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WO2009122203A1 - Procédé de création d’une zone de découpe subaquatique, dispositifs et procédés d’obturation associés - Google Patents

Procédé de création d’une zone de découpe subaquatique, dispositifs et procédés d’obturation associés Download PDF

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Publication number
WO2009122203A1
WO2009122203A1 PCT/GB2009/050305 GB2009050305W WO2009122203A1 WO 2009122203 A1 WO2009122203 A1 WO 2009122203A1 GB 2009050305 W GB2009050305 W GB 2009050305W WO 2009122203 A1 WO2009122203 A1 WO 2009122203A1
Authority
WO
WIPO (PCT)
Prior art keywords
aperture
plugging
component
cutting
medium
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.)
Ceased
Application number
PCT/GB2009/050305
Other languages
English (en)
Inventor
Jonathon Edwards
Alexender Burns
David White
Stuart Tennant
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.)
Helix Well Ops SEA Pty Ltd
WELL OPS UK Ltd
Original Assignee
Well Ops SEA Pty Ltd
WELL OPS UK Ltd
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
Priority claimed from GB0806162A external-priority patent/GB0806162D0/en
Priority claimed from AU2008902729A external-priority patent/AU2008902729A0/en
Application filed by Well Ops SEA Pty Ltd, WELL OPS UK Ltd filed Critical Well Ops SEA Pty Ltd
Priority to AU2009233524A priority Critical patent/AU2009233524B8/en
Priority to EP09726842A priority patent/EP2288471B1/fr
Publication of WO2009122203A1 publication Critical patent/WO2009122203A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

Classifications

    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B24—GRINDING; POLISHING
    • B24C—ABRASIVE OR RELATED BLASTING WITH PARTICULATE MATERIAL
    • B24C1/00—Methods for use of abrasive blasting for producing particular effects; Use of auxiliary equipment in connection with such methods
    • B24C1/04—Methods for use of abrasive blasting for producing particular effects; Use of auxiliary equipment in connection with such methods for treating only selected parts of a surface, e.g. for carving stone or glass
    • B24C1/045—Methods for use of abrasive blasting for producing particular effects; Use of auxiliary equipment in connection with such methods for treating only selected parts of a surface, e.g. for carving stone or glass for cutting
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B24—GRINDING; POLISHING
    • B24C—ABRASIVE OR RELATED BLASTING WITH PARTICULATE MATERIAL
    • B24C3/00—Abrasive blasting machines or devices; Plants
    • B24C3/32—Abrasive blasting machines or devices; Plants designed for abrasive blasting of particular work, e.g. the internal surfaces of cylinder blocks
    • B24C3/325—Abrasive blasting machines or devices; Plants designed for abrasive blasting of particular work, e.g. the internal surfaces of cylinder blocks for internal surfaces, e.g. of tubes
    • 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
    • E21B29/00—Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
    • E21B29/12—Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground specially adapted for underwater installations
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like

