Abstract: A downhole tool pumping apparatus comprising a body and an active valve block. The body comprises a cavity housing a reciprocating piston defining first and second chambers within the cavity. The active valve block comprises a plurality of active valves, wherein the plurality of active valves includes a first active valve fluidly connected to the first chamber of the body, the plurality of active valves includes a second active valve fluidly connected to the second chamber of the body, and each of the plurality of active valves is configured to be actively actuated between open and closed positions.

Abstract: A downhole valve for insertion in a production tubing string permits recirculation of fluid pumped into the casing annulus. The valve includes a cylindrical housing defining an opening, an internal mandrel disposed within the housing, defining a central bore and defining an opening, a valve between the housing and the mandrel, wherein said valve opens to allow fluid communication from the mandrel central bore to the annulus space in response to a pressure differential between the mandrel central bore and the annular space, and biasing means for biasing the valve in a closed position.

Abstract: A subsurface safety valve features vertically stacked springs that are each independently supported in the valve housing and each having an opposite end that bears on a shoulder connected to the flow tube. When mounted this way their applied force is additive as they are in effect mounted in parallel between the housing and the flow tube for overcoming hydrostatic pressure in deep set applications that can exceed 20,000 feet. The stacking also allows the cross-sectional area of the flow tube to be maximized for a given housing outside diameter dictated by well conditions.

Abstract: An actuator device for setting a downhole tool is disclosed. The actuator device includes a gas releasing material that releases a gas when activated by a solvent or other activator. The gas produced due to the contact with the activator is captured within a chamber in the downhole tool. As a result, gas pressure builds up inside the tool to move a piston and cause setting of the downhole tool.

Abstract: A control system can be used with a single control line to a subsurface safety valve. The operating piston is exposed to the flow tube between two blocks with near identical seals to make the piston insensitive to tubing pressure. A control system seal is carried by the piston in the upper block and a passage between the control system seal and the tubing pressure seal in the upper block communicates to a compressible fluid reservoir in the lower block that is also isolated from tubing pressure by a tubing pressure seal. Movement of the piston compresses the fluid in the reservoir. The reservoir can also include a spring to return the piston and the flow tube to a position to close the valve. A redundant system can be actuated if the primary system fails.

Abstract: Drill string flow control valves and more particularly, drill string flow control valves for prevention of u-tubing of fluid flow in drill strings are provided. Drill string flow control valves may comprise a valve housing, a valve sleeve axially movable within a valve housing from a closed position to an open position, a biasing mechanism for biasing the valve sleeve into the closed position, and a plurality of pressure ports for allowing a differential pressure to be exerted on the valve sleeve. The differential pressure exerted on the valve sleeve may be the result of an upstream pressure and a downstream pressure. By allowing a differential pressure resulting from a fluid flow to act on the valve sleeve, u-tubing in a drill string can be prevented or substantially reduced. Methods of use are also provided.

Abstract: Systems and methods for selectively operating multiple hydraulic pressure controlled devices (PCDs) within a borehole using a common inflow and outflow line and a common cycling line. A control system is used wherein each of the PCDs is operationally associated with a separate sleeve controller. The sleeve controller for each PCD controls whether the individual PCD can be actuated by hydraulic pressure variations in the common inflow and outflow lines.

Abstract: A differential pressure operated blanking tool comprises a Y-tool (2) having first and second limbs (4, 5) connected together via a throat (6) and a ball valve (9) selectively positionable to close one or other limb of the Y-tube against fluid flow.

Abstract: Implementations of various technologies are directed to a downhole actuation tool. In one implementation, the downhole actuation tool includes a tubular housing, an oil piston disposed inside the tubular housing, and a first housing disposed inside the tubular housing. The first housing includes an orifice. The downhole actuation tool may further include an oil chamber defined by the oil piston, the first housing and the tubular housing. The oil chamber includes oil. The downhole actuation tool may further include a sliding element disposed inside the tubular housing proximate the first housing.

