Sealing of an Annular Space Proximate to a Sand Screen

None.

Not applicable.

The present disclosure relates generally to sealing of an annular space proximate to a sand screen. More particularly, the present disclosure relates to deploying a flexible seal, for example, a flexible seal, to seal the annular space.

Sand screens may be, for example, filtration devices used in well production which are designed to prevent sand and/or other fine particles from entering and damaging production equipment. They may be helpful for extraction of hydrocarbons from sandstone or other reservoirs where sand production may be a problem. Sand screens may also help maintain the structural integrity of the well by filtering out sand and sediments while allowing fluids like oil, gas, and water to flow through, and/or by providing some level of support for the wellbore.

In some scenarios, it may be beneficial to seal tail ends of a sand screen joint, seal off other parts of the sand screen, or otherwise tailor flow in, around, or near the sand screen. However, conventional methods of sealing may require multiple trips, specialized chemicals, and/or specialized tools.

Thus, there may be a need for an apparatus for tailoring flow in, around, or near a sand screen that can be run in a single trip and/or without the need for special chemicals or specialized tools.

It should be understood at the outset that although illustrative implementations of one or more embodiments are illustrated below, the disclosed systems and methods may be implemented using any number of techniques, whether currently known or not yet in existence. The description that follows includes example systems, methods, techniques, and program flows that embody aspects of the disclosure. However, it is understood that this disclosure may be practiced without these specific details. For brevity, well-known steps, protocols, structures, and techniques have not been shown in detail in order not to obfuscate the description. The disclosure should in no way be limited to the illustrative implementations, drawings, and techniques illustrated below, but may be modified within the scope of the appended claims along with their full scope of equivalents.

As used herein the terms “uphole”, “upwell”, “above”, “top”, and the like refer directionally in a wellbore towards the surface, while the terms “downhole”, “downwell”, “below”, “bottom”, and the like refer directionally in a wellbore towards the toe of the wellbore (e.g. the end of the wellbore distally away from the surface), as persons of skill will understand. Orientation terms “upstream” and “downstream” are defined relative to the direction of flow of fluid, for example relative to flow of well fluid in the well. As used herein, orientation terms “upstream,” “downstream,” are defined relative to the direction of flow of well fluid in the well casing. “Upstream” is directed counter to the direction of flow of well fluid, towards the source of well fluid (e.g., towards perforations in well casing through which hydrocarbons flow out of a subterranean formation and into the casing). “Downstream” is directed in the direction of flow of well fluid, away from the source of well fluid.

As used herein, the term “seal” does not necessarily mean a perfect seal. In some embodiments, there may be leakage past the seal but the flow can be significantly reduced by the seal.

According to an embodiment, an apparatus according to the present disclosure may be configured to seal an annular space (e.g. between a tubular and a wellbore into which the tubular is disposed) in proximity to a sand screen, for example in proximity to the tail ends of a sand screen. For example, the apparatus may include a flexible seal configured to encircle a tubular, and a deployment mechanism configured to cause the flexible seal to transition from a first state to a second state. In the first state, the flexible seal may have an outer diameter less than a diameter of the wellbore (e.g. a radial gap may exist between the flexible seal and the interior surface of the wellbore), and in the second state, the outer diameter of the flexible seal may be the same as the diameter of the wellbore (e.g. the flexible seal may span from the tubular to the interior surface of the wellbore, with no gap therebetween). For example, in the second state, the flexible seal may be configured to seal the annular space about the tubular, for example substantially preventing axial fluid flow therepast. In embodiments, the apparatus may include a settable seal style element configured to seal the end of a sand screen, for example, in order to control/tailor fluid flow. It should be understood that in this context providing a seal may not require a complete seal with no leakage, but may for example provide significant and/or substantial sealing (e.g. significantly reducing axial fluid flow therepast and/or blocking substantially all axial fluid flow therepast). Embodiments of the apparatus may be configured for use with an expandable sand screen.

In embodiments, the deployment mechanism may be configured to be activated responsive to expansion of the sand screen. In some embodiments, activating the expansion screen comprises inflating the expansion screen so that it plastically deforms and is not easily deflated. In embodiments, transitioning the flexible seal from the first state to the second state may comprise placing a portion of the flexible seal into contact with and/or overlapping the sand screen, so that expansion of the sand screen can transition the flexible seal to the second state. For example, upon activation, the seal element may move axially to slide over a corresponding end of the sand screen. In embodiments, expansion of the sand screen (e.g. by activation of the activation chambers of the sand screen) may push the seal (e.g., a rubber cup) radially outward and enable sealing against the wellbore. In some embodiments, the seal outer diameter in the first state may fit within the existing tool max outer diameter.

