EP2466064A1 - Casing anchor - Google Patents
Casing anchor Download PDFInfo
- Publication number
- EP2466064A1 EP2466064A1 EP10195570A EP10195570A EP2466064A1 EP 2466064 A1 EP2466064 A1 EP 2466064A1 EP 10195570 A EP10195570 A EP 10195570A EP 10195570 A EP10195570 A EP 10195570A EP 2466064 A1 EP2466064 A1 EP 2466064A1
- Authority
- EP
- European Patent Office
- Prior art keywords
- fixation
- tubular part
- fixation device
- fixation unit
- wellbore
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Withdrawn
Links
- 239000012530 fluid Substances 0.000 claims abstract description 38
- 238000000034 method Methods 0.000 claims abstract description 9
- 239000003999 initiator Substances 0.000 claims description 15
- 230000004888 barrier function Effects 0.000 claims description 14
- 230000007246 mechanism Effects 0.000 claims description 14
- 230000003213 activating effect Effects 0.000 claims description 2
- 230000015572 biosynthetic process Effects 0.000 description 10
- 239000000243 solution Substances 0.000 description 8
- 238000005452 bending Methods 0.000 description 7
- 239000003921 oil Substances 0.000 description 6
- 230000008901 benefit Effects 0.000 description 5
- 238000005553 drilling Methods 0.000 description 4
- 238000002347 injection Methods 0.000 description 4
- 239000007924 injection Substances 0.000 description 4
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- 239000007789 gas Substances 0.000 description 3
- 230000004913 activation Effects 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- 230000003247 decreasing effect Effects 0.000 description 2
- 238000007373 indentation Methods 0.000 description 2
- 230000000977 initiatory effect Effects 0.000 description 2
- 238000002955 isolation Methods 0.000 description 2
- 239000003345 natural gas Substances 0.000 description 2
- 238000007789 sealing Methods 0.000 description 2
- 238000003466 welding Methods 0.000 description 2
- 230000001010 compromised effect Effects 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 230000001976 improved effect Effects 0.000 description 1
- 230000001939 inductive effect Effects 0.000 description 1
- 239000011499 joint compound Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 230000002459 sustained effect Effects 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/10—Setting of casings, screens, liners or the like in wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
- E21B23/01—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
Definitions
- the present invention relates to a fixation device for securing a tubular in a wellbore, the fixation device comprising a tubular part, a fixation unit and a fluid passage. Furthermore, the invention relates to a downhole fixation system for securing a casing comprising a first end and a second end in a wellbore and to a method of permanently fixating a tubular part in a wellbore.
- Wells are completed in a variety of ways; some are made as openhole completions and some as casing completions.
- casing completing the casing is often cemented in the wellbore. This process is slow and requires a drilling rig at the surface, which is very expensive to use. It is desirable to be able to run in and secure the casing in a wellbore as fast as possible to reduce costs associated with renting expensive drilling rigs.
- WO 09/120759 describes a combined "Wellbore anchor and isolation system" comprising a tubular which may be attached to a tool string and lowered into a well.
- the tubular is provided with an anchor system comprising telescopic pistons which are extended in a radial direction by applying hydraulic pressure from within.
- Each of the telescopic pistons is comprised by three rings movable in relation to one another.
- An isolation element is disposed on the outside of the tubular, creating an isolated zone when engaged with the walls of a wellbore.
- a permanent fixation device for securing a tubular in a wellbore, the fixation device comprising:
- an advantage in this respect is that the casing may be rapidly secured in a wellbore during construction of an oil or gas well just pressurise the casing from within e.g. by means of a drill pipe. This reduces the time required to complete the well and thereby reduces the days in which an expensive drilling rig is needed. Further, it may be possible to secure the casing in the wellbore and deploy the annular barriers as part of the same working procedure and substantially simultaneously.
- the fixation unit may comprise a locking mechanism for permanently locking the fixation unit in the projected position.
- fixation unit does not collapse when the tubular part is no longer pressurised.
- the fixation unit may comprise a slotted liner having a plurality of members connecting the first end and the second end, the members being projected in a radial direction in relation to the tubular part when the ends of the fixation unit are moved towards each other.
- the slotted liner may surround the tubular part.
- each of the members may have a bend initiator, such as a transverse slot or fold, arranged substantially in a middle part of each member in the axial direction.
- a bend point of the members may be controlled and the bend initiated, thereby decreasing the amount of force used for initial bending.
- fixation unit may comprise two pivotally connected members.
- fixation unit may be arranged in a recess in the tubular part.
- An advantage in this respect is that the use of a fixation unit in combination with a casing does not affect the outer diameter of the casing.
- fixation unit may be arranged on the outside of the tubular part.
- fixation unit may be connected with the exterior surface of the tubular part.
- fixation unit may be arranged party inside the tubular part and extends through a slot in the exterior surface.
- one of the ends of the fixation unit may constitute a piston part comprising a surface adapted for receiving a force induced by a pressurised medium contained in the hollow interior of the tubular part.
- both ends of the fixation unit may constitute a piston part comprising a surface adapted for receiving a force induced by a pressurised medium contained in the hollow interior of the tubular.
- one of the ends of the fixation unit may be fixed in relation to the tubular part.
- both ends of the fixation unit may be movable in relation to the tubular part.
- the fixation device may comprise a plurality of fixation units.
- the plurality of fixation units may be distributed around a periphery of the tubular part.
- the plurality of fixation units may be distributed along the axial direction of the tubular part.
- the plurality of piston parts may be distributed around a periphery of the tubular.
- the plurality of piston parts may move one end of the fixation unit, e.g. the slotted liner.
- the plurality of fixation units distributed along the axial direction of the tubular part may be displaced relative to one another around the periphery of the tubular part.
- the plurality of fixation units may be evenly distributed in the axial direction and around the periphery of the tubular part.
- the present invention furthermore relates to a downhole fixation system for securing a casing comprising a first end and a second end in a wellbore, the fixation system comprising:
- the pressure creating device may be a downhole tool adapted to be arranged in fluid connection with the fluid passage.
