Abstract: Apparatus and method for filling and sealing a chamber with fluid at a predetermined pressure in a well bore. In a downhole assembly (10) comprising a tubular body (14) having a cylindrical throughbore (18) and a chamber (16) to be filled on an outer surface (26) of the body, a fill mechanism is provided to control fluid flow between the throughbore and the chamber. The fill mechanism includes a sliding seal (72) arrangement at the outer surface which is operated by the fluid flow in the throughbore to allow fluid flow into the chamber and then seal the chamber. Embodiments are described where the chamber is between a morphable sleeve (64) and the outer surface of the tubular, filling of the chamber morphs the sleeve and sealing the chamber at a predetermined fluid pressure secures the tubular within a borehole, creates an annular seal across an annulus or centralizes the tubing within a wellbore.

Abstract: A pressure control device for sealing a conduit comprises a seal element comprising an elastomer, the seal element defining a seal element external surface portion, the seal element external surface portion defining an external perimeter. The external perimeter is adapted to increase as an environmental temperature increases, such that, in use, an increase in the environmental temperature can move the seal element external surface portion into engagement with the conduit or, once engaged with the conduit or if already engaged with the conduit, can create an improved seal with the conduit.

Abstract: Apparatus and method for filling and sealing a chamber with fluid at a predetermined pressure in a well bore. In a downhole assembly (10) comprising a tubular body (14) having a cylindrical throughbore (18) and a chamber (16) to be filled on an outer surface (26) of the body, a fill mechanism is provided to control fluid flow between the throughbore and the chamber. The fill mechanism includes a sliding seal (72) arrangement at the outer surface which is operated by the fluid flow in the throughbore to allow fluid flow into the chamber and then seal the chamber. Embodiments are described where the chamber is between a morphable sleeve (64) and the outer surface of the tubular, filling of the chamber morphs the sleeve and sealing the chamber at a predetermined fluid pressure secures the tubular within a borehole, creates an annular seal across an annulus or centralizes the tubing within a wellbore.

Abstract: An annular space surrounding an expandable well tubular (1) is sealed by: —a concave seal pusher assembly (5) with concave pusher elements comprising buckling joints (7) of which assembly (5) a first end is secured at a selected first location (2) of the outer surface of the unexpanded well tubular (1); —an annular elastomeric sealing ring (9) arranged with an inwardly tapered first end thereof against an outwardly tapered second end (8) of the concave seal pusher assembly (5); —a set of staggered and overlapping steel support strips (11) arranged around a second end of the sealing ring (9) and connected at one end thereof to a selected second location (3) of the outer surface of the unexpanded tubular (1); —expanding and thereby shortening the tubular (1) to push the inwardly tapered end of the sealing ring over the outwardly tapered end (8) of the seal pusher assembly (5) and buckling the staggered strips (11) against the outer surface (12) of the annular space surrounding the expanded tubular (1) to compre

Abstract: A stimulation tool includes a tubular having a port; a first sleeve member disposed in the tubular and actuatable by an actuating member to move from a closed position wherein fluid communication between a bore of the tubular and the port is blocked; and a closure member disposed in the tubular and actuatable by the actuating member to a closed position wherein fluid communication through the bore of the tubular is blocked. A method of stimulating multiple zones of a tubular in a wellbore includes moving a sleeve member in the tubular by receiving an actuating member in the sleeve member; releasing the actuating member from the sleeve member; and actuating a closure member by receiving the released actuating member in a seat.

Abstract: The present invention is to a packer plug that can be tripped into a particular location in a well bore and set using slips or expansion rings and packer elements. The plug presents little flow resistance because of its wide inner diameter throat through the mandrel. A ball seat at an upper end allows for the sealing of the interior passage. The ball can be flowed upward or dissolved to remove the seal and allow flow through the plug.