Abstract: A control system for a downhole tool, such as a subsurface safety valve, features an operating piston that is insensitive to tubing pressure in the valve. The hydrostatic forces from the single control line from the surface are significantly reduced with a branch line to a piston bottom that is slightly smaller than the piston top. A variable volume between piston seals is connected to a low pressure compressible fluid reservoir to permit piston movement. The piston can be modular to facilitate assembly or bore offsets in the valve body. Failsafe closure upon seal failures is contemplated.

Abstract: A downhole tool and capillary biasing system includes a housing; an intrusion fluid contained within a portion of the housing; a capillary biasing member in fluid contact with the intrusion fluid; and a pressure application configuration capable of pressurizing the intrusion fluid within the housing and method.

Abstract: A gas inflow control system is used in a well. A downhole tool is combined with an automatic valve that is automatically actuatable to a flow position in the presence of a well liquid flowing into the downhole tool. In the presence of gas flow into the valve, the valve automatically transitions toward or to a closed position.

Abstract: A flapper type downhole valve is opened by flow against the flapper. The flapper and the housing contain magnets that hold the flapper open after it has been opened by flow to keep the flapper from chattering from the flow going past it. The strength of the force is not sufficient to hold the flapper open against a torsion spring on a pivot pin, when there is no flow through the valve. The valve can still be held in the locked open position with no flow through the housing by pressurizing the surrounding annulus to position another magnet to increase the holding force to a level greater than the force of the torsion spring. The additional magnet is spring biased so that upon removal of annulus pressure it shifts to allow the flapper to close. Alternative designs with and without a flow tube are possible. Fixed or movable restrictions can be associated with the flow tube to create a force to shift it to open a flapper with flow into the well.

Abstract: Embodiments of the invention are directed to a valve. In one embodiment, the valve includes a body having a first biasing member and a sealing member configured to axially move inside the body against the first biasing member to provide a path for fluid to flow from an interior region of the body to an exterior region of the body at a first predetermined pressure difference across the sealing member.

Abstract: A system is provided for switching between redundant control systems for a subsurface safety valve (SSV) while being able to isolate the closure spring from hydrostatic pressure in the control line of the system that is not being used. There are two control lines that connect to discrete operating pistons that are both coupled to the flow tube. Each operating piston is connected to a control rod with the control rods terminating near opposed ends of a pivoting member. Pushing down on one rod pushes up on the other rod so that the other rod is held supported and the hydrostatic pressure in its associated control line doesn't affect the force needed by the closure spring to close the SSV. Releasing control line pressure puts the system in neutral to allow either of the systems to be reselected.

Abstract: A gas lift valve has a flow restrictor, a valve part on one side of the flow restrictor, a flow deflector and a tubular member on another side of the flow restrictor, and a flapper valve on the side of the flow restrictor where the tubular member is located, the flapper valve being adjacent to the tubular member. When fluid flows into the gas lift valve at sufficient pressure, the valve part opens, the fluid flows through the flow restrictor and acts on the flow diverter thereby moving the tubular member and opening the flapper valve. The tubular member extends though the opening the flapper valve covered.

Abstract: The present invention generally relates to controlling the flow of fluids in a wellbore. In one aspect, a valve for selectively closing a flow path through a wellbore in a first direction is provided. The valve includes a body and a piston surface formable across the flow path in the first direction. The piston surface is formed at an end of a shiftable member annularly disposed in the body. The valve further includes a flapper member, the flapper member closable to seal the flow path when the shiftable member moves from a first position to a second position due to fluid flow acting on the piston surface. In another aspect, a valve for selectively closing a flow path through a wellbore in a single direction is provided. In yet another aspect, a method for selectively closing a flow path through a wellbore in a first direction is provided.

