EP2006486A2 - Abandon de puits en une seule manoeuvre avec des garnitures d'étanchéité permanentes doubles et canon de perforation - Google Patents

Abandon de puits en une seule manoeuvre avec des garnitures d'étanchéité permanentes doubles et canon de perforation Download PDF

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Publication number
EP2006486A2
EP2006486A2 EP08251821A EP08251821A EP2006486A2 EP 2006486 A2 EP2006486 A2 EP 2006486A2 EP 08251821 A EP08251821 A EP 08251821A EP 08251821 A EP08251821 A EP 08251821A EP 2006486 A2 EP2006486 A2 EP 2006486A2
Authority
EP
European Patent Office
Prior art keywords
packer
tool string
wellbore
packer assembly
perforating gun
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Withdrawn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
EP08251821A
Other languages
German (de)
English (en)
Other versions
EP2006486A3 (fr
Inventor
John H. Hales
John D. Burleson
Gavin H. Drummond
R. George Flint
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.)
Halliburton Energy Services Inc
Original Assignee
Halliburton Energy Services Inc
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 Halliburton Energy Services Inc filed Critical Halliburton Energy Services Inc
Publication of EP2006486A2 publication Critical patent/EP2006486A2/fr
Publication of EP2006486A3 publication Critical patent/EP2006486A3/fr
Withdrawn legal-status Critical Current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
    • 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
    • E21B33/134—Bridging plugs
    • 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
    • E21B33/12—Packers; Plugs
    • 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
    • E21B33/12—Packers; Plugs
    • E21B33/124—Units with longitudinally-spaced plugs for isolating the intermediate space

Definitions

  • the present invention relates generally to operations performed and equipment utilized in conjunction with a subterranean well and, in an embodiment described herein, more particularly provides a single trip well abandonment system and method with dual permanent packers and perforating gun.
  • a method of abandoning a well or a portion thereof includes the steps of: assembling a tool string including a perforating gun interconnected between first and second packer assemblies; conveying the tool string into a wellbore in a single trip into the wellbore; setting the packer assemblies; firing the perforating gun; and flowing cement into an annulus longitudinally between the packer assemblies.
  • the assembling step may include providing a permanent packer in each of the first and second packer assemblies.
  • the first packer assembly setting step may further comprise reciprocating the tool string in the wellbore to grippingly engage an anchoring device in the wellbore, and then compressing the tool string against the anchoring device to set the first packer assembly.
  • the tool string compressing step may further comprise using a compressive force to apply fluid pressure to a piston to thereby apply a tensile force to a mandrel of the first packer assembly.
  • the second packer assembly setting step ideally further comprises rotating a work string releasably attached to the tool string.
  • the second packer assembly setting step ideally further comprises applying pressure to the second packer assembly.
  • the method may, further comprise the step of releasing the perforating gun from a packer of the first packer assembly after the first packer assembly setting step, and prior to the second packer assembly setting step.
  • the cement flowing step may further comprise flowing cement into perforations formed by the perforating gun.
  • the cement flowing step may further comprise flowing cement into an annulus outside of casing lining the wellbore.
  • the perforating gun firing step may further comprise applying pressure to a firing head of the tool string.
  • the conveying step further comprises conveying the tool string on a work string, the method further comprising the step of closing a valve of the second packer assembly by separating the tool string from the work string after the cement flowing step.
  • a system for abandoning a well or a portion thereof includes a tool string configured for conveyance into a wellbore in a single trip into the wellbore.
  • the tool string includes a perforating gun interconnected between first and second packer assemblies.
  • Each of the packer assemblies includes a permanent packer.
  • the first packer assembly may further comprise a setting tool which applies pressure to set the permanent packer of the first packer assembly in response to compression of the tool string.
  • the first packer assembly may further comprise an anchoring device for grippingly engaging the wellbore prior to setting the permanent packer of the first packer assembly.