In some embodiments, a cup style metal bonded rubber element (e.g. seal) may be disposed in proximity to one or more end of the sand screen, and may sit below the max outer diameter of the tool. The flexible seal (e.g. rubber element) may be biased towards the sand screen, for example by a spring. Upon activation, the seal may slide axially until the rubber element of the flexible seal overlaps a length of the sand screen. This way, when the activation chamber of the sand screen pushes the screen out, it may also push the rubber of the flexible seal out until the rubber seals against the wellbore.

In some embodiments, the deployment mechanism may have a metal coupling that connects it to a screen clamp ring, for example with a shear pin. The activation of the activation chambers of the sand screen may cause the screen clamp ring to rotate as it sets/expands the screen. This may cause the shear pin connecting the seal to the clamp ring to shear, and allow the compressed spring (e.g. biasing the flexible seal towards the sand screen) to release its energy and push the seal axially.

When deployed, the spring may press against the seal (e.g. driving the seal towards the sand screen), and the seal may ride up and radially outward at an angle. For example, the rubber element of the flexible seal and/or the end (e.g. screen clamp ring or separate wedge element) of the sand screen may include an angled portion. The seal may then come into contact with the open hole inner diameter of the wellbore and create a seal. An internal slip (e.g., a collar with teeth or other axial fixing element on the inside of it to prevent axial movement) may be used to anchor an end of the spring in place. The rubber seal may releasably pinned to a body portion of the sand screen so that when the screen is activated, there may a component that rotates radially, which may shear the pin (e.g. overlapping layers of the sand screen may slide over each other to shear the pin). When the pin shears, the spring may be free to extend. The spring may push the seal over the screen component. As the screen is activated, the seal may extend over it.

In some embodiments, the seal may be activated hydrostatically. For example, the flexible seal may transition from the first state to the second state based on activation by hydrostatic pressure (e.g. in the annular space between the tubular and the wellbore), placing a portion of the flexible seal into contact with and/or overlapping the sand screen, so that expansion of the sand screen can transition the flexible seal to the second state. In an embodiment, a difference in piston areas at the metal end of the seal and a vacuum inside the metal end may cause the downhole hydrostatic pressure to have a net force to drive the seal axially towards the sand screen. The seal may pinned to a value equal to the force applied when the seal reaches depth. The hydrostatic force may then push the seal over the screen. In another embodiment, the seal may be pinned (e.g. using a shear pin) to a value slightly greater than the hydrostatic at depth. The formation may be pressured up to a small applied value (e.g., 200-300 psi) to cause the shear pins to shear. There may be a vacuum inside the apparatus, and hydrostatic pressure outside. A vacuum port (e.g., a hole) may be used to pull the vacuum, and then the vacuum port may be plugged.

In some embodiments, the seal may be filled with an oil instead of vacuum and/or may include a flow restrictor to cause a time delay. When the seal is run to depth, the shear pins may shear due to hydrostatic pressure alone, but the flow restrictor may cause a delay so that the sand screen can be run to position before the seal slides over the screen thereby ensuring that the seal always stays below the max outer diameter of the sand screen.

In some embodiments, the flexible seal may be biased radially outward (e.g. towards the wellbore), but initially retained in its first state. The biasing may be configured so that, when unrestrained, the flexible seal transitions to its second state. In some embodiments, a positively biased seal may be packed under a dissolvable sleeve to cause a time delay for deployment of the seal. For example, the seal may be run to depth in an inert fluid. Upon swapping the inert fluid with another fluid, the sleeve may start to dissolve. Alternatively, the seal may be run in fluid that causes it to start dissolving immediately but is designed such that it will only dissolve enough to enable the positively biased seal to deploy long after the tool has been run to depth. At a desired time (e.g. based on exposure to the fluid), the sleeve may dissolve completely (or dissolve sufficiently to break), at which time the positively biased seal may be deployed to create a seal with the open hole inner diameter. In some embodiments, the seal may not need to hold a pressure differential, but may be designed to create a choke in the flow of the production fluid. When the dissolvable sleeve loses structural integrity, the rubber seal may come out and make contact with the sand screen.

