WO2007085047A1 - Dispositif de colmatage a distance pour puits - Google Patents

Dispositif de colmatage a distance pour puits Download PDF

Info

Publication number
WO2007085047A1
WO2007085047A1 PCT/AU2007/000065 AU2007000065W WO2007085047A1 WO 2007085047 A1 WO2007085047 A1 WO 2007085047A1 AU 2007000065 W AU2007000065 W AU 2007000065W WO 2007085047 A1 WO2007085047 A1 WO 2007085047A1
Authority
WO
WIPO (PCT)
Prior art keywords
punch
casing
well
sealant
hydraulic
Prior art date
Application number
PCT/AU2007/000065
Other languages
English (en)
Inventor
Jonathon Paul Edwards
Alexander Jeffrey Burns
Original Assignee
Well Ops Sea Pty 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 AU2006900347A external-priority patent/AU2006900347A0/en
Application filed by Well Ops Sea Pty Ltd filed Critical Well Ops Sea Pty Ltd
Priority to AU2007209762A priority Critical patent/AU2007209762A1/en
Priority to US12/162,083 priority patent/US20090301720A1/en
Priority to MX2008009622A priority patent/MX2008009622A/es
Priority to EP07701400A priority patent/EP1982045A1/fr
Publication of WO2007085047A1 publication Critical patent/WO2007085047A1/fr

Links

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
    • 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
    • E21B33/14—Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
    • E21B33/146—Stage cementing, i.e. discharging cement from casing at different levels
    • 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
    • E21B43/11—Perforators; Permeators
    • E21B43/112—Perforators with extendable perforating members, e.g. actuated by fluid means