- the pressure creating device may be a pump positioned on the outside of the wellbore.
- the pressure creating device may be connected with one end of a drill pipe and another end of the drill pipe is connected with a connecting unit which is sealingly connectable with the first end of the casing, and the second end of the casing being sealed.
- sealing means such as packers, may be arranged around the drill pipe on opposite sides of the fluid passage, whereby a defined section of the casing may be pressurised.
- the invention relates to a method of permanently fixating a tubular part in a wellbore, the method comprising the steps of:
- Figs. 1a and 1b show a fixation device 1 for positioning in a cased or an uncased wellbore.
- Fig. 1a shows the fixation device 1 in a relaxed position an unset condition
- Fig. 1b shows the fixation device in an activated position.
- the fixation device 1 comprises a tubular part 10 having a hollow interior 29.
- the tubular part 10 extends in an axial direction and has an exterior surface 11 defining a periphery of the fixation device 1.
- the fixation device 1 further comprises a fixation unit 20 projectable in a radial direction of the tubular part for fixating the fixation device in the wellbore by pressurizing the tubular from within.
- the fixation units 20 can be activated, whereby the fixation unit 20 projects in the radial direction in relation to the tubular part 10.
- the fixation device 1 is said to be in an activated or set condition, as shown in Fig. 1b .
- Each fixation unit 20 comprises a first end 21 and a second end 22 movable in relation to one another in an axial direction of the tubular part 10 when the tubular part is pressurized from within.
- the fixation units 20 are projected by moving the first end 21 a distance "d" towards the second end 22 which is fixed relative to the tubular part 10.
- the second end 22 could be moved towards the first end 21, or both ends could be moved towards each other.
- the fixation unit 20 is shown comprising a slotted liner 26 surrounding the tubular part 10.
- the slotted liner 26 has a first end 21 and a second end 22.
- the slotted liner 26 comprises a plurality of slots 25 forming members 23 connecting the first and second ends 21, 22.
- each of the members 23 has bend initiators 24.
- the bend initiators 24 are arranged substantially in a middle part of each member 23, but may alternatively be arranged in other positions along the length of the members 23.
- the bend initiators 24 are indentations, but may also be slots or folds or any other suitable initiators for initiating and/or controlling the bending of the members 23.
- Fig. 3 the members 23 of the slotted liner 26 are shown in its bent and projected position when the fixation device 1 is in the set or activated condition.
- the members 23 are projected by moving the first end 21 a distance "d" towards the second end 22, thereby inducing a force in the members and initiating the bending of each member, and thus the projection of the fixation unit 20.
- the members 23 may alternatively be projected by moving the second end 22 towards the first 21 end or by moving both ends 21, 22 towards each other.
- the tubular part 10 extends in the entire length of the fixation device 1, as indicated by the axial dotted lines shown in Fig. 2a .
- the fixation device 1 is hollow and thus, has a hollow cavity extending in the axial direction from one end to the other.
- the tubular part 10 is shown with protrusions 27 extending around the periphery of the tubular part 10.
- the protrusion 27 adjacent to the first end 21 of the fixation unit 20 has a hollow interior 28 into which the end 21 of the fixation unit 20 extends.
- the principle of protrusions 27 having a hollow interior 28 is illustrated in Fig. 4 .
- the first end 21 arranged inside the interior 28 of the protrusion 27 is formed as a piston part 30 acting in the hollow interior 28 functioning partly as a piston housing.
- the second end 22 is fixated in a recess formed by an edge 14 in the other protrusion 27, similar to what is shown in Fig. 6 .
- the second end 22 may be fixed to the tubular part 10 by welding or in any other way found suitable by a skilled person.
- the fixation device 1 When the fixation device 1 is activated by pressurising a fluid in the interior of the tubular part 10, the fluid is pushed through the fluid passage 28, thereby exerting a force on a surface 40 of the piston part 30. This force is directed into the members 23, whereby the members 23 is forced to project and the fixation unit 20 enters into the set position when the members presses against and partly into the wall of the borehole.
- Fig. 4 shows the fixation unit 20 comprising two pivotally connected members 31.
- One end of each member 31b is pivotally secured to the surface 11 of the tubular part 10, and the other end of each member 31a is pivotally connected to a piston part 30.
- the piston part 30 moves towards a surface 41 of interior 28, the angle between the members 31a and 31b is decreased, and the fixation unit 20 projects in the radial direction.
- Figs. 5a and 5b show a close-up of the first end 21 of the fixation unit 20.
- the first end 21 is positioned in the interior 28 of the protrusions 27, and seals 42 are arranged in grooves in the outer surface of the piston part 30 between the first end 21 and the inner surfaces of the interior 28.
- the seals 42 create a fluid-tight connection and prevent the fluid inside the hollow interior 29 from flowing into the annulus surrounding of the fixation device 1 when the tubular is pressurised from within and prevent the formation fluid from flowing into the tubular part 10 when the tubular part in no longer pressurised.
- each seal is arranged on a piston part 30, and in the solution shown in Figs. 2a-3 , the seals are arranged as circumferential seals on the inner and outer surfaces of the slotted liner 26.
- the fixation unit 20 further comprises a locking mechanism 50 for fixating the fixation unit 20 in the projected and set position when the fixation device 1 has been activated.
- Figs. 5a and 5b show two different examples of a locking mechanism 50 which may be used with any of the above-mentioned embodiments of the fixation device 1.
- Fig. 5a shows a locking mechanism 50.
- the exterior surface 11 of the tubular part 10 is serrated, threaded or tooth thereby forming a plurality of studs 51 and intermediate grooves.
- the studs 51 are configured for engagement with a tooth 52 positioned on the piston part 30. As the piston part 30 is moved towards the surface 41, the tooth 52 shifts from engagement with one stud 51 to engagement with the subsequent stud 51 until the fixation unit 20 has reached its set position.
- the locking mechanism 50 shown in Fig. 5b comprises a plurality of recesses 54 in the piston part 30.
