Abstract: A system is provided that is conducive to multi-stage stimulation in a near-continuous fashion. That is, unlike conventional stimulation systems, embodiments herein may operate without the requirement of traditional plug-setting, perforating and fracturing interventions on a zone by zone basis for a cemented completion. Rather, the system is outfitted with frac sleeves that may be shifted open to expose the bore to the formation while simultaneously achieving a seal through a ball drop technique. Once more, this manner of operation is rendered practical by the sleeve being of a passable configuration such that cementing of the casing is not impeded.

Abstract: Hydraulically fracturable downhole valve assembly and methods for using same are provided. The method can include setting a downhole tool in the wellbore. The downhole tool can include a body having a bore formed therethrough, and one or more sealing members disposed therein. The one or more sealing members can include an annular base and a curved surface having an upper face and a lower face, wherein one or more first radii define the upper face, and one or more second radii define the lower face, and wherein, at any point on the curved surface, the first radius is greater than the second radius. The sealing members can be disposed within the bore of the tool using one or more annular sealing devices disposed about the one or more sealing members. The method can also include fracturing the one or more sealing members using pump pressure, formation pressure, percussion, explosion, or a combination thereof.

Abstract: A bi-directional fluid safety valve for preventing spillage when filling tanks, vessels, fill lines, and or hoses for transportation of fluids in pipelines or tubulars with a tubular body with an external body and an internal bore having a fluid flow path from a first end to a second end, the first and second members concentrically disposed and moveable along a longitudinal axis within the tubular body; with means such as springs to longitudinally bias the first member toward the second member and means to longitudinally bias said second member toward said first member. Also provided are embodiments for connection of the tubular body to alternative connection systems.

Abstract: A system is provided that include a safety device configured to mount in a mineral extraction system and block axial movement of a plug in the mineral extraction system while the plug is released from a retainer. The safety device may be a sleeve configured to receive screws or other retention mechanism in a tubular. A method is provided that includes installing a plug safety catch into a tubular of a mineral extraction system in which the plug is configured to block axial movement of a plug in response to a pressure differential while the plug is released from a mount position.

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: Certain aspects and embodiments of the present invention are directed an inflow control device tube that can be disposed in a wellbore through a fluid-producing formation. The inflow control device tube can include a body, such as a tubular body, and an inlet portion at a first end of the body. The inlet portion can be integrally formed with the body. The inlet portion can be adapted to provide a fluid bypass for a fluid flowing from the inlet portion to an outlet portion at a second end of the body. The fluid bypass can be shaped to allow fluid to bypass one or more objects causing a blockage at an opening of the inlet portion.

Abstract: A drill string element for use in the drilling of a borehole, the drill string element comprising: a main body; and a flow control mechanism, wherein the drill string element defines a first aperture, another aperture and a passage configured to provide a fluid flow path between the first aperture and the other aperture, the first and other apertures provide fluid communication between a volume around the drill string element and the passage, and the flow control mechanism is configured to inhibit the flow of fluid through the passage in a first operating mode and to permit the flow of fluid through the passage in a second operating mode.

Abstract: Two control systems are provided to run in parallel between a surface location and the final controlled element, in this case a subsurface safety valve. The primary control circuit is controlling until a predetermined signal is given to the secondary control line which has the effect of actuating the valve a single time against the force of a bias or a shear pin that breaks. The movement of a shuttle in the housing due to the predetermined signal being provided in the secondary line puts the secondary control system in the position of running the tool. The primary system is valved off and cannot return into service. There are just two lines into and out of the housing to make the valve operate at the desired location. A test port is provided for surface testing.

Abstract: The present disclosure relates to downhole tools, including downhole valves, which actuate via a pressure differential created across a shifting element having one or more pressure surfaces isolated from fluid, and fluid pressure, flowing through the interior flowpath. Embodiment downhole tools of the present disclosure may actuate in response to, among other signals, fluid pressure in the interior flowpath of the tool and fluid pressure communicated to a pressure surface of the shifting sleeve from the exterior of the tool. Certain embodiments may also have an outlet connector whereby fluid pressure from the downhole tool may be communicated to its exterior, including to additional tools in the tubing strings via flowlines connecting the two tools. Isolation of the shifting element from the interior flowpath may be accomplished using a frangible, shiftable, degradable or other members which may be moved from a closed state to an open state in response to fluid conditions in the interior flowpath.