Definitions

  • the present invention relates to cutting environments, plugging devices and methods for plugging apertures in abandoned subsea wellheads for removal thereof from casing strings.
  • a string of concentric casings of the wellhead are located in the seabed.
  • a cutting medium is ejected at high pressure from a nozzle at the end of a conduit.
  • the objective is to cut through the casings such that their upper parts, and any associated wellhead, can be removed.
  • the entrained grit must necessarily be very abrasive and this means that the conduit pipe work taking the grit to the cutting nozzle is unable to withstand the abrasive effects of the grit for long periods of time.
  • the pipe work can be quite long - e.g. 300 metres. Accordingly, the pipes and fittings in these prior proposals wear out, in many cases before the cut is completed, and the pipes have to be renewed.
  • Wellheads and associated components can include external and/or internal apertures, such as through which liquid cement based medium pumped into the well casing and/or trapped gases may vent during installation or maintenance of the well bore.
  • low density medium can be pumped into the casing in an amount greater than can escape in a given time, thereby providing a build up of the medium (such as pressurisation within a section of the casing) and exclusion of the water from the cutting zone.
  • At least one form of the present invention provides a method of creating a cutting zone in an underwater structure, including; plugging at least one aperture in the underwater structure; introducing a low density medium into the structure to remove higher density medium from a required cutting zone; whereby the plugging restricts escape of the low density medium to enable a low density medium cutting zone to be created in the underwater structure.
  • cutting may be carried out on the structure more efficiently and effectively in a low density medium environment, such as cutting with an abrasive jet in air by expelling seawater from the required zone.
  • Plugging may include insertion of a mechanical device, or part thereof, into the at least one aperture.
  • plugging may include covering the at least one aperture with a cover device, such as a plate or cap.
  • Plugging may also or alternatively include locating a plugging device over and/or in the at least one aperture. This may assist in correct positioning of a plugging device and thus enhanced success of plugging.
  • Plugging may further include expanding a portion of a plugging device within and/or against the at least one aperture.
  • opposed mechanical means such as cones
  • a resilient means such as a rubber sleeve or collar or similar material. This may be achieved mechanically, such as by a helical drive, or hydraulically or pneumatically operated.
  • biasing means such as a spring drive, is envisaged.
  • the cover may be magnetised and/or include one or more magnets attached to a metal structure.
  • the cover may include one or more rare earth magnets having a relatively strong magnetic attraction compared with other magnets to thereby resist removal from the structure resulting from pressure caused by the pumped low density medium.
  • adhesive(s) may be used.
  • one or more magnets may be employed to initially hold the device to the structure until an adhesive bond is sufficiently formed.
  • adhesive(s) may reduce the need for strong magnets, such as rare earth magnets, which are relatively expensive, or reduce the number of magnets required. This can provide cost savings. It is also envisaged that an adhesive may be used when it is not desirable or necessary to recover and reuse the plug after the structure has been severed. It will be appreciated that suitable adhesive(s) may be used negating the need for magnetic attachment entirely.
  • the cover may include a seal to assist in sealing the cover against the surface of the structure, which may help reduce loss of pressure/low density medium.
  • the plugging step may includes introducing a settable medium into the aperture and allowing the settable medium to set.
  • the settable medium may comprise at least two components that are mixed in the plugging step to react with one another and thereby cause the settable medium to set.
  • the plugging step may include introducing a low-temperature medium to the vicinity of the aperture, thereby to cause a medium in the vicinity of the aperture to solidify.
  • a further form of the present invention provides a plugging device for an aperture in an underwater structure, including means to restrict escape of low density medium from a required cutting zone within the structure.
  • the plugging device may include a seal to enhance restriction of escape of the medium.
  • the device may include a resilient portion which, in use, inserts into and/or over the aperture to create a seal in and/or over the aperture respectively.
  • the resilient portion may include rubber or similar material.
  • the resilient portion may be a dumb plug.
  • the resilient portion may be expanded by mechanical and/or fluid means to seal within the aperture.
  • opposed cones brought together within a sleeve or collar may utilised.
