EP2466064A1 - Casing anchor - Google Patents

Casing anchor Download PDF

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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Withdrawn
Application number
EP10195570A
Other languages
German (de)
English (en)
French (fr)
Inventor
Jørgen HALLUNDBAEK
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Welltec AS
Original Assignee
Welltec AS
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Welltec AS filed Critical Welltec AS
Priority to EP10195570A priority Critical patent/EP2466064A1/en
Priority to BR112013014561A priority patent/BR112013014561A2/pt
Priority to PCT/EP2011/073100 priority patent/WO2012080486A1/en
Priority to US13/994,856 priority patent/US20140102719A1/en
Priority to EP11807670.2A priority patent/EP2652257A1/en
Priority to CN2011800607752A priority patent/CN103261578A/zh
Priority to RU2013132394/03A priority patent/RU2013132394A/ru
Priority to AU2011343204A priority patent/AU2011343204A1/en
Priority to MX2013006624A priority patent/MX2013006624A/es
Priority to CA2821840A priority patent/CA2821840A1/en
Publication of EP2466064A1 publication Critical patent/EP2466064A1/en
Withdrawn legal-status Critical Current

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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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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)
  • Piles And Underground Anchors (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)
EP10195570A 2010-12-17 2010-12-17 Casing anchor Withdrawn EP2466064A1 (en)

Priority Applications (10)

Application Number Priority Date Filing Date Title
EP10195570A EP2466064A1 (en) 2010-12-17 2010-12-17 Casing anchor
BR112013014561A BR112013014561A2 (pt) 2010-12-17 2011-12-16 ancora de rocha
PCT/EP2011/073100 WO2012080486A1 (en) 2010-12-17 2011-12-16 Rock anchor
US13/994,856 US20140102719A1 (en) 2010-12-17 2011-12-16 Rock anchor
EP11807670.2A EP2652257A1 (en) 2010-12-17 2011-12-16 Rock anchor
CN2011800607752A CN103261578A (zh) 2010-12-17 2011-12-16 岩石锚定件
RU2013132394/03A RU2013132394A (ru) 2010-12-17 2011-12-16 Анкерное крепление в скальной породе
AU2011343204A AU2011343204A1 (en) 2010-12-17 2011-12-16 Rock anchor
MX2013006624A MX2013006624A (es) 2010-12-17 2011-12-16 Ancla de roca.
CA2821840A CA2821840A1 (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 (ru)
EP (2) EP2466064A1 (ru)
CN (1) CN103261578A (ru)
AU (1) AU2011343204A1 (ru)
BR (1) BR112013014561A2 (ru)
CA (1) CA2821840A1 (ru)
MX (1) MX2013006624A (ru)
RU (1) RU2013132394A (ru)
WO (1) WO2012080486A1 (ru)

Cited By (2)

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Publication number Priority date Publication date Assignee Title
CN104755700A (zh) * 2012-10-31 2015-07-01 韦尔泰克有限公司 屏障检测方法
WO2022260685A1 (en) * 2021-06-07 2022-12-15 Halliburton Energy Services, Inc. Collapsible shell packer for metal-to-metal sealing

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DK3350408T3 (da) 2015-09-15 2021-03-15 Abrado Inc Rørformet borehulsfræseindretning, navnlig egnet til indsættelse af snoet rørledning
US11162313B2 (en) 2017-07-13 2021-11-02 Halliburton Energy Services, Inc. Anchor for a downhole linear actuator
CN110552658A (zh) * 2019-09-26 2019-12-10 西南石油大学 一种大通径预应力固井工具
CN114991702B (zh) * 2022-06-01 2024-05-03 中煤科工集团西安研究院有限公司 一种煤矿井下深孔封闭用孔底注浆装置、系统及方法

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GB2246585A (en) * 1990-07-31 1992-02-05 Masx Energy Services Group Inc Hydraulically set anchor for well tools
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WO2009071874A2 (en) * 2007-12-03 2009-06-11 Petrowell Ltd Improved centraliser
WO2009120759A2 (en) 2008-03-25 2009-10-01 Baker Hughes Incorporated Wellbore anchor and isolation system

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US2315931A (en) * 1940-06-17 1943-04-06 Baker Oil Tools Inc Liner hanger apparatus
US3085327A (en) * 1957-08-02 1963-04-16 Commissariat Energie Atomique Devices for opening and handling from a distance a container, and in particular an irradiated tube
US4429741A (en) * 1981-10-13 1984-02-07 Christensen, Inc. Self powered downhole tool anchor
GB2246585A (en) * 1990-07-31 1992-02-05 Masx Energy Services Group Inc Hydraulically set anchor for well tools
US5220959A (en) * 1991-09-24 1993-06-22 The Gates Rubber Company Gripping inflatable packer
US5301759A (en) * 1992-03-02 1994-04-12 Ruhle James L Method and apparatus for core-sampling subsurface rock formations
US5979550A (en) * 1998-02-24 1999-11-09 Alberta Ltd. PC pump stabilizer
US20020144815A1 (en) * 2001-03-10 2002-10-10 Van Drentham-Susman Hector F.A. Guide apparatus
WO2009071874A2 (en) * 2007-12-03 2009-06-11 Petrowell Ltd Improved centraliser
WO2009120759A2 (en) 2008-03-25 2009-10-01 Baker Hughes Incorporated Wellbore anchor and isolation system

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN104755700A (zh) * 2012-10-31 2015-07-01 韦尔泰克有限公司 屏障检测方法
US9835023B2 (en) 2012-10-31 2017-12-05 Welltec A/S Barrier testing method
CN104755700B (zh) * 2012-10-31 2019-01-11 韦尔泰克油田解决方案股份公司 屏障检测方法
WO2022260685A1 (en) * 2021-06-07 2022-12-15 Halliburton Energy Services, Inc. Collapsible shell packer for metal-to-metal sealing
GB2619673A (en) * 2021-06-07 2023-12-13 Halliburton Energy Services Inc Collapsible shell packer for metal-to-metal sealing
PL446825A1 (pl) * 2021-06-07 2024-06-03 Halliburton Energy Services, Inc. Urządzenie pakujące składane powłoki do uszczelniania metal-metal
ES2958091R1 (es) * 2021-06-07 2024-06-11 Halliburton Energy Services Inc Empacador de carcasa plegable para sellado metal a metal

Also Published As

Publication number Publication date
US20140102719A1 (en) 2014-04-17
EP2652257A1 (en) 2013-10-23
BR112013014561A2 (pt) 2016-09-20
MX2013006624A (es) 2013-06-28
WO2012080486A1 (en) 2012-06-21
CN103261578A (zh) 2013-08-21
CA2821840A1 (en) 2012-06-21
RU2013132394A (ru) 2015-01-27
AU2011343204A1 (en) 2013-05-02

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