Abstract: A wellbore servicing tool comprising a housing comprising ports, a triggering system, a first sliding sleeve transitional from a first position to a second position, and a second sliding sleeve transitional from a first position to a second position, wherein, when in the first position, the first sliding sleeve retains the second sliding sleeve in the first position, wherein, when in the first position, the second sliding sleeve prevents a route of fluid communication via the one or more ports of the housing and, when is in the second position, the second sliding sleeve allows fluid communication via the ports, and wherein the triggering system is configured to allow the first sliding sleeve to transition from the first position to the second position responsive to recognition of a predetermined signal comprising a predetermined pressure signal, a predetermined temperature signal, a predetermined flow-rate signal, or combinations thereof.

Abstract: An apparatus and method for restricting fluid flow with a seat assembly. The seat is configured to go from a first position, in which it is adapted to engage a plug element, to a second position, in which the plug element passes through the seat. A second portion of the seat, and alternatively of a housing in which the seat is disposed, is formed of a disintegrable material. The second portion of the seat and housing comprising the disintegrable material are isolated from a fluid flow when engaged with the seat.

Abstract: A device for controlling fluid flow from a subsurface fluid reservoir into a production tubing siring includes, a tubular member defining a central bore. At least one nozzle extends through a side wall of the tubular member. A popper is moveable between an open position where fluids can flow into the central, bore through the nozzle, and a closed position where the nozzle is fluidly sealed. A circumferential external bead profile is located, on the stem and a circumferential groove is located in the nozzle for mating with the head profile of the stem and maintaining the popper in a closed position. The device can also have a shear member disposed between the stem of the popper and an inner surface of the nozzle for supporting the popper in an open position before the popper Is moved to the closed position.

Abstract: A multiplier sleeve has a releasable seat coupled to a dog within the slidable sleeve allows a single sized ball, dart, or plug to actuate several sliding sleeves. Upon actuation by properly sized ball the ball, slidable sleeve, seat, and dog move downward where the dog is no longer supported allowing the seat to move within the slidable sleeve to a point where the seat is no longer supported thereby releasing the ball. With the slidable sleeve moved downward the port or ports in the sliding sleeve is exposed. A staged port and piston assembly inserted into the ports maintain pressure within the tubular assembly to allow the ball to move through and actuate the targeted sliding sleeves.

Abstract: The present invention is a valve tool utilized for hydraulically fracturing multiple zones in an oil and gas well without perforating the cement casing. An oil/gas well completion method involves the use of a valve that is installed as part of the casing string of the well. A mandrel-less casing provides for cement flow within the casing when the valve element is in a closed position and allows for axial flow of fracturing fluid through the cement casing to fracture the formation near the valve when the sleeve is open. The invention disclosed herein is an improved valve used in this process.

Abstract: A non-ballistic tubular perforating system includes a tubular having a wall with perforations therethrough, and plugs positioned within the perforations that are configured to dissolve in response to exposure to a first environment thereby creative of a second environment that can dissolve or increase porosity of cement.

Abstract: A “passive” apparatus and method for isolating flow within a thermal wellbore wherein inflow apertures are plugged with a temporary fusible alloy plug that can be selectively removed by increasing the wellbore temperature.

Abstract: A smooth bore toe valve includes a first sub defining a through bore and a fluid flow path through a wall thereof; a second sub; a housing mechanically engaged with the first and second subs to define a valve cavity axially between the first and second subs and to define a chamber radially between the first and second subs and the housing, the housing further defining a plurality of openings in a wall thereof; and a sleeve disposed within the chamber between the housing and the first and second subs to close the openings and, upon application of fluid pressure horn the through bore through the fluid this path, open the openings to fluid flow from the valve cavity to the exterior of the housing. A method for using such a valve is also disclosed.

Abstract: A valve includes: a housing; a mandrel disposed in the housing; a rupture disk disposed in a passageway of the mandrel; a sliding sleeve disposed between the housing and the mandrel; and a ball seat disposed in the mandrel. A method for actuating a valve includes: flowing a fluid through the valve; dropping a ball; seating the ball in the ball seat and blocking fluid flow through the mandrel; flowing fluid through the passageway to the sliding sleeve; moving the sliding sleeve axially within the valve; and exiting fluid through the openings of the housing and mandrel. A valve includes: a housing having an opening; a mandrel disposed in the housing; a sliding sleeve disposed between the housing and the mandrel; and a ball seat disposed in the mandrel blocking fluid communication between the mandrel and the passageway.

Abstract: An injection mandrel may include a valve controlling the flow of the injection fluid. A valve actuator operatively connected to the valve sequentially generates a first predetermined pressure and a larger second predetermined pressure in the valve. The valve actuator generates the second predetermined pressure in the valve in response to a predetermined change in a pressure at an annulus surrounding the mandrel.