Abstract: A sealing apparatus for sealing a well bore is described. The sealing apparatus comprises a sealing element adapted to be moved from a run-in configuration to a set configuration, a first back-up layer and at least one second back-up layer sandwiched between the sealing element and the first back-up layer. The at least one second back-up layer comprises a thinner material than the first back-up layer. The first back-up layer and the at least one second back-up layer are adapted to be moved from the run-in configuration to the set configuration under the action of the sealing element.

Abstract: An apparatus for releasably connecting a cable with a tool that has an outer cone. The outer cone has a lower portion and an upper portion. A weak point is located between the lower portion and upper portion. The apparatus also includes an inner cone configured to fit within the outer cone.

Abstract: A device and method prevent damage to an anti-extrusion device on a tool, such as a plug or a packer, prior to and during setting of the tool. Typically, the upper or outer edges of the anti-extrusion device are relatively delicate. A reinforcing band on the device's sheath strengthens or armors the upper or outer edge of the anti-extrusion device so the anti-extrusion device may be protected while running the tool into the well or casing. Longitudinal slots on the sheath allow the sheath to expand at least partially with the expansion of the sealing element, while the reinforcing band resists expansion of the distal edge of the sheath.

Abstract: The present invention is related to a downhole tool having a flapper valve assembly for controlling the backflow of fluid into a tubing string. The downhole tool includes a first sleeve slidably disposable within at least a portion of the flapper valve assembly and the downhole tool. The downhole tool can also include a second sleeve slidably disposed within the downhole tool. The present invention is also related to a method of using the downhole tool. The method includes the step of positioning the downhole tool in a wellbore. Once the downhole tool is positioned in the wellbore, the first sleeve is shifted to interact with the flapper valve assembly.

Abstract: A device, for sealing the end face of a tube, includes an inner tube which has a smaller diameter than the tube to be sealed and is introduced at the end face into the tube to be sealed; a sealing body which is provided to seal a ring gap between the inner tube and the tube to be sealed, the sealing body being arranged in a movable manner on the inner tube; a turbine configured to be driven by a fluid flow from the tube; and a mechanical transmission. The mechanical transmission is connected between the turbine and the sealing body, and acts to translate rotational movement of the turbine from the fluid flow into a movement of the sealing body, thereby bringing the sealing body from a position having reduced sealing capacity into a position having higher sealing capacity.

Abstract: An annular seal for a setting tool in a packer tieback extension comprises a downhole oriented packer cup assembly. As the tool is run in the hole the packer cup flexes as the rising hydrostatic pressure equalizes across the cup into what started as a zone with atmospheric pressure inside the packer tieback extension. Once the pressure is equalized the self energizing feature of the packer cup maintains grit and debris in the mud from entering the tieback extension where the spring loaded dogs of the setting tool are held in a retracted position. If the seal fails to equalize and allows a large differential across the setting sleeve from the surrounding annulus, the rupture disc breaks inwardly into the tieback extension so that pressure is equalized. If the packer is never set after being lowered to depth and the pressure from the tieback extension is equalized into the annulus.

Abstract: A packer for sealing against an inner cylindrical mandrel and a wellbore wall.

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

Abstract: A downhole apparatus and assembly for use in a well bore and associated method are disclosed. The downhole apparatus includes a mandrel, a first slip, and a second slip, both slips being disposed on the mandrel. The slips are configured to grippingly engaging the well bore when in a set position. A packer cup is also disposed on the mandrel. The packer cup is provided for sealing an annulus between the mandrel and the well bore. The packer cup is slidable relative to the mandrel, and can be controlled to slide along the mandrel in order to move the slip to the set position. The downhole assembly includes a downhole tool and a setting apparatus. The setting apparatus can be used to lower the downhole apparatus to a desired setting depth and then to release the downhole apparatus.

Abstract: An annular seal for a setting tool in a packer tieback extension comprises a downhole oriented packer cup assembly. As the tool is run in the hole the packer cup flexes as the rising hydrostatic pressure equalizes across the cup into what started as a zone with atmospheric pressure inside the packer tieback extension. Once the pressure is equalized the self energizing feature of the packer cup maintains grit and debris in the mud from entering the tieback extension where the spring loaded dogs of the setting tool are held in a retracted position. If the seal fails to equalize and allows a large differential across the setting sleeve from the surrounding annulus, the rupture disc breaks inwardly into the tieback extension so that pressure is equalized. If the packer is never set after being lowered to depth and the pressure from the tieback extension is equalized into the annulus.

