Field of the Invention
Embodiments of the present invention generally relate to an expandable liner. In particular, embodiments of the present invention relate to an expandable liner for a fracturing operation and methods of installing the liner.
Description of the Related Art
Expandable tubular liners have been used in existing wellbores as a repair liner or in open hole as a drilling liner. These liners can be just a few joints of pipe or can be more than one hundred joints. These joints may be 30 to 40 feet in length and are connected using a threaded connection. In some instances, the connection is a flush pipe connection, which has a similar wall thickness to the pipe wall thickness. This type of connection will be much weaker in tension, compression, or bending than the pipe body. For example, these expandable threaded connections may have tension and compression strengths that are about 50% of the pipe body.
In most repair or open hole applications, the tension or compression loads applied to the unexpanded connections is equal to the buoyed weight of the liner, plus any bending that might be present. In the case of the liner being set at bottom of the well, the liner would experience a compression load due to its own weight. After expansion, the liner may be fixed against the outer or parent casing or open hole by the expanded external rubber seals. In this position, applied internal or external pressure may cause the liner to shrink. However, because the liner is fixed and cannot shrink, the liner and its connections will experience additional tension loads as a consequence of the applied pressure.
Changes in wellbore conditions may increase the tension load on the expandable tubular connection. In addition to the tension load generated during expansion, there are at least three other potential sources of tension load. The tension loads from these sources are additive. If they occur, the total tension load can be enough to cause a connection to fracture. Even without connections, the tension can be enough to cause the pipe body itself to fail.
The first source of tension load is trapped expansion force due to the expanded liner being fixed to the outer casing by the compressed rubber seals in the annulus between the liner and the casing. Although these seals are desirable for blocking annulus communication, they are also the problem with the tension load build up. During expansion, the expansion force is locked into the liner and connections between the rubbers because the liner is expanded using a tension constraint. That is, as the expansion cone is being pulled through the liner while the bottom of the liner is fixed to the parent casing, all of the liner between the anchor and the cone is in tension. As the cone passes through each rubber seal, that tension in the liner is trapped and permanent.
A second source for load build up is thermal changes in the wellbore. For example, a wellbore fluid is initially at ambient temperature when it is at the surface. When it goes downhole, it cools the liner which is at the production zone temperature or bottom hole temperature, which may be at 300° F. As the liner is cooled by the wellbore fluid, the liner will tend to shrink in length. However, because the liner is trapped in place by the rubber seals and therefore, cannot shrink in length, the liner will experience a tension load build up that will remain until the temperature goes back up. Conversely, if the temperature is increased (e.g., steam injection), the liner would tend to grow in length. Because it cannot do so as a result of being fixed by the seals, the load experienced by the liner will be a compression load.
A third source for load build up is pressure changes inside the expanded liner. High pressure fluid inside the expanded liner may cause the liner to want to grow circumferentially, which would normally cause a liner to shrink in length. This is often called the Poisson Effect. Again, because the seals or anchors do not allow the liner to shrink in length, a tension load is generated.
Finally, if the liner is blocked off by a plug or ball situated at the bottom of the liner or other sections of the liner, high pressure in the liner may create a downward force (or end thrust) on the plug, thereby generating a tension load in the liner between the plug and the expanded seal that is located above and closest to the plug.
Because these loads are additive, the result is the potential to build up load beyond the connection's ability to resist the load. The total tension load can build up to more than three times the elastic limit or two times the ultimate strength (or point of fracture). These additional tension loads are constant along the length of the liner. Therefore, under these loads, a connection would break in between every pair of external rubber seals.
There is, therefore, a need for an expandable liner capable of handling changes in tension loads. There is also a need for a method of installing an expandable liner to withstand changes in tension loads caused by high pressures.
In one embodiment, an expandable liner is used to re-complete a wellbore for a re-fracturing operation. The expandable liner may be used to cover the old perforations and provide a larger bore after expansion. The larger bore allows more fracturing fluid to be supplied to the newly perforated zones than would be allowed by an unexpanded liner. In this respect, use of the expandable liner provides a more efficient fracturing operation. Also, the expandable liner may be configured to expand sufficiently to create a small annulus between itself and the parent casing. External seals may be included to provide true isolation.
In one embodiment, an expandable liner is used to re-complete a wellbore for a re-fracturing operation. The expandable liner may be used to cover the old perforations and provide a larger bore after expansion. The larger bore allows the new completion perforations and fracturing operation to be more easily achieved.
