Abstract: A hybrid-tieback seal assembly and methods for tying a well back to the surface or subsea well head are disclosed. A method to tie a well back to the surface or subsea well head comprises running a hybrid-tieback seal assembly into a wellbore, the hybrid-tieback seal assembly comprising one or more anchoring bodies, one or more packer seal assemblies; and a device for creating a pressure differential in a tieback string, wherein the tieback string is coupled to the hybrid-tieback seal assembly. The method further comprises landing a casing hanger in a well head, increasing pressure in the tieback string, setting the anchoring bodies and one or more packer seal assemblies within at least one of a previously installed liner hanger system and a host casing above a previously installed hanger system, and testing the hybrid-tieback seal assembly down an annulus between the host casing and the tieback string.

Abstract: A dissolvable tool includes, a body with a surface having at least one perforation therethrough, the at least one perforation being dimensioned to control a rate of intrusion of an environment reactive with at least a portion of the dissolvable tool located below the surface.

Abstract: Pressure actuable downhole tool such as a packer and a method for actuating the same typically uses a control line to trigger a configuration change in the tool in which a communication line is opened between the throughbore of the tool and apressure responsive actuator, allowing the pressure responsive actuator to be set by downhole fluid pressure applied via the throughbore. Thus the pressure from the control line is used to trigger actuation of the tool, but the throughbore pressure is used to set the tool. The advantage of this activation mechanism is that the tool can be set even when pressure supplied by the control line is insufficient to fully actuate or set the tool, and in certain embodiments, the tool can be set using much higher tubing pressure than could be supplied through the control line, thereby allowing more reliable and instantaneous setting than tools set using control line pressure alone.

Abstract: A treatment system including a seal assembly operatively arranged with respect to a first zone in a borehole for isolating the first zone from a second zone and a third zone. The second and third zones are located on opposite sides of the first zone. A string assembly extends between the second zone and the third zone, forms a first fluid pathway operatively arranged to bypass the first zone and enable fluid communication between the second and third zones. The first fluid pathway is fluidly connected to an annulus of the borehole for enabling a treatment of the second and third zones to be performed simultaneously. A method of operating a treatment system is also included.

Abstract: A probe for establishing fluid communication between a downhole tool and a subterranean formation is provided. The downhole tool is positioned in a wellbore penetrating the subterranean formation. The probe includes a platform operatively connected to the downhole tool, at least one packer operatively connected to the platform, the packer having at least one hole extending therethrough and at least one embedded member disposed in the packer for enhancing the operation of the packer as it is pressed against the wellbore wall.

Abstract: A downhole apparatus has a radially expanding portion comprising a swellable elastomeric material selected to increase in volume on exposure to at least one predetermined fluid. A support assembly is operable to be deployed from a first retracted position to a second expanded condition. The support assembly comprises an inner surface arranged to face the radially expanding portion, and at least a portion of the inner surface is concave. The support assembly may be configured to direct a force from the swellable material to boost or energise a seal created between the radially expanding portion and a surrounding surface in use.

Abstract: System, devices, and methods are described relating to the treatment (e.g., perforating, fracturing, foam stimulation, acid treatment, cement treatment, etc.) of well-bores (e.g., cased oil and/or gas wells). In at least one example, a method is provided for treatment of a region in a well, the method comprising: positioning, in a well-bore, a packer above the region of the well-bore, fixing, below the region, an expansion packer, treating the region, the treatment fixing the packer, moving the expansion packer, and moving the packer after the moving of the expansion packer.

Abstract: A swellable packer with composite material end rings. A packer assembly includes at least one generally tubular seal element extending longitudinally between opposite ends thereof. At least one end ring is positioned proximate one of the seal element opposite ends. The end ring includes a nonmetal material. A method of constructing a packer assembly includes the steps of: chemically bonding at least one end ring to a base pipe; providing at least one generally tubular seal element which extends longitudinally between opposite ends thereof; and restricting longitudinal displacement of the seal element relative to the base pipe utilizing the end ring positioned at one of its opposite ends.