In some embodiments, a positively biased seal may be packed under a sleeve of a material that is brittle. For example, the sleeve may include fracture lines. In embodiments, the sleeve may not create a seal and/or may prevent the seal from deploying. In embodiments, the sleeve may have holes. In embodiments, the sleeve may rest on an end of the sand screen (e.g., on the transition zone). When the sand screen is deployed, the expansion of the sand screen may cause the brittle sleeve to shatter and deploy the positively biased rubber seal to create a seal with the open hole outer diameter. In embodiments, the seal may not need to hold a pressure differential but may be designed to create a choke in the flow of the production fluid.

Referring to, a wellwith components for filtering sand from formation fluid in a well is depicted. A wellboremay extend through the various earth strata. In some embodiments, the wellboremay have a vertical section, the upper portion of which is have installed therein a casing stringthat may be cemented within wellbore. In embodiments, the wellboremay also have a horizontal sectionthat may extend through a hydrocarbon bearing subterranean formation. The horizontal sectionof wellboremay be open hole in some embodiments. It should be understood that in some embodiments, the well may be substantially vertical, substantially horizontal, angled, or some combination thereof, and that orientation of the well may not impact implementation of the disclosed apparatus, system, or method embodiments.

Positioned within the wellboreand extending from the surface may be a tubular(e.g., tubing string). The tubularmay provide a conduit for formation fluids to travel from the formationto the surface. For example, one or more pump, for example positioned at the surface and/or in the wellbore, may be configured to pump formation fluids uphole (e.g. through the tubular). Positioned within the tubularmay be one or more sand screens. In embodiments, the sand screensmay be configured to be expandable. The sand screensare shown inin a running or unactivated configuration. In, the sand screensare shown in an activated configuration.

Those skilled in the art will recognize that the tubularmay include any number of other tools and systems such as fluid flow control devices, communication systems, safety systems and the like. Also, the tubularmay be divided into a plurality of intervals using zonal isolation devices such as packers. Similar to the swellable material in sand screens, these zonal isolation devices may be made from materials that swell upon contact with a fluid, such as an inorganic or organic fluid. Some exemplary fluids that may cause the zonal isolation devices to swell and isolate include water, gas and hydrocarbons.

In the exemplary embodiment of, the sand screenshave been run to setting depth. The sand screensmay be run below hanger or packer systems. The sand screensmay be disposed in production zones (e.g., zones that have been fractured). The wellmay be balanced to well hydrostatic when running inhole. As can be seen in, screen valve modulesin each screen joint when closed may provide a high-pressure window, and circulation may be achieved without premature screen activation. Upon reaching the desired depth, the hanger may be set. In some embodiments, circulation may occur before screen activation. Placement of filter cake breaker systems can be achieved. After hanger running tool release, and the completion circulation flowpath may be closed, and internal tubing pressure can be applied.

Referring to, the screen may include a tubular(or a body configured to be made up in a tool string) and activation chamberssurrounding the tubular. A drainage/support layermay surround the activation chambers. One or more production flow channelsmay be bounded by the tubular, the activation chambers, and the support layer. A sand filtration mediamay surround the support layer. A protective outer shroudmay surround the sand filtration media. That is, the support layermay be disposed between the activation chambersand the sand filtration media, and the sand filtration mediamay be disposed between the support layerand the protective outer shroud.

Referring to, an apparatus,′,″,′″ respectively may be provided for sealing an annular space S proximate to an endE of a sand screenon a downhole tubular. Hereinafter, reference numbers may also refer to primed element numbers where applicable. For example, reference numbermay refer in the alternative to,″, or′″ where applicable. A flexible seal(e.g. cup) may be configured to encircle the tubular. The flexible sealmay have a first (e.g. run-in) state in which an outer diameter of the flexible sealis less than a diameter of the wellbore(e.g. there is a gap G between the flexible sealand the interior surface of the wellbore), and a second (e.g. deployed) state in which the outer diameter of the flexible sealis the same as the diameter of the wellbore(e.g. the flexible sealextends radially outward from the tubularto contact an interior surface of the wellbore) and/or in which the flexible sealseals the annular space between the tubularand the wellbore. A deployment mechanismmay be configured to cause the flexible sealto transition from the first state to the second state. The apparatusmay be configured to seal an area adjacent to the sand screen(e.g. adjacent an end of the sand screen). The wellboremay be a wellbore of a hydrocarbon (e.g. oil and/or gas) well. The wellboremay be either cased or uncased. The sealing of the annular space S may substantially prevent axial flow of fluid in the annular space S beyond the endE of the sand screen(e.g. above or below the sand screen).