In another embodiment, a method of completing a wellbore includes providing an expandable liner having a first end and an anchor at a second end; setting the anchor; expanding the liner while allowing the first end to shrink or grow during expansion; and supplying a fluid into the liner while allowing the first end to shrink or grow in response to the changes in length of the liner. In one embodiment, the fluid is a high pressure fracturing fluid. In another embodiment, the changes in length are caused by changes in temperature.
In yet another embodiment, a method of completing a wellbore includes providing a coiled tubing having an anchor at a first end; setting the anchor; expanding the coiled tubing; perforating the coiled tubing; and supplying a fluid through the coiled tubing. In one embodiment, the method includes conveying the coiled tubing using a second, smaller diameter coiled tubing.
In yet another embodiment, an expandable liner includes an expandable tubular body; an expandable threaded portion welded to each end of the tubular body, wherein the threaded portion has a higher strength than the tubular body. In one embodiment, the expandable threaded end is strengthened using a heat treatment such as a localized quenching and tempering process. In another embodiment, the weld zone of the tubular body may be strengthened using the heat treatment
In yet another embodiment, an expandable liner includes an expandable tubular having a threaded connection; two sealing members disposed on the exterior of the expandable tubular and axially spaced apart; a groove formed in the interior of the expandable tubular and between the two sealing members, wherein the groove is configured to fail before the threaded connection fails. In another embodiment, the groove may be formed on the exterior and/or the interior of the expandable tubular.
In yet another embodiment, an expandable liner includes an expandable tubular having a threaded connection. The threaded connection may include a thread section configured to fail at a predetermined tension load; and a sealing section configured to maintain pressure sealing integrity of the threaded connection when thread section fails. The liner may also include two sealing members disposed on the exterior of the expandable tubular and on each side of the threaded connection. In one embodiment, the thread section includes a groove configured to fail at the predetermined tension load. In another embodiment, the thread section includes threads configured to fail at the predetermined tension load. In yet another embodiment, the sealing section includes a seal disposed between a pin portion and a box portion of the connection.
In one embodiment, the expandable liner may have a rib disposed around an outer diameter of the expandable tubular, wherein the rib is configured to form a seal with the outer tubular.
The patent or application file contains at least one drawing executed in color. Copies of this patent or patent application publication with color drawing(s) will be provided by the Office upon request and payment of the necessary fee.
So that the manner in which the above recited features of the present invention can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments of this invention and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments.
In one embodiment, an expandable liner is equipped with an anchor at one end. After setting the anchor, the other end of the liner is allowed to freely move. In this respect, the liner is allowed to shrink and grow in length, thereby preventing build up of tension load in the liner.
Exemplary expansion tools include a solid cone or an expandable cone. The expansion tool 30 may be mechanically or hydraulically actuated. In one embodiment, the expansion tool 30 may be a hydraulically pumped cone. During operation, the bottom of the liner is sealed so pressure can build up between the cone and the liner bottom. The expansion starts at the bottom of the liner and moves up toward the top of the liner. This type of expansion process does not require any anchors unless there is a desire to retain the liner in a certain location in the wellbore. If needed, one or more anchors may be used to anchor the liner. In another embodiment, the expansion tool 30 is a mechanical cone, as shown in
In operation, the expandable liner 100 may be used in a re-fracturing application of an existing wellbore 10. The wellbore 10 may be a gas well having a long horizontal completion section. Initially, the liner 100 is positioned in the wellbore 10 at the location of interest, as shown in
After expansion, the liner 100 may be perforated in one stage or multiple stages. During the first stage, a plug 41 is set at the bottom of the liner 100 and then the liner 100 is perforated. The liner 100 may be perforated with openings of any suitable shape. For example, the openings may be round or a small slit. An elongated opening such as a slit may facilitate fluid communication from the liner to the casing if the liner length changes during the fracturing operation. After perforation, fracturing fluid is supplied at high pressure and high volume. Because the liner 100 is free at one end, the liner 100 is allowed to shrink or expand in response to temperature changes in the liner 100, the internal pressure increase caused by the fracturing fluid, and the end thrust from the fracturing fluid acting on the plug. As a result, tension load on the liner 100 is not dramatically increased, thereby maintaining the tension load below the liner connection's load ratings during the fracturing process. After completing the fracturing process, a second plug (not shown) may be installed above the first zone, and the process is repeated to fracture another zone. In this manner, the wellbore may be re-completed using the expandable liner 100 and re-fractured using a high pressure, high volume fracturing fluid.