Abstract: A compression assembly (500) for actuating packing elements of a through tubing bridge plug in a casing string of a wellbore. The compression assembly (500) includes a support assembly (502) and an anti extrusion assembly (504). The support assembly (502) has a running configuration in which link arm assemblies are substantially longitudinally oriented and an operating configuration in which short arms (514) are pivoted relative to long arms (520) of link arm assemblies such that the short arms (514) form a support platform. The anti extrusion assembly (504) is operably associated with the support assembly (502). The anti extrusion assembly (504) has a running configuration in which petals (536) are substantially perpendicular to a base member (534) and nested relative to one another and an operating configuration in which the petals (536) are radially outwardly disposed substantially filling gaps between the short arms (514).

Abstract: A swelling element packer is made with internal rings that are either split or scrolled. After the swelling element is built on a temporary mandrel a longitudinal seam of a variety of designs is cut through the element. This allows the rapid deployment of the element on the tubular that will be a part of a string and will serve as the final mandrel. The assembly is then magnetic pulse welded or crimped so as to urge the open ends of the rings to move toward each other and become secured to each other and further opening the possibility of attaching parts on the ring itself to the underlying tubular by displacing or otherwise removing the swelling material that was between the ring and the final mandrel when the magnetic pulse process began. The rings can be embedded wholly within the element or can extend beyond the opposed ends.

Abstract: A well production and injection string includes a plurality of spaced apart packers each adapted to seal with a wall of the wellbore. A plurality of flow control devices are provided in the string, distributed between pairs of adjacent packers. The flow control devices are adapted to communicate flow between an interior and an exterior of the string with less restriction to flow from the interior to the exterior of the string than to flow from the exterior to the interior of the string.

Abstract: A retrofit assembly for functionally replacing a fluid isolation valve disposed in a borehole above a lower completion, including a barrier valve operatively arranged to selectively isolate the lower completion when the fluid isolation valve is open. The barrier valve is transitionable between an open position and a closed position due to engagement with an upper completion string. A packer device is included and operatively arranged to isolate a formation in which the borehole is formed. A method of retrofitting a completion system is also included.

Abstract: A completion system for arrangement in a borehole including a lower completion, an upper completion string, and an intermediate assembly engaged between the lower completion and the upper completion string. The intermediate assembly includes a single barrier valve only. The barrier valve is operatively arranged to be transitionable to an open position when engaged with the upper completion string and transitions to a closed position via the upper completion string when the upper completion string is pulled out of the borehole. A method of completing a borehole is also included.

Abstract: A completion system, including a lower completion installed in a borehole proximate to a downhole formation. An intermediate completion assembly is included directly engaged with the lower completion. The intermediate completion assembly includes a barrier valve and packer device. The barrier valve is operatively arranged to selectively impede fluid flow through the lower completion and the packer device operatively arranged for isolating the formation. An upper completion string is included that is selectably engagable with the intermediate completion assembly. The barrier valve is operatively arranged to be transitionable to an open position when engaged with the upper completion string and transitions to a closed position via the upper completion string when the upper completion string is pulled out of the borehole. A method of completing a borehole is also included.

Abstract: One or more fluid-jetting subs having jet ports and a packer element are incorporated into a completion string for deployment into a wellbore for perforation and treatment operations. The packer element, being either an inflatable packer element or a compressible packer element, is downhole of the jet ports and is fluid pressure actuated. Pressure in the completion string is maintained at a pressure higher than in the annulus thereabout to keep the packer set for sealing the annulus therebelow while fluid is delivered through the jet ports for perforating or treatment such as fracturing.

Abstract: The invention relates to isolation of part of a well, which comprises pipe provided, along its external face, with a first external sleeve, wherein the opposite ends are connected directly or indirectly to said external face of the pipe. The pipe, first external sleeve and its ends together delimit an annular space, the wall of said pipe exhibiting at least one opening which allows it to communicate with said space, this sleeve being likely to expand and to be applied tightly against the well over an intermediate part of its length. The device also comprises on the one hand, a second internal sleeve, which extends between said pipe and the first sleeve, its ends being also connected directly or indirectly to the external face of said pipe and, on the other hand, at least one communication passage between the exterior of the first sleeve and said space.