  • the system may, further comprise a work string engaged with the tool string for conveying the tool string into the wellbore, and the second packer assembly may comprise a valve which closes in response to separation of the work string from the tool string. The valve may selectively permit and prevent fluid flow through a sidewall of the second packer assembly.
  • the perforating gun is releasable from the permanent packer of the first packer assembly after the permanent packer of the first packer assembly is set.
  • the system may further comprise cement flowed into the wellbore between the first and second packer assemblies and hardened therein.
  • the cement extends into perforations formed by the perforating gun.
  • the cement may extend into an annulus outside of casing lining the wellbore.
  • the system may, further comprise a firing head which initiates firing of the perforating gun in response to pressure applied to the firing head.
  • a method of abandoning a well or a portion thereof includes the steps of:
  • the assembling step may further comprise interconnecting a perforating gun between the first and second packer assemblies.
  • the method further comprises the step of forming perforations in the wellbore by firing the perforating gun, wherein the cement flowing step further comprises flowing cement into the perforations.
  • the method may further comprise the step of releasing the perforating gun from a packer of the first packer assembly after the first packer assembly setting step, and prior to the second packer assembly setting step.
  • the cement flowing step may further comprise flowing cement into perforations between the first and second packer assemblies.
  • the cement flowing step may further comprise flowing cement into an annulus outside of casing lining the wellbore.
  • the assembling step includes providing a permanent packer in each of the first and second packer assemblies.
  • the first packer assembly setting step may further comprise reciprocating the tool string in the wellbore to grippingly engage an anchoring device in the wellbore, and then compressing the tool string against the anchoring device to set the first packer assembly.
  • the tool string compressing step may further comprise using a compressive force to apply fluid pressure to a piston to thereby apply a tensile force to a mandrel of the first packer assembly.
  • the conveying step may further comprise conveying the tool string on a work string, the method further comprising the step of closing a valve of the second packer assembly by separating the tool string from the work string after the cement flowing step.
  • FIGS. 1-5 Representatively illustrated in FIGS. 1-5 is a well abandonment system 10 and associated method which embody principles of the present invention.
  • the system 10 and method allow a well abandonment operation to be performed in only a single trip, thereby substantially reducing the cost and time required to perform the operation.
  • the system 10 includes a perforating gun 14 interconnected between two packer assemblies 16, 18. These components are part of a tool string 12 which may be conveyed into the wellbore 20 by a work string 34 (such as drill pipe, production tubing, coiled tubing, etc.). Other types of conveyances (such as wireline, slickline, etc.) may be used instead, if desired.
  • a work string 34 such as drill pipe, production tubing, coiled tubing, etc.
  • Other types of conveyances such as wireline, slickline, etc.
  • each of the packer assemblies 16, 18 includes a permanent packer 24, 26.
  • Permanent packers are designed for permanent installation in a well, and do not include release mechanisms such as those used to release retrievable packers.
  • FIG. 1 the perforating gun 14 and packer assemblies 16, 18 are being conveyed into the wellbore 20 using the work string 34.
  • a valve 40 of the upper packer assembly 18 may be open at this time to permit fluid circulation through the work string 34.
  • the tool string 12 has been appropriately positioned in the wellbore 20 at a desired depth.
  • the lower packer 24 is set to isolate the wellbore 20 below the packer.
  • a setting tool 42 is used which sets the packer in response to compression of the tool string 12 by applying set down weight to the tool string.
  • An anchoring device 28 (not shown in FIG. 2 , see FIGS. 6G & H ) is included in the tool string 12 and grips the wellbore 20 below the packer 24 to allow set down weight to be applied to the setting tool 42.
  • the setting tool 42 releases from the packer 24. This allows the remainder of the tool string 12 to be displaced upwardly in the wellbore 20 away from the packer 24.
  • the upper packer 26 is set by rotating the work string 34 from the surface.
  • a conventional rotational packer setting tool 106 may be included in the work string 34.