In another embodiment, the liner 100 may optionally include one or more sleeves attached to an outer surface of the liner. The sleeves may limit migration or communication of the fracturing fluid between fracturing sections. The sleeves are configured to barely come into contact with the outer casing during the expansion operation. As such, the sleeve will move with the liner. The sleeves may be made from metal, rubber, or combinations thereof. These sleeves could also be a combination of metal with rubber on the outside that could come into light contact with the outer casing without creating a meaningful amount of anchoring strength. In yet another embodiment, the sleeve may be a combination of metal on the inside and elastomer on the outside. The sleeve will seal against the wellbore upon expansion. However, the metal is configured to shear from the elastomer when a predetermined tension load is reached, such as just below the tension load limit of the expandable connection. After metal separates from the elastomer, the liner is allowed to shrink or grow in response to changes in the tension load.
In another embodiment, the optional step of squeezing the old perforations with cement may be performed before running the liner to maximize the sealing off of perforations. In yet another embodiment, the optional step of pumping a certain amount of cement behind the liner so that as the cone expanded the pipe, the liner is cemented in place.
In another embodiment, the casing can optionally be callipered to determine the average inner diameter of the casing. The measurement can be used to select a cone that will expand the liner as close as possible to the casing. This process will result in a minimal annulus between the liner and the casing. The annulus may get packed off by the fracturing sand during each fracture stage so that a sealing system between the expanded liner and the casing would not be necessary.
In another embodiment, a coiled tubing may be used as an expandable liner. Because the coiled tubing does not have any threaded connections, the coiled tubing eliminates the possibility of a threaded connection failure. Use of the coiled tubing as a liner may also significantly increase the burst pressure of the liner and may allow the deployment of the liner in one run.
In one embodiment, the cone 30 may be coupled to the bottom of the coiled tubing 200 prior to deployment. Other components necessary to expand the coiled tubing 200 may also be coupled to the coiled tubing 200. An exemplary cone launching assembly is described below with respect to
In the example shown in
At the well, the coiled tubing 200 is lowered into the wellbore 10. After the entire length is positioned in the wellbore, the coiled tubing 200 may be deployed by attaching a smaller size coiled tubing 220 as a running string. The size of the running string could be selected based on its tension strength. For example, a 2.000 in. O.D.×0.203 in. wall 100 ksi grade coiled tubing has a tension strength of about 126 kips. In another embodiment, a 2.625 in. O.D.×0.203 in. wall 100 ksi grade coiled tubing has a tension strength of about 170 kips. The running string 220 could be run inside the liner 200 and latch into the cone 30. The liner 200 would then be run to its proper location for expansion.
In one embodiment, a support member 230 is positioned above the liner 200 to prevent the liner 200 from moving up during expansion of the anchor 30. In one embodiment, a packer type system may be set at the liner top to prevent upward movement of the liner 200. The anchor 30 may be set against the casing 15 using pressure from the conveying string 220. Exemplary anchors 30 include an inflatable packer or a mechanical packer. After the anchor 110 has expanded, the coiled tubing unit at the surface may pull the cone 30 through the liner 200 to completely expand the liner 200.
After expansion, the liner 100 may be perforated in one stage or multiple stages as described above. In one embodiment, abrasive jet cutting may be used to form a hole or slot in the liner 200. This perforation process may include setting a packer 241 and then perforating the liner using an abrasive jet. After perforation, the liner 200 may be fractured as described above. Thereafter, the packer is unset and move up to the next zone of perforation to repeat the process.
In yet another embodiment, a second anchor may be provided at the top of the liner 200 to fix the liner in the casing after expansion. In another embodiment, a filter may be provided at the top of the liner to prevent sand movement but allow permeability through the annulus at the upper end of the liner 200. The filter may be selected from steel wool, screen, or combinations thereof.
In another embodiment, the casing can optionally be callipered to determine the average inner diameter of the casing. The measurement can be used to select a cone that will expand the liner as close as possible to the casing. This process will result in a minimal annulus between the liner and the casing. Instead of an elastomer coating, the annulus may get packed off by the fracturing sand during each fracture stage so that a sealing system between the expanded liner and the casing would not be necessary.