Definitions

  • the present invention relates to the plugging of hydrocarbon wells, particularly subsea hydrocarbon wells, when barriers must be maintained between the hydrocarbon formation and the surface to prevent hydrocarbon contamination by leakage from the well.
  • Barrier systems for offshore wells consist of active and passive systems, with the passive systems a physical barrier is maintained between the formation and the seabed. Active systems are designed then in the case of an emergency or in unforeseen circumstance the active system deploys to provide a barrier between the formation and the seabed.
  • active systems When abandoning an offshore well the use of active systems to maintain the barriers between the seabed and the formation is not suitable as there will be no ongoing maintenance of the barrier. Further during removal of the well head of the subsea well one of the barriers covering the annulus between the inner casing and the first intermediate casing is removed and needs to be replaced prior to severing the well head.
  • a cement plug is cast into the central casing and cement is injected into the annulus between the central casing and the first intermediate casing.
  • To pump the cement into the annulus it is first necessary to provide a pathway for the cement to travel from the central casing into to the annulus. This is usually done by the use of explosives to puncture holes in the central casing through to the annulus.
  • explosives When a subsea well is abandoned the use of a jack up oil rig, work barge or semi submersible has traditionally been used.
  • the production of holes in the casing through to the annulus is usually by the use of explosives.
  • There are several issues with the use of explosives not least of which is the safety aspects. Further a large stable platform must be provided so that explosives can be safely handled.
  • the present invention provides a device for oil field operations including means for perforating holes in a wall of a first well casing and means for injecting sealant into an annulus between the first well casing and a second well casing, including at least one punch assembly, a cutting tool the cutting tool being designed to produce a hole in the casing and a sealant delivery means. wherein the tool is able to perforate the holes and deliver sealant to the annulus without the need to withdraw the tool from the well casing.
  • a further aspect of the present invention provides a remote plugging device for well operations, including at least one perforating means for perforating at least one hole through one or more well casings, and sealant injection means to inject sealant between at least one of said one or more well casings and at least another of said well casings or a further well casing, wherein the perforating means includes at least one punch actuated by pressurised fluid to perforate the at least one the hole, and thereafter the sealant is delivered to the annulus to form the sealant plug without the need to withdraw the device from the well casing.
  • the device and ancillary equipment is adapted for deployment from a work boat for use in subsea applications.
  • a remote plugging device for well operations including at least one perforating means for perforating at least one hole through a wall of a first well casing, and injection means to inject a sealant into an annulus between the first well casing and a second well casing, wherein the perforating means includes at least one punch actuated by compressed fluid to perforate the at least one the hole, and thereafter the sealant is delivered to the annulus to form the sealant plug without the need to withdraw the device from the well casing.
  • the sealant is cement based, or may be a none setting medium such as drilling mud.
  • Actuation of the punch(s) by compressed fluid advantageously avoids the need for explosive charges to effect perforation.
  • the at least one punch may be actuated by hydraulic or pneumatic pressure.
  • the at least one punch may be extended or retracted by at least one double acting hydraulic or pneumatic piston, which provides positive actuation and retraction to assist in ensuring that the perforator(s) is/are retracted so that the sealant can flow through the perforation(s).
  • the at least one punch may be extended by hydraulic or pneumatic pressure and retracted by at least one resilient biasing means, which simplifies the means of return actuation, such as by return spring(s).
  • At least one packer assembly may be provided, whereby, when the packer assembly or assemblies is/are expanded to hold the device by pressure inside the well casing e.g. by pressure against an interior wall of the inner casing of the well.
  • packers may be energized by hydraulic or pneumatic pressure.
  • packers may be provided which are self energizing. These may expand as a result of initial pressure from a pressurized fluid supply line (e.g. from the surface) or from hydrocarbon escaping through at least one hole made by the device. The applied pressure causes the packers to seal the device within the bore prior to the sealant being pumped into the hole(s).
  • the device may include at least one fluid pressure accumulator, preferably hydraulic or pneumatic accumulators), within or proximate to a leading nose end of the device, the accumulator providing fluid pressure to the at least one packer assembly in the event of a failure of the device. Fluid pressure may be supplied from the hydraulic or pneumatic supply used to actuate the perforation means.
  • At least two of the perforation means may be spaced apart such that the distance between a first punch of a first perforation means and a first punch of a second perforation means is greater than a length of coupling members used to couple together lengths of well casing.
  • One or more of the punches may have a breakaway shaft such that in the event of the punch being jammed in the perforated hole, the piston and base of the punch can be positively retracted and a working end of the punch sheared off. At least one of the punches may be retained to the piston by a quick release means, such as by a quick release ring, clip or other retainer.
  • At least one resilient packer may be provided which absorbs shock induced on the respective punch during perforation of the casing. Silicon rubber, rubber, nitrile, or the like, or combinations thereof may be used.
  • the perforating means may be adapted to perforate consecutive holes through multiple casing walls, one after the other. That is, where the well has multiple casings one within another, the perforator may, for example, perforate a hole through more than one casing to set a sealant (e.g. cement) plug between the first and/or second and third concentric casings.
  • a sealant e.g. cement
  • a further aspect of the present invention provides a method of sealing a well riser, including the steps of; a) inserting a remote plugging device into a riser; b) supplying compressed fluid to the plugging device; c) perforating at least one hole through at least a first well casing using at least one respective punch actuated by the compressed fluid; and d) pumping a sealant through said at least one hole into an annulus between the at least one first casing and a second or intermediate casing to form a plug seal.