Abstract: A frangible pressure control plug includes a first portion of a body adjacent a first end of the plug. A second portion of the body adjacent a second end of the plug. The second portion attached to the first portion in a first condition. A groove in the body interposed between the first portion and the second portion. A bore within the body passing through the first end and the first portion and inaccessible from the second end and wherein, fluid communication between the bore and the groove is prevented in the first condition and allowed in a second condition. Also included is a method of actuating a tool.

Abstract: A wellbore isolation device comprises: at least a first material, wherein the first material: (A) is a metal or a metal alloy; and (B) is capable of at least partially dissolving when an electrically conductive path exists between the first material and a second material and at least a portion of the first and second materials are in contact with an electrolyte, wherein the second material: (i) is a metal or metal alloy; and (ii) has a greater anodic index than the first material. A method of removing the wellbore isolation device comprises: contacting or allowing the wellbore isolation device to come in contact with an electrolyte; and allowing at least a portion of the first material to dissolve.

Abstract: A downhole assembly with controlled degradation including a body having a cavity therein and is formed from a first material having a first electrode potential. An insert is disposed in the cavity, the insert electrically coupled to the body and formed from a second material having a second electrode potential, with the first electrode potential being more negative than the second electrode potential.

Abstract: Various embodiments of the present invention disclose enhanced and improved well production tools for increasing the stability of production zones in a wellbore. Various embodiments of the present invention generally relate to apparatuses, systems, and processes for efficiently and effectively isolating zones within a wellbore.

Abstract: A downhole tool comprising a housing having at least one flow port disposed providing a communication path between the interior and exterior of the sleeve. A sleeve assembly has an expandable seat and an inner sleeve, and is moveable within the housing between a first position and a second position, wherein in the first position the sleeve assembly is radially positioned between the flow ports and the flowpath to substantially prevent fluid communication. Shearable port inserts are positioned within the flow ports, with each port insert having a shearable portion extending into the interior of the housing and engaging the sleeve assembly when the inner sleeve is in said first position.

Abstract: A technique protects against premature actuation of a tool, such as a downhole well tool. The technique utilizes a degradable material positioned along a hydraulic actuation passage and/or between shiftable components of the tool. In some applications, the tool may comprise a primary flow passage and a hydraulic actuation passage separate from the primary flow passage. Hydraulic actuation of the tool or a corresponding tool is temporarily blocked by placing a degradable material in the hydraulic actuation passage. The degradable material dissolves or otherwise degrades over time via exposure to a degradation fluid. In other applications, the degradable material may be positioned to block movement of a shiftable component of the tool until the degradable material is sufficiently degraded to allow tool actuation.

Abstract: A method of stimulating a subterranean formation using a tubular member with one or more burst disks therein.

Abstract: A well system has a fluid flow path for the inflow of production fluid. An inflow control device is disposed within the fluid flow path. The inflow control device has at least first and second fluid passageways. A first plug is disposed within the first fluid passageway and is operable to restrict fluid flow therethrough. The first plug is operably removable from the first fluid passageway responsive to a first stimulus. A second plug is disposed within the second fluid passageway and is operable to restrict fluid flow therethrough. The second plug is operably removable from the second fluid passageway responsive to a second stimulus, wherein the first stimulus is different from the second stimulus.

Abstract: A production sleeve assembly for use downhole comprises a fluid pathway configured to provide fluid communication between an exterior of a wellbore tubular and an interior of the wellbore tubular, a flow restriction disposed in the fluid pathway, and a valve disposed in series with the flow restriction in the fluid pathway. The valve comprises: a rupture disk and a plug releasably engaged in the fluid pathway in series with the rupture disk. The valve is configured to allow production from the exterior of the wellbore tubular to the interior of the wellbore tubular through the chamber without producing past the plug once the rupture disk is actuated.

Abstract: A flow control system for use in a subterranean well can include a flow chamber through which a fluid composition flows, and a plug which is released in response to an increase in a ratio of undesired fluid to desired fluid in the fluid composition. Another flow control system can include a flow chamber through which a fluid composition flows, a plug, and a structure which supports the plug, but which releases the plug in response to degrading of the structure by the fluid composition. Yet another flow control system can include a flow chamber through which a fluid composition flows, and a plug which is released in response to an increase in a velocity of the fluid composition in the flow chamber.

Abstract: The present invention relates to an inflow control device for controlling the flow of fluid into a tubular deployed in a wellbore comprising coupling between joints of tubulars. The inflow control device is mounted transversely through the coupling in any inflow can control devices the initial condition fluid flow between the exterior and interior of the tubular is prevented. As sufficient pressure is exerted upon the inflow control device from the interior of the tubular the inflow control device is actuated to allow fluid flow between the interior and exterior the tubular. A nozzle in the inflow control device allows fluid to pass at a preset rate.