In another embodiment, a shaped cone may optionally be used that eliminated any high contact pressures between the cone and the liner. Optionally, a fluid, such as a fracturing fluid, may be treated to act as a lubricant to prevent galling the cone. In another embodiment, the cone may be configured to allow fluid inside of the liner to pass through the cone during expansion. For example, the fluid may traveled through one or more fluid bypass 222 in the cone. In another embodiment, lubrication by a porting system on the cone would decrease the probability of galling. In yet another example, the inner diameter of the liner may be coated to reduce friction during expansion.
Many advantages may be realized in using coiled tubing as the expandable liner. First, coiled tubing has no threaded connections so no significant weak point. Second, coiled tubing can be made in any size needed for a typical re-frac application, and can be made more than twice as strong as the pipe used in threaded expandable liners. Third, coiled tubing can be expanded by using an inner string that is also a coiled tubing. In this respect, the expansion is smooth and steady without the need to stop often to stand back two or three joints as the work string comes out of the well. Fourth, the coiled tubing may be electric resistance welded, which means the wall thickness is exactly the desired thickness and the outer diameter of the coiled tubing can be made exactly to the desired diameter. Fifth, coiled tubing is extremely high grade metallurgy because of its need to be fatigue resistant. Sixth, the expanded coiled tubing can withstand the high pressures and tension loads generated in a typical re-completion/re-frac operation without plastically deforming. Seventh, deployment of the expandable liner is much faster.
In another embodiment, the expandable liner may include a high strength connection. Exemplary stronger connections include connections with higher efficiency and connections made with a stronger material. For example, the stronger material may be P-110 grade versus a normal material such as L-80 grade.
The higher strength material can be welded to the tubular body using any suitable method. In one embodiment, the welding method may allow the higher grade ends to be welded to the tubular body without leaving rams horns at the welded sections, thereby eliminating the need to remove excess material from the outside and the inside. An exemplary welding technique is a clean electric induction welding method developed by Spinduction Weld Inc., located in Calgary, Canada.
It is believed that by increasing the strength of the tubular ends to P-110 strength, a gain of about 37.50% strength will be immediately created over the original L-80 material. The expanded material could also exhibit additional stronger properties due to the radial expansion, which in itself is actually cold working the expanded material and adding to its strength. This expansion process may cause the material strength of the P-110 material to gain additional strength, thereby resulting in a material that may exhibit 40% higher strength than that of the original L-80 material.
In operation, the higher strength connection may prevent the connections from parting in response to tension load changes. Thereafter, the expanded liner string can be perforated at optimal locations as desired.
In another embodiment, an expandable liner may include a tension failure groove that would allow the liner to fracture at a designated point in each frac stage section.
In another embodiment, the expandable liner 350 may include a shearable connection 360 that will seal internal pressure after the connection 360 shears. The connection 360 may be selectively placed to control the location of the failure.
As shown in
After expansion, the expansion tension load is trapped by the seals 375 engaged to the casing 15. During the fracturing operation, the tension load experienced by the connection 360 may reach above the predetermined tension load. When that occurs, the groove 365 will shear to allow separation of the connection 360 due to changes in length, as shown in
In another embodiment, as shown in
In one embodiment, each joint of liner 350 may be fixed at both ends to the casing 15, such as using external rubber seals 375 that are trapped between the liner 350 and the casing 15. The connection 360 in between the rubber seals 375 may be designed to fail. This configuration may keep the connection 360 opening to about 0.50 in.
If a section of expanded liner includes external rubber seals at each end, the shearable connection could be placed so that the fracture occurred in the best location. For example, if ten joints are connected in the liner section, the total shrinkage may be ten times, or 5 inches. Thus, the pieces of the connection that come apart would separate by the same amount. In this configuration, the seals would need to remain engaged after 5 inches of axial separation.
Referring back to
In another embodiment, the expandable liner may be coated with a sealing material on a substantial portion of its exterior surface, for example, at least 80% of its exterior surface. Upon expansion, the coating would fix the liner to the parent casing, thereby ensuring the perforations in the liner and the parent casing would remain aligned. Also, the coating function as anchors for the connections in the liner, thereby strengthening the connections' resistance to tension load buildup.