Abstract: A system that is usable with a well includes a tubular member and an inflow control device. The screen receives a well fluid flow, and the tubular member has a well fluid communication passageway. The inflow control device changes a momentum of the well fluid flow and/or introduces a flow resistance to regulate a pressure of the well fluid. The number of momentum changes and/or the flow resistance may be changed while the inflow control device is deployed downhole in the well.

Abstract: Two subs are held in a fixed position relative to each other when assembled to a string and run into a wellbore. A reservoir of fluid is defined in a wall between the subs. The reservoir has one or more outlets connected by a short jumper line to an adjacent tool to be operated. At the appropriate time, set down weight breaks a shear pin to reduce the reservoir volume and create pressure in the exit lines. The exit lines can be connected to operating pistons in adjacent tools to actuate them or to perform other desired functions using a stream of pressurized fluid. The device can be set for one time or multiple cycles where fluid in the reservoir can be replenished and re-pressurized for multiple cycles of operation.

Abstract: The present invention generally relates to controlling the flow of fluids in a wellbore. In one aspect, a valve for selectively closing a flow path through a wellbore in a first direction is provided. The valve includes a body and a piston surface formable across the flow path in the first direction. The piston surface is formed at an end of a shiftable member annularly disposed in the body. The valve further includes a flapper member, the flapper member closable to seal the flow path when the shiftable member moves from a first position to a second position due to fluid flow acting on the piston surface. In another aspect, a valve for selectively closing a flow path through a wellbore in a single direction is provided. In yet another aspect, a method for selectively closing a flow path through a wellbore in a first direction is provided.

Abstract: An isolation system employing a containment zone within the casing or tubing of a wellbore. The containment zone can be isolated from the wellbore pressure and leak tested to ensure no leakage is occurring across the zone. The isolation system prevents wellbore pressure below the system from communicating with the surface, thereby allowing for safe egress of tools from within the wellbore.

Abstract: A downhole tool for circulating fluid in a well bore. The tool includes an axial inlet and outlet with radial second outlets. A sleeve moves over the second outlets to control circulation of fluid. The sleeve can be selectively locked in an opened or closed configuration while the tool is in tension or compression. Variation of fluid pressure in the work string and stroking the tool move the sleeve between the operating positions. Cyclic operation of the tool is also described.

Abstract: A method and apparatus for actuating a downhole tool is provided. The apparatus of the present invention includes a remotely energized actuator device that facilitates storage of energy needed to actuate a downhole tool after the device is placed downhole. By energizing the tool downhole, surface exposure to potential safety hazards is reduced.

Abstract: The present invention is directed to an electric-hydraulic power unit. In one illustrative embodiment, the power unit comprises a body having a movable pressure barrier positioned therein, the movable pressure barrier defining first and second chambers therein, a configurable flow path in fluid communication with the first and second chambers, and at least one valve for configuring the flow path in a first state wherein fluid may flow within the flow path only in a direction from the first chamber toward the second chamber, and a second state wherein fluid within the flow path may flow in both directions between the first and second chambers.

Abstract: A subsurface safety valve for controlling a fluid flow through a well conduit includes a housing having a bore and disposed within an annulus defined by the space between the well conduit and the housing, a valve closure member movable between an open position and a closed position, and adapted to restrict the fluid flow through the bore when in the closed position, a flow tube moveably disposed within the housing and adapted to shift the valve closure member between its open and closed positions, a primary piston member in operative communication with the flow tube and a secondary piston member in operative communication with the flow tube.

Abstract: A well downhole liquid dispenser is disclosed in which an inlet/discharge port assembly is provided having an inlet port in fluid communication with the shoulders of a conical piston. The point of the conical piston is in physical contact with the discharge channel leading from the center of the inlet/discharge port assembly to the discharge ports on the exterior of the inlet/discharge port assembly. The piston is held in place by an adjustable tensioning mechanism by which the pressure required to depress the piston may be varied to match the hydrostatic column pressure of a liquid column connected to the inlet port of the dispenser such that when the hydrostatic column pressure reaches a desired level, the piston is depressed, allowing fluid to flow from the liquid column regardless of the exterior downhole pressure exerted on the point of the piston through the discharge ports.

