EP2725278A1 - System zur Erweiterung eines röhrenförmigen Elements in einem Bohrloch - Google Patents

System zur Erweiterung eines röhrenförmigen Elements in einem Bohrloch Download PDF

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Publication number
EP2725278A1
EP2725278A1 EP12190414.8A EP12190414A EP2725278A1 EP 2725278 A1 EP2725278 A1 EP 2725278A1 EP 12190414 A EP12190414 A EP 12190414A EP 2725278 A1 EP2725278 A1 EP 2725278A1
Authority
EP
European Patent Office
Prior art keywords
tubular element
section
unexpanded
wall
tubular
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Withdrawn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
EP12190414.8A
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English (en)
French (fr)
Inventor
Fausto Ciotta
Petrus Cornelis Kriesels
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.)
Shell Internationale Research Maatschappij BV
Original Assignee
Shell Internationale Research Maatschappij BV
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 Shell Internationale Research Maatschappij BV filed Critical Shell Internationale Research Maatschappij BV
Priority to EP12190414.8A priority Critical patent/EP2725278A1/de
Publication of EP2725278A1 publication Critical patent/EP2725278A1/de
Withdrawn legal-status Critical Current

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    • 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
    • E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
    • E21B43/108—Expandable screens or perforated liners

Definitions

  • the present invention relates to a system for radially expanding a tubular element in a borehole formed in an earth formation.
  • casing and “liner” refer to tubular elements for supporting and stabilising the wellbore wall.
  • a casing extends from surface into the wellbore and a liner extends from a certain depth further into the wellbore.
  • casing and liner are used interchangeably and without such intended distinction.
  • WO-2008/006841 discloses a wellbore system for radially expanding a tubular element in a wellbore.
  • the wall of the tubular element is induced to bend radially outward and in axially reverse direction so as to form an expanded section extending around an unexpanded section of the tubular element.
  • the length of the expanded tubular section is increased by moving, for instance by forcing or pushing, the unexpanded section into the expanded section.
  • the expanded section retains the expanded tubular shape.
  • the unexpanded section can, for instance, be extended by adding pipe sections or by unreeling, folding and welding a sheet of material into a tubular shape.
  • the present invention aims to provide an improved system for expanding a tubular element in a borehole, which overcomes the problem of the prior art.
  • the invention therefore provides a system for lining a borehole formed in an earth formation, the system comprising:
  • each strengthening member suitably extends substantially in longitudinal direction of the tubular element.
  • the system of the present invention is equally suitable for applications whereby the weld extends in any other direction, for example whereby the weld extend at an angle to the axial direction or even whereby the weld extends in axial direction.
  • the strengthening member(s) extend(s) substantially transverse to the weld.
  • said at least one strengthening member comprises a plurality of strengthening members regularly spaced along the circumference of the unexpanded tubular section.
  • the strengthening members are arranged staggered in longitudinal direction of the tubular element.
  • Each strengthening member can be formed, for example, as an elongate strip or a patch. Furthermore, each strengthen member is suitably connected to said first and second wall portions by brazing, welding or gluing.
  • the system of the invention is most advantageously applied during drilling of the borehole, whereby a drill string extends through the unexpanded tubular section for further drilling of the wellbore.
  • a short open-hole section can be maintained throughout the drilling operation, so that there is a reduced risk of fracturing the formation due to drilling fluid pressure being too high and also a reduced risk of undesired formation fluid inflow into the wellbore due to drilling fluid pressure being too low.
  • the actuator is adapted to move the unexpanded tubular section axially downward at a speed substantially twice the speed of lowering the drill string into the borehole during further drilling of the borehole with the drill string.
  • Fig. 1 shows a wellbore 1 formed in an earth formation 2 whereby an expandable tubular element 4 extends into the wellbore.
  • Reference sign 6 indicates the earth surface.
  • the tubular element 4 includes an unexpanded tubular section 8 and a radially expanded tubular section 10 of outer diameter substantially equal to the diameter of the wellbore.
  • the expanded tubular section serves to support the wellbore wall and to prevent undesired inflow of formation fluid into the wellbore 1, or to prevent undesired outflow of wellbore fluid into the formation 2.
  • the expandable tubular element therefore also will be referred to as "liner”, the unexpanded tubular section will be referred to as “unexpanded liner section”, and the radially expanded tubular section will be referred to as “expanded liner section”.
  • the unexpanded liner section 8 extends substantially concentrically within the expanded liner section 10.