In another embodiment, the liner 500 may optionally include a plurality of seals 512, 513, 522, 532 disposed on the exterior of the joints and relatively close to the threaded connections. Even though only two seals 512, 513 are shown with joint 510, each joint 510, 520, 530 may be provided with any number of seals. In another embodiment, one or more seals may be positioned in close proximity to the anchor 508. In operation, the liner 500 would be fixed by the anchor 508 after expansion and the two seals 512, 513 of the joint 510 would prevent fluid communicate through the annulus between the joint 510 and the casing. In one embodiment, the seals 512, 513, 522, 532 may be made of rubber or elastomer. In another embodiment, the seals may be positioned 4 inches to 6 inches away from the threaded connection, or any suitable distance to sufficiently close off fluid communication after the connection fractures.
In another embodiment, an expandable liner may include a tension failure groove that would allow the liner to fracture at a designated point in each frac stage section. In one embodiment, the expandable liner 550 may include a shearable connection 560 that is selectively placed to control the location of the failure.
As shown in
In another embodiment, the thread connection 560 may optionally include one or more seals 575 from
After expansion and during the fracturing operation, the tension load experienced by the connection 560 may increase above the predetermined tension load. When that occurs, the groove 565 will shear box portion 552 and allow the connection 560 to separate. The pressure integrity is maintained by the seal 575 that remains engaged after the connection 560 fractures.
It is contemplated that features of any embodiment described herein may be used with any other embodiment. For example, each joint of liner 550 may be fixed at both ends to the casing 15, such as using the anchor 508 and/or the seals 512, 513 shown in
In operation, the inflatable expander 625 may be actuated to expand the temporary anchor 615. After expansion, the inflatable expander 625 is deflated. Thereafter, the conveying string 620 is pulled to pull the cone 30 through the liner 600. The temporary anchor 615 is configured to resist the expansion force, thereby allowing the cone 30 to be pulled through the first anchor 611. Initially, the cone 30 expands the first anchor 611 against the casing 15, then the cone 30 travels under the temporary anchor 615, and then the cone 30 expands the second anchor 612 against the casing 15. The first and second anchors 611, 612 prevent the temporary anchor 615 from being exposed to tension loads sufficient to cause failure of the temporary anchor 615.
In another embodiment, the liner 700 may include a casing anchor for securing the liner 700 against the casing 15 prior to expansion. As shown in
In operation, the packer 740 is pre-assembled with the cone 730 and liner 700 and lowered into the wellbore. Fluid is supplied down the work string 720 and out of the setting ports 747. The pressure in the chamber 748 increases sufficiently to shear the pins 745, 746 and cause the packer 740 to move up. As a result, the slips 742 and cone 743 compress and expand the sealing element 741 against the casing 15 and set the slips 742 against the casing 15, thereby securing the liner 700 to the casing 15. The work string 720 may now be pulled to pull the cone 730 through the liner 700 to expand the liner 700. The cone 730 will also expand any anchors on the liner 700. After expansion, the casing anchor will not be un-deployed and can be used as the first frac plug during the fracturing operation. Once the casing anchor is set, optional pressure ports may be opened so that the liner 700 can be expanded without fluid trapped inside.
In another embodiment, the liner 700 may include a bottom trip anchor for securing the liner 700 against the casing 15 prior to expansion. In one embodiment, the anchor may be expanded by a mechanically set packer, such as the packer shown in
In another embodiment, a wider rib 810 may provide more contact area and thus more barrier for preventing fluid communication of high pressure fluids between the expanded liner 800 and the parent casing 15. In yet another embodiment, a plurality of ribs 810 may be positioned adjacent each other on the liner 800 to prevent communication between the liner 800 and the parent casing 15. Any suitable number or ribs 810 may be used; such as 2, 3, 6, or 12 or more ribs. The plurality of ribs 810 may ensure at least one of the ribs form a seal in the event the inner surface of the parent casing 15 is not smooth or straight.
In one embodiment, the ribs may be arranged in any suitable configuration. For example, the ribs may form a polygonal shape such as a diamond shape.
In another embodiment, the weld beads may be arranged to form a labyrinth seal, as illustrated in
In another embodiment, the rib may be made of a material that is softer than the casing or the liner. Exemplary rib materials include brass, aluminum, or combinations thereof. In yet another embodiment, the rib material may be non-metallic so long as the rib material can effectively bond with the liner.
In another embodiment, the rib can be made of material that is harder than either the liner or the parent casing. In this respect, the harder rib may penetrate the surface of the parent casing during expansion. As a result, the harder rib may create a metal to metal seal as well as form a mechanical anchor between the liner and the parent casing. In one embodiment, post-weld shaping of the weld bead may be performed to enhance penetration and sealing contact. It is contemplated that the weld beads may be any suitable shape or arrangement.