Abstract: Presented is a subsurface safety valve in which the flapper mount, hard seat and spring housing have been integrated into a single assembly. To accommodate a “soft seat insert,” a special retainer soft seat ring and soft seat seal are provided. The soft seat seal fits over a conical protruding surface (hard seat) that surrounds the main bore of the safety valve on the bottom side of the spring housing. The retainer ring fits over the soft seat seal and holds it in place against the conical surface. Notches along the perimeter of an upper flanged end of the soft seat seal prevent gases, such as nitrogen, from becoming trapped behind the seal and potentially damaging it during a rapid decompression event. A gap between the upper flanged end of the soft seat seal and the lower spring housing allow the seal to move up and down the conical protruding surface as the flapper opens and closes, reducing compression of the seal and the risk of a compression set due to repeated opening and closing of the flapper.

Abstract: A multi-drop flow control valve system having a plurality of hydraulically actuated flow control valve, each valve set in an initial operating position. The flow control valves are connected to a hydraulic control line in sequence, wherein the second flow control valve is below the first flow control valve and so on. Wherein a first hydraulic pressure in the control line will operate at least the first flow control valve to an actuated position and a second hydraulic pressure greater than the first hydraulic pressure will operate at least the first and second flow control valves to actuated positions. It may be desired for each of the control valves to be biased in the initial position when the hydraulic pressure is less than a base pressure.

Abstract: A subsea production system is disclosed. The subsea production system may comprise a well head, a tubing spool, a tubing hanger, an annulus, a production tree, and a bypass flow path.

Abstract: The present invention is directed to an electric-hydraulic power unit. In one illustrative embodiment, the power unit comprises a body having a movable pressure barrier positioned therein, the movable pressure barrier defining first and second chambers therein, a configurable flow path in fluid communication with the first and second chambers, and at least one valve for configuring the flow path in a first state wherein fluid may flow within the flow path only in a direction from the first chamber toward the second chamber, and a second state wherein fluid within the flow path may flow in both directions between the first and second chambers.

Abstract: The present invention provides for a valve in a tubing string that allows the tubing string to fill with well fluids as the string is assembled and lowered into a well bore, but can be used to check pressure integrity of the tubing string during various stages of the assembly.

Abstract: A method and apparatus for actuating a downhole tool is provided. The apparatus of the present invention includes a remotely energized actuator device that facilitates storage of energy needed to actuate a downhole tool after the device is placed downhole. By energizing the tool downhole, surface exposure to potential safety hazards is reduced.

Abstract: This invention discloses a valve that generates a hydraulic negative pressure pulse and a frequency modulator for the creation of a powerful, broadband swept impulse seismic signal at the drill bit during drilling operations. The signal can be received at monitoring points on the surface or underground locations using geophones. The time required for the seismic signal to travel from the source to the receiver directly and via reflections is used to calculate seismic velocity and other formation properties near the source and between the source and receiver. This information can be used for vertical seismic profiling of formations drilled, to check the location of the bit, or to detect the presence of abnormal pore pressure ahead of the bit. The hydraulic negative pressure pulse can also be used to enhance drilling and production of wells.

Abstract: An isolation assembly for use with coiled tubing is described. The isolation assembly has a check valve for providing selective fluid communication through from the coiled tubing, through the isolation assembly, and into a downhole tool, such a straddle packer. The isolation assembly includes a shuttle moveable within a housing, and plurality of ports to selectively provide fluid communication from within the isolation assembly below the check valve, through the ports, and into the annulus, thus allowing selective surface-controlled equalization of downhole equipment. Also described is a bottom hole assembly including the isolation assembly. An improved method of fracing a formation includes providing a check valve, thus improving the life of the coiled tubing and the safety of the operation, and reducing the time to perform a given downhole operation.