  • the unexpanded liner section 8 has an upper end located at a position in the wellbore 1 commensurate with the length and depth of the wellbore section that is to lined by eversion of the expandable tubular element 4.
  • the lower end of the unexpanded liner section 8 is located a short distance above the wellbore bottom during drilling of the wellbore 1.
  • the wall of the unexpanded liner section 8 bends radially outward and in axially reverse (in Fig. 1 upward) direction so as to form a curved lower section 12 defining a bending zone 14 of the tubular element 4.
  • the curved lower section 12 is U-shaped and interconnects the unexpanded liner section 8 and the expanded liner section 10.
  • the expanded liner section 10 and the unexpanded liner section 8 define an annular space 16 there between, which is closed at its lower end by the curved lower section 12 of the expandable tubular element 4.
  • the annular space 16 is also referred to as the blind annulus.
  • the unexpanded liner section 8 is at its outer surface provided with a plurality of metal strips 17, which will be described hereinafter in more detail.
  • a drill string 18 extends from surface through the unexpanded liner section 8 to the bottom of the wellbore 1.
  • the lower end of the drill string 18 is provided with a drill bit 20 comprising a pilot bit 22 of outer diameter slightly smaller than the inner diameter of the unexpanded liner section 8, and a reamer section 24 having an outer diameter adapted to drill the wellbore 1 to its nominal diameter.
  • the reamer section 24 is radially retractable to a smaller outer diameter, allowing it to be lowered or retrieved through the unexpanded liner section 8.
  • the drill string 18 may comprise multiple drill pipe sections 26 mutually interconnected by threaded connections 28.
  • An annular space 30 is formed between the drill string 18 and the unexpanded liner section 8, said annular space 30 being referred to hereinafter as the drilling annulus 30.
  • connections 28 are not shown in detail, but comprise for instance threaded pin and box type connections.
  • the connections 28 may comprise joints fabricated with male threads on each end, wherein short-length coupling members (not shown) with female threads are used to join the individual joints of drill string together, or joints with male threads on one end and female threads on the other.
  • the threaded connections may comprise connections which are standardized by the American Petroleum Institute (API).
  • API American Petroleum Institute
  • the drill string 18 and the unexpanded liner section 8 extend through an opening 32 of a rig floor 34 which is part of a drilling rig (not shown).
  • a pipe pusher 36 is provided for moving the unexpanded liner section 8 in downward direction.
  • the pipe pusher 36 is for instance arranged below the rig floor and is supported by a base frame 38 that is connected to the drilling rig or directly to surface 6.
  • the pipe pusher may comprise one or more conveyor belts 40, whereby each conveyor belt engages the outer surface of the unexpanded liner section 8 and is driven by a respective motor (not shown).
  • Each conveyer belt 40 is adapted to exert a downward force to the unexpanded liner section 8 so as to push the unexpanded liner section into the borehole.
  • Other embodiments of the pipe pusher 36 capable of exerting a downward or upward force to the unexpanded liner section 8, are conceivable.
  • a sealing device 42 is connected to the upper end of the expanded liner section 10 to seal the unexpanded liner section 8 relative to the expanded liner section 10.
  • the sealing device 42 enables the unexpanded liner section 8 to slide in axial direction relative to the sealing device 42.
  • the sealing device comprises a conduit 44 connected to a pump (not shown) for pumping fluid into or out of the blind annulus 16.
  • the sealing device includes one, two or more annular seals 46 whereby each annular seal engages the outside of the unexpanded liner section 8 so as to prevent undesired outflow of fluid from the blind annulus.
  • the sealing device 42 comprises at least two seals 46 for improved safety and reliability in case one of the seals fails.
  • the sealing device 42 can be regarded as a blind annulus blow out preventer (BABOP). Therefore, the annular seals 46, the connection of the sealing device 42 to the upper end of the expanded liner section 10, and one or more valves (not shown) for closing conduit 44 are all designed to withstand fluid pressures that may arise in a well control situation.
  • the sealing device 42 is for instance designed to withstand fluid pressures that may be expected in case of a blowout, for instance in the range of 200 bar to 1600 bar, for instance about 400 bar to 800 bar or more. Such pressures may arise in the blind annulus 16 in case of a failure, for instance due to rupturing of the expandable tubular element 4 during a well control situation.
  • the expanded liner section 10 is axially fixed relative to the wellbore by any suitable fixation means.
  • the upper end of the expanded liner section may be connected to a ring or flange (not shown) by welding and/or screwing.
  • Said ring can be attached to or incorporated in any suitable structure at surface, such as the sealing device 42.
  • the inner diameter of said ring may be larger than the outer diameter of the expanded liner section.
  • the expanded liner section 10 may be fixed to the wellbore wall, for instance by virtue of frictional forces between the expanded liner section 10 and the wellbore wall as a result of the expansion process.