  • the method may further include the steps of perforating one or more holes with a respective at least one punch, and leaving at least one said punch extended to act as an anchor for the device.
  • one or more punches may remain unretracted to anchor the device.
  • this anchoring arrangement can assist in maintaining the device in place.
  • An accumulator may be employed to provide sufficient pressure to maintain the at least one punch extended.
  • a one way or check valve may be employed to prevent pressure loss once the hydraulic or pneumatic feed is removed from the device.
  • the method may include withdrawing the at least one punch from at least one respective hole.
  • the device may pump fluid around, through, or a combination thereof, the at least one punch; Hydraulic fluid may be used to actuate the punch(s).
  • the sealant contains cement.
  • Retraction of the at least one punch may be by hydraulic or pneumatic pressure.
  • extending the at least one punch may be by hydraulic or pneumatic pressure and retraction by resilient biasing means.
  • Perforating said at least one hole may be through a multiplicity of well casing walls, and injecting the sealant into the annulus between at least one of said multiplicity of walls and a further casing wall.
  • Figure 1 shows an overview of an embodiment of the device.
  • Figure 2 shows a section of the entry nose and lower packer assembly of the embodiment shown in Figure 1.
  • Figure 3 shows a section of hydraulic punch assembly of the embodiment shown in Figure 1.
  • Figure 4 shows the lower perforation tool of figure 1 in more detail.
  • Figure 5 shows an alternative embodiment of the device.
  • Figures 6a shows a sectional view of an alternative embodiment of the device including spring return hydraulic pistons.
  • Figure 6b shows a perspective view of the complete device of figure 6a.
  • Figure 7a is a perspective view of a perforation assembly of an embodiment of the present invention.
  • Figure 7b is a sectional view of the embodiment shown in Figure 7a.
  • the invention will now be described with reference to the accompanying figures. Referring first to Figure 1 that shows an overview of the remote plugging device herein after referred to as the "tool". Whilst cement is referred to hereinafter as the sealant, it will be appreciated that other sealants may be employed, such as drilling mud.
  • the construction of the tool 10 is based on modular construction methods so that individual components can be replaced if they are damaged during an offshore campaign. Other possible arrangement of the components are possible provide that they allow for the operation of the tool 10 such that the casing is perforated and cement is injected into the annulus. Only a typical example is described in the following detailed description.
  • the overall layout of the tool 10 includes of an entry nose 20 at a leading end 25, designed to allow the cement injection tool 10 to be inserted into a subsea well.
  • the entry nose 20 is connected to a lower packer mandrel 30 that has a packer assembly 40 fitted.
  • This packer assembly 40 is designed so that when the tool 10 is inserted into the inner casing of the subsea well, the packer assembly 40 can expand and hold the tool 10 in place and seal the tool 10 in the casing.
  • the lower packer mandrel 30 is connected to a hydraulic module 50 at the hydraulic module first end 52.
  • the hydraulic module 50 consists of a number of punch assemblies 60 with punches 65.
  • the punch assemblies 60 are arranged circumferentially around the hydraulic module 50 and are designed so that they can punch holes in the inner casing. It will however be appreciated that at least one said punch may be used to perforate through more than one casing wall, such that sealant can be pumped into the annulus or cavity between further casings e.g, between the inner and intermediate casing, and between the intermediate casing and an outer casing.
  • a cement exit port 75 At the hydraulic module second end 54, there is a cement exit port 75.
  • an upper packer mandrel 80 which includes a packer assembly 90 to seal the tool 10 into the well inner casing attached to the second end 81 of the upper packer mandrel 80 there is a breakaway barrier 70.
  • the entry nose 20 is designed with a taper 22 at the leading end thereof to allow for positioning the tool in a subsea well and to guide the tool 10 in to the well inner casing during deployment of the tool 10.
  • the entry nose 20 has also been designed to incorporated a hydraulic accumulator 25.
  • the hydraulic accumulator 25 is used to provide hydraulic pressure to the packer assemblies 40, 90 in the event of a failure in the tool 10 necessitating abandonment of the tool 10 in the well.
  • the hydraulic accumulator 25 allows for the tool 10 to act as a barrier in the event that the tool 10 needs to be abandoned.
  • the entry nose 20 may be held by a threaded portion 28 to the first end 31 lower packer mandrel 30.
  • the lower packer mandrel 30 is generally hollow but could be made of a range of materials or densities to provide the desired buoyancy characteristics of the tool 10.
  • the packer assembly 40 associated with the lower packer mandrel 30 is designed that once subjected to a hydraulic pressure, the packer assembly 40 can expand and seal against the inner casing.
  • the pressure that can be applied to the packer assembly 40 is approximately 5000psi, but could be more on some applications.
  • packer mandrel threaded portion 33 that connects the lower packer mandrel 30 to the hydraulic module 50 at the hydraulic module first end 52.
  • the hydraulic module 50 is the module that contains active hydraulic components and the tooling required to perforate holes through the well inner casing.
  • the hydraulic module 50 includes at least one hydraulic punch assembly 60, though there may be as many as ten or more hydraulic punch assemblies 60.
  • the spacing and orientation of the hydraulic punch assemblies 60 is such that holes can be perforated through the inner casing in different locations around the circumference of the inner casing and in different positions vertically along the inner casing.
  • the punch assemblies 60 are spaced apart such that the distance between a first punch 62 and second and subsequent punches 65 is greater than the length of the coupling members not shown normally used to couple lengths of well casing together.
  • breakaway barrier 70 At the second end of the upper punch mandrel 82 there is a breakaway barrier 70.
  • This breakaway barrier 70 is designed such that should the device need to be abandoned in the well due to unforeseen circumstances, the well remains plugged such that the contents of the well will not leak.
  • the breakaway barrier 70 has hydraulic lines and coupling check valves connected so that in the event of a breakaway event, the hydraulic pressure in the packer assemblies 40 90 remains constant, thus, ensuring that the packer assemblies 40 90 are held firmly in place against the inner casing.
  • the breakaway barrier 70 is designed to have locking pins to take a predetermined load.
  • These locking pins are designed to have sufficient strength that the tool 10 can be extracted from the inner casing even with residual cement surrounding the hydraulic module 50 yet can be broken away in the event that the tool 10 must be abandoned.