  • An expandable container is also envisaged, such as a balloon type means, in which may be filled an expandable settable (such as a foam) or non-setting fluid (such as a gas or liquid) material.
  • a non-expandable, settable material may be used, such as an epoxy resin or cement/grout.
  • the plugging device may be operated manually, or if preferred by mechanical means, such as a helical screw means and/or hydraulically or pneumatically driven.
  • the plugging device may include a locator to assist in positioning the device correctly over/within the aperture.
  • a method of cutting an underwater component that contains water and/or hydrocarbons comprising: creating a seal in the component; introducing at least one conduit into the component; delivering pressurized gas into the component to displace at least some of the water and thereby create a cutting zone; and delivering via the at least one conduit a cutting fluid at high pressure at the cutting zone to cut the component.
  • An air pipe, and a hose preferably with a nozzle, may be passed into the component. This may be through the seal created in the component.
  • the cutting fluid may be delivered as a fluid jet through said nozzle, which jet may be directed at an area of said component from which the water has been displaced i.e. in the cutting zone, thereby to cut said area by said jet.
  • a method as above further includes the step of passing a pressure relief conduit (e.g. a hose or pipe) into said component, preferably through said seal, to allow relief of pressure within said component.
  • a pressure relief conduit e.g. a hose or pipe
  • Other pressure relief means may be provided, such as a pressure relief “valve”, which may be a plugging device configured to release or open at or above a required pressure.
  • a pressure relief means is provided at or adjacent the underwater component to be cut.
  • said component comprises a casing connected to a subsea wellhead.
  • said casing is one of a string of casings disposed one inside another.
  • a pair of said casings defines therebetween an annular gap, wherein there is at least one aperture through one or both of the casings (which may or may not align), and sealing includes sealing the or each said aperture.
  • the or each said aperture is sealed by means of cement.
  • said cement is lighter than water.
  • said cement is a rapid setting cement.
  • said nozzle directs said jet upwardly or downwardly, with respect to the horizontal.
  • said nozzle directs said jet at an angle in the range 5° to 15° with respect to horizontal.
  • the invention provides a system for cutting an underwater component that contains water and/or hydrocarbons, the system comprising: at least one seal for the component; a gas delivery conduit to, in use, provide pressurized gas into the component for displacing water and/or hydrocarbons present in the component an abrasive fluid delivery conduit to, in use, deliver a cutting fluid therethrough into the component; and means for directing a jet of said cutting fluid at an area of said component from which the water and/or hydrocarbons has been displaced, thereby to cut said area by said jet.
  • such apparatus is adapted to perform a method according to any of the preceding aspects of the invention.
  • sealing used within the specification means total or partial sealing as required. That is sealing sufficient to create/maintain displacement of the water and/or hydrocarbons from the component.
  • Figure 1 illustrates a string of concentric casings that are located in the seabed, together with an underwater cutting apparatus.
  • Figure 2 is a view similar to Figure 1 , without the cutting apparatus but with a wellhead attached.
  • Figure 3 is a view similar to Figure 2, showing the blocking of cement circulation ports.
  • Figure 4 is a view similar to Figure 3, showing an alternative blocking method.
  • Figure 5 shows an embodiment of the present invention mounted in place over an aperture in a structure.
  • Figure 6 shows an alternative embodiment of the present invention.
  • Figures 7a and 7b show a further embodiment of the present invention in alternative actuation positions.
  • Figures 8a and 8b show alternative actuation positions of an embodiment of the present invention.
  • Figure 9 shows a pad containing a hydrophilic hydro-expanding urethane.
  • Figure 10 shows a hydraulic ram with rubber ends.
  • Figure 11 shows a tool with four independent chambers for applying chemicals in various ratios.
  • Figure 12 is a view similar to Figure 11 , but showing a tool with two independent chambers.
  • Figure 13 is a view similar to Figure 12, with the addition of a flexible expanding membrane.
  • Figure 14 shows an expandable rubber plug containing a settable mixture.
  • Figure 15 illustrates a rubber block that is expandable by a hydraulic actuator.
  • Figure 16 illustrates use of liquid nitrogen to freeze water in a localised area.
  • Figure 1 illustrates a string of concentric casings 111 to 114 that are located in the seabed 102.
  • An abrasive cutting medium 103 is ejected at high pressure from a nozzle 101 at the end of a pipe 104, which is a high-pressure hose.
  • the objective is to cut through the casings 111 to 114 such that their upper parts, and any associated wellhead, can be removed.