Abstract: A system for pressure testing the joints and walls of a production pipe includes a fluid system component that can be disposed at a first end of the production pipe so as to seal off the first end of the production pipe. The fluid system component prevents the flow of fluid out of the first end of the production pipe when the pressure within the production pipe is below a predetermined level. The fluid system component includes a sacrificial element that is adapted for preferential failure when the pressure within the production pipe exceeds the predetermined level. Upon failure of the sacrificial element, fluid is able to flow out of the production pipe through the fluid system component. The system may also include a test plug that prevents the activation of a drain component in the production pipe during the pressure testing of the production pipe.

Abstract: An apparatus and method for providing a time delay in injection of pressured fluid into a geologic formation. In one aspect the invention a toe valve activated by fluid pressure that opens ports after a predetermined time interval to allow fluid to pass from a well casing to a formation, providing a time delay before fluid is passed through the ports, allowing multiple valves to be used in the same well casing and providing a focused jetting action to better penetrate a concrete casing lining.

Abstract: A down hole pressure isolation tool is placed in a pipe string and includes a pair of pressure discs having one side that is highly resistant to applied pressure and one side that ruptures when much lower pressures are applied to it. The weak sides of the pressure discs face each other. Rather than rupturing the discs by dropping a go-devil into the well, in some embodiments, a first of the discs is ruptured or broken by the application of fluid pressure from the well head or surface. Formation pressure is then used, in different ways according to the different embodiments, to rupture the remaining disc. In another embodiment, a gas generating assembly located between the discs is actuated to produce enough pressure to rupture the discs.

Abstract: A cementing tool (20) capable of being installed in a casing string (10) and configured to selectively permit the flow of cement through one or more ports (34) in the tool is provided. The ports (34) are normally sealed by rupture disc assemblies (36) comprising a rupture disc (62) that can be opened to permit flow of cement through the casing string central bore (32) and into the annulus (14) defined by the casing string (10) and the downhole formation (16). The cementing tool (20) is particularly useful during cementing operations in which the annulus (14) has become blocked by a collapsed portion of the formation by allowing the obstruction (104) to be bypassed and the flow of cement (100) into the annulus to be continued without substantial interruption. Tool (20) may also be used in multistage cementing operations.

Abstract: At least a portion of a wellbore isolation device consists essentially of: a metal alloy, wherein the metal alloy: (A) comprises magnesium at a concentration of at least 50% by volume of the metal alloy; and (B) at least partially dissolves in the presence of an electrolyte. A method of removing the wellbore isolation device comprises: contacting or allowing the wellbore isolation device to come in contact with an electrolyte; and allowing at least a portion of the metal alloy to dissolve.

Abstract: Downhole tools for use in oil and gas production which degrade into non-toxic materials, a method of making them and methods of using them. A frac ball and a bridge plug comprised of polyglycolic acid which can be used in fracking a well and then left in the well bore to predictably, quickly, and safely disintegrate into environmentally friendly products without needing to be milled out or retrieved.

Abstract: A downhole tool for use in completing a well includes a plug body selectively securable to a wellbore at a desired elevation and having a flowbore. A non-dissolvable flow restrictor is operably disposed in the flowbore and operates to restrict fluid flow through the flowbore, and a time-dissolvable retainer or spacer is operably coupled to the flow restrictor to retain the flow restrictor in a first position within the flowbore. The retainer is dissolvable within a predetermined passage of time to release the flow restrictor to move between the first position and a second position within the flowbore to control the flow of fluid through the downhole tool.

Abstract: A kobe sub includes a kobe installed in a port of the sub, the kobe includes a cap portion accessible in the inner bore, a base mounted in the port and connected to the cap portion, a channel extending through the base and closed by the cap portion; and an inflow controller positioned to control fluid flowing through the channel toward the inner bore when the cap portion is opened; and a port opening tool for opening the cap portion. The kobe may be employed with a frac port.

Abstract: A gas lift valve can include a degradable component; a valve; and a longitudinally extending tubular body that defines a flow path therein that includes the valve disposed between the degradable component and an opening of the tubular body.

Abstract: A wellbore isolation device comprising: a first material, wherein the first material: (A) is a metal or a metal alloy; and (B) partially dissolves when an electrically conductive path exists between the first material and a second material and at least a portion of the first and second materials are in contact with an electrolyte; and an electrolytic compound, wherein the electrolytic compound dissolves in a fluid located within the wellbore to form free ions that are electrically conductive. A method of removing the wellbore isolation device comprises: placing the wellbore isolation device into the wellbore; and allowing at least a portion of the first material to dissolve.