Abstract: The invention relates to apparatus for controlling the flow rate of a fluid in tubing (4), said apparatus (5) comprising at least one hole (7) passing through the wall of said tubing and a moving shutterjacket (8) mounted to engage said hole. According to the invention, said apparatus further comprises deflector means (9) covering said jacket and said hole so that said deflector means directs the fluid through the wall of said tubing.

Abstract: A bi-directional seal assembly can be used in various types of cartridge valves including dirty fluid valves and a variety of other valves. The present seal assembly utilizes a seal spool, two O-rings and opposing seal cups. Back-up rings are provided to engage the O-rings to control deformation of the O-rings. The O-rings are compressed during manufacture of the seal assembly and the valve more than typically recommended by O-ring manufacturers. Because of this compression, the O-rings serve a dual function. At lower pressures, the O-rings act as a spring causing the seal cups to contact the opposing seal plates and at higher pressures they act as seals between the seal assembly and the valve.

Abstract: The present invention provides for a valve in a tubing string that allows the tubing string to fill with well fluids as the string is assembled and lowered into a well bore, but can be used to check pressure integrity of the tubing string during various stages of the assembly.

Abstract: An underground drilling method and apparatus generates intense pressure pulses at a location at the surface. The pressure pulses propagate down through a drill string to a drill bit. The pulses may be generated by creating water hammer in flowing drilling mud. Intensity of the acoustic pulses is increased in the bit nozzles. Vigorous pulsing of the fluid exiting the bit nozzles results in better cleaning of the hole bottom and faster drilling. The pulses may be used to drive the operation of various down hole tools. One type of tool has multiple pistons arranged in series. High pressure pulses move the pistons to generate strong mechanical vibration in the drill string. Vibration of the drill string may also reduce the friction between the drill string and the hole, resulting in lower torque requirements.

Abstract: A tubing retrievable safety valve (50) having a non annular hydraulic chamber (60) in a sidewall portion thereof is operable to received a communication tool (100) therein such that relative rotation between at least a portion of the communication tool (100) and the tubing retrievable safety valve (50) is substantially prevented. The communication tool (100) is operable to create a fluid passageway (150) between the non annular hydraulic chamber (60) and the interior of the tubing retrievable safety valve (50) by penetrating through the sidewall portion and into the non annular hydraulic chamber (60). Thereafter, when a wireline retrievable safety valve (44) is positioned within the tubing retrievable safety valve (50), hydraulic fluid is communicatable thereto through the fluid passageway (150).

Abstract: A mud saver valve being operable in conjunction with a top drive unit to retain mud in the top drive unit when a tubular is disconnected therefrom. The valve utilizes a spring-loaded piston to control the flow of mud or other fluid onto the work area and environment while the top drive unit is being connected to the new tubular and re-connected to the original tubular string. The valve further comprises multiple check valves for evaluating as well as monitoring wellbore pressure. The valves provides for full bore flow passages for the mud or fluid being pumped into a tubular fluidly connected to the top drive.

Abstract: A multi zone isolation tool (50) for use in a subterranean wellbore includes a first tubular and a second tubular disposed within the first tubular forming an annular flow path (110a, 110b) therebetween and a central flow path (70a, 80a, 80b) through the second tubular. An annular valving assembly (90, 80) is positioned in the annular flow path (110a, 110b) and a central valving assembly (148, 186) is positioned in the central flow path (70a, 80a, 80b). The central valving assembly (186) is operably coupled to the annular valving assembly (90) such that when the central valving assembly (148, 186) is in a closed position, a pressure variation in the central flow path (70a, 80a, 80b) will operate the annular valving assembly (90, 80) from a closed position to an open position.

Abstract: A valve for downhole use allows flow of mud or completion fluids but closes when subjected to produced hydrocarbons. The flow through the valve is through an annular passage that features a sleeve preferably made of rubber. The passage remains open during completion operations, but when hydrocarbons are produced the rubber swells and the passage is closed off. Applications include completions involving long horizontal runs and small inside diameter laterals where access to a sliding sleeve with coiled tubing or a wireline run tool is not practical.