Abstract: The present invention relates to downhole injection tool (1) for injecting an injection fluid into an annular space (5a) surrounding the downhole injection tool and enclosed by an inside wall (3a) of a borehole or a well tubular structure (3).

Abstract: A gravel pack system and method for zonal isolation includes a swellable element used in conjunction with a primary isolation device, such as a cup packer. The zones may be isolated by both the isolation device and the swellable element. Shunt tubes may be used to convey a gravel slurry to each zone. At least one upper shunt tube extends through the isolation device to provide the slurry to the zone therebelow. Once the gravel packing is completed, the swellable member may be activated to provide and supplement a hydraulic seal between adjacent zones.

Abstract: A packer cup assembly uses a shape memory alloy packer cup reformed for run in into a cylindrical shape about a mandrel with opposed end rings that extend radially further out during run in to protect the cup. Upon application of a thermal stimulus the cup reverts to a functional cup seal shape by engaging the rim and parts of the cup to the surrounding wellbore. The shape change can also involve a shortened axial dimension that results in the cup shape moving away from the end ring to which it is unattached. The stimulus is provided with well fluids or artificially through heaters or other techniques. External elongated protective elements can be provided to overlay the cup seal during run and bend outwardly with the cup seal during reversion to its functional shape.

Abstract: The present invention generally relates to a packer for creating a seal in an annular area. In one aspect, a packer cup for use in a wellbore is provided. The packer cup includes a base and a first seal segment having a first end and a second end. The first end of the first seal segment is attached to the base. The packer cup further includes a second seal segment that is spaced apart from the base. The second seal segment is attached to the second end of the first seal segment, wherein each seal segment is configured to move from a retracted shape to an expanded shape upon activation of the respective seal segment. In another aspect, a method for creating a seal between a tubular and a wellbore is provided. In a further aspect, a packer is provided.

Abstract: A sealing system and method for sealing a tubular conduit, the sealing system includes a housing, at least one annular seal surrounding the outer surface of the housing, at least one seal back-up mounted on the housing outer surface, and seal and anchor energising means for urging the annular seal and the anchor surface into contact with the tubular conduit in response to an actuation force.

Abstract: A packer for a well. The packer comprises a seal element and seal setting apparatus. The seal setting apparatus is moveable with respect to the seal element in a setting direction to apply a setting force to the seal element to move the seal element from a run-in configuration to a set configuration in which, in use, the seal element forms a contact seal with a conduit wall. In use, the packer is arranged such that, in the set configuration, a pressure differential across the packer, which creates a force in the setting direction, will increase the setting force applied by the seal setting apparatus to the seal element to maintain the seal.

Abstract: The seal has a base ring that expands with the underlying supporting tubular. Extending from the base ring is a pleated structure with segments folded over each other so that the run in shape is small and up against the supporting tubular for run in. The pleated segments can have internal stiffeners that also add a bias radially outwardly when the structure is freed to move in that direction. A retaining band keeps the assembly retracted until tubular expansion defeats the band to allow the unitary structure to move out radially to the wellbore or surrounding tubular. The pleated portion unfolds and spans outwardly from the base ring to retain pressure differential in one direction while allowing fluid flow in the opposite direction. The assembly can be attached to a swage device so that pressure from above can drive one or more swage members to expand a tubular.

Abstract: A system for plugging an oil well after a blowout comprises a hollow drill string. A connecting device is loosely situated around the string. The connecting device has an upper surface, a side surface and a lower surface having a recess. An inflatable bladder comprises an impermeable material. A skirt has a plurality of rods, each of which are pivotally connected to the lower surface. The first fastening ring is configured to selectively allow the bladder to transition from an unfilled state to a filled state. A second fastening ring is configured to selectively allow the skirt to transition from a closed position to an open position. A stop having a beveled edge is secured to the drill string. The recess is configured to allow the connecting device to mate with the stop beveled edge.

