US20080236829A1 - Casing profiling and recovery system - Google Patents

Casing profiling and recovery system Download PDF

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Publication number
US20080236829A1
US20080236829A1 US11/728,401 US72840107A US2008236829A1 US 20080236829 A1 US20080236829 A1 US 20080236829A1 US 72840107 A US72840107 A US 72840107A US 2008236829 A1 US2008236829 A1 US 2008236829A1
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Prior art keywords
casing
cutting
piston
apparatus
assembly
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Abandoned
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US11/728,401
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Gerald D. Lynde
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Baker Hughes Inc
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Baker Hughes Inc
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Publication of US20080236829A1 publication Critical patent/US20080236829A1/en
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    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B29/00Cutting 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
    • E21B29/06Cutting windows, e.g. directional window cutters for whipstock operations
    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B29/00Cutting 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
    • E21B29/02Cutting 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 by explosives or by thermal or chemical means
    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B31/00Fishing for or freeing objects in boreholes or wells
    • E21B31/06Fishing for or freeing objects in boreholes or wells using magnetic means
    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B31/00Fishing for or freeing objects in boreholes or wells
    • E21B31/12Grappling tools, e.g. tongs or grabs
    • E21B31/16Grappling tools, e.g. tongs or grabs combined with cutting or destroying means

Abstract

A casing cutting and recovery tool having a cutting assembly, an expansion assembly having one or more deforming members, and a recovery assembly is used to cut a window in wellbore casing, secure a removable segment of wellbore casing that was previously disposed within the window, and recover the removable segment of wellbore casing with the tool. One or more cutting assemblies provides one or more cuts in the wellbore casing. The deforming members of the expansion assembly then expand outwardly at least two portions of the wellbore casing shaped by the cut or cuts. The recovery assembly secures the removable segment of the wellbore casing to the tool so that the tool and the removable segment of wellbore casing can be recovered together from the wellbore.

Description

    BACKGROUND
  • 1. Field of Invention
  • The invention is directed to a casing profiling, or cutting, and recovery systems for use in oil and gas wellbores and, in particular, to a downhole tool for cutting a section of wellbore casing and recovering the section from the wellbore.
  • 2. Description of Art
  • In general, cutting “windows” or openings in oil and gas wellbore casing so that “offshoot,” “lateral,” or “branch” wellbores are well known in the art. Previously, the windows were cut using a whipstock or whipstock-packer assembly and a cutting or milling tool disposed on the end of a drill string. Cutting the windows using these milling tools usually results in jagged edged and irregularly shaped openings. As a result, if it is desired to close the window, sealing the irregularly shaped opening is extremely difficult, if not impossible.
  • Additionally, cutting the windows using these prior milling tools resulted in various sized debris falling into or remain in the wellbore after being cut by the milling tools. As a result, these pieces had to be recovered using wellbore fluid or fishing tools, both of which requires the wellbore to be “off-line” or “down” during the recovery efforts.
  • Accordingly, prior to the development of the present invention, there has been no downhole tool for cutting and recovering a section or segment of wellbore casing or method for forming an opening in casing in a well that: permits cutting the casing segment and removing the segment of wellbore casing from the wellbore in a single downhole trip; permits cutting a segment of wellbore casing with relatively smooth edges, thereby increasing the possibility that the window can be re-sealed; and decreases the amount of debris within the wellbore as a result of cutting the window. Therefore, the art has sought a downhole tool for cutting and recovering a section or segment of wellbore casing and a method for forming an opening in casing in a well that: permits cutting the casing segment and removing the segment of wellbore casing from the wellbore in a single downhole trip; permits cutting a segment of wellbore casing with relatively smooth edges, thereby increasing the possibility that the window can be re-sealed; and decreases the amount of debris within the wellbore as a result of cutting the window.
  • SUMMARY OF INVENTION
  • Broadly, the disclosure is directed to a casing cutting and recovery tool having a cutting assembly, an expansion assembly having one or more deforming members, and a recovery assembly that preferably includes a magnet. The casing cutting and recovery tool is used to cut a window in wellbore casing, secure a removable section of wellbore casing that was previously disposed within the window, and recover the removable section of wellbore casing with the tool. One or more cutting assemblies provide primary cuts and secondary cuts in the wellbore casing. The expansion assembly expands outwardly two portions of the wellbore casing shaped by the primary cuts. The magnet secures the removable section of wellbore casing to the tool so that the tool and the removable section of wellbore casing can be recovered together from the wellbore.
  • In one specific embodiment, the casing cutting and recovery tool comprises a housing having a housing bore. The housing bore has a piston chamber and piston operatively associated therein. The piston is operatively associated with the expansion assembly and the expansion assembly has at least two expansion members operatively associated therewith. The recovery assembly includes an actuating member, such as a motor or solenoid and a recovery assembly housing. The magnet is disposed on the outer wall surface of the recovery assembly. The recovery assembly housing is moveable radially outward and inward relative to the housing by the actuating member.
  • The downhole tools for cutting and recovering a section or segment of wellbore casing and methods for forming an opening in casing in a well have the advantages of: permitting cutting the casing segment and removing the segment of wellbore casing from the wellbore in a single downhole trip; permitting cutting a segment of wellbore casing with relatively smooth edges, thereby increasing the possibility that the window can be re-sealed; and decreasing the amount of debris within the wellbore as a result of cutting the window.
  • In one aspect, one or more of the foregoing advantages is achieved by an apparatus for forming an opening in casing in a well in which the apparatus comprises a cutting assembly for lowering into a casing of a well, the cutting assembly having at least one cutting member for Cutting at least one slot in the casing to define a segment for removal; a deforming member carried with the cutting assembly, the deforming member being selectively actuated from a surface of the well for deforming outward at least two portions of the casing adjacent the slot; and a recovery assembly carried with the cutting assembly for engaging and removing the segment from the casing.
  • A further feature of the apparatus is that the cutting assembly may be disposed above the deforming member. Another feature of the apparatus is that the deforming member may be disposed above the recovery assembly. An additional feature of the apparatus is that the deforming member may comprise