  • other methods of setting the upper packer 26 may be used, if desired.
  • the perforating gun 14 has been fired (e.g., by detonating explosive shaped charges therein) to thereby form perforations 38 through casing 44 lining the wellbore 20.
  • the perforating gun 14 is preferably fired by applying increased pressure to a conventional pressure operated firing head 36 connected to the perforating gun.
  • cement 22 and any abandonment fluids have been flowed through the work string 34 to the tool string 12, and out of the open valve 40 into the wellbore 20 between the packers 24, 26.
  • the cement 22 also flows into the perforations 38, and any abandonment fluids may also flow into the annulus behind the casing and into the formation surrounding the wellbore 20.
  • the work string 34 is then separated from the tool string 12, which causes the valve 40 to close.
  • the cement 22 is allowed to harden in the annulus 98 and perforations 38 between the packers 24, 26, and in the annulus behind the casing and in the formation.
  • cement 22 is preferably a cementitious material, but as used herein, the term "cement” can include any hardenable fluid or slurry. For example, epoxies, other polymers, etc. may be used in place of, or in addition to, cementitious material.
  • the system 10 forms an isolation barrier in the annulus 98 and wellbore 20 which securely prevents fluid communication through the wellbore.
  • Further details of the system 10 and the tool string 12 are provided below, but it should be clearly understood that the principles of the invention are not limited to any of the details described above or below, in part because many variations are possible for performing the methods and constructing the systems of the present invention.
  • FIGS. 6 A-H A representative example of one embodiment of the tool string 12 is illustrated in FIGS. 6 A-H , apart from the remainder of the system 10.
  • the tool string 12 is depicted in FIGS. 6A-H in its run-in configuration, that is, while the tool string is being conveyed into the wellbore 20.
  • slips 46 When the tool string 12 has been appropriately positioned for setting the lower packer assembly 16, the anchoring device 28 is actuated to cause slips 46 to grippingly engage the wellbore 20 (i.e., the interior of the casing 44 lining the wellbore).
  • slips 46 may not be used in the anchoring device 28. Instead, other gripping elements (such as a swellable locator plug, etc.) could be used.
  • the anchoring device 28 is actuated by reciprocating the tool string 12 up and down in the wellbore 20 to operate a ratchet or J-slot device 50 which includes a lug 48 engaged in a J-slot profile 52 formed on an inner mandrel 54 of the anchoring device.
  • FIG. 7 An enlarged view of the mandrel 54 and profile 52 are illustrated in FIG. 7 .
  • a conventional drag block 108 carried on the mandrel 54 to bias a sleeve 56 in which the lug 48 is installed upwardly against the slips 46, thereby radially outwardly displacing the slips along an inclined surface of a conical wedge 58.
  • Compressive force (e.g., set down weight) may now be applied to the tool string 12 by slacking off on the work string 34 at the surface.
  • shear pins 60 releasably secure a plunger 62 relative to a reservoir housing 64 of the setting tool 42.
  • a piston 66 is reciprocably received in the housing 64 between the plunger 62 and a reservoir of hydraulic fluid 68.
  • the pressurized fluid 68 is in communication with an annular chamber 70 via an inner passage 72 formed through a mandrel 74.
  • FIGS. 8A-C Enlarged views of the setting tool 42 and the lower packer 24 are illustrated in FIGS. 8A-C .
  • the chamber 70 is formed axially between a piston 30 and a bulkhead 76.
  • the piston 30 is secured to the mandrel 74 and is reciprocably received in an outer housing 78.
  • the interior of the housing 78 above the piston 30 is exposed to pressure in the wellbore 20 via an opening 80.
  • the interior of the housing 64 is also exposed to pressure in the wellbore 20, and so initially the fluid 68 is at wellbore pressure.
  • the upwardly directed biasing force is transmitted as a tensile force from the mandrel 74 of the setting tool 42 to an inner mandrel 32 of the lower packer 24 via a shear sleeve 82. Simultaneously, the compressive force in the tool string 12 is applied via the housing 78 of the setting tool 42 to an upper ring 84 of the packer 24.