Abstract: A dissolvable tool includes a body having at least a portion configured to dissolve in a fluid, and a barrier connected to the body. The barrier is configured to slidably fluidically seal to a structure that the body and the barrier are movable within to maintain a volume of the fluid between the barrier and the body while the barrier and the body are moved through the structure.

Abstract: A downhole sleeve has an insert movable in the sleeve's bore from a closed condition to an opened condition when a ball dropped in the bore engages an indexing seat in the sliding sleeve. In the closed condition, the insert prevents communication between the bore and the sleeve's port, while the insert in the opened condition permits communication between the bore and port. Keys of a seat extend into the bore to engage the ball and to move the insert open. After opening, the keys retract so the ball can pass through the sleeve to another cluster sleeve or to an isolation sleeve of an assembly. Insets or buttons disposed in the sleeve's port temporarily maintain fluid pressure in the sleeve's bore so that a cluster of sleeves can be opened before treatment fluid dislodges the button to treat the surrounding formation through the open port.

Abstract: A flow control assembly can be disposed in a wellbore and can include a membrane that can be perforated in response to a pressure, such as a setting pressure, from an inner area of a tubing. Subsequent to the membrane being perforated, fluid can be allowed to flow from an area external to the tubing to an area internal to the tubing. The membrane may remain closed during a packer setting operation and be perforated subsequent to the packer setting operation.

Abstract: A flow control assembly can be disposed in a wellbore and can include a membrane that can be perforated in response to a pressure, such as a setting pressure, from an inner area of a tubing. Subsequent to the membrane being perforated, fluid can be allowed to flow from an area external to the tubing to an area internal to the tubing. The membrane may remain closed during a packer setting operation and be perforated subsequent to the packer setting operation.

Abstract: Disclosed is a secondary system and method for initiating a down hole operation in a wellbore when a primary activation system fails. The primary activation system is configured to provide fluid communication between a first chamber and a second chamber in response to a primary activation operation. The secondary activation system includes a passageway between the first chamber and the second chamber, and a rupture member positioned in the passageway. The rupture member has a threshold pressure differential at which the rupture member ruptures to afford fluid communication between the first chamber and the second chamber to thereby initiate the down hole operation if the primary activation system fails. The primary activation operation may be configured to move a trigger member to initiate the down hole operation, whereas the secondary activation operation may be configured to initiate the down hole operation without moving the trigger member.

Abstract: A down hole pressure isolation tool is placed in a pipe string and includes a pair of pressure discs having one side that is highly resistant to applied pressure and one side that ruptures when much lower pressures are applied to it. The weak sides of the pressure discs face each other. Rather than rupturing the discs by dropping a go-devil into the well, a first of the discs is ruptured or broken by the application of fluid pressure from the well head or surface. Formation pressure is then used, in different ways according to the different embodiments, to rupture the remaining disc.

Abstract: A downhole tool comprising an inner sleeve with a plurality of sleeve ports and a housing positioned radially outwardly of the inner sleeve and having a plurality of housing ports, with the housing and inner sleeve partially defining a space radially therebetween. The space is occupied by a shifting sleeve. A fluid path extends between the interior flowpath of the tool and the space. A fluid control device, such as a burst disk, occupies at least portion of the fluid path. In one state, the shifting sleeve is in a first position between the housing ports and the sleeve ports to prevent fluid flow between the interior flowpath and exterior of the tool. The fluid control device may selectively permit fluid flow, and thus pressure communication, into the annular space to cause a differential pressure across the shifting sleeve.

Abstract: A plug is disposable in a well bore to block fluid from passing through the wellbore. The plug includes a body formed from water soluble glass. The body is dissolvable in water. A method of utilizing water soluble glass includes employing an element formed of the water soluble glass, performing a first function in the system when the element is present, dissolving the element in the presence of water, and performing a second function in the system different than the first function.

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: Systems and methods for activating a down hole tool in a wellbore. A piston is moveable from a first position to a second position for activating the down hole tool. The piston includes a first side exposed to a first chamber, and a second side exposed to a second chamber. A rupture member has a first side exposed to the first chamber and a second side exposed to a third chamber. The rupture member is configured to rupture when a pressure differential between the first chamber and the third chamber reaches a predetermined threshold value, at which point the rupture member allows fluid communication between the first chamber and the third chamber. When the rupture member is intact, the piston is in the first position, and when the rupture member ruptures, the piston moves to the second position and activates the down hole tool.