Abstract: An apparatus positionable along a downhole string. The apparatus includes a flexible structure retained on a surface of the string in a first condition. The flexible structure movable by a flow to substantially fill an annular space between the string and a radially positioned structure in a second condition. A method of diverting fracturing treatments in a wellbore is also included.

Abstract: A system for plugging an oil well comprises a hollow drill string. A connecting device having an upper surface, a side surface, and a lower surface having a recess is loosely situated around the drill string. A first skirt has a plurality of first rods that are each pivotally connected to the upper surface. A second skirt has a plurality of second rods that are each pivotally connected to the lower surface. A first fastening ring is configured to selectively allow the first skirt to transition from a closed position to an open position. A second fastening ring is configured to selectively allow the second skirt to transition from a closed position to an open position. A stop having a beveled edge is secured to the drill string. The recess is configured to allow the connecting device to mate with the stop's beveled edge.

Abstract: A sealing apparatus for sealing an annulus is described. The apparatus comprises a first sealing element (20) adapted for sealing the annulus against fluid pressure from above the sealing apparatus and adapted to be actuated by fluid pressure from above the apparatus and a second sealing element (40) adapted for sealing the annulus against fluid pressure from below the sealing apparatus and adapted to be actuated by fluid pressure from below the apparatus. In use, the sealing elements are arranged such that the second sealing element is above the first sealing element.

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 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: An annular seal for a setting tool in a packer tieback extension comprises a downhole oriented packer cup assembly. As the tool is run in the hole the packer cup flexes as the rising hydrostatic pressure equalizes across the cup into what started as a zone with atmospheric pressure inside the packer tieback extension. Once the pressure is equalized the self energizing feature of the packer cup maintains grit and debris in the mud from entering the tieback extension where the spring loaded dogs of the setting tool are held in a retracted position. If the seal fails to equalize and allows a large differential across the setting sleeve from the surrounding annulus, the rupture disc breaks inwardly into the tieback extension so that pressure is equalized. If the packer is never set after being lowered to depth and the pressure from the tieback extension is equalized into the annulus.

Abstract: An apparatus for wellbore fluid treatment having a body with a lower end, an upper end, an exterior surface and an interior surface defining a long bore open at the upper end, an outlet port spaced from the upper end, and a die in the long bore between the upper end and the outlet port. The outlet port permits the communication of fluids between the long bore and the exterior surface. The die is substantially immovable within the long bore and has an inner open diameter in which a plug is landable to create a seal in the long bore before passing through the inner open diameter.

Abstract: A downhole apparatus and for use in a well bore and associated method are disclosed. The downhole apparatus includes a center mandrel. A slip means is disposed on the mandrel. The slip means can include teeth or the like for grippingly engaging the well bore when in a set position. A retractable packer cup is also disposed on the mandrel. The retractable packer cup is provided for sealing an annulus between the mandrel and the well bore. The retractable packer cup is slidable relative to the mandrel, and can be controlled to slide along the mandrel in order to move the slip to the set position. Also disclosed is a downhole assembly that includes a downhole tool and a setting apparatus. The setting apparatus can be used for lowering the downhole apparatus to a desired setting depth and then releasing the downhole apparatus.

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 packer assembly can include an annular seal element and an end ring including leaves formed on a body of the end ring, whereby the leaves are biased radially outward when the seal element extends radially outward. A method of sealing an annulus in a subterranean well can include positioning a circumferential series of leaves radially outwardly overlying an annular seal element of a packer assembly, and the leaves pivoting radially outward in response to swelling of the seal element. Another packer assembly can include an annular seal element which swells in response to contact with a selected fluid in the well, and an end ring including an end ring body with a removable portion being engaged with the end ring body via interlocking profiles.