  • a typical breakaway load is 25 tons but this load could be varied depending on the application of the tool 10.
  • the breakaway barrier 70 also includes a check valve on the sealant line that may be actuated by hydraulic pressure or automatically actuated (e.g. by spring loaded pressure).
  • This check valve may be located in the upper packer mandrel 80 the check valve can be a normally closed check valve that is actuated by hydraulic pressure, or pneumatic pressure.
  • the tool may be provided with a number of lines that communicate with the vessel (not shown). These lines will include hydraulic, control, monitoring and bypass lines. These line allow for the tool 10 to be operated from the vessel and parameters such as the pressure in the well can be monitored.
  • the hydraulic punch cylinder assemblies 60 include two way hydraulic pistons 61 capable of at least 5000 psi or more, though the upper pressure limit may vary depending on the expected loads required to perforate the casing.
  • the hydraulic pistons are fitted with punches 65 used to perforate the inner casing.
  • the two-way piston is selected to ensure that the punch 65 can be retracted once a hole has been perforated in the inner casing.
  • the two way type of hydraulic punch assembly includes a hydraulic feed 69 to provide hydraulic pressure to retract the piston
  • the punch 65 is manufactured of a tool steel and is used to punch holes in the inner casing.
  • the punch 65 is designed with a breakaway shaft 66 so that in the event of the punch 65 being jammed in the perforated hole in the inner casing the hydraulic piston 61 can be positively retracted and the punch 65 sheared.
  • the punch 65 is held into the punch piston assemblies with a quick release ring 67. This quick release ring can be removed to allow for field removal and replacement of the punch 65 in the situation where multiple wells are being abandoned and a punch 65 requires replacement.
  • these would preferably be non-breakaway punches, such that the punches remain extended to hold the device in place.
  • the resilient packer 68 may be made out of a range of materials capable of absorbing a shock load. Preferred materials are ultra high molecular weight synthetic materials, such as PEEK, UHMPE, HFPE, or Nylon etc, or other water stable dense synthetic materials.
  • the hydraulic pistons 61 are not two way hydraulic pistons but use the pressure of the cement or formation to retract the hydraulic pistons 61 once the holes have been punched.
  • the use of spring actuated hydraulic pistons may be used when the tool 10 is intended to be abandoned in the well.
  • FIG 4 shows the hydraulic module 50 of the lower perforation tool of figure 1 in more detail.
  • the module that contains active hydraulic components and the tooling required to perforate holes through the well inner casing.
  • the hydraulic module includes at least one hydraulic punch assemblies 60, and one of the cement feed outlets 75.
  • Figure 5 shows an alternative embodiment of the device including first 60a and second 60b lower perforation assemblies, and first 60c and second 6Od upper perforation assemblies. These are connected via a cable link 110 of variable length "D" to suit a particular application.
  • Upper cup packer 112a and lower cup packer 112b are provided. These act to provide a seal between the device and the casing wall to prevent cement from flowing beyond the packer. They also provide a pressure seal if hydrocarbons present after perforating would otherwise leak out.
  • Upper and lower bore supply ports 114 are provided. These ports supply cement respectively to the upper and lower sections of the device.
  • Figures 6a and 6b shows a further embodiment including single acting spring biased hydraulic punches 65a-65d.
  • the punches are hydraulically extended to create holes through the inner casing of the bore, and are biased by spring pressure to the retracted position shown in the figures.
  • Figures 7a and 7b show one of the hydraulic perforation assemblies 60.
  • Figure 7a is a perspective view of the assembly with a punch 65.
  • Figure 7b of the assembly 60 With the hydraulic piston 61b retracted within the body 61a of the assembly.
  • the punch 65 is retained in place by a screw fit ring 120 analogous to the quick release ring in Figure 3.
  • Grub screws 122a and 122b retain the hydraulic cylinder 61a within the casing 124.
  • a hydraulic release shackle 116 is provided (analogous to the breakaway system previously described), which allows the device to be completely uncoupled i.e. in the event that the device becomes unrecoverable from the well. Annulus bore pressure monitoring and bleed off ports are provided.
  • the cement injection tool 10 is lowered from a vessel 1 and with the assistance of divers or an ROV is positioned into the inner casing of a subsea well.
  • hydraulic pressure is applied forcing the packer assemblies 40, 90 to lock the cement injection tool 10 against the inner casing walls.
  • the packers are then tested to ensure there are no leaks. Hydraulic pressure is then applied to each of the punch assembly 60 in turn resulting in a series of holes being perforated in the inner casing. Any pressure from the annulus is then bled off in a controlled manner either into the sea or into a tank on the vessel.
  • the hole punching will result in multiple holes being punched in the inner casing, the holes being evenly distributed around the circumference and along a length of the inner casing.
  • a cement inhibitor is injected to inhibit the setting of the cement in the crevices and joints surrounding the packer assemblies and the punch assemblies.
  • the inhibiter is injected through the cement injection port 54, it then travels down past the hydraulics in the hydraulic module 50.
  • cement injection port 54 After the inhibiter has been injected, cement is injected through the cement injection port 54 and flows around the hydraulic module 50 and through the holes punched in the inner casing into the annulus between the inner casing and the first intermediate casing. Once the cement is injected into this annulus and pressure tested, the packer assemblies are released and the cement injection tool 10 is extracted.
  • the punch assembly 60 includes hydraulics specifically designed for this application, which include a double acting hydraulic piston 61 (positive displacement and retraction piston). This is designed so that the punch 65 can be forcibly retracted from the inner casing in the event of a problem.
  • the punch includes hydraulics specifically designed for this application, which include a double acting hydraulic piston 61 (positive displacement and retraction piston). This is designed so that the punch 65 can be forcibly retracted from the inner casing in the event of a problem.
  • the punch assembly 60 includes hydraulics specifically designed for this application, which include a double acting hydraulic piston 61 (positive displacement and retraction piston). This is designed so that the punch 65 can be forcibly retracted from the inner casing in the event of a problem.
  • the punch assembly 60 includes hydraulics specifically designed for this application, which include a double acting hydraulic piston 61 (positive displacement and retraction piston). This is designed so that the punch 65 can be forcibly retracted from the inner casing in the event of a problem.