In some embodiments, the tubularmay be casing or tubing. The sand screenmay be configured to expand radially outwardly from the tubular(e.g. into contact and/or proximity with the interior surface of the wellbore). The sand screenmay expand in response to the activation chambersof the sand screenbeing pressurized. The activation chamberbeing pressurized may occur as a result of the tubularbeing pressurized in some embodiments. The sand screenmay be configured to filter out sand particles between the interior surface of the wellboreand the tubular(e.g. filtering formation fluid before it enters inside the tubular). In embodiments, the flexible sealmay be made of rubber or some other elastomeric material. The flexible sealmay include a holeH extending therethrough. The holeH may be an axial hole. The holeH may be configured to have the tubularextending therethrough.

The flexible sealmay be impermeable. The flexible sealmay include a flexible wallencircling the tubular. A proximal end of the flexible wallmay be mounted/fixed to the tubular, and a distal end of the flexible wall may be free (in some embodiments, the proximal end of the flexible wallmay be (radially) fixedly attached to the tubular, while the remainder of the flexible wallmay be free). In some embodiments, the distal end of the flexible wallextends towards the sand screen(e.g. the free end may be disposed towards the sand screen, with the distal end disposed between the sand screenand the proximal end). In the first state, the flexible sealmay be axially spaced from the sand screen, and in the second state, the flexible sealmay extend over an end of the sand screen(e.g. axially overlap and/or be sandwiched between the sand screenand the wellbore, thereby being held in the second state).

Referring to, the deployment mechanismmay include a coupling(e.g., rod) configured to fix the axial position of the flexible sealwith respect to the sand screen(or any other means of mechanically coupling the sealto the sand screenso that the activation of the sand screenreleases the mechanical coupling and allows the biasing memberto push the sealover the sand screen). A biasing membermay be configured to bias the (e.g. distal end of the) flexible sealtowards the sand screen. The couplingmay be configured to release the flexible sealin response to expansion of the sand screen. The deployment mechanismmay include a base, The flexible sealmay be mounted (e.g. radially affixed) to the tubularby the base. The couplingmay extend from the base or the flexible sealand/or may be configured to be affixed to the sand screen. A slip(e.g., locking device) may be configured to be affixed to the tubular, and the biasing membermay extend from the slipto the base. Any other locking device that forces to biasing memberto move the sealupon activation of the sand screenmay be used. In some embodiments, the slipor other locking device fixes the end of the biasing member(e.g., spring) in place so that when released the biasing memberforces the sealover the expanding sand screen.

The basemay be a metal base configured to encircle the tubular. The flexible sealmay be bonded to the metal base. The couplingmay be made of metal. The couplingmay include a shear pin. The couplingmay be shearably attached to the sand screen(e.g. with a shear pin).

The deployment mechanismmay be configured to cause the flexible sealto transition to the second state, in response to the coupling(or its attachment) breaking/shearing. The couplingmay be configured to break/shear, in response to the sand screenexpanding. The sand screenexpanding may cause a clamp ring of the sand screento rotate. The couplingmay be affixed to the clamp ring. The couplingmay be configured to break/shear, in response to the rotation of the clamp ring.

The biasing membermay include a spring. The spring may include a coil spring configured to encircle the tubular. In response to the couplingbreaking/shearing, the biasing membermay expand to push the baseaxially along the tubular(e.g. the basemay be mounted to the tubular in such a way as to allow axial movement from the first position to the second position, once the couplingis no longer fixing its axial position). In some embodiments, the biasing membermay drive the flexible sealtowards the sand screen, and radial expansion of the sand screen may radially expand the flexible sealto the second state. In some embodiments, the activated sand screen may push the distal end of the flexible sealradially outward into contact with the wellbore. In some embodiments, the distal end of the flexible sealmay be sandwiched between the sand screen and the wellbore in the second state, while in other embodiments the distal end of the flexible sealmay not be wedged between the sand screen and the wellbore.

Referring to, the flexible sealmay include an inclined plane(e.g. at its distal end, for example with the thickness of the flexible wallreducing as the flexible wallextends away from the baseand/or with the inclined planedisposed in proximity to/facing the tubular). In embodiments, the inclined planecan be configured to guide the flexible sealover a wedge(e.g., a clamp ring) when the flexible sealtransitions from the first state to the second state. Sliding of the flexible sealover the wedge(as the sand screenexpands) may cause the flexible sealto transition from the first state to the second state (e.g. the expansion of the sand screenand/or the axial movement of the flexible sealwith respect to the wedgecan induce radial movement of the flexible sealoutward). In the second state, the distal end of the flexible sealmay be disposed/wedged between the interior of the wellboreand the sand screen.