Abstract: An open hole packer uses mandrel expansion and a surrounding sealing element that can optionally have a swelling feature and further a seal enhancing feature of a ring with an internal taper to match an undercut on the mandrel exterior. As a swage progresses to the taper at the transition between the ring and the extending flat fingers, the fingers get plastically deformed in an outward radial direction to push out the sealing element. Shrinkage of the mandrel axially due to radial expansion brings a ring on the mandrel outer surface under the fingers to act as a support for the fingers against the seal which is pushed against the open hole. Mirror image orientations are envisioned to aid in retaining pressure differentials in opposed directions. Another external mandrel ring extends into the seal to keep its position during differential pressure loading.

Abstract: A downhole apparatus and for use in a well bore and associated method are disclosed. The downhole apparatus includes a center mandrel. A slip means is disposed on the mandrel. The slip means can include teeth or the like for grippingly engaging the well bore when in a set position. A retractable packer cup is also disposed on the mandrel. The retractable packer cup is provided for sealing an annulus between the mandrel and the well bore. The retractable packer cup is slidable relative to the mandrel, and can be controlled to slide along the mandrel in order to move the slip to the set position. Also disclosed is a downhole assembly that includes a downhole tool and a setting apparatus. The setting apparatus can be used for lowering the downhole apparatus to a desired setting depth and then releasing the downhole apparatus.

Abstract: A downhole apparatus and for use in a well bore and associated method are disclosed. The downhole apparatus includes a center mandrel. A slip means is disposed on the mandrel. The slip means can include teeth or the like for grippingly engaging the well bore when in a set position. A packer cup is also disposed on the mandrel. The packer cup is provided for sealing an annulus between the mandrel and the well bore. The packer cup is slidable relative to the mandrel, and can be controlled to slide along the mandrel in order to move the slip to the set position. Also disclosed is a downhole assembly that includes a downhole tool and a setting apparatus. The setting apparatus can be used for lowering the downhole apparatus to a desired setting depth and then releasing the downhole apparatus.

Abstract: A downhole apparatus and assembly for use in a well bore and associated method are disclosed. The downhole apparatus includes a mandrel, a first slip, and a second slip, both slips being disposed on the mandrel. The slips are configured to grippingly engaging the well bore when in a set position. A packer cup is also disposed on the mandrel. The packer cup is provided for sealing an annulus between the mandrel and the well bore. The packer cup is slidable relative to the mandrel, and can be controlled to slide along the mandrel in order to move the slip to the set position. The downhole assembly includes a downhole tool and a setting apparatus. The setting apparatus can be used to lower the downhole apparatus to a desired setting depth and then to release the downhole apparatus.

Abstract: A sealing device is disclosed for separating sections inside an elongate hole with at least one duct extending inside and along the hole. The sealing device includes a first portion which is arranged, in use of the sealing device, to surround the duct and fit substantially tightly against the same, and a flexible cup-shaped second portion, which is arranged to surround the first portion and be resilient radially outwards to seal, in use, against the hole. Moreover, a method is disclosed for separating sections in an elongate hole with a duct extending inside and along the hole. A sealing device is slipped onto the duct at the intended level so that the sealing device after installation forms a cup shape around the duct. The duct and the sealing device are inserted into the hole, and the duct and the sealing device are installed at the intended level.

Abstract: A method to connect a lifting assembly to a bore of a downhole tubular includes providing a communication tool to a distal end of the lifting assembly, the communication tool comprising a body assembly, an engagement assembly, a valve assembly and a seal assembly, sealingly engaging a first portion of the seal assembly in the bore of the downhole tubular, selectively permitting fluid to flow between the lifting assembly and the downhole tubular with the valve assembly, and disengaging the first portion of the seal assembly from the bore of the downhole tubular.

Abstract: A packer cup for sealing the interior of a pipe under pressure includes a first region of relatively soft material and a second region of relatively hard material. The region of the relatively softer material would begin at the lip of the cup and extend for at least one third the length of the cup up to the entire length of the cup.