  • upper and lower slips 86, 88 are driven onto respective conical wedges 90, 92 and seal elements 94 are compressed between the wedges.
  • the slips 86, 88 grip the interior of the casing 44, and the seal elements seal against the interior of the casing, thereby setting the packer 24.
  • the upper packer 26 (depicted in FIGS. 6A & B ) is set.
  • Setting the upper packer 26 is similar in many respects to setting the lower packer 24, in that a compressive force is applied to an upper ring 84 and a tensile force is applied to an inner mandrel 32 via a shear sleeve 32.
  • these forces are preferably applied to set the upper packer 26 using a conventional rotational packer setting tool 106 of the type well known to those skilled in the art which is connected at the lower end of the work string 34.
  • a rotational packer setting tool is the Mechanical Setting Tool available from Halliburton Energy Services, Inc. of Houston, Texas and used for setting the Halliburton EZ Drill SV squeeze packer.
  • the perforating gun 14 is then fired by applying pressure to the firing head 36 (see FIG. 6C ). To accomplish this step, increased pressure is applied to the work string 34 at the surface, and this pressure is communicated to the firing head 36 via an internal passage 96 of the tool string 12.
  • the firing head 36 is preferably a conventional pressure operated firing head which causes detonation of explosive charges in the perforating gun 14 in response to application of a predetermined fluid pressure to the firing head.
  • Another pressure operated firing head could alternatively, or in addition, be connected to a lower end of the perforating gun 14, in which case increased pressure could be communicated to the firing head via the open valve 40 and the annulus 98 between the tool string 12 and the wellbore 20.
  • the cement 22 is pumped through the work string 34 to the tool string 12, and out of the valve 40 into the annulus 98 and the remainder of the wellbore 20 between the packers 24, 26.
  • the cement 22 also flows into the perforations 38 (see ( FIG. 5 ) and into the annulus outside of the casing.
  • the work string 34 is then raised, thereby applying an upwardly directed force to a hollow stinger rod 100 in the upper packer 26.
  • the stinger 100 displaces upward with the work string 34, thereby upwardly displacing a valve sleeve 102 of the valve 40, and closing the valve.
  • the stinger 100 is retrieved from the well with the work string 34.
  • the wellbore 20 between the packers 24, 26 is isolated from the remainder of the wellbore.
  • the cement 22 is allowed to harden in this isolated portion of the wellbore 20 and the annulus outside of the casing 44, forming an isolation barrier in the wellbore and the annulus outside of the casing, at which point the well is abandoned or at least isolated from the surface.
  • valve 40 may be closed by raising the work string 34 a sufficient distance to shift the sleeve 102 and close the valve.
  • the increased pressure may be applied to the passage 96 to actuate the firing head 36.
  • the valve 40 may be reopened by lowering the work string 34, to thereby allow the cement 22 to be flowed into the wellbore 20 between the packers 24, 26 and into the annulus outside of the casing 44.
  • FIG. 9 An alternative configuration of the system 10 is representatively illustrated in FIG. 9 .
  • This configuration is similar in many respects to the system 10 described above (compare FIG. 9 to FIG. 3 ), in that it includes the perforating gun 14 positioned between the packer assemblies 16, 18.
  • a perforated nipple 104 provides for fluid communication through a sidewall of the tool string 12.
  • the method using the system 10 of FIG. 9 does not include the step of closing the valve 40.
  • the hardened cement 22 can effectively close off the perforated nipple 104 and isolate the wellbore 20 and the annulus outside of the casing 44 between the set packers 24, 26.
  • a vent or sliding sleeve-type valve could be used below the upper packer assembly 18.
  • system 10 of FIGS. 1-9 could use drill pipe, production tubing, coiled tubing, wireline (electric line) or slickline as a conveyance.