- a spring-loaded stud 53 arranged in a recess in the tubular part 10 is pushed into engagement with the recesses 54 of the piston part 30.
- the spring-loaded stud 53 shifts from engagement with one recess 54 to engagement with the subsequent recess on the piston part 30.
- each piston part 30 comprises a locking mechanism 50, and in the solution shown in Figs. 2a-3 , the locking mechanism comprises several spring-loaded studs 53 arranged around the periphery of the tubular part 10 in connection with circumferential recesses 54 on the inner surface of the slotted liner 26.
- such a locking mechanism 50 may be designed in a number of other ways, e.g. as a mechanical locking mechanism, an electro-mechanical locking mechanism, etc.
- the fixation unit 20 is arranged in a recess 12 in the tubular part 10, as shown in Fig. 6 .
- the first end 21 of the fixation unit 20 is formed as a piston part 30 and is arranged between the tubular part 10 and an internal wall 13 thereof.
- the second end 22 is fixated by an edge 14 forming a recess.
- the second end 22 may be fixed to the tubular part 10 by for example welding.
- a number of bend initiators 24 are shown both on the outside and inside of the fixation units 20.
- the bend initiators 24 are arranged substantially in the middle part of the fixation unit 20, as described above, but also adjacent to the ends 21, 22 of the fixation unit 20.
- the bend initiators 24 are formed as indentations, but may also be slots or folds.
- a pivotally mounted piston part 30 may be used in combination with the slotted liner 26.
- the piston part 30 in the solution shown in Fig. 4 may also be integrated with the member 31a.
- the fixation unit 20 may be arranged in recesses in the tubular part 10 or on the outside of the tubular part in connection with protrusions 27 irrespective of whether the fixation unit comprises a slotted liner 26 or linked members 31a, 31b.
- the fixation unit 20 may also be constructed with both ends 21, 22 movable in relation to the tubular part 10.
- the fixation device 10 is activated by pressurising the hollow interior 29 of the tubular part 10.
- the hollow interior 29 may be pressurised by injecting a fluid, such as a fluid present in oil or gas wells downhole, drilling fluid or any other fluid supplied from the surface of the well.
- a fluid such as a fluid present in oil or gas wells downhole, drilling fluid or any other fluid supplied from the surface of the well.
- a fluid When a fluid is injected and pressurised, it flows into the fluid passage 28 and exerts a force on the surface 40 of the fixation unit 20.
- the magnitude of the force exerted on the piston part 30 depends on the surface area of the surface 40 and the pressure of the fluid inside the fixation device 1.
- the force exerted on the surface 40 must exceed the force exerted on the fixation unit 20 by the formation pressure in the annulus 70 surrounding the fixation device 1.
- the pressurised fluid moves the piston part 30 towards the surface 41 of the interior 28, away from its initial position.
- the piston part 30 can only move in one direction due to the locking mechanism 50 preventing backwards moving.
- the fixation unit 20 is gradually projected radially.
- the fixation unit 20 hits the walls of the wellbore, it will gradually dig into the formation and anchor the fixation device 1.
- the fixation unit 20 will dig more or less into the formation.
- the projection of the fixation unit 20 stops when the force exerted on the fixation unit 20 by for example formation sand or rock exceeds the force exerted by the pressurised fluid inside the fixation device 1. Alternatively, the projection stops when the piston part 30 has been pushed all the way to surface 41.
- the fixation device 1 may be used either alone or in combination with any device or structure to be secured in a wellbore.
- the fixation device 1 is used in combination with casing elements 64 and one or more annular barriers 63 in a casing assembly 80 or casing string.
- Casing elements 64, annular barriers 63 and one or more fixation devices 1 are assembled into a casing string at the surface, e.g. by screwing them together, and are lowered into the wellbore.
- the fixation device 1 is used in combination with an annular barrier 63
- the fixation device 1 is positioned right next to the annular barrier. This is done to secure in the best possible way that the position of the annular barrier 63 is fixed in the wellbore by the fixation device 1.
- the fixation device may also be used when fixating a liner hanger.
- fixation devices 1 When in the desired position, one or more fixation devices 1 is/are activated to secure the casing assembly 80 in the wellbore.
- the fixation units 20 of the one or more fixation devices 1 When activated, the fixation units 20 of the one or more fixation devices 1 project radially and engage with the walls of the wellbore.
- the fixation units 20 Depending on the material composition of the formation surrounding the wellbore, the degree of penetration of the fixation units 20 of the walls varies. This way, the fixation units 20 secure the fixation device 1 and attached casing elements 64 in the wellbore. Aside from securing the casing, the fixation device 1 contributes to centralising the casing elements 64 in the wellbore.
- the one or more fixation devices 1 may be activated by injecting a fluid in a number of different ways.
- the fluid may be injected locally in a defined section of the casing assembly 80 comprising one or more fluid passages 28.
- Local injection may be conducted by lowering a drill pipe 60 with circumferential packers into the casing assembly 80 and positioning the packers 61 on opposite sides of the one or more fluid passages 28.
- the fixing device 1 is pressurised and activated.
- Local injection may alternatively be done by a well tool comprising a pump. Such a tool may be lowered into the casing assembly 80 and connected directly to the fluid passage 28.
- the well tool may inject fluid already present in the well or fluid carried by the tool into the fluid passage 28.
- the entire casing assembly 80 may be pressurised, as illustrated in Fig. 7b .
- the casing assembly 80 is sealed in one end.
- the opposite end of the casing assembly 80 is connected to a drill pipe 60 via a connecting unit creating a seal between the drill pipe 60 and the casing assembly 80.
- the one or more fixation devices 1 is/are then activated by injecting a fluid into the entire casing assembly 80.
- Such injection of fluid may also be used to simultaneously activate annular barriers 63 and thus expand expandable sleeves of the barriers.
- the fixation device 1 may be a permanent fixation device.
- permanent is meant that the projection of the fixation unit 20 cannot be reversed without destroying the functionality of the fixation device 1.
