. A circulation port extends through a sidewall of the circulation sub body. A valve member is moveable between a closed position where the valve member prevents a flow of fluid through the circulation port and an open position where the valve member provides a fluid flow path through the circulation port. An actuation assembly includes an isolated hydraulic fluid system operable to move the valve member between the closed position and the open position. A control system includes an electronic processor, a memory, a data transmitter, and a data receiver. The control system is operable to instruct the actuation assembly to move the valve member between the closed position and the open position.

Abstract: Downhole electrical energy harvesting and communication in systems for well installations having metallic structure carrying electric current, for example CP current. In some instances there is a harvesting module (4) electrically connected to the metallic structure (2) at a first location and to a second location spaced from the first location, the first and second locations being chosen such that, in use, there is a potential difference therebetween due to the electric current flowing in the structure (2); and the harvesting module (4) being arranged to harvest electrical energy from the electric current. In addition or alternatively, there may be communication apparatus (4, 5, 6) for communication by modulation of the current, for example CP current, in the metallic structure (2).

Abstract: A downhole tool string for conveying within a wellbore, including an engagement device for engaging a downhole feature located within the wellbore, a first actuator for applying a substantially non-vibrating force to the engagement device while the engagement device is engaged with the downhole feature, and a second actuator for applying a vibrating force to the engagement device while the engagement device is engaged with the downhole feature.

Abstract: A system and method to actuate a downhole tool, where the tool can include a body, a closure member and a degradable actuation ring. A profile of the actuation ring can be configured to engage an actuation tool (e.g. shifting tool, ball drop, dart, plug, etc.) used to displace the activation ring via the engagement and thereby displacing the closure member to a different position. The degradable actuation ring can be degraded by an agent downhole to degrade and/or remove the actuation ring from the downhole tool thereby providing an increased clearance through the tool.

Abstract: An extraction systems in the oil sector, in particular to the equipment intended for the completion of the wells after their drilling; more in particular, the system relates to a safety valve for artificial lifting wells driven by reciprocating downhole rod pumps.

Abstract: A flow system, comprising: a flow control device, wherein a portion of the flow control device is disposed within a fluid pathway, wherein the flow control device is configured to rotate, wherein the flow control device comprises floats, wherein the floats block a potential flow path for fluids to travel through an outlet of the flow control device; a regulatory valve, wherein the regulatory valve is configured to receive a remaining portion of fluids from the fluid pathway; a control line, wherein the control line couples the outlet of the flow control device to the regulatory valve; an offset line, wherein the offset line provides fluid communication between fluids that travel past the flow control device and the regulatory valve; and a fluid restrictor, wherein the fluid restrictor is disposed within the fluid pathway upstream from the flow control device, wherein the fluid restrictor is configured to reduce fluid pressure.

Abstract: The invention relates to the oil industry and the production of oil. An insert safety valve is mounted inside a piping safety valve in a production tubing string and comprises a housing having a longitudinal bore, an upper landing assembly with extendable slips for fixing inside the piping safety valve having a landing nipple, a hydraulic line, annular seals and a valve device with a spring-driven element. The insert safety valve is mounted on a carrying cable, the hydraulic line has tubes connected to two valves. The first valve is connected to the piping safety valve housing in the production tubing string, and the second valve extends to a port in the inner portion of the landing nipple. A hollow sleeve functions as a moving element, and the valve device is formed as openings in the sleeve and in the housing, wherein the openings are configured to being aligned.

Abstract: A substance deposition and backflow preventing arrangement including a housing having a port therein, a sleeve disposed within the housing and positionable to cover or uncover the port, the sleeve having a first seal at one end thereof presenting a first hydraulic dimension and a second seal at another end of the sleeve having a different hydraulic dimension, a biasing member operably connected to the sleeve and to the housing and configured to urge the sleeve to a position covering the port.

Abstract: An exemplary activation device for a downhole tool includes an outer shell configured to sealingly engage a seat and configured to be sheared by the seat whereby the activation device can pass through the seat.

Abstract: Downhole tools including a wellbore isolation device that provides a plurality of components including a mandrel, and a slip assembly comprising a plurality of slip elements including a slip wedge and a slip, wherein an element of the slip assembly is composed of a degradable metal material, and wherein the slip comprises a slip insert embedded therein, the slip insert having a compressive strength of greater than about 120,000 psi.

Abstract: Bypass devices are disclosed for providing alternative flow paths within an annulus formed around a production string of a subterranean wellbore. In some embodiments, the bypass devices include inlet flow paths and outlet flow paths in fluid communication with the annulus so that fluids may flow through the inlet and outlet flow paths to bypass a blockage in the annulus. The bypass devices are also configured to avoid internal blockages within the internal flow paths defined by the inlet flow paths and outlet flow paths.

Abstract: An object removal enhancement arrangement including a seat, a volume movable with the seat, the volume being protected in a first condition of the seat and unprotected in a second condition of the seat, and a material disposed within or as a part of the volume, the material degradative of an object.

Abstract: An untethered sensing object able to sense and record well fluid and wellbore parameters. The untethered sensing object is adapted to transmit recorded data towards a communication module of a toolstring, whereas the toolstring is conveyed from surface and reaches a proximity distance with the untethered sensing object inside the well fluid of a wellbore. The untethered sensing object includes at least one sensor, an acquisition module, a recording module and a transmitting module.

Abstract: A dissolvable frac plug is disclosed. The dissolvable frac plug has an internal chamber surrounded by an external wall with the chamber containing a dry powder component in an amount sufficient to combine with ground water or other wellbore fluids to form a solution or environment that enhances dissolution of the plug. The dry powder is released from the chamber as a portion or portions of the external wall dissolves due to contact with water or other wellbore fluids.

Abstract: Provided is a multi-functional well completion apparatus and method of operation thereof that offers the ability, in a single trip and with limited running tool manipulation, to perform a sand control frac or other fluid stimulation operation and reverse out operations that has improved reverse out flow rates. Furthermore, a combination of dropped balls and hydraulic pressure open one or more sleeves for selective access to a plurality of isolated zones. Additionally, a combination of concentric pipe and internal flow paths creates a reverse flow path. This reverse flow path provides a live annulus during treating, the ability to take returns, and the ability to reverse excess proppant from the wellbore.

Abstract: A pressure response fracture port tool and method for its use reliably provides a noticeable indication at surface to an operator as to when the flow port is opened. The tool includes an outer housing and a sliding sleeve which resides within the outer housing. The outer housing has a first and second set of flow ports. The inner mandrel moves between a first position and a third position to expose the flow ports to the wellbore. The first set of flow ports, with its smaller area relative to the second set of flow ports, creates a noticeable pressure increase or spike that can be observed at surface when exposed to the wellbore. The second set of flow ports creates a noticeable pressure drop when it is exposed to the wellbore.