Referring to, the slipmay include a set screw configured to fasten the slipto the tubular. The slipmay be annular. The slipmay be configured to encircle the tubular. The springmay extend from an end of the metal baseto an end of the slip.

Referring to, in some embodiments, the deployment mechanism′ may include a base′. The flexible sealmay extend from the base′ towards the sand screen(e.g. with a proximal end attached to base′ and a distal end free and disposed towards and/or in proximity to the sand screen). The base′ may be configured for activation based on hydrostatic pressure in the well. For example, the base′ may include a first portionhaving a first inner diameter corresponding to a first outer diameter of the tubular; and a second portionhaving a second inner diameter corresponding to a second outer diameter of the tubular.

In embodiments, a portmay extend radially inward from an outer surface. A volume/chamber C may be formed between the tubularand the base′. A shearable retaining element′ (e.g. shear pin) may axially fix the base′ to the tubular. The portmay include a vacuum port configured to facilitate drawing a vacuum in the volume/chamber C, with the portthen being closed/plugged to seal the chamber C. Alternatively, the portmay be configured for introduction of oil, and chamber C may contain oil. In some embodiments, a flow restrictor may be configured to cause a time delay. In some embodiments, for the sealto be able to move, it must first displace the oil (or other fluid) contained inside chamber C. In one embodiment, this fluid may be displaced into another chamber in the tubular. A check valve or other fluid control devices may be used to prevent the fluid from being vented into the other chamber prematurely. Upon reaching depth where the hydrostatic pressure is sufficient to shear the retaining element′, the sealmay start to move axially due to the hydrostatic pressure. However, due to the flow restrictor, there may be a time delay in the movement and there may be a time lag between when the retaining member′ shears and the sealhas moved axially at a distance sufficient for the inclined planeto ramp over wedge. As a result, the sealmay continue to sit below the tool diameter even after the retaining member′ has been sheared. This may be useful operationally because a ramping of the sealover the wedgecan cause the rubber to be proud of the tool outer diameter and can cause the tool to get stuck before the tool has reached its intended depth. The time delay can be configured by adjusting the fluid volume in chamber C, size/design of restriction of the restrictor, the length of gap between base′ to where it bottoms out on the third surfaceSor a combination thereof. In some embodiments, the time lag is configured to be 4 hours. In some embodiments, the time lag can be from 1 hour to several days. The first inner diameter of the base′ may be greater than the second inner diameter of the base′. The first outer diameter of the tubular may be greater than the second outer diameter of the tubular. The first inner diameter may be sized to create a slip fit with the first outer diameter. The second inner diameter may be sized to create a slip fit with the second outer diameter. The first outer diameter may be configured to act as a stop for axial movement of the base′ (e.g. due to interference interaction between the first inner diameter of the base′ and the second outer diameter of the tubular). The base′ may include a first axial endEand a second axial endE. The shearable retaining element′ (e.g., shear pin) may be configured to break/shear in response to a difference between a first hydrostatic force on the first axial endEand a second hydrostatic force on the second axial endEexceeding a threshold (thereby moving the flexible sealfrom the first position to the second position).

The first hydrostatic force may be based on a first projected surface area of the first axial endEin a plane approximately perpendicular to a longitudinal central axis of the tubular. The second hydrostatic force may be based on a second projected surface area of the second axial endEin another plane approximately perpendicular to a longitudinal central axis of the tubular(e.g. the two planes are approximately parallel to each other). The first hydrostatic force may be further based on pressure in the well/annular space at a first axial location at which the first projected surface area is disposed, and/or the second hydrostatic force may be further based on pressure in the well/annular space at a second axial location at which the first projected surface area is disposed. The force at the second axial endEmay be greater than the pressure at the first axial endEdue to the area difference between the second axial endEand the first axial endE. The first projected surface area may be greater than the second projected surface area. Due to the configuration of the base′, hydrostatic pressure may be used to activate the deployment mechanism, transitioning the flexible sealfrom the first state to the second state. The base′ may comprises a stepped (e.g. inner) profile (e.g. forming the vacuum chamber/volume between the base and the tubular).