- the fixation device 1 can thus not be reused after having been activated or set for the first time.
- the fixation unit is locked in the set position.
- the fixation unit 20 has been set and the fixation device 1 is in the activated condition, the pressure inside the fixation device does not have to be sustained.
- the fixation device 1 is permanently locked in the activated condition.
- fluid or well fluid any kind of fluid that may be present in oil or gas wells downhole, such as natural gas, oil, oil mud, crude oil, water, etc.
- a casing any kind of pipe, tubing, tubular, liner, string etc. used downhole in relation to oil or natural gas production.
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- Engineering & Computer Science (AREA)
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- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Piles And Underground Anchors (AREA)
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Abstract
The present invention relates to a fixation device for securing a tubular in a wellbore, the fixation device comprising a tubular part, a fixation unit and a fluid passage. Furthermore, the invention relates to a downhole fixation system for securing a casing comprising a first end and a second end in a wellbore and to a method of permanently fixating a tubular part in a wellbore.
Description
- The present invention relates to a fixation device for securing a tubular in a wellbore, the fixation device comprising a tubular part, a fixation unit and a fluid passage. Furthermore, the invention relates to a downhole fixation system for securing a casing comprising a first end and a second end in a wellbore and to a method of permanently fixating a tubular part in a wellbore.
- Wells are completed in a variety of ways; some are made as openhole completions and some as casing completions. In casing completing, the casing is often cemented in the wellbore. This process is slow and requires a drilling rig at the surface, which is very expensive to use. It is desirable to be able to run in and secure the casing in a wellbore as fast as possible to reduce costs associated with renting expensive drilling rigs.
- An alternative to cemented casings is disclosed in
WO 09/120759 - When the casing has been positioned in a wellbore, it is sometimes important that it does not move and that the exact position is maintained. This is especially important when annular barriers are used to seal off a section of the wellbore. If the casing is moved following the deployment of the annular barriers, the sealing characteristics of the annular barriers may be compromised. The deployment of the annular barriers may in itself contribute to a movement of the casing in the well.
- It is an object of the present invention to wholly or partly overcome the above disadvantages and drawbacks of the prior art. More specifically, it is an object to provide an improved fixation device, system and method for securing casing in a wellbore downhole.
- The above objects, together with numerous other objects, advantages, and features, which will become evident from the below description, are accomplished by a solution in accordance with the present invention by a permanent fixation device for securing a tubular in a wellbore, the fixation device comprising:
- a tubular part extending in an axial direction, the tubular part having an exterior surface and a hollow interior,
- a fixation unit arranged at the exterior surface of the tubular part, the fixation unit having a first end and a second end movable in relation to one another in the axial direction, and
- a fluid passage extending from the hollow interior to one of the ends of the fixation unit;
wherein at least one of the ends of the fixation unit is moved when the tubular part is pressurised from within, forcing the fixation unit to project in a radial direction in relation to the tubular part, whereby the fixation unit enters into a projected position. - An advantage in this respect is that the casing may be rapidly secured in a wellbore during construction of an oil or gas well just pressurise the casing from within e.g. by means of a drill pipe. This reduces the time required to complete the well and thereby reduces the days in which an expensive drilling rig is needed. Further, it may be possible to secure the casing in the wellbore and deploy the annular barriers as part of the same working procedure and substantially simultaneously.
- In an embodiment of the invention, the fixation unit may comprise a locking mechanism for permanently locking the fixation unit in the projected position.
- An advantage in this respect is that the fixation unit does not collapse when the tubular part is no longer pressurised.
- Furthermore, the fixation unit may comprise a slotted liner having a plurality of members connecting the first end and the second end, the members being projected in a radial direction in relation to the tubular part when the ends of the fixation unit are moved towards each other.
- This creates a simple and reliable construction with a plurality of members engaging the formation.
- The slotted liner may surround the tubular part.
- Moreover, each of the members may have a bend initiator, such as a transverse slot or fold, arranged substantially in a middle part of each member in the axial direction.
- By having a bend initiator, a bend point of the members may be controlled and the bend initiated, thereby decreasing the amount of force used for initial bending.
- Furthermore, the fixation unit may comprise two pivotally connected members.
- Additionally, the fixation unit may be arranged in a recess in the tubular part.
- An advantage in this respect is that the use of a fixation unit in combination with a casing does not affect the outer diameter of the casing.
- Also, the fixation unit may be arranged on the outside of the tubular part.
- In addition, the fixation unit may be connected with the exterior surface of the tubular part.
- Moreover, the fixation unit may be arranged party inside the tubular part and extends through a slot in the exterior surface.
- In an embodiment, one of the ends of the fixation unit may constitute a piston part comprising a surface adapted for receiving a force induced by a pressurised medium contained in the hollow interior of the tubular part.
- In another embodiment, both ends of the fixation unit may constitute a piston part comprising a surface adapted for receiving a force induced by a pressurised medium contained in the hollow interior of the tubular.
- Moreover, one of the ends of the fixation unit may be fixed in relation to the tubular part.
- In addition, both ends of the fixation unit may be movable in relation to the tubular part.
- This may reduce the axial movement of the device during activation of the fixation unit and facilitate the engagement of the fixation unit with the formation.
- In an embodiment, the fixation device may comprise a plurality of fixation units.
- The plurality of fixation units may be distributed around a periphery of the tubular part.
- Moreover, the plurality of fixation units may be distributed along the axial direction of the tubular part.
- Furthermore, the plurality of piston parts may be distributed around a periphery of the tubular.
- Additionally, the plurality of piston parts may move one end of the fixation unit, e.g. the slotted liner.
- Also, the plurality of fixation units distributed along the axial direction of the tubular part may be displaced relative to one another around the periphery of the tubular part.
- In addition, the plurality of fixation units may be evenly distributed in the axial direction and around the periphery of the tubular part.
- The present invention furthermore relates to a downhole fixation system for securing a casing comprising a first end and a second end in a wellbore, the fixation system comprising:
- the fixation device described above,
- a casing connected with the tubular of the fixation device,
- one or more annular barriers comprising a tubular part and a surrounding expandable sleeve, and
- a pressure creating device fluidly connected to the hollow interior of the tubular part of the fixation device.