Abstract: A production pipe arrangement for a producing petroleum well with at least one of the well fluids (oil, gas, or water) with influx fluids two or more influx zones or influx locations to a production flow in a central production pipe in said well, with tracer sources with distinct tracer materials in known levels of the well, one or more separate delay chambers arranged as a completion component in said pipe, the delay chambers provided with said one or more of the tracers sources arranged in an annular space formed between the completion pipe and a borehole wall, with at least one of said tracer sources arranged exposed to the fluids in at least one of said influx zones, the delay chambers having one or more apertures to the fluid flow in said central pipe.

Abstract: A packer deactivation system can include a packer and a safety joint. Activation of the safety joint can prevent setting of the packer. A method for use with a subterranean well can include activating a safety joint in the well, and deactivating a packer connected to the safety joint, in response to the safety joint activating. Another packer deactivation system can include a safety joint and a packer drag block locking mechanism. Activation of the safety joint can operate the drag block locking mechanism, thereby preventing a drag block from displacing in a certain direction relative to a mandrel of a packer.

Abstract: A bottomhole assembly deployable into a wellbore on coiled tubing and which has at least a casing collar locator, a fluid-delivery apparatus for delivery treatment fluid and a sealing element, typically a packer positioned therebetween, permits delivery of treatment fluid to a plurality of ports formed in casing through either the annulus between the BHA and the casing, through the coiled tubing or through both. Variable volumes of treatment fluid can be delivered as a result of the different volumes of the coiled tubing and the annulus or the combined volume of both. Sleeves used to cover the fracturing ports in the casing to permit selective opening and fracturing therethrough are made shorter than prior art sleeves as a result of the particular arrangement of the BHA and engagement of collars in the casing with the casing collar locator.

Abstract: An apparatus for use in controlling first and second downhole tools includes a first cyclical indexing mechanism associated with a first downhole tool, and a second cyclical indexing mechanism associated with a second downhole tool, wherein the first indexing mechanism defines at least three sequential indexing positions within a cycle and the second indexing mechanism defines at least two sequential indexing positions within a cycle. The apparatus includes at least one actuator for actuating the first and second indexing mechanisms in response to a common stimulus to cause said first and second indexing mechanisms to advance between respective indexing positions so as to permit co-ordination of the operational states of the associated first and second downhole tools. The apparatus may be used for controlling first and second under reamers or for controlling an under reamer and a corresponding stabilizer.

Abstract: A bridge style fractionation plug for use in a wellbore to separate a lower fractionation zone from an upper fractionation zone with no communication between the zones.

Abstract: A completions fluid loss control system for incorporation into upper completion hardware. The system allows for the avoidance of a dedicated intermediate completion installation in advance of upper completion delivery to a lower completion at a formation interface. The system includes a unique cup packer and flow regulation arrangement such that annular fluid thereabove may be isolated away from space below the system while at the same time allowing annular fluid therebelow to bypass the system. As such, the upper completion may be advanced toward the installed lower completion while maintaining well control at the noted formation interface.

Abstract: A perforating tool usable in a well casing to perforate the well casing is described. Perforating tool comprises an activation member disposed in body wherein the activation member is moveable relative to the body to move at least one working member between and inwardly retracted condition an outwardly deployed condition relative to the body. A plurality of pistons is arranged to move the activation member relative to the body, each said piston being disposed in a respective pressure chamber arranged to be filled with fluid in response to an increase in fluid pressure in the body.

Abstract: A wellbore fluid treatment apparatus includes a tubing string including a first port with a first closure disposed thereover to close the first port to fluid flow and a second port spaced axially uphole from the first port and having a second closure disposed thereover to close the second port to fluid flow; and an actuator tool configured to move through the tubing string and (i) to set a seal in the tubing string downhole of the first port; (ii) to actuate the first closure to open the first port; and (iii) to actuate the second closure to open the second port. A method for treating a well may employ the tool.

Abstract: A method of and apparatus for treating a zone in a well is disclosed. A tube that is permeable to a material is inserted into a wellbore, creating an annulus inside the wellbore. Two zones—the annular region and the formation surrounding the wellbore—may be treated. The method comprises the following steps. (1) A setting section surrounded by a sleeve is placed inside the tube near the zone to treat, the sleeve being expandable and impermeable to the material. (2) The sleeve is inflated inside the tube near the zone to treat, ensuring that a first zone of the tube is impermeable to the material, but leaving a second zone permeable to the material. (3) A treatment fluid is pumped to the zone to treat, the treatment fluid passing into the annulus via the second zone. (4) The zone to treat is treated with the treatment fluid.