Upon release of the shearable retaining element′ (e.g. due to application of sufficient hydrostatic pressure), a first surfaceSof the base′ may slide along a first surfaceSof the tubular, and a second surfaceSof the base may slide along a second surfaceSof the tubular (e.g. from the first position to the second position). The first inner diameter may be an inner diameter of the first surfaceSof the base′ and the second inner diameter may be the inner diameter of the second surfaceSof the base′. A third surfaceSof the base′ may be configured to stop against a third surfaceSof the tubular(upon axial movement of the base, e.g. to the second position, for example towards the sand screenand/or downward). The third surfaceSof the base′ may be disposed between the first surfaceSof the base′ and the second surfaceSof the base′, and the third surfaceSof the tubularmay be disposed between the first surfaceSof the tubularand the second surfaceSof the tubular. The first surfaceSof the base′ may be approximately parallel with the second surfaceSof the base′. The first surfaceSof the tubularmay be approximately parallel with the second surfaceSof the tubular. The third surfaceSof the base′ may be approximately parallel with the third surfaceSof the tubular. The third surfaceSof the base′ may extend radially outward, for example at an oblique angle, with the first surfaceSof the base′. The third surfaceSof the tubularmay extend radially outward as well (e.g. at an oblique angle with the first surfaceSof the tubular). The third surfaceSof the tubularmay limit axial translation of the base′ (e.g. act as a stop on axial movement).

The threshold at which the deployment mechanismis configured to actuate via hydrostatic pressure may be based on the desired depth of deployment (e.g. a shearable retaining element has a threshold based on the force applied when the flexible sealreaches desired depth, e.g. automatically deploying at the desired depth). The threshold at which the deployment mechanismis configured to actuate may be greater than the hydrostatic pressure based on the desired depth of deployment (e.g. the shearable retaining element has a threshold based on the force applied when the flexible sealreaches desired depth plus some additional applied pressure (e.g. from the surface), e.g. being deployed in response to being properly located and then having sufficient pressure applied downhole in the annular space).

In the first state, the third surfaceSof the base′ may be spaced apart from the third surfaceSof the tubular(e.g. forming the vacuum chamber). In the second state, the third surfaceSof the base′ may abut or be in proximity to the third surfaceSof the tubular(e.g. there may be substantially no vacuum chamber remaining). A first sealcan be disposed between the first portion′ of the base and the tubularand a second sealcan be disposed between the second portion′ of the base′ and the tubular. The first portion′ may have a first grooveformed therein, the second portion′ may have a second grooveformed therein. The first sealmay be disposed within the first groove, and the second sealmay be disposed within the second groove. The first sealmay make a seal on the first surfaceSof the tubular, and the second sealmay make a seal on the second surfaceSof the tubular. The first sealand the second sealmay maintain the vacuum (e.g. inside the vacuum chamber C between the base′ and the tubular, at least in the first state). The first sealmay be a first O-ring, and/or the second sealmay be a second O-ring.

The vacuum portmay include a boreextending (e.g. substantially radially) from an outer surfaceSof the base′ to an inner surface of the base′ (e.g. the third surfaceSof the base′). A plugmay plug/seal the bore (e.g. after the vacuum is drawn). The vacuum portmay facilitate the pulling of the vacuum (thereby creating the vacuum in the vacuum chamber C disposed between the base′ and the tubular).

The base′ may be made of metal, such as steel. The flexible sealmay be made of rubber or another elastomeric material. The flexible sealmay be bonded to the base′. For example, the flexible sealmay be bonded to the first axial endEof the base′. The base′ may be integrally formed in some embodiments.

Referring to, the deployment mechanism″ may include a dissolvable sleeveconfigured to constrain the flexible seal″ in the first state. The flexible seal″ may be biased outward (e.g. configured so that, if unrestrained, the distal end would expand radially outward to the second state (e.g. to make (e.g. substantially sealing) contact with the wellbore). The dissolvable sleevemay be configured to restrain the flexible seal″ (e.g. the distal end of the flexible seal) at a diameter less than that of the wellbore(e.g. at a diameter no more than the run-in outer diameter of the tubularand/or sand screen). The dissolvable sleevemay be mounted on the tubular. In the first state, the flexible seal″ may be disposed between the dissolvable sleeveand the tubular. The dissolvable sleevemay be approximately concentrically located about the flexible sealand/or the tubularin some embodiments. The dissolvable sleevemay be cup-shaped. The dissolvable sleevemay have a boreB in a first endEthereof. The boreB may have the tubularextending therethrough. The boreB may be concentric with a hole/boreB″ in the flexible seal″. The boresB,B″ of the dissolvable sleeveand the flexible seal″ may be concentric with the tubular(e.g. the longitudinal bore of the tubular).