- In an embodiment, the pressure creating device may be a downhole tool adapted to be arranged in fluid connection with the fluid passage.
- Furthermore, the pressure creating device may be a pump positioned on the outside of the wellbore.
- Moreover, the pressure creating device may be connected with one end of a drill pipe and another end of the drill pipe is connected with a connecting unit which is sealingly connectable with the first end of the casing, and the second end of the casing being sealed.
- In addition, sealing means, such as packers, may be arranged around the drill pipe on opposite sides of the fluid passage, whereby a defined section of the casing may be pressurised.
- Finally, the invention relates to a method of permanently fixating a tubular part in a wellbore, the method comprising the steps of:
- connecting the permanent fixation device described above with one or more casing elements,
- positioning the fixation device at a predetermined location in a wellbore,
and - activating the fixation unit by applying a hydraulic pressure to one of the ends of the fixation unit, whereby the fixation unit engages with the sides of the wellbore.
- The invention and its many advantages will be described in more detail below with reference to the accompanying schematic drawings, which for the purpose of illustration show some non-limiting embodiments and in which
-
Fig. 1a shows a view of a fixation device in an unset condition according to the invention, -
Fig. 1b shows a view of the fixation device shown inFig. 1a in a set condition, -
Fig. 2a shows one embodiment of a fixation device comprising a slotted liner, -
Fig. 2b shows a cross-sectional view across line a-a of the fixation device shown inFig. 2a , -
Fig. 2c shows a view of a member having a bend initiator, -
Fig. 3 shows a view of the embodiment shown inFig. 2a in the set condition, -
Fig. 4 shows a view of one embodiment of a fixation unit in an intermediate position, -
Fig. 5a shows a view of a locking mechanism, -
Fig. 5b shows another embodiment of the locking mechanism, -
Fig. 6 shows an alternative embodiment of the permanent fixation device with the fixation unit arranged in a recess in the tubular part, -
Fig. 7a shows a schematic drawing of a wellbore with the permanent fixation device arrange in connection with other casing elements and a pressure creating device deployed in the well, -
Fig. 7b shows a schematic drawing of a wellbore with an alternative pressure creating device deployed in the well, - All the figures are highly schematic and not necessarily to scale, and they show only those parts which are necessary in order to elucidate the invention, other parts being omitted or merely suggested.
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Figs. 1a and 1b show afixation device 1 for positioning in a cased or an uncased wellbore.Fig. 1a shows thefixation device 1 in a relaxed position an unset condition, whereasFig. 1b shows the fixation device in an activated position. InFigs. 1a and 1b , thefixation device 1 comprises atubular part 10 having ahollow interior 29. Thetubular part 10 extends in an axial direction and has anexterior surface 11 defining a periphery of thefixation device 1. Thefixation device 1 further comprises afixation unit 20 projectable in a radial direction of the tubular part for fixating the fixation device in the wellbore by pressurizing the tubular from within. - When the
fixation device 1 is in the relaxed position, thefixation units 20 can be activated, whereby thefixation unit 20 projects in the radial direction in relation to thetubular part 10. When thefixation unit 20 is projected so that the fixation units are fastened or anchored in the wall of the wellbore, thefixation device 1 is said to be in an activated or set condition, as shown inFig. 1b . - Each
fixation unit 20 comprises afirst end 21 and asecond end 22 movable in relation to one another in an axial direction of thetubular part 10 when the tubular part is pressurized from within. During activation of thefixation device 1, thefixation units 20 are projected by moving the first end 21 a distance "d" towards thesecond end 22 which is fixed relative to thetubular part 10. As an alternative to the embodiments shown inFigs. 1a and 1b , thesecond end 22 could be moved towards thefirst end 21, or both ends could be moved towards each other. - In
Fig. 2a , thefixation unit 20 is shown comprising a slottedliner 26 surrounding thetubular part 10. The slottedliner 26 has afirst end 21 and asecond end 22. The slottedliner 26 comprises a plurality ofslots 25 formingmembers 23 connecting the first and second ends 21, 22. - As shown in
Figs. 2b and 2c , each of themembers 23 hasbend initiators 24. The bend initiators 24 are arranged substantially in a middle part of eachmember 23, but may alternatively be arranged in other positions along the length of themembers 23. InFig. 2c , thebend initiators 24 are indentations, but may also be slots or folds or any other suitable initiators for initiating and/or controlling the bending of themembers 23. By havingbend initiators 24 the bending of themembers 23 is controlled to occur at the position of the bend initiators and the force required to initiate the bending is substantially reduced. - In
Fig. 3 , themembers 23 of the slottedliner 26 are shown in its bent and projected position when thefixation device 1 is in the set or activated condition. Themembers 23 are projected by moving the first end 21 a distance "d" towards thesecond end 22, thereby inducing a force in the members and initiating the bending of each member, and thus the projection of thefixation unit 20. Themembers 23 may alternatively be projected by moving thesecond end 22 towards the first 21 end or by moving both ends 21, 22 towards each other. - The