In another embodiment, the weld beds may be applied using a welding technique or any suitable mechanism. For example, the weld beads may be applied using a flame spray or a sputtering technique.
In yet another embodiment, the rib may comprise a ring 835 that is welded to the outer surface of the liner 800, as illustrated in
It is contemplated any suitable number of weld beads 850 and elastomers 855 may be positioned on the liner 800 to provide an effective seal.
In another embodiment, the expandable liner may have a longitudinally corrugated configuration, which may be reformed into a round configuration downhole. Referring to
At step 2, an inner string 1020 such as an inner coiled tubing is deployed into the liner 1000, as shown in
At step 3, the liner 1000 is released from the rig and run into position using the inner string 1020, as shown in
At step 4, the casing anchor 1008 is set by supplying hydraulic fluid through the inner string 1020 to the casing anchor.
At step 5, the inner string 1020 is pulled up to pull the cone 1022 through the liner's bottom anchor.
At step 6, the inner string 1020 continues to be pulled until the liner 1000 is fully expanded, including the top anchor 1004.
At step 7, the perforating gun 1040 and the frac plug 1050 are deployed into the liner.
At step 8, fracturing 1070 is supplied through the liner 1000 and the casing to perform stage 1 of the fracturing operation.
It is contemplated features of each embodiment may optionally be used with another embodiment. For example, the shearable connection discussed with respect to the fifth embodiment may be included with the expandable liner of the sixth embodiment.
In another embodiment, a method of completing a wellbore includes providing a coiled tubing having an anchor at a first end; setting the anchor; expanding the coiled tubing; perforating the coiled tubing; and supplying a fluid through the coiled tubing.
In one or more of the embodiments described herein, the method includes conveying the coiled tubing using a second, smaller diameter coiled tubing.
In one or more of the embodiments described herein, the method includes using a packer type system to preventing axial movement of coiled tubing during setting of the anchor.
In one or more of the embodiments described herein, the coiled tubing is expanded by pulling an expander tool using a coiled tubing unit at the surface.
In one or more of the embodiments described herein, the coiled tubing includes an elastomeric outer coating.
In another embodiment, an expandable liner includes an expandable tubular body; and an expandable threaded portion welded to each end of the tubular body, wherein the threaded portion has a higher strength than the tubular body.
In one or more of the embodiments described herein, the expandable threaded end is strengthened using a localized quenching and tempering process.
In one or more of the embodiments described herein, the threaded portion comprises P-110 strength.
In another embodiment, an expandable liner includes an expandable tubular having a threaded connection, wherein the threaded connection includes a groove configured to fail at a predetermined tension load.
In one or more of the embodiments described herein, the groove is disposed on a box portion of the threaded connection.
In one or more of the embodiments described herein, the groove is disposed between the box portion and a pin portion of the threaded connection.
In one or more of the embodiments described herein, the groove is disposed outside of the threads of the threaded connection.
In one or more of the embodiments described herein, the liner includes a sealing element configured to maintain seal integrity of the threaded connection when the groove fails.
In one or more of the embodiments described herein, the sealing element is disposed between a pin portion and a box portion of the connection.
In one or more of the embodiments described herein, the liner includes two sealing members disposed on the exterior of the expandable tubular and on each side of the threaded connection.
In another embodiment, a method of completing a wellbore includes providing an expandable liner having a first anchor and a second anchor at a lower end; setting the second anchor to temporarily hold the liner against a casing; and expanding the liner and setting the first anchor using an expander cone.
In one or more of the embodiments described herein, the second anchor comprises a slotted tubular.
In one or more of the embodiments described herein, the second anchor comprises a thinner wall section than the liner.
In one or more of the embodiments described herein, the method setting a third anchor, wherein the second anchor is disposed between the first and second anchor.
In one or more of the embodiments described herein, the second anchor is set by hydraulic pressure.
In one or more of the embodiments described herein, the second anchor is attached to the liner using a sleeve.
In one or more of the embodiments described herein, the expander cone is initially housed in the sleeve.
In one or more of the embodiments described herein, the liner has a corrugated shape.
In one or more of the embodiments described herein, the method includes lowering the liner using a coiled tubing.
In one or more of the embodiments described herein, the second anchor is set by hydraulic pressure.