The dissolvable sleevemay be fastened to the tubular. The dissolvable sleevemay be configured to be fastened to the tubularby a set screw. In some embodiments, the dissolvable sleevemay be configured to extend to an end of the sand screen(although in other embodiments, the dissolvable sleeve may be configured to retain the flexible seal in its first state without contacting the sand screen). The dissolvable sleevemay be configured to extend over the end of the sand screenin some embodiments. The dissolvable sleevemay be configured to dissolve when in contact with fluid in the well. The fluid may include hydrocarbons. The fluid may include a chemical pumped into the well. The sleeve material may be selected based on the fluids in the wellbore, or in other cases where the wellborefluid may not be able to dissolve the sleeve, a fluid that can dissolve the sleeve may be swapped with the fluid in the wellborefor a designated amount of time to dissolve the sleeve. The dissolving fluid may be hydrocarbons, water, brine or any other suitable chemical substance. The dissolvable sleevemay be configured to dissolve within an hour, a day, or a week of continuous exposure to the fluid.

In embodiments, the dissolvable sleevecan comprise one or more degradable (e.g. including dissolvable) material that will undergo degradation and/or dissolution and cause the dissolvable sleeveto lose structural integrity in situ under ambient conditions within the wellbore. The degradation and/or dissolution may be the result of contact of the degradable material with an ambient wellbore fluid, contact of the degradable material with an activator/catalytic fluid or compound placed into the wellbore, the effect of ambient conditions (e.g., heat or corrosion) in the wellbore, or combinations thereof. Examples of suitable degradable materials include metals and alloys, polymers, composite materials, or combinations thereof. Suitable metals and alloys may include corrosive metals, such as magnesium and aluminum alloys. Suitable polymers include hydrophilic polymeric materials such as polylactic acid (PLA), polyglycolic acid (PGA), polycaprolactone (PCL), or combinations thereof. Composite materials include fiber reinforced composites having synthetic or natural fibers (e.g., cellulose) and a binder resin/matrix (e.g., a polymer such as PLA, PGA, or PCL). In embodiments, the dissolvable sleevemay comprise one or more degradable material, such as a polymeric or metal alloy based degradable material. In some embodiments, the degradable material may comprise polymeric-based material, polymeric material that uses reinforcement particles or materials, and/or degradable metal alloys (such as Magnesium or Aluminum based alloys). In some embodiments, the degradable material may comprise a coating, for example providing a delay in degradation. In some embodiments, the degradable materials may comprise lactic acid, polylactic acid (PLA), PGA, and/or highly corrosive materials. In some embodiments, the reactive fluid for degrading the degradable material may comprise wellbore fluid, activator/catalytic fluid or compound, water, and/or mud. In some embodiments, the temperature of the reactive fluid may be controlled to cause or accelerate degradation. In some embodiments, the reactive fluid may have a high chlorine content. In some embodiments, the dissolvable sleevemay be configured to degrade (e.g. when exposed to reactive fluid and/or conditions) in more than 12 hours and/or in less than 5 days. In some embodiments, the dissolvable sleevemay be configured to degrade (e.g. when exposed to reactive fluid and/or conditions) in more than 5 days (e.g. approximately 5-10 days, approximately 5-7 days, or approximately 7-10 days).

In some embodiments, the dissolvable sleevemay include holes/apertures configured to allow the fluid to pass from an exterior of the sleeveto an interior of the sleeve(e.g. radially extending). The holes may be pores. In the first state, the flexible seal″ may be configured to exert outward pressure on an interior surface of the dissolvable sleeve. In the first state, the flexible seal″ may be fastened to the dissolvable sleeve. In the second state, the flexible seal″ may be configured to contact and/or exert outward pressure on the wellbore(e.g. substantially sealing contact). In the second state, the flexible seal″ may be configured to seal the annular space S in proximity to the end of the sand screen(but typically not overlapping)

Referring to, the deployment mechanism′″ may include a fracturable sleeveconfigured to constrain the flexible seal′″ in the first state. The flexible seal′″ may be biased outward (e.g. configured so that, unrestrained, the distal end would expand radially outward to the second state (e.g. to make (e.g. substantially sealing) contact with the wellbore). The fracturable sleevemay be configured to restrain the flexible seal′″ (e.g. the distal end of the flexible seal′″) at a diameter less than that of the wellbore(e.g. at a diameter no more than the run-in outer diameter of the tubularand/or sand screen). The fracturable sleevemay be mounted on the tubular. In the first state, the flexible seal′″ may be disposed between the fracturable sleeveand the tubular. The fracturable sleevemay be approximately concentrically located about the flexible seal′″ and/or the tubular. The fracturable sleevemay be cup-shaped in some embodiments. The fracturable sleevemay include a boreB in a first end thereof. The boreB may have the tubularextending therethrough. The boreB may be concentric with a hole/boreB′″ in the flexible seal′″ and/or a longitudinal bore of the tubularand/or sand screen. The fracturable sleevemay be configured to be fastened to the tubular. The fracturable sleevemay be configured to be fastened to the tubular by set screws. In the first state, the fracturable sleevemay extend over the end of the sand screen. The fracturable sleevemay be configured to extend over at least a portion of the sand screen(e.g. over at least a portion of the filter element).