  • the cutting jet 103 is inclined downwardly at a small angle to the horizontal - about 10° in this case.
  • the cutting jet 103 is substantially horizontal.
  • a problem with known cutting apparatus of this type is that, as the abrasive water jet 103 passes through water that fills the casings 111 to 114, it loses energy and naturally breaks up into the surrounding water. As the abrasive water jet 103 works at increasing depths, this phenomenon becomes more noticeable until a stage is reached, at comparatively shallow depths, where the prevailing hyperbaric pressure effectively prevents efficient cutting.
  • compressed air is delivered at high pressure into the inner casing 111 via a pipe 122.
  • the seawater 123 in the inner casing 111 may be displaced so that, instead of trying to cut through seawater, the abrasive water jet 103 cuts in air, which is very much more efficient.
  • a further pipe 121 which terminates a little lower in the casing 111 , below the nozzle 101 , allows excess pressure to be relieved. It also allows debris to be exhausted, particularly during start up.
  • the pipe 121 may terminate higher in the casing, above the nozzle 101 , and the pipe 122 may terminate lower in the casing 111 , below the nozzle 101.
  • FIG. 2 shows casings 111 to 114 generally as shown in Figure 1 , but with a wellhead 105 in position and cement return ports 151 at intervals around the wellhead. It may be seen that the intermediate annuli, between casings 111 and 112, and between casings 112 and 113, are effectively capped by the wellhead 105.
  • the nozzle 101 , jet 103, pipes 104, 121 , 122 and seawater level 123 are omitted, in the interests of clarity. However, in use, those components would be present.
  • socks 161 are filled with a settable material and inserted in their unset state into cement ports 151. When the material sets, it prevents the general escape of compressed air.
  • a nozzle 171 directs into successive cement return ports 151 a rapid-setting, lighter-than-seawater cement 172, which is pumped into the annulus between the outer two casings 113, 114.
  • the cement 172 forms an effective barrier to inhibit the general escape of compressed air.
  • the pipes 104 and 121 will typically communicate with apparatus located at the surface of the water above the wellhead.
  • holes may be formed from inside the casings, and cement (or other sealant) injected through the holes into the annular space(s) between casings.
  • Figure 5 shows a plugging device 1 incorporating a cover 2 to cover an aperture 7 leading to an annular space 8 between outer 9 and middle 10 casing walls of a wellhead.
  • Magnets 3 attach the device to the outer casing 9, with a seal 4 (e.g. an annular O-ring), a locating portion 5, and a handle 6 to allow an operator to manipulate the device 1 into position.
  • a seal 4 e.g. an annular O-ring
  • a locating portion 5 e.g. an annular O-ring
  • handle 6 e.g. an annular O-ring
  • Figure 6 shows an alternative embodiment but without having a seal.
  • the locator 5 includes a resilient material 11 , in a preferred form of a cone, to seal against the walls of the aperture. It will however be appreciated that the seal 4 could also be provided.
  • the plugging device includes an expandable portion 12, such as a balloon, over a projecting portion 13 also serving to locate the device.
  • An “inflation” aperture 14 passes through the cover 2 but does not pass through the expandable portion.
  • the expandable portion may be "inflated” by introducing fluid under pressure through the aperture 14 which may be greater than the counter pressure acting against the expandable portion. However, pressure may be actively applied through that aperture, such as by pumping air or other medium, like a settable flowable material, into the expandable portion.
  • the inflation aperture may thereafter be sealed to retain pressure therein or the material allowed to set firm/solid.
  • a resilient material 15 may be expanded within an aperture to be plugged. This is achieved in the embodiment shown by bringing towards each other a pair of cones 16a, 16b, which may themselves form a locator similar to locator 5. This may be achieved by rotating the handle 6 to operate a helical screw mechanism, thereby drawing together the cones to expand the resilient material.
  • mechanically driven means may be utilised, such as a hydraulic or pneumatic actuator.
  • spring operated actuating means may be adopted, whereby the device is retained in an unactuated state until placed in position and then the spring mechanism released to plug the aperture.
  • FIGS 9 to 16 show further embodiments of plugging devices.
  • a medium with high absorbent properties such as an "oil spill pad” 21
  • a material that expands on contact with water or when mixed which may be a hydrophilic hydro-expanding urethane.
  • the medium is shaped and sized for a particular wellhead cement overflow port to be blocked.
  • the soaked absorbent pad 21 is then placed in a waterproof membrane 22.
  • a weight and/or a small magnet 23 is placed in the bottom of the membrane 22, which is then sealed around the pad 21.
  • the plugging device 20 is then run subsea and placed into a wellhead cement overflow port to be plugged.