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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)
  • Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)

Abstract

L’invention concerne un dispositif de colmatage au ciment à distance (10) et son procédé d’utilisation. Le dispositif comprend au moins un moyen (60) servant à percer au moins un trou à travers une paroi d’un premier tubage de puits, et un moyen servant à injecter du ciment dans un espace annulaire entre le premier tubage intérieur de puits et un deuxième tubage de puits. Le moyen de perçage comprend au moins un poinçon (65) actionné par un fluide comprimé (hydraulique, pneumatique) pour former le(s) trou(s). Le ciment est ensuite introduit dans l’espace annulaire entre les tubages intérieur et extérieur/intermédiaire pour former le bouchon de colmatage au ciment sans nécessiter le retrait du dispositif du tubage de puits.
PCT/AU2007/000065 2006-01-24 2007-01-24 Dispositif de colmatage a distance pour puits WO2007085047A1 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
AU2007209762A AU2007209762A1 (en) 2006-01-24 2007-01-24 Remote plugging device for wells
US12/162,083 US20090301720A1 (en) 2006-01-24 2007-01-24 Remote plugging device for wells
MX2008009622A MX2008009622A (es) 2006-01-24 2007-01-24 Dispositivo de sellado remoro para pozos.
EP07701400A EP1982045A1 (fr) 2006-01-24 2007-01-24 Dispositif de colmatage a distance pour puits