In one or more of the embodiments described herein, the method includes forming a perforation in the liner and supplying a fracturing fluid through the perforation.
In another embodiment, an expandable liner for use with an outer tubular includes an expandable tubular having a rib disposed around an outer diameter of the expandable tubular, wherein the rib is configured to form a seal with the outer tubular.
In one or more of the embodiments described herein, the rib comprises a weld bead.
In one or more of the embodiments described herein, the rib comprises a material that is softer than the expandable tubular.
In one or more of the embodiments described herein, a plurality of ribs are disposed on the expandable tubular.
In one or more of the embodiments described herein, the liner includes an elastomeric material.
In one or more of the embodiments described herein, the elastomeric material is disposed between two ribs.
In one or more of the embodiments described herein, the plurality of ribs form a labyrinth seal.
In one or more of the embodiments described herein, the at least one rib is positioned at an angle relative to a longitudinal axis of the expandable tubular.
In one or more of the embodiments described herein, the rib comprises a metal ring disposed around the expandable tubular, wherein one or more weld beads are used to attach the metal ring to the expandable tubular.
In one or more of the embodiments described herein, the liner includes an elastomeric material coupled to the metal ring.
In one or more of the embodiments described herein, the rib is raised about 0.1 inches to about 0.25 inches above an outer surface of the expandable tubular.
In one or more of the embodiments described herein, the rib comprises a material that is harder than the expandable tubular.
In one or more of the embodiments described herein, the rib comprises a non-metallic bead.
In one or more of the embodiments described herein, the rib is applied onto the expandable tubular using a mechanism selected the group consisting of a welding technique, a flame spray, a sputtering application, and combinations thereof.
In one or more of the embodiments described herein, the metal rib extends about 0.7 inches to about 1.3 inches along an axial length of the expandable tubular and is raised about 0.1 inches to about 0.25 inches above an outer surface of the expandable tubular.
In another embodiment, a method for use in a wellbore includes deploying an expandable tubular into the wellbore, the expandable tubular having a rib extending circumferentially around its outer surface; radially expanding the expandable tubular substantially against an inner wall of the wellbore; and substantially preventing fluid flow along an axial length of an interface between the radially expanded tubular and the inner wall of the wellbore, using the rib.
In one or more of the embodiments described herein, the rib comprises a weld bead.
In one or more of the embodiments described herein, the rib comprises a material that is softer than the expandable tubular.
In one or more of the embodiments described herein, a plurality of ribs are disposed on the expandable tubular.
In one or more of the embodiments described herein, the method includes disposing an elastomeric material adjacent one of the ribs.
In one or more of the embodiments described herein, the elastomeric material is disposed between two ribs.
In one or more of the embodiments described herein, the plurality of ribs form a labyrinth seal.
In one or more of the embodiments described herein, the method includes positioning at least one rib at an angle relative to a longitudinal axis of the expandable tubular.
In one or more of the embodiments described herein, the rib comprises a metal ring disposed around the expandable tubular, and attaching the to attach the metal ring to the expandable tubular using one or more weld beads.
In one or more of the embodiments described herein, the method includes coupling an elastomeric material to the metal ring.
In one or more of the embodiments described herein, the rib comprises a non-metallic bead.
In one or more of the embodiments described herein, the method includes disposing the rib onto the expandable tubular using a mechanism selected the group consisting of a welding technique, a flame spray, a sputtering application, and combinations thereof.
In another embodiment, an expandable liner includes an expandable tubular having a metal rib disposed around an outer diameter of the tubular, wherein the metal rib extends about 0.7 inches to about 1.3 inches along an axial length of the expandable tubular and raised about 0.1 inches to about 0.25 inches above an outer surface of the expandable tubular.
While the foregoing is directed to embodiments of the present invention, other and further embodiments of the invention may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.
This application claims benefit of U.S. Provisional Patent Application Ser. No. 61/843,198, filed Jul. 5, 2013; U.S. Provisional Patent Application Ser. No. 61/798,095, filed Mar. 15, 2013; U.S. Provisional Patent Application Ser. No. 61/693,669, filed Aug. 27, 2012; and Provisional Patent Application Ser. No. 61/677,383, filed Jul. 30, 2012, which applications are incorporated herein by reference in their entirety.
Number | Name | Date | Kind |
---|---|---|---|
7275601 | Cook | Oct 2007 | B2 |
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