  • Control over positioning the tool string 12 at appropriate depths in the wellbore 20 could be through use of pipe measurements, by tagging an existing component (such as a bridge plug or casing shoe) in the wellbore, or by using sensors and/or measuring devices (such as a wheel counter, pressure sensor, temperature sensor, or combination thereof) incorporated into the tool string.
  • sensors and/or measuring devices such as a wheel counter, pressure sensor, temperature sensor, or combination thereof.
  • the anchoring device 28 which allows compressive force to be applied to the tool string 12 to set the lower packer 24 could be a mechanical slip assembly, a collar stop (which engages a collar recess in the casing 44) or a swellable packer assembly.
  • the tool string 12 could tag the bottom of the wellbore 20, or a bridge plug, etc.
  • a cast iron bridge plug could be used in place of the lower packer 24 and anchoring device 28.
  • the lower packer 24 could be set using compressive force, such as set down weight as described above, using compressive force without the hydraulic force multiplier, using tensile force, using pressure applied via a control line, etc.
  • Setting of the lower packer 24 could be controlled by telemetry (e.g., electromagnetic, pressure pulse, acoustic, etc.) and/or other means (e.g., timer, accelerometer, temperature/pressure/depth sensor, etc.) to allow setting the packer by hydrostatic or applied pressure, ignition of a propellant or explosive charge, etc.
  • An electric line may be used to initiate ignition of a propellant or explosive charge, or to operate an electric motor or valve, to set the packer 24, if desired.
  • Similar techniques could also be used for setting the upper packer 26, instead of the rotational packer setting tool 106 described above.
  • the setting mechanism could be operated by first setting a tension-type mechanically operated slip assembly (similar to the anchoring device 28 turned upside-down). With the slip assembly set, the packer setting mechanism could then be operated by pulling tension in the tool string 12 using the work string 34. For example, this tensile force could be used to remove hydrostatic pressure from one side of a setting piston and create an atmospheric chamber on another side of the piston, allowing well hydrostatic pressure to bias the piston and set the packer. Or, the tensile force could be used to set the packer without use of applied pressure.
  • An electric line could be used to operate a solenoid valve or other type of valve to open a port and allow use of hydrostatic pressure to actuate the setting tool. Electricity could be used to generate heat to cause one or more thermostats to operate valves in the setting tool. Valves can be opened to expose a piston to increased (e.g. well hydrostatic) or reduced pressure (e.g., atmospheric pressure) to operate a setting tool.
  • tensile or compressive force in the tool string 12 is not used to initiate setting of either of the packers 24, 26, then use of the anchoring device 28 may not be required. For example, if a packer is set using hydrostatic pressure, or pressure applied via a control line or the work string 34, or if a packer is set by igniting a propellant or explosive, or by electric motor, then it may not be necessary to use the anchoring device 28 to permit application of tensile or compressive force to the tool string 12.
  • the perforating gun 14 could be an explosive jet perforating gun made of any material (e.g., aluminum, steel, composite, strip, etc.) and may include any type of explosive shaped charge (e.g., big hole or deep penetrating, etc.).
  • the perforations 38 could be formed by bullets, lasers, water jet or other type of perforating device.
  • a method of abandoning a well includes the steps of: assembling a tool string 12 including a perforating gun 14 interconnected between two packer assemblies 16, 18; conveying the tool string 12 into a wellbore 20 in a single trip into the wellbore; setting the packer assemblies 16, 18; firing the perforating gun 14; and flowing cement 22 into the annulus 98 between the packer assemblies 16, 18 and into the annulus outside of the casing 44.
  • the assembling step may include providing permanent packers 24, 26 in the packer assemblies 16, 18.
  • the first packer assembly 16 may be set by reciprocating the tool string 12 in the wellbore 20 to grippingly engage an anchoring device 28 in the wellbore, and then compressing the tool string against the anchoring device to set the packer assembly.