The fracturable sleevemay be configured to fracture in response to the sand screenbeing deployed (e.g. expanding, for example to contact the wellbore). For example, the force of the expansion of the sand screenradially outward may be sufficient to break/fragment/shatter the fracturable sleeve, for example when the activation chambersof the sand screenare pressurized. The fracturable sleevemay include one or more fracture lines. The fracture linesmay extend axially along the fracturable sleevein some embodiments. For example, the fracture linesmay define rectangular detachable/fragmentable segments. The detachable segmentsmay be arranged in a cylinder. Alternatively, the detachable segmentsmay be arranged in a polygon. The fracturable sleevemay be cup-shaped. The fracturable sleevemay be made of a brittle material.

The flexible seal′″ may transition from the first state to the second state, in response to the fracturable sleevefracturing. The fracturable sleevefracturing may involve the detachable/fragmentable segmentsdetaching/fragmenting. In the second state, the flexible seal′″ may contact and/or exert outward pressure on the wellbore(e.g. substantially sealing contact). In the second state, the flexible seal′″ may seal the annular space in proximity to the end of the sand screen(but typically not overlapping). In some embodiments, the spacing from the flexible seal′″ to the end of the sand screenis approximately the same as the radial distance between the tubularand the inner diameter of the wellbore. In some embodiments, the spacing from the flexible seal′″ to the end of the sand screenmay be from 2 inches to 1 foot.

Referring to, an exemplary methodof installing a sand screen in a well may include the stepof expanding the sand screen radially outward (e.g. so that the sand screen conforms to an interior surface of a wellbore of the well). The sand screen may be disposed between the interior surface of the wellbore and a tubular of the well. The methodmay further include the stepof activating an apparatus to cause a flexible seal to transition from a first state to a second state. In the first state, there may be a gap between the flexible seal and the interior surface of the wellbore. In the second state, the flexible seal may span from the tubular to the interior surface of the wellbore to seal an area proximate to the sand screen and between the interior surface of the wellbore and the tubular (e.g. in proximity to an end of the sand screen). Activating the apparatus may include activating the apparatus by activating a deployment mechanism. Expanding the sand screen may include activating an activation chamber. Activating the activation chamber may include applying pressure to the activation chamber and/or contracting fluid with swellable material in the activation chamber. The transition from the first state to the second state may include closing the gap/sealing the annular space between the wellbore and the tubular.

In some embodiments, activating the apparatus may occur in response to expanding the sand screen. The activating of the deployment mechanism may be responsive to the activating of the activation chamber. The methodmay further include positioning the sand screen axially at a position in the wellbore for production. The methodmay further include prior to positioning, perforating and/or fracturing at the position (e.g. using a perforating gun or other tool string, which may then be removed to allow insertion of the tubular with sand screen(s)). The methodmay further include activating the sealing sleeve, and producing fluid from the formation to the surface. A pump may be used to draw fluid from the formation, through the sand screen, into the tubular bore, up the bore to the surface.

In some embodiments, expanding the sand screen may shear a shearable retaining element. Activating the apparatus may occur in response to shearing the shearable retaining element. Activating the apparatus may include axially shifting the flexible seal towards the sand screen (e.g. until the distal end of the flexible seal overlaps or contacts the end of the sand screen). The distal end of the apparatus may expand radially due to radial expansion of the sand screen (e.g. when overlapped). In the second state the distal end of the flexible seal may be wedged/sandwiched/held between the sand screen and the wellbore. The activating of the deployment mechanism may be responsive to the activating of the activation chamber shearing a pin of the deployment mechanism. The flexible seal may be biased towards the sand screen. The axial position of the flexible seal may be fixed by a shear pin, and the deployment mechanism may axially translate the flexible seal along the tubular and/or towards the sand screen, in response to the shearing of the pin. The axial translation may be caused by expansion of a spring between a metal base of the expansion mechanism and a slip of the expansion mechanism. The slip of the expansion mechanism may be affixed to the tubular. In an alternate embodiment, axial position of the flexible seal may be fixed by a J-slot mechanism whereby rotation of a component of the sand screen during activation may cause the J-slot mechanism to disengage thereby allowing axial translation of the flexible seal.