  • the expanded liner section 10 can be anchored, for instance to the wellbore wall, by any suitable anchoring means.
  • Fig. 2 shows a top drive system 50 for optional use in combination with the system of Fig. 1 .
  • the top drive system is adapted to be connected to the system of Fig. 1 at the common interface indicated by line 1-1 ( Fig. 1 ), and comprises a motor 52 and an upper connection part 54 driven by the motor.
  • the upper connection part forms a flush pipe having a smooth outer surface and being connected at its lower end to an additional drill string section 56 by means of a threaded connection 28.
  • the additional drill string section 56 is substantially similar to the drill string sections 26 shown in Fig. 1 .
  • the additional drill string section 56 can be connected to the upper end of the drill string 18 shown in Fig. 1 .
  • the top drive system 50 further comprises a drilling annulus sealing device 58 including a housing 60 that encloses the flush pipe 54, with an annular space 62 there between.
  • the annular space 62 is in fluid communication with the drilling annulus 30.
  • the housing 60 At the top end, near the top drive motor 52, the housing 60 comprises one, two or more seals 64 which engage the outside of the flush pipe 54.
  • the seals 64 enable the housing to slide along the flush pipe 54.
  • the top drive system comprises an additional pipe section 66 of substantially the same outer diameter and wall-thickness as the unexpanded liner section 8.
  • the housing 60 may comprise one, two or more seals 68 which engage the outer surface of the additional pipe section 66.
  • the housing may comprise grippers 70 that engage the outside and/or the inside of the additional pipe section 66.
  • An activation conduit 72 is connected to the housing for activating or releasing the seals 68 and/or the grippers 70.
  • a fluid conduit 74 is provided to the housing for supply or drainage of (drilling) fluid to or from the drilling annulus 30 via the annular space 62.
  • the sealing device 58 comprises an extending part or stinger 76 that extends into the inside of the additional pipe section 66.
  • the stinger may comprise seals 78 and/or grippers to engage the upper end of the pipe section 66.
  • the stinger may also comprise seals 80 to engage a lower end of the pipe section 66, and seals 82 to engage the inside of the upper end of the unexpanded liner section 8.
  • a backing gas tool (not shown) may be integrated in the stinger between the seals 80, 82 to cover the inner interface between the additional pipe section 66 and the unexpanded liner section 8.
  • the stinger 76 is at least slightly longer than the pipe section 66 so that the stinger may extend into the unexpanded liner section 8 to enable the stinger to function as an alignment tool for aligning the pipe section 66 with the unexpanded liner section 8.
  • the length of the pipe section 66 may be in the range of about 5-20 metres, for instance 10 metres.
  • the stinger will for instance be about 2% to 10% longer, for instance 5% longer than the pipe section 66.
  • the sealing device 58 may be referred to as drilling annulus blow out preventer (DABOP).
  • DABOP drilling annulus blow out preventer
  • the seals 64, 68, 78, 80, 82, the grippers 70, and one or more valves (not shown) for closing conduits 72, 74 are all designed to at least withstand fluid pressures that may arise in a well control situation.
  • the DABOP 58 is for instance designed to withstand pressures in the range of about 200 bar to 800 bar or more, for instance about 400 bar.
  • the DABOP may comprise any number of seals, for example one seal 64 and one seal 68, or a plurality of seals.
  • two seals 64 that engage the flush pipe 66 and two seals 68 that engage the pipe section 66 will provide a balance between fail-safety and reliability on one hand and costs on the other hand.
  • the double barrier provided by the inner seals 78 engaging the inside of the pipe section 66, and the outer seals 68 engaging the outside of the pipe section 66 improves the reliability and leaktightness of the sealing device 58.
  • the diameter and/or wall thickness of the expandable tubular element 4 is selected such that the expanded liner section 10 is pressed against the wellbore wall during the eversion process.
  • the expanded liner section 10 thereby seals against the wellbore wall and/or stabilizes the wellbore wall.
  • the wall thickness of the expandable tubular element 4 may be equal to or larger than about 2 mm (0.08 inch), for example larger than 2.5 mm.
  • the wall thickness is for instance about 3 to 30 mm or for instance about 2 to 10 mm.
  • the outer diameter of the unexpanded liner section may be larger than 50 mm (2 inch), for instance in the range of about 50 to 400 mm (16 inch).
  • the expanded liner section may have any outer diameter suitable for, or commonly used in, hydrocarbon production.
  • the wall of the expandable tubular element 4 may comprise a relatively strong material, such as a metal, preferably steel. Thus, the expandable tubular element 4 can be designed to have adequate collapse strength to support the wellbore wall and/or to withstand internal or external pressures encountered when drilling for hydrocarbon reservoirs.