tubular part 10 extends in the entire length of thefixation device 1, as indicated by the axial dotted lines shown inFig. 2a . Thefixation device 1 is hollow and thus, has a hollow cavity extending in the axial direction from one end to the other. InFigs. 2a and3 , thetubular part 10 is shown withprotrusions 27 extending around the periphery of thetubular part 10. Theprotrusion 27 adjacent to thefirst end 21 of thefixation unit 20 has ahollow interior 28 into which theend 21 of thefixation unit 20 extends. The principle ofprotrusions 27 having ahollow interior 28 is illustrated inFig. 4 . Thefirst end 21 arranged inside the interior 28 of theprotrusion 27 is formed as apiston part 30 acting in thehollow interior 28 functioning partly as a piston housing. Thesecond end 22 is fixated in a recess formed by anedge 14 in theother protrusion 27, similar to what is shown inFig. 6 . Alternatively, thesecond end 22 may be fixed to thetubular part 10 by welding or in any other way found suitable by a skilled person. - The interior 28 of the
protrusion 27, wherein thepiston part 30 offirst end 21 of thefixation unit 20 is arranged, constitutes afluid passage 28 between thehollow interior 29 of thetubular part 10 and thepiston part 30 of thefirst end 21. When thefixation device 1 is activated by pressurising a fluid in the interior of thetubular part 10, the fluid is pushed through thefluid passage 28, thereby exerting a force on asurface 40 of thepiston part 30. This force is directed into themembers 23, whereby themembers 23 is forced to project and thefixation unit 20 enters into the set position when the members presses against and partly into the wall of the borehole. -
Fig. 4 shows thefixation unit 20 comprising two pivotally connected members 31. One end of eachmember 31b is pivotally secured to thesurface 11 of thetubular part 10, and the other end of eachmember 31a is pivotally connected to apiston part 30. When thepiston part 30 moves towards asurface 41 ofinterior 28, the angle between themembers fixation unit 20 projects in the radial direction. -
Figs. 5a and 5b show a close-up of thefirst end 21 of thefixation unit 20. Thefirst end 21 is positioned in theinterior 28 of theprotrusions 27, and seals 42 are arranged in grooves in the outer surface of thepiston part 30 between thefirst end 21 and the inner surfaces of the interior 28. Theseals 42 create a fluid-tight connection and prevent the fluid inside the hollow interior 29 from flowing into the annulus surrounding of thefixation device 1 when the tubular is pressurised from within and prevent the formation fluid from flowing into thetubular part 10 when the tubular part in no longer pressurised. In the solution shown inFigs. 1a and 1b , each seal is arranged on apiston part 30, and in the solution shown inFigs. 2a-3 , the seals are arranged as circumferential seals on the inner and outer surfaces of the slottedliner 26. - The
fixation unit 20 further comprises alocking mechanism 50 for fixating thefixation unit 20 in the projected and set position when thefixation device 1 has been activated.Figs. 5a and 5b show two different examples of alocking mechanism 50 which may be used with any of the above-mentioned embodiments of thefixation device 1. -
Fig. 5a shows alocking mechanism 50. Theexterior surface 11 of thetubular part 10 is serrated, threaded or tooth thereby forming a plurality ofstuds 51 and intermediate grooves. Thestuds 51 are configured for engagement with atooth 52 positioned on thepiston part 30. As thepiston part 30 is moved towards thesurface 41, thetooth 52 shifts from engagement with onestud 51 to engagement with thesubsequent stud 51 until thefixation unit 20 has reached its set position. - The
locking mechanism 50 shown inFig. 5b comprises a plurality ofrecesses 54 in thepiston part 30. A spring-loadedstud 53 arranged in a recess in thetubular part 10 is pushed into engagement with therecesses 54 of thepiston part 30. As thepiston part 30 is moved towards thesurface 41, the spring-loadedstud 53 shifts from engagement with onerecess 54 to engagement with the subsequent recess on thepiston part 30. - In the solution shown in
Figs. 1a and 1b , eachpiston part 30 comprises alocking mechanism 50, and in the solution shown inFigs. 2a-3 , the locking mechanism comprises several spring-loadedstuds 53 arranged around the periphery of thetubular part 10 in connection withcircumferential recesses 54 on the inner surface of the slottedliner 26. - It will be evident for a person skilled in the art that such a
locking mechanism 50 may be designed in a number of other ways, e.g. as a mechanical locking mechanism, an electro-mechanical locking mechanism, etc. - In the solution shown in
Figs. 1a and 1b , thefixation unit 20 is arranged in arecess 12 in thetubular part 10, as shown inFig. 6 . Thefirst end 21 of thefixation unit 20 is formed as apiston part 30 and is arranged between thetubular part 10 and aninternal wall 13 thereof. Thesecond end 22 is fixated by anedge 14 forming a recess. Alternatively, thesecond end 22 may be fixed to thetubular part 10 by for example welding. Still referring toFig. 6 , a number ofbend initiators 24 are shown both on the outside and inside of thefixation units 20. The bend initiators 24 are arranged substantially in the middle part of thefixation unit 20, as described above, but also adjacent to theends fixation unit 20. The bend initiators 24 are formed as indentations, but may also be slots or folds. By havingbend initiators 24 the bending of themembers 23 is controlled to occur at the position of the bend initiators and the force required to initiate the bending is substantially reduced. - It will be evident for a person skilled in the art that several other solutions may be conceived by combining the above described embodiments. For example, a pivotally mounted
piston part 30 may be used in combination with the slottedliner 26. Thepiston part 30 in the solution shown inFig. 4 may also be integrated with themember 31a. Further, thefixation unit 20 may be arranged in recesses in thetubular part 10 or on the outside of the tubular part in connection withprotrusions 27 irrespective of whether the fixation unit comprises a slottedliner 26 or linkedmembers fixation unit 20 may also be constructed with both ends 21, 22 movable in relation to thetubular part 10. - Having described the structural features, the functionality and use will be described in further detail below.