Abstract: In accordance with a broad aspect of the present invention there is provided an apparatus for wellbore fluid treatment, comprising: a body with a lower end, an upper end, an exterior surface and an interior surface defining a long bore open at the upper end; an outlet port spaced from the upper end, the outlet port permitting the communication of fluids between the long bore and the exterior surface; and, a die in the long bore between the upper end and the outlet port, the die being substantially immovable within the long bore and having an inner open diameter in which a plug can land to create a seal in the long bore before passing through the inner open diameter.

Abstract: An anchoring device for tool is disclosed that can be positioned downhole and used in casing. The anchoring device can have an architecture that supports installation by running downhole and into engagement with a recess formed in the casing. The anchoring device can support the use of weak materials such as plastic.

Abstract: A self adjusting excluder sub includes a first subassembly; a second subassembly with respect to which the first subassembly is axially movable; and a support disposed at the second subassembly and when actuated being resiliently disposed against the first subassembly while being laterally movable relative to the first and second subassemblies jointly and method.

Abstract: A tool for subterranean use employs relative movement between a housing and a piston by pressurizing and removing pressure in a variable volume defined between them. The variable volume is sealed with packer cups preferably with one supported from the piston and the other off the housing and in opposed orientations so that the broad surface area on each packer cup abuts the surface where relative movement takes place. The downhole tasks accomplished with the relative movement can be varied and include tubular expansion, setting packers or shifting sleeves, for example. A single or multiple packer cups are tied to a structure that needs to be driven and building pressure behind a packer cup or reducing pressure ahead of it advance the piston.

Abstract: An apparatus for use with production tubing to pump fluid from a well to the surface includes a tubular conduit having upper and lower portions. The lower portion has an inner or outer diameter greater than the diameter of the upper portion to form a first internal or external shoulder where the lower and upper portions are engaged. Seals are disposed on the conduit for sealing between the conduit and a well casing. One or more valve sections have a valve adapted to open during downwards motion through fluid and to close during upwards motion through fluid.

Abstract: A wiper plug release tool uses a first pump down plug that lands in the tool to pressurize an internal chamber to slide a sleeve that undermines a set of dogs to allow the lower wiper plug to be decoupled from support. The shifting of this sleeve cams a second set of dogs into an internal passage in the tool to act as a landing location for a second pump down plug. Landing the second pump down plug on the now extended dogs allows a net pressure to be applied to an upper piston which shifts a sleeve to release the support for the second wiper plug. The upper piston remains in pressure balance unless the second pump down plug can be landed on the dogs that only extended because the sleeve that released the lower wiper plug had shifted.

Abstract: A tool for subterranean use envisions relative movement between a housing and a piston by pressurizing and removing pressure in a variable volume defined between them. The variable volume is sealed with packer cups preferably with one supported from the piston and the other off the housing and in opposed orientations so that the broad surface area on each packer cup abuts the surface where relative movement takes place. The downhole tasks accomplished with the relative movement can be varied and include tubular expansion, setting packers or shifting sleeves, for example. Alternative embodiments envision use of a single or multiple packer cups tied to a structure that needs to be driven and building pressure behind a packer cup or reducing pressure ahead of it to advance it.

Abstract: A packer provides multiple seals when deployed downhole. Exposed to an activating agent, a swellable element on the packer's mandrel expands radially outward to form a seal with the borehole wall. One or more deformable elements, such as compressible packers or cup packers, are disposed on the mandrel adjacent the swellable element. These deformable element deform outward to the surrounding borehole wall to at least partially isolate the downhole annulus and the swellable element. Bias units releasably affixed on the tool adjacent the deformable elements can deform the elements. These bias unit can be released either by swelling of the swellable element or by fluid pressure. Once released, the bias units are axially biased toward the deformable elements to deform them. In this way, the packer can form multiple seals with the borehole wall, and the deformable elements can isolate the swellable element from the downhole annulus, which can keep the swellable element from degrading or being overly extruded.