  • the length and hence the weight of the unexpanded liner section 8 gradually increases during extension of the wellbore. Hence, the downward force exerted by the pipe pusher 36 can be gradually decreased in correspondence with the increasing weight. As said weight increases, the downward force eventually may need to be replaced by an upward force to maintain the total force within a predetermined range and to prevent buckling of the unexpanded liner section 8.
  • Fig. 3 shows the unexpanded liner section 8 in more detail.
  • the unexpanded liner section 8 may be made up of several pipe sections interconnected by circumferential welds.
  • weld 90 interconnects first pipe section 92 and second pipe section 94.
  • a number of metal strips 17 are provided at the outer surface of the unexpanded tubular section 8 to strengthen the weld 90.
  • Each metal strip 17 is connected to the outer surface by, for example, brazing, welding or gluing. Each metal strip 17 extends in longitudinal direction across the weld 90 and has a resistance to stretching in said longitudinal direction.
  • the metal strips 17 are of substantially equal length and are arranged in a staggered configuration (as shown in Fig. 3 ).
  • FIGS. 4a-4f Examples of suitable cross-sectional shapes of the strengthening members 17 are shown in Figs. 4a-4f .
  • reference sign 98 indicates the wall of the unexpanded tubular section 8
  • the respective strengthening members are indicated by reference signs 17a, 17b, 17c, 17d, 17e, 17f.
  • the strengthening members may be triangular, having either rounded ends as shown in Fig. 4a , or pointy ends as shown in Figs. 4b, 4d .
  • the base of the triangles may face in either uphole or downhole direction.
  • the strengthening members may be rectangular ( Fig. 4c ), for instance having the form of strips or being square or any rectangular form therein between.
  • the strengthening members may be T-shaped or n-shaped, as shown in Figs. 4e, 4f .
  • the strengthening members may have a shape and size to provide a predetermined bending stiffness.
  • the bending stiffness is for instance equal to the product of the elastic modulus E and the area moment of inertia I of the strip cross-section about the axis of interest.
  • the bending stiffness is EI .
  • a ratio of the bending stiffness of the wall of the tubular element to the bending stiffness of the one or more strengthening members combined is for instance in the range of 1:6 to 1:10, for instance about 1:8.
  • the strengthening members may have a length in the range of 5 to 30 cm, for instance about 15 cm long.
  • the circumference of the unexpanded section may be provided with any number of strips, for instance about 5 to 50 strips in total.
  • the strengthening members may be made of any suitable material to provide the above bending stiffness. Suitable materials include for instance metal, steel, and rubber-like materials.
  • the most appropriate method to connect the strengthening members to the tubular element may depend on the size and shape of the strengthening members.
  • a tubular element having an outer diameter of 6-5/8 inch may be provided with strips 17 of about 10 cm long, about 1 cm wide and about 1 mm thick. Substantially the entire inner surface (i.e. the surface facing the tubular element) of said strips may be provided with a brazing material. By heating to a temperature exceeding the melting temperature of the brazing material, the strips can be metallurgically bonded to the tubular element along their inner surface.
  • the opposite ends of the strips 17 may be welded to the pipe 8, in addition to the brazing, to improve the bonding and to prevent said ends from peeling off during eversion of the pipe.
  • connection methods or combinations of connection methods may be suitable, depending on for instance the size, shape and material of the strengthening members.
  • Rubber-like materials or relatively thin strips e.g. in the order of 0.5 mm or less
  • Relatively thick strengthening members e.g. in the order of 2 mm or more
  • Fig. 5 shows the downhole portion of the tubular element during the eversion process.
  • the weld 90 and the metal strips 17 are near but not yet in the bending zone 14 of the tubular element.
  • Fig. 6 shows the downhole portion of the tubular element 4 during the eversion process, wherein the weld 90 and the metal strips 17 are in the bending zone 14 of the tubular element.
  • the drill string 18 is operated to rotate the drill bit 20 to extend the borehole.
  • the drill string is gradually lowered into the borehole.
  • the pipe pusher 36 is operated to push the unexpanded liner section 8 into the borehole at a speed substantially twice the speed of downward movement of the drill string 18.
  • the unexpanded liner section may be pushed downhole to extend the liner may during drilling, but may also be pushed subsequently in a separate step.
  • the expanded liner section 10 remains stationary in the wellbore, and the unexpanded liner section 8 is gradually everted to extend the downhole end of the expanded liner section 10.
  • the bending zone 14 moves in downward direction.
  • the bending zone may move at substantially the same speed at which the drill string 18 is lowered into the wellbore. In this manner the distance between the bending zone 14 and the drill bit 20 can be kept relatively short, limiting the length L1 of the open hole section (see Fig. 1 ).
  • the open hole section is the unlined section of the wellbore 1.
  • the method of the present invention enables an open hole section of length L1 less than, for instance, 100 metres or even less than 50 metres at all times while drilling the borehole.