- Starting from the unset condition, e.g. as shown in
Fig. 2a , thefixation device 10 is activated by pressurising thehollow interior 29 of thetubular part 10. Thehollow interior 29 may be pressurised by injecting a fluid, such as a fluid present in oil or gas wells downhole, drilling fluid or any other fluid supplied from the surface of the well. When a fluid is injected and pressurised, it flows into thefluid passage 28 and exerts a force on thesurface 40 of thefixation unit 20. The magnitude of the force exerted on thepiston part 30 depends on the surface area of thesurface 40 and the pressure of the fluid inside thefixation device 1. To project thefixation unit 20, the force exerted on thesurface 40 must exceed the force exerted on thefixation unit 20 by the formation pressure in the annulus 70 surrounding thefixation device 1. - In
Fig. 5a , the pressurised fluid moves thepiston part 30 towards thesurface 41 of the interior 28, away from its initial position. Thepiston part 30 can only move in one direction due to thelocking mechanism 50 preventing backwards moving. As thepiston part 30 moves, thefixation unit 20 is gradually projected radially. When thefixation unit 20 hits the walls of the wellbore, it will gradually dig into the formation and anchor thefixation device 1. Depending on the characteristics of the formation, thefixation unit 20 will dig more or less into the formation. The projection of thefixation unit 20 stops when the force exerted on thefixation unit 20 by for example formation sand or rock exceeds the force exerted by the pressurised fluid inside thefixation device 1. Alternatively, the projection stops when thepiston part 30 has been pushed all the way to surface 41. - The
fixation device 1 may be used either alone or in combination with any device or structure to be secured in a wellbore. Now referring toFig. 7a , thefixation device 1 is used in combination withcasing elements 64 and one or moreannular barriers 63 in acasing assembly 80 or casing string.Casing elements 64,annular barriers 63 and one ormore fixation devices 1 are assembled into a casing string at the surface, e.g. by screwing them together, and are lowered into the wellbore. When thefixation device 1 is used in combination with anannular barrier 63, thefixation device 1 is positioned right next to the annular barrier. This is done to secure in the best possible way that the position of theannular barrier 63 is fixed in the wellbore by thefixation device 1. The fixation device may also be used when fixating a liner hanger. - When in the desired position, one or
more fixation devices 1 is/are activated to secure thecasing assembly 80 in the wellbore. When activated, thefixation units 20 of the one ormore fixation devices 1 project radially and engage with the walls of the wellbore. Depending on the material composition of the formation surrounding the wellbore, the degree of penetration of thefixation units 20 of the walls varies. This way, thefixation units 20 secure thefixation device 1 and attachedcasing elements 64 in the wellbore. Aside from securing the casing, thefixation device 1 contributes to centralising thecasing elements 64 in the wellbore. - The one or
more fixation devices 1 may be activated by injecting a fluid in a number of different ways. The fluid may be injected locally in a defined section of thecasing assembly 80 comprising one or morefluid passages 28. Local injection may be conducted by lowering adrill pipe 60 with circumferential packers into thecasing assembly 80 and positioning thepackers 61 on opposite sides of the one or morefluid passages 28. By injecting a fluid through thedrill pipe 60 and into thehollow interior 29 between thepackers 61, the fixingdevice 1 is pressurised and activated. Local injection may alternatively be done by a well tool comprising a pump. Such a tool may be lowered into thecasing assembly 80 and connected directly to thefluid passage 28. The well tool may inject fluid already present in the well or fluid carried by the tool into thefluid passage 28. - As an alternative to local injection, the
entire casing assembly 80 may be pressurised, as illustrated inFig. 7b . In this embodiment, thecasing assembly 80 is sealed in one end. The opposite end of thecasing assembly 80 is connected to adrill pipe 60 via a connecting unit creating a seal between thedrill pipe 60 and thecasing assembly 80. The one ormore fixation devices 1 is/are then activated by injecting a fluid into theentire casing assembly 80. Such injection of fluid may also be used to simultaneously activateannular barriers 63 and thus expand expandable sleeves of the barriers. - The
fixation device 1 may be a permanent fixation device. By permanent is meant that the projection of thefixation unit 20 cannot be reversed without destroying the functionality of thefixation device 1. Thefixation device 1 can thus not be reused after having been activated or set for the first time. When thefixation device 1 has been activated and thefixation unit 20 has dug into the formation, the fixation unit is locked in the set position. When thefixation unit 20 has been set and thefixation device 1 is in the activated condition, the pressure inside the fixation device does not have to be sustained. Thefixation device 1 is permanently locked in the activated condition. - By fluid or well fluid is meant any kind of fluid that may be present in oil or gas wells downhole, such as natural gas, oil, oil mud, crude oil, water, etc. By a casing is meant any kind of pipe, tubing, tubular, liner, string etc. used downhole in relation to oil or natural gas production.
- Although the invention has been described in the above in connection with preferred embodiments of the invention, it will be evident for a person skilled in the art that several modifications are conceivable without departing from the invention as defined by the following claims.
Claims (16)
- A fixation device (1) for securing a tubular in a wellbore, the fixation device (1) comprising:- a tubular part (10) extending in an axial direction, the tubular part (10) having an exterior surface (11) and a hollow interior (29),- a fixation unit (20) arranged at the exterior surface (11) of the tubular part (10), the fixation unit having a first end (21) and a second end (22) movable in relation to one another in the axial direction, and- a fluid passage (28) extending from the hollow interior to one of the ends (21, 22) of the fixation unit;
wherein at least one of the ends (21, 22) of the fixation unit is moved when the tubular part is pressurised from within, forcing the fixation unit to project in a radial direction in relation to the tubular part, whereby the fixation unit enters into a projected position. - A fixation device according to claim 1, wherein the fixation unit comprises a locking mechanism (50) for permanently locking the fixation unit in the projected position.
- A fixation device according to claim 1 or 2, wherein the fixation unit comprises a slotted liner (26) having a plurality of members (23) connecting the first end and the second end, the members being projected in a radial direction in relation to the tubular part when the ends of the fixation unit are moved towards each other.
- A fixation device according to claim 3, wherein the slotted liner surrounds the tubular part.
- A fixation device according to claim 3 or 4, wherein each of the members has a bend initiator (24), such as a transverse slot or fold, arranged substantially in a middle part of each member in the axial direction.
- A fixation device according to claim 1 or 2, wherein the fixation unit comprises two pivotally connected members (31).
- A fixation device according to any of the preceding claims, wherein the fixation unit is arranged in a recess in the tubular part.
- A fixation device according to any of the preceding claims, wherein one of the ends of the fixation unit constitutes a piston part (30) comprising a surface (40) adapted for receiving a force induced by a pressurised medium contained in the hollow interior of the tubular part.
- A fixation device according to any of the preceding claims, wherein both ends of the fixation unit constitute a piston part comprising a surface adapted for receiving a force induced by a pressurised medium contained in the hollow interior of the tubular.]