  • the purpose of the weight is to make the plugging device 20 neutral to negatively buoyant and the magnet assists in keeping the plugging device 20 in place in the port to be plugged, due to magnetic attraction between the magnet 23 and ferromagnetic material in the vicinity of the port.
  • the waterproof membrane 22 is punctured, allowing the expanding material to react with the seawater. Once expanded, the material fills the port to be plugged and becomes set in position.
  • the plugging device 30 of Figure 10 comprises a hydraulic ram 31 having rubber stops 32 fitted respectively to the cylinder 33 and piston 34, at opposite ends of the ram 31.
  • the plugging device 30 is placed between a wellhead structure and a port to be plugged.
  • Most wellheads have a surrounding frame structure that provides a convenient bracing point.
  • one of the rubber stops 32 plugs the port and the other reacts against the frame, thereby jamming the respective rubber stop 32 in the port to create a seal.
  • the rubber stops may be of hemispherical or any other convenient shape.
  • a plugging device 40 comprises a tool with multiple (here shown with four) independent chambers 41 for applying chemicals in various ratios subsea. Chemicals that react with one another to form a sealing compound are placed in the respective chambers and ejected hydraulically to pass through an in-line static mixer 42 where they react together as they are ejected from the tool.
  • a set of pistons 43 is arranged to be actuated which may be by a hydraulic cylinder or a remotely operated underwater vehicle (ROV) in order to eject the chemicals from the tool.
  • ROV remotely operated underwater vehicle
  • the tool is designed primarily for blocking cement overflow ports and slots (as can be found on older wellhead systems).
  • two chemical components A and B are shown in equal proportions in the chambers 41. This may be particularly suitable for two-part hydrophilic hydro- expanding urethanes. However, any number of chemicals may be mixed in desired ratios by suitable choice of the number of chambers.
  • Figure 12 shows a similar plugging device 50 which has only two chambers.
  • Figure 13 is similar to Figure 12, but shows a plugging device 60 with a flexible expanding membrane 43 at the output of the static mixer 42, in order to contain the sealing compound while it sets.
  • the plugging device 70 shown in Figure 14 comprises a compressible plug 71 (e.g. of rubber), which is constrained between a pair of washers 72.
  • a screwthreaded rod 73 passes through the centre of the plug and washers and has a wing nut 74 and regular nut 75 engaged at opposite ends.
  • the nuts 74, 75 may be tightened by an ROV.
  • the nuts 74 and/or 75 may be replaced by a bolt with captive nut or other convenient arrangement to enable the assembly to be tightened reliably from one end.
  • the plug 71 has two separate internal spaces 76, 77 which are sealed from one another and contain respective chemical components A and B (e.g. of a two-part resin) and also a rotatable blade 78.
  • a and B e.g. of a two-part resin
  • the blade 78 rotates to rupture an internal dividing wall so that the two chemical components A and B are mixed together to react, expand and then set, thereby locking the plugging device 70 firmly in place in a port to be plugged.
  • a plugging device 80 comprises a rubber toroid 81 which is expanded radially outwardly by two cones 82 that are urged together by a hydraulic actuator 83.
  • the toroid 81 may contain two or more chemical components that become mixed together as the toroid is expanded such that they react, expand and then set, thereby locking the plugging device 80 firmly in place in a port to be plugged.
  • liquid nitrogen 181 is delivered through pipes 180 to the vicinity of ports 151 in order to freeze the water locally 182 and thereby block the ports 151.
  • the pipes 180 may extend into the outer annulus between the outermost casings. Since seawater is generally cold at typical wellhead depths, the water may remain frozen long enough for a cutting operation to be completed.
  • one or more plugging devices are placed over respective apertures in the undersea structure, such as an abandoned wellhead.
  • a low density medium such as air is pumped into the structure to expel water and/or hydrocarbon bearing liquid from the structure.
  • the apertures need not be completely sealed provided the air can be pumped into the space to be evacuated at a greater rate than is lost through leakage.
  • the water etc is expelled under pressure. This creates an air filled environment which is of lower density than the previous water/hydrocarbon filled space, and therefore easier for cutting operations e.g. to sever the wellhead by reducing energy losses in the cutting jet.
  • the illustrated methods and apparatus are for cutting subsea casing strings, the methods and apparatus may be adapted to cut other components underwater.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)
  • Excavating Of Shafts Or Tunnels (AREA)
  • Processing Of Stones Or Stones Resemblance Materials (AREA)
  • Perforating, Stamping-Out Or Severing By Means Other Than Cutting (AREA)
  • Placing Or Removing Of Piles Or Sheet Piles, Or Accessories Thereof (AREA)