Abstract: A subsurface safety valve has a closure sleeve or rod mounted below the closure mechanism. Control signal pushes the sleeve up (uphole) or down (downhole), whichever is applicable, which causes the closure element to rotate (or slide, or otherwise translate) to its open position. A loss of control signal allows the closure spring to push the sleeve or rod downhole (or uphole, whichever is appropriate). This movement causes the closure element to be driven to its closed position against the seat.

Abstract: An interventionless bi-directional barrier device of a downhole tool for use in a wellbore and a method of utilizing the barrier device to control the flow of production fluids in the wellbore are described herein. The barrier device includes a flapper mechanism having first and second flappers articulably linked together and articulably linked to a base member that is slidable within the downhole tool. The flapper mechanism provides a seal between opposing uphole-and downhole ends of the downhole tool upon actuation thereof. The method of controlling the flow of production fluids in the wellbore includes closing the barrier device to block flow through the tool, supporting the barrier device from a pressure exerted from a first direction, and supporting the barrier device from a pressure exerted from a second direction.

Abstract: Bypass valve for use in wellbores, particularly during the setting of hydraulic anchor packers, a bypass valve is provided with a body (4) incorporating a wall provided with at least one opening (20) and a piston (30) slidably mounted and having a longitudinal bore extending therethrough. The piston (30) is movable between a first position, in which the bore of the piston (30) is substantially isolated from the exterior of the body (4), and a second position in which a passage is provided from the bore of the piston (30) to the exterior of the body (4). Constraining means (42, 52) prevent movement of the piston (30) from the first to the second position. Overriding means are provided to permit movement to the second position.

Abstract: An in-line flow control device for a well chokes flow through a conduit while allowing access therethrough.

Abstract: A system for the downhole injection of chemical into a well through capillary tubing using a surface chemical pump includes downhole injection valve. The downhole injection valve includes an upstream and a downstream check valve connected in series. The upstream check valve has an adjustable spring bias. The amount of bias is dependent on the nature of the well and the system for inserting chemical through the capillary tube into the well. The lower check valve has a fixed bias and protects the injection valve from the unwanted backflow of gas, fluids or solids.

Abstract: A downhole safety valve for a central circulation completion system having concentric inner and outer tubular members defining a production bore therebetween comprises a generally cylindrical body which includes an outer surface which is sealed to the outer tubular member and an axial through bore to which the inner tubular member is secured. In this manner, the downhole safety valve forms a pressure barrier between a first portion of the production bore located below the body and a second portion of the production bore located above the body. The downhole safety valve further comprises at least one flow passage which extends through the body and communicates between the first and second portions of the production bore, and at least one closure member which is disposed across the flow passage to control fluid flow between the first and second portions of the production bore.

Abstract: A subsurface safety valve for controlling fluid flow in a well bore. In one embodiment, the subsurface safety valve includes a tubular member having a longitudinal bore extending therethrough, a curved flapper removably connected to the tubular member. The curved flapper is configured to pivot against the tubular member between an open position and a closed position. The subsurface safety valve further includes a hard seat positioned inside the tubular member, in which the hard seat defines a seating surface configured to receive a sealing surface defined on a bottom periphery portion of the curved flapper to form a sealing interface having a slope that varies along the sealing interface.

Abstract: A cyclic check valve is provided for a coiled tubing string which enables reverse circulating for a specific period when a specific combination of pumping condition and oil conditions are favorable. The check valve may be activated to prevent reverse flow up through the valve and into the coiled tubing in the event of a failure of the coiled tubing at surface. The valve may be de-activated to allow reverse circulating. The check valve includes a flapper valve which may be de-activated by shiftable sleeve locked in place by a J-slot assembly. The check valve may be cycled from the activated to de-activated position and verified by a change in pressure drop through the tool.