Abstract: A downhole packer assembly for steam injection and casing pressure testing. The downhole packer assembly includes a housing assembly having intake and discharge ports. A seal assembly is positioned around the housing assembly between the intake and discharge ports and is operable to provide a fluid seal with a casing string. A mandrel is positioned within the housing assembly forming a micro annulus therewith and providing an internal pathway for fluid production therethrough. A valve assembly is disposed between the housing assembly and the mandrel and is operable between closed and open positions by a piston assembly such that the intake and discharge ports and the micro annulus provide a bypass passageway for steam injection around the seal assembly when the valve assembly is open and the seal assembly provides a downhole surface for pressure testing of the casing string uphole thereof when the valve assembly is closed.

Abstract: A dissolvable tool includes a body having at least one stress riser configured to concentrate stress thereat to accelerate structural degradation of the body through chemical reaction under applied stress within a reactive environment.

Abstract: A downhole actuation system comprises an actuation mechanism comprising an indicator; a wellbore tubular; and a collet coupled to the wellbore tubular. The collet comprises a collet protrusion disposed on one or more collet springs, and the collet protrusion has a position on the one or more collet springs that is configured to provide a first longitudinal force to the indicator in a first direction and a second longitudinal force to the indicator in a second direction. The first longitudinal force is different than the second longitudinal force.

Abstract: Embodiments of the present invention generally relate to a method and/or apparatus for deploying wireline tools with a non-electric string. In one embodiment, a method of determining a free point of a tubular string stuck in a wellbore includes deploying a tool string in the stuck tubular with a non-electric string. The free point assembly includes a battery, a controller, and a free point tool. The method further includes activating the free point tool by the controller. The free point tool contacts an inner surface of the stuck tubular string. The method further includes applying a tensile force and/or torque to the stuck tubular string; and measuring a response of the tubular string with the free point tool.

Abstract: An assembly for minimizing damaging effects of pressure waves on devices in a wellbore. The assembly comprises a dynamic device disposed in the wellbore and generating pressure waves during actuation; a barrier device disposed in the wellbore and presenting an obstacle to the pressure waves generated by the dynamic device; and an occlusion disposed in the wellbore between the dynamic device and the barrier device which reduces the damaging effects of the pressure waves on the barrier device.

Abstract: A well tool includes a generally tubular mandrel with a flow passage extending longitudinally through the mandrel, and a flow controller which initially prevents a fluid from contacting a swellable material, but which permits the fluid to contact the material in response to manipulation of pressure in the flow passage. Another well tool includes a swellable material, a generally tubular mandrel, and a conduit wrapped circumferentially about the mandrel, the conduit containing a fluid which, upon contact with the swellable material, causes the material to swell. A method of actuating a well tool in a well includes manipulating pressure in a flow passage extending through a tubular string, thereby opening at least one flow control device of the well tool which selectively permits fluid communication between a reservoir of the well tool and a swellable material of the well tool, whereby a fluid in the reservoir contacts the swellable material.

Abstract: A well drilling system including: an annular valve; a well casing in fluid communication with the annular valve; a first check valve in fluid communication with the annular valve; a hydraulic cylinder including a first chamber having an inlet and an outlet, wherein the inlet of the first chamber is in fluid communication with an outlet of the first check valve; and a transfer unit including an inlet and an outlet, wherein the inlet of the transfer unit is in fluid communication with the outlet of the first chamber, the outlet of the transfer unit is in fluid communication with an inlet of a second check valve, and an outlet of the second check valve is in fluid communication with the annular valve.

Abstract: An inflatable packer contains a reactive metal in an annular space between the mandrel and the element. A fluid is admitted into the annular space to start a reaction that gives off gas. The generated gas fills the annular space and inflates the element in the process. The actuating fluid can be water and the off gas can be hydrogen. The volume of the reactants can also increase as they swell in the reaction that generates the gas. A valve arrangement associated with the mandrel retains the gas pressure and prevents over-pressurization. The packer can be set in a surrounding tubular or in open hole.