- A fixation device according to any of the preceding claims, wherein one of the ends of the fixation unit is fixed in relation to the tubular part.
- A fixation device according to any of the preceding claims, wherein both ends of the fixation unit are movable in relation to the tubular part.
- A fixation device according to any of the preceding claims, wherein the fixation device comprises a plurality of fixation units.
- A downhole fixation system for securing a casing comprising a first end and a second end in a wellbore, the fixation system comprising:- the fixation device according to any of the claims 1-12,- a casing connected with the tubular of the fixation device,- one or more annular barriers comprising a tubular part and a surrounding expandable sleeve, and- a pressure creating device fluidly connected to the hollow interior of the tubular part of the fixation device.
- A downhole fixation system according to claim 12, wherein the pressure creating device is a downhole tool adapted to be arranged in fluid connection with the fluid passage.
- A downhole fixation system according to claim 12, wherein the pressure creating device is a pump positioned outside the wellbore.
- A method of permanently fixating a tubular part in a wellbore, the method comprising the steps of:- connecting the permanent fixation device according to any of the claims 1-11 with one or more casing elements,- positioning the fixation device at a predetermined location in a wellbore,
and- activating the fixation unit by applying a hydraulic pressure to one of the ends of the fixation unit, whereby the fixation unit engages with the sides of the wellbore.
Priority Applications (10)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EP10195570A EP2466064A1 (en) | 2010-12-17 | 2010-12-17 | Casing anchor |
US13/994,856 US20140102719A1 (en) | 2010-12-17 | 2011-12-16 | Rock anchor |
PCT/EP2011/073100 WO2012080486A1 (en) | 2010-12-17 | 2011-12-16 | Rock anchor |
CA2821840A CA2821840A1 (en) | 2010-12-17 | 2011-12-16 | Rock anchor |
CN2011800607752A CN103261578A (en) | 2010-12-17 | 2011-12-16 | Rock anchor |
EP11807670.2A EP2652257A1 (en) | 2010-12-17 | 2011-12-16 | Rock anchor |
AU2011343204A AU2011343204A1 (en) | 2010-12-17 | 2011-12-16 | Rock anchor |
BR112013014561A BR112013014561A2 (en) | 2010-12-17 | 2011-12-16 | rock anchor |
RU2013132394/03A RU2013132394A (en) | 2010-12-17 | 2011-12-16 | ANCHOR FASTENING IN ROCK ROCK |
MX2013006624A MX2013006624A (en) | 2010-12-17 | 2011-12-16 | Rock anchor. |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EP10195570A EP2466064A1 (en) | 2010-12-17 | 2010-12-17 | Casing anchor |
Publications (1)
Publication Number | Publication Date |
---|---|
EP2466064A1 true EP2466064A1 (en) | 2012-06-20 |
Family
ID=44041711
Family Applications (2)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP10195570A Withdrawn EP2466064A1 (en) | 2010-12-17 | 2010-12-17 | Casing anchor |
EP11807670.2A Withdrawn EP2652257A1 (en) | 2010-12-17 | 2011-12-16 | Rock anchor |
Family Applications After (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP11807670.2A Withdrawn EP2652257A1 (en) | 2010-12-17 | 2011-12-16 | Rock anchor |
Country Status (9)
Country | Link |
---|---|
US (1) | US20140102719A1 (en) |
EP (2) | EP2466064A1 (en) |
CN (1) | CN103261578A (en) |
AU (1) | AU2011343204A1 (en) |
BR (1) | BR112013014561A2 (en) |
CA (1) | CA2821840A1 (en) |
MX (1) | MX2013006624A (en) |
RU (1) | RU2013132394A (en) |
WO (1) | WO2012080486A1 (en) |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN104755700A (en) * | 2012-10-31 | 2015-07-01 | 韦尔泰克有限公司 | Barrier testing method |
WO2022260685A1 (en) * | 2021-06-07 | 2022-12-15 | Halliburton Energy Services, Inc. | Collapsible shell packer for metal-to-metal sealing |
Families Citing this family (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CA3036786A1 (en) | 2015-09-15 | 2017-03-30 | Abrado, Inc. | Downhole tubular milling apparatus, especially suitable for deployment on coiled tubing |
US11162313B2 (en) | 2017-07-13 | 2021-11-02 | Halliburton Energy Services, Inc. | Anchor for a downhole linear actuator |
CN110552658A (en) * | 2019-09-26 | 2019-12-10 | 西南石油大学 | Large-drift-diameter prestressed well cementation tool |
CN114991702B (en) * | 2022-06-01 | 2024-05-03 | 中煤科工集团西安研究院有限公司 | Hole bottom grouting device, system and method for underground deep hole sealing of coal mine |
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- 2011-12-16 AU AU2011343204A patent/AU2011343204A1/en not_active Abandoned
- 2011-12-16 WO PCT/EP2011/073100 patent/WO2012080486A1/en active Application Filing
- 2011-12-16 RU RU2013132394/03A patent/RU2013132394A/en not_active Application Discontinuation
- 2011-12-16 CN CN2011800607752A patent/CN103261578A/en active Pending
- 2011-12-16 MX MX2013006624A patent/MX2013006624A/en not_active Application Discontinuation
- 2011-12-16 EP EP11807670.2A patent/EP2652257A1/en not_active Withdrawn
- 2011-12-16 CA CA2821840A patent/CA2821840A1/en not_active Abandoned
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Also Published As
Publication number | Publication date |
---|---|
US20140102719A1 (en) | 2014-04-17 |
EP2652257A1 (en) | 2013-10-23 |
CN103261578A (en) | 2013-08-21 |
RU2013132394A (en) | 2015-01-27 |
BR112013014561A2 (en) | 2016-09-20 |
AU2011343204A1 (en) | 2013-05-02 |
CA2821840A1 (en) | 2012-06-21 |
WO2012080486A1 (en) | 2012-06-21 |
MX2013006624A (en) | 2013-06-28 |
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