Abstract

L'invention concerne un ensemble de tubages concentriques (111) à (114) placés sur le fond marin (102). Un agent abrasif (103) de découpe est éjecté sous haute pression à partir d’une buse (101) située à l’extrémité d’une conduite (104) afin de découper les tubages (111) à (114) de telle sorte que leurs parties supérieures, et une éventuelle tête de puits associée, puissent être éliminées. De l’air est acheminé sous haute pression jusque dans le tubage intérieur (111) via la conduite (122), afin de chasser ainsi  l’eau (123) de mer présente dans le tubage intérieur (111) de telle sorte qu’au lieu de tenter de couper à travers l’eau de mer, le jet d’eau abrasif (103) coupe dans l’air, ce qui accroît considérablement le rendement. Sur la Figure (3), des manchons(161) sont remplis d’un matériau durcissable et insérés à l’état non durci dans des orifices (151) à ciment. Lorsque le matériau durcit, il empêche de façon générale la fuite d’air comprimé. On décrit également divers autres dispositifs d’obturation.
PCT/GB2009/050305 2008-04-05 2009-03-30 Procédé de création d’une zone de découpe subaquatique, dispositifs et procédés d’obturation associés Ceased WO2009122203A1 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
AU2009233524A AU2009233524B8 (en) 2008-04-05 2009-03-30 Method of creating an underwater cutting zone, and related plugging devices and methods
EP09726842A EP2288471B1 (fr) 2008-04-05 2009-03-30 Procédé de création d'une zone de découpe subaquatique, dispositifs et procédés d'obturation associés

Applications Claiming Priority (6)

Application Number Priority Date Filing Date Title
GB0806162A GB0806162D0 (en) 2008-04-05 2008-04-05 Underwater cutting methods
GB0806162.4 2008-04-05
AU2008902729 2008-05-30
AU2008902729A AU2008902729A0 (en) 2008-05-30 Method of Creating an Underwater Cutting Zone, and Related Plugging Devices and Methods
AU2008902776A AU2008902776A0 (en) 2008-06-02 Products, Methods and Apparatus for Underwater Cutting
AU2008902776 2008-06-02

Publications (1)

Publication Number Publication Date
WO2009122203A1 true WO2009122203A1 (fr) 2009-10-08

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PCT/GB2009/050305 Ceased WO2009122203A1 (fr) 2008-04-05 2009-03-30 Procédé de création d’une zone de découpe subaquatique, dispositifs et procédés d’obturation associés

Country Status (4)

Country Link
EP (1) EP2288471B1 (fr)
AU (1) AU2009233524B8 (fr)
GB (1) GB2458786B (fr)
WO (1) WO2009122203A1 (fr)

Cited By (4)

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WO2011074981A1 (fr) * 2009-12-17 2011-06-23 Norse Cutting & Abandonment As Procédé et dispositif pour fermer un puits
US8307903B2 (en) 2009-06-24 2012-11-13 Weatherford / Lamb, Inc. Methods and apparatus for subsea well intervention and subsea wellhead retrieval
US10385640B2 (en) 2017-01-10 2019-08-20 Weatherford Technology Holdings, Llc Tension cutting casing and wellhead retrieval system
EP4055247A4 (fr) * 2019-11-06 2023-12-06 Petroliam Nasional Berhad (Petronas) Système et procédé de coupe de structures en mer

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US8307903B2 (en) 2009-06-24 2012-11-13 Weatherford / Lamb, Inc. Methods and apparatus for subsea well intervention and subsea wellhead retrieval
US8662182B2 (en) 2009-06-24 2014-03-04 Weatherford/Lamb, Inc. Methods and apparatus for subsea well intervention and subsea wellhead retrieval
WO2011074981A1 (fr) * 2009-12-17 2011-06-23 Norse Cutting & Abandonment As Procédé et dispositif pour fermer un puits
US10385640B2 (en) 2017-01-10 2019-08-20 Weatherford Technology Holdings, Llc Tension cutting casing and wellhead retrieval system
EP4055247A4 (fr) * 2019-11-06 2023-12-06 Petroliam Nasional Berhad (Petronas) Système et procédé de coupe de structures en mer
US12220787B2 (en) 2019-11-06 2025-02-11 Petroliam Nasional Berhad (Petronas) System and method for cutting of offshore structures

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AU2009233524B8 (en) 2015-06-25
AU2009233524A8 (en) 2015-06-25
GB0905334D0 (en) 2009-05-13
AU2009233524A1 (en) 2009-10-08
EP2288471B1 (fr) 2012-07-04
GB2458786A (en) 2009-10-07
AU2009233524B2 (en) 2015-05-28
EP2288471A1 (fr) 2011-03-02
GB2458786B (en) 2010-08-04

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