Abstract: This stuffing box (46) defines a circulation passage (66) of a cable working line (28), a packer (70), and a back-pressure resistant valve (74). The passage (66) extends between an upstream end (62) of the stuffing box (46), intended to be connected to a well, and a downstream end (64). The back-pressure resistant valve (74) is arranged in the passage (66) to prevent, in case of break of the line (28), the back-pressure of a fluid from the upstream end (62) towards the downstream end (64). The or each packer (70) is situated between the upstream end (62) of the stuffing box (46) and the back-pressure resistant valve (74). No packer (70) is arranged between the back-pressure resistant valve (74) and the downstream end (64).

Abstract: A dart or other dropped object having a shearable sleeve member is dropped or launched down hole, typically during cementing operations, until it lands on a seat within a dart catcher receptacle. By increasing a pressure differential across the landed dart to a predetermined amount, the shearable sleeve member shears from the dart. The dart extrudes through the still-seated stationary sleeve member and passes to a ported catcher sub. A first alternative embodiment utilizes a novel collet member as a seat in a dart catcher receptacle, while a second alternative embodiment utilizes a resilient flexible seat member.

Abstract: A temperature activated actuator installed on a tubular to actuate an adjacent device may include one or more shape-memory alloy elements. The elements may be coupled between a first portion and a second portion of a device, or the elements may be coupled between the tubular and a portion of the device. The elements are activated by raising the temperature to a transition temperature to cause metallurgical phase transformation, causing the elements to shrink and displace at least a portion of the device. The actuator may be used, for example, to actuate a centralizer from a run-in mode to a deployed mode or, alternately, to actuate a packing member from a run-in mode to an isolating mode. A nickel-titanium alloy, for example, may be used as the shape-memory alloy material from which the shape-memory element is made.

Abstract: A swellable packer including a first retainer, a second retainer, a swellable element, a piston, and a piston lock. The second retainer is spaced axially apart from the first retainer. The swellable element is at least partially disposed between and fixed to the first and second retainers. The piston is fixed to the second retainer and configured to move the second retainer from a first position in which the swellable element is unstrained, to a second position in which the swellable element is strained. The piston lock is configured to releasably fix the second retainer in the second position.

Abstract: A completion system, including a barrier valve transitionable between an open position and a closed position. An upper completion is operatively coupled with the barrier valve for mechanically transitioning the barrier valve to the closed position when the upper completion is withdrawn. A method of operating a completion system is also included.

Abstract: A completion system including a barrier valve operatively arranged in a tubing string to selectively impede fluid flow through a lower completion. At least one control line is included for supplying a control line pressure for controlling operation of the barrier valve. The at least one control line is operatively arranged with the tubing string for enabling tubing pressure in the tubing string to determine the control line pressure. A method of operating a barrier valve is also included.

Abstract: A sealing and/or anchoring element for use in pipelines. The sealing and/or anchoring element includes at least one helical element disposed around a string section, with the helical element being configured so as to be able to expand radially towards an inner wall of the pipeline as the circumferential diameter thereof is increased.

Abstract: A pressure relief device is used to relieve pressure in a void within a wellhead housing. In one embodiment, the pressure relief device includes a plunger having a stepped plug, wherein the plug can be fully open to allow flow from the void, restricted to allow a predetermined flow to relieve pressure, or closed to prevent flow from the void. In another embodiment, the pressure relief device includes a vacuum puller that creates negative pressure in a vessel. As fluid in the void expands, it is able to enter the space formerly occupied by the plunger. In yet another embodiment, a rupture disc is used to prevent fluid from flowing from the void, through a passage, to the wellbore. If pressure in the void exceeds a predetermined value, the rupture disc yields and allows the trapped fluid to flow to the wellbore.

Abstract: A downhole retrievable dual directional isolation tool, comprising a mandrel, a compressor ring concentric with the mandrel, and a packing element concentric with the mandrel and having an outer surface defining a plurality of grooves. A downhole retrievable dual directional isolation tool, comprising a mandrel, a packing element concentric with the mandrel, a compressor ring concentric with the mandrel and having a first side wall proximate to a second side wall of the packing element, and a stop ring concentric with the mandrel having a third side wall proximate to a fourth side wall of the packing element, wherein the first side wall of the compressor ring or the third side wall of the stop ring have a circumferential land, whereby in a set state of the tool a contact area between the circumferential land and the second side wall of the packing element or the fourth side wall of the packing element achieves higher contact pressure.