  • the tool string 12 compressing step may further include using a compressive force to apply fluid pressure to a piston 30 to thereby apply a tensile force to a mandrel 32 of the packer assembly 16.
  • the second packer assembly 18 may be set by rotating a work string 34 releasably attached to the tool string 12. Alternatively, the second packer assembly 18 may be set by applying pressure to the packer assembly.
  • the perforating gun 14 may be released from a packer 24 of the first packer assembly 16 after the first packer assembly is set, and prior to setting the second packer assembly 18.
  • the perforating gun 14 firing step may include applying pressure to a firing head 36 of the tool string 12.
  • the cement 22 flowing step may include flowing cement into perforations 38 formed by the perforating gun 14, and into the annulus outside of the casing 44.
  • the tool string 12 may be conveyed on a work string 34, and a valve 40 of the packer assembly 18 may be closed in response to separating the tool string from the work string after the cement 22 flowing step.
  • a system 10 for abandoning a well may include a tool string 12 configured for conveyance into a wellbore 20 in a single trip into the wellbore.
  • the tool string 12 may include a perforating gun 14 interconnected between two packer assemblies 16, 18.
  • the packer assemblies 16, 18 may include permanent packers 24, 26.
  • the packer assembly 16 may also include a setting tool 42 which applies pressure to set the permanent packer 24 in response to compression of the tool string 12.
  • the packer assembly 16 may include an anchoring device 28 for grippingly engaging the wellbore 20 prior to setting the permanent packer 24.
  • the system 10 may include a work string 34 engaged with the tool string 12 for conveying the tool string into the wellbore 20.
  • the packer assembly 18 may include a valve 40 which closes in response to separation of the work string 34 from the tool string 12. The valve 40 selectively permits and prevents fluid flow through a sidewall of the packer assembly 18.
  • the perforating gun 14 may be releasable from the permanent packer 24 of the packer assembly 16 after the packer is set.
  • the system 10 may include cement 22 flowed into the wellbore 20 between the packer assemblies 16, 18 and hardened therein.
  • the cement 22 may extend into perforations 38 formed by the perforating gun 14, and into an annulus outside of the casing 44.
  • the system 10 may include a firing head 36 which initiates firing of the perforating gun 14 in response to pressure applied to the firing head.

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  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Working Measures On Existing Buildindgs (AREA)
  • Processing Of Stones Or Stones Resemblance Materials (AREA)
  • Piles And Underground Anchors (AREA)
  • Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
EP08251821A 2007-06-21 2008-05-23 Abandon de puits en une seule manoeuvre avec des garnitures d'étanchéité permanentes doubles et canon de perforation Withdrawn EP2006486A3 (fr)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US11/766,647 US20080314591A1 (en) 2007-06-21 2007-06-21 Single trip well abandonment with dual permanent packers and perforating gun

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EP2006486A2 true EP2006486A2 (fr) 2008-12-24
EP2006486A3 EP2006486A3 (fr) 2011-08-31

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US (1) US20080314591A1 (fr)
EP (1) EP2006486A3 (fr)
BR (1) BRPI0802170A2 (fr)

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WO2013133720A1 (fr) * 2012-03-09 2013-09-12 Hydra Systems As Procédé d'isolation de zone dans un puits souterrain
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US10301904B2 (en) 2013-09-06 2019-05-28 Hydra Systems As Method for isolation of a permeable zone in a subterranean well
WO2019177466A1 (fr) * 2018-03-14 2019-09-19 Archer Oiltools As Système de bouchons de support en tandem libérables amélioré et procédé de mise en place de tels bouchons en tandem libérables
US10465462B2 (en) 2014-10-24 2019-11-05 Magnum Oil Tools International, Ltd. Electrically powered setting tool and perforating gun
GB2624438A (en) * 2022-11-18 2024-05-22 Bernard Lee Paul Assembly for use in abandoning a wellbore

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US20080314591A1 (en) 2008-12-25
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