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
AU2006900347A AU2006900347A0 (en) 2006-01-24 Cement injection
AU2006900347 2006-01-24

Publications (1)

Publication Number Publication Date
WO2007085047A1 true WO2007085047A1 (fr) 2007-08-02

Family

ID=38308779

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/AU2007/000065 WO2007085047A1 (fr) 2006-01-24 2007-01-24 Dispositif de colmatage a distance pour puits

Country Status (5)

Country Link
US (1) US20090301720A1 (fr)
EP (1) EP1982045A1 (fr)
AU (1) AU2007209762A1 (fr)
MX (1) MX2008009622A (fr)
WO (1) WO2007085047A1 (fr)

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EP2574721A1 (fr) * 2011-09-30 2013-04-03 Welltec A/S Outil de poinçonnage

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CN104632124B (zh) * 2013-11-15 2017-06-06 中国石油天然气股份有限公司 一种污染严重的深井砂岩储层封堵方法
WO2015175025A1 (fr) * 2014-05-16 2015-11-19 Aarbakke Innovation A.S. Outil de penetration tubulaire de puits de forage multifonction
US9797219B2 (en) 2014-10-23 2017-10-24 Saudi Arabian Oil Company Remedial second-stage cementing packer
US10214988B2 (en) 2015-08-12 2019-02-26 Csi Technologies Llc Riserless abandonment operation using sealant and cement
US10378299B2 (en) 2017-06-08 2019-08-13 Csi Technologies Llc Method of producing resin composite with required thermal and mechanical properties to form a durable well seal in applications
US10428261B2 (en) 2017-06-08 2019-10-01 Csi Technologies Llc Resin composite with overloaded solids for well sealing applications
WO2019103780A1 (fr) * 2017-11-22 2019-05-31 Exxonmobil Upstream Research Company Dispositifs de perforation comprenant des structures d'alimentation en gaz et leurs procédés d'utilisation
WO2020009695A1 (fr) 2018-07-03 2020-01-09 Halliburton Energy Services, Inc. Procédé et appareil de pincement de lignes de commande
GB2590319B (en) * 2018-07-16 2022-07-20 Aarbakke Innovation As Method and apparatus for sealing a side pocket mandrel
WO2020229440A1 (fr) * 2019-05-15 2020-11-19 Shell Internationale Research Maatschappij B.V. Poinçon et outil d'injection pour tubage de fond de trou et procédé d'utilisation correspondant
US11767732B2 (en) 2021-03-29 2023-09-26 Halliburton Energy Services, Inc. Systems and methods for plugging a well
US11920425B2 (en) * 2022-02-16 2024-03-05 Saudi Arabian Oil Company Intelligent detect, punch, isolate, and squeeze system

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US4709760A (en) * 1981-10-23 1987-12-01 Crist Wilmer W Cementing tool
GB2275282A (en) * 1993-02-11 1994-08-24 Halliburton Co Abandonment of sub-sea wells
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Cited By (3)

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Publication number Priority date Publication date Assignee Title
EP2574721A1 (fr) * 2011-09-30 2013-04-03 Welltec A/S Outil de poinçonnage
WO2013045550A1 (fr) * 2011-09-30 2013-04-04 Welltec A/S Outil de poinçonnage
CN103797212A (zh) * 2011-09-30 2014-05-14 韦尔泰克有限公司 冲击工具

Also Published As

Publication number Publication date
AU2007209762A1 (en) 2007-08-02
US20090301720A1 (en) 2009-12-10
EP1982045A1 (fr) 2008-10-22
MX2008009622A (es) 2008-12-19

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