  • the wall of the tubular element 4 is initially bent radially outward whereby the wall assumes a curved shape, and thereafter bent in reverse direction whereby the wall again assumes a straight shape (as shown in Figs. 5, 6 ). It was found that, prior to applying the metal strips in accordance with the invention, tensile stresses during reverse bending of the weld sometimes cause fracturing of the weld or fracturing of the wall in the heat-affected zone near the weld. This problem is overcome by virtue of the metal strips 17 which provide resistance to stretching at the inner surface of the weld 96 (i.e. the surface facing the blind annulus 16) during reverse bending of the weld.
  • the bending stresses across the thickness of the wall vary substantially linearly from compressive to tensile, whereby a neutral line is defined by the points where the bending stresses vanish.
  • a neutral line is defined by the points where the bending stresses vanish.
  • the neutral line extends in in the middle of the wall.
  • the metal strips 17 cause the neutral line during reverse bending to shift towards the metal strips, or even into the metal strips. It is thereby achieved that the tensile stresses in the weld 96 and in the heat affected zone around the weld, become less severe or totally vanish while the compressive stresses in the wall increase.
  • the unexpanded liner section 8 may be supported by the drill string 18, for example by means of a bearing device (not shown) connected to the drill string, which supports the curved lower section 12 of the liner 4.
  • a bearing device (not shown) connected to the drill string, which supports the curved lower section 12 of the liner 4.
  • an upward force is suitably transmitted from the drill string 18 to the curved lower section 12 via the bearing device.
  • at least part of the weight of the unexpanded liner section 8 and the pipe then can be transferred to the drill string and utilised to provide a thrust force to the drill bit 20.
  • Drilling fluid containing drill cuttings is discharged from the drilling annulus 30 via fluid conduit 74.
  • drilling fluid may be circulated in reverse circulation mode wherein the drilling fluid is pumped into the wellbore via the conduit 74 and discharged from the wellbore via the drill string 18.
  • the reamer section 24 can be collapsed to its radially retracted mode whereby the diameter is smaller than the inner diameter of the unexpanded liner section 8. Subsequently, the drill string 18 can be retrieved through the unexpanded liner section 8 to surface.
  • a remaining portion of the unexpanded liner section can be left in the wellbore or it can be retrieved to surface.
  • expansion of the liner is started at surface or at a down hole location.
  • the bending zone moves from the offshore platform to the seabed and subsequently into the wellbore.
  • the resulting expanded tubular element not only forms a liner in the wellbore, but also a riser extending from the offshore platform to the seabed. The need for a separate riser is thereby obviated.
  • conduits such as electric wires or optical fibres for communication with down hole equipment can be extended in the annulus between the expanded and unexpanded sections.
  • Such conduits can be attached to the outer surface of the tubular element before expansion thereof.
  • the expanded and unexpanded liner sections can be used as electricity conductors to transfer data and/or power down hole.
  • a friction reducing layer such as a Teflon layer, may be applied between the unexpanded liner section and the expanded liner section to reduce friction forces during the eversion process.
  • a friction reducing coating can be applied to the outer surface of the unexpanded liner section.
  • the friction reducing layer reduces the width of the blind annulus, and thereby minimizes or eliminates a possible tendency of the unexpanded liner section to buckle.
  • centralizing pads and/or rollers can be applied in the blind annulus between the unexpanded and expanded sections to reduce the friction and the annular clearance.
  • the expanded liner section can be expanded against the inner surface of another tubular element, e.g. casing or a liner, already present in the wellbore.
  • another tubular element e.g. casing or a liner
  • the present invention is likewise suitable for use with alternative drilling systems.
  • the latter may include for instance a down hole motor instead of a top drive.
  • Said down hole motor is a drilling tool comprised in the drill string directly above the bit. Activated by pressurized drilling fluid, it causes the bit to turn while the drill string remains fixed.
  • Examples of the down hole motor include a positive-displacement motor and a down hole turbine motor.
  • the present invention is likewise suitable for directional drilling, i.e. drilling wherein the drilling direction can be adjusted.
  • a down hole motor may be used as a deflection tool in directional drilling, where it is made up between the bit and a bent sub, or the housing of the motor itself may be bent.
  • the metal strips are directly connected to the outer surface of the unexpanded liner section.
  • the strips can be formed from a tubular metal layer fixedly connected to the outer surface of the unexpanded liner section, whereby longitudinal grooves are machined into the layer, and whereby each strip is defined between two such adjacent longitudinal grooves.
  • the strips are made of a metal such as steel, the strips alternatively can be made of any other suitable material which provides the required resistance to stretching.