Abstract: A multi-zone formation treatment assembly has sections disposed on a tubular structure in a borehole. An isolation element disposed on the tubular structure that isolates a borehole annulus around the section from the other sections, and a flow valve disposed on the tubular structure is selectively operable between opened and closed conditions permitting and preventing fluid communication between the through-bore and the borehole annulus. A screen disposed on the tubular structure communicates with the borehole annulus, and a closure disposed on the tubular structure at least prevents fluid communication from the through-bore to the screen. A workstring of the assembly can be manipulated in the tubular structure relative to each section in the same trip to: open the flow valve, position in the through-bore relative to the open flow valve, deliver the treatment from an outlet to the section through the open flow valve, and close the flow valve.

Abstract: Disclosed herein is an apparatus for use downhole comprising an expandable component; a support member that has a selected corrosion rate; wherein the support member is disposed on the expandable component; where the support member comprises a plurality of particles fused together; the particles comprising a core comprising a first metal; and a first layer disposed upon the core; the first layer comprising a second metal; the first metal having a different corrosion potential from the second metal; the first layer comprising a third metal having a different corrosion potential from the first metal.

Abstract: A plug device for closing of a pipe bore where the plug comprises an exterior sleeve formed in a flexible material, and a setting mechanism, and where the setting mechanism comprises wedges which between their passive position and their active position are displaced along a curved path.

Abstract: The disclosure relates to a system (10) for improving zonal isolation in a well in a subterranean formation, comprising: a tubular (1) having a outer surface (11); and a swellable coating (2) coating the outer surface (11) of said tubular (1), said swellable coating (2) having an external surface (21); and/or a composition (20) provided in an annular space outside said tubular (1). The swellable coating (2) is made of a first swellable material (3) able to swell in contact with a first fluid (6) on said external surface (21) and/or the composition (20) is made of a second swellable material (4) able to swell in contact with a second fluid (7), and wherein said first (3) and/or said second (4) swellable materials include an elastomer compounded with an aqueous inverse emulsion of particles of a polymer comprising a betaine group, said elastomer being able to swell in contact with hydrocarbon and saline aqueous fluids.

Abstract: A well system can include a drill string having a drill bit at an end thereof, and a swellable seal exposed to fluid in an annulus external to the drill string. The swellable seal can include a swellable material which swells in response to the fluid comprising a predetermined activating agent. A method of preventing undesired release of fluid from a wellbore can include displacing a drill string through the wellbore, thereby drilling the wellbore, and installing in the wellbore a swellable seal which, in response to the fluid comprising a predetermined activating agent, reduces flow through an annulus formed radially between the drill string and the wellbore. Another well system can include a swellable seal carried into a wellbore on a drill string, with the swellable seal including a swellable material which swells in response to a fluid in the wellbore comprising a predetermined activating agent.

Abstract: A downhole tool for use in a well. A pumpable plug is used to urge bottom hole assemblies to a desired location in a well. The pumpable plug has a diameter greater than the maximum outer diameter of the casing in which the bottom hole assembly is to be located.

Abstract: A swellable downhole packer (10) is provided for positioning downhole in a well to seal with the interior surface of a borehole or the interior surface of a downhole tubular. The packer includes a swellable elastomeric sleeve-shaped body (14) positioned over a mandrel (12) for swelling, and a rigid end ring (16,18). An elastomeric anti-extrusion member (20) is spaced axially between the sleeve-shaped body and the rigid end ring, and has a radial thickness adjacent the end ring greater than the radial thickness adjacent the sleeve-shaped body. A swellable elastomeric member (32) is spaced radially between the exterior surface of the mandrel and the elastomeric anti-extrusion member.

Abstract: Systems and methods for producing from multiple zones in a subterranean formation are provided. The system can include a liner including a first frac valve, a second frac valve, and a formation isolation valve. The second frac valve can be positioned above the first frac valve, and the formation isolation valve can be positioned above the second frac valve. A completion assembly can be disposed at least partially within the liner. The completion assembly can include a valve shifting tool adapted to actuate the formation isolation valve between an open position and a closed position. The completion assembly can also include a first flow control valve in fluid communication with the first frac valve and a second flow control valve in fluid communication with the second frac valve.