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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)
EP12190414.8A 2012-10-29 2012-10-29 System zur Erweiterung eines röhrenförmigen Elements in einem Bohrloch Withdrawn EP2725278A1 (de)

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Application Number Priority Date Filing Date Title
EP12190414.8A EP2725278A1 (de) 2012-10-29 2012-10-29 System zur Erweiterung eines röhrenförmigen Elements in einem Bohrloch

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EP12190414.8A EP2725278A1 (de) 2012-10-29 2012-10-29 System zur Erweiterung eines röhrenförmigen Elements in einem Bohrloch

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EP2725278A1 true EP2725278A1 (de) 2014-04-30

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Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6254709B1 (en) * 1998-10-26 2001-07-03 Shonan Gosei-Jushi Seisakusho K.K. Method of manufacturing a pipe liner bag
WO2008006841A1 (en) 2006-07-13 2008-01-17 Shell Internationale Research Maatschappij B.V. Method of radially expanding a tubular element
WO2009056514A1 (en) * 2007-10-29 2009-05-07 Shell Internationale Research Maatschappij B.V. Method of radially expanding a tubular element
EP2460972A1 (de) * 2010-12-03 2012-06-06 Shell Internationale Research Maatschappij B.V. Verfahren und System zur radialen Erweiterung eines röhrenförmigen Elements

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6254709B1 (en) * 1998-10-26 2001-07-03 Shonan Gosei-Jushi Seisakusho K.K. Method of manufacturing a pipe liner bag
WO2008006841A1 (en) 2006-07-13 2008-01-17 Shell Internationale Research Maatschappij B.V. Method of radially expanding a tubular element
WO2009056514A1 (en) * 2007-10-29 2009-05-07 Shell Internationale Research Maatschappij B.V. Method of radially expanding a tubular element
EP2460972A1 (de) * 2010-12-03 2012-06-06 Shell Internationale Research Maatschappij B.V. Verfahren und System zur radialen Erweiterung eines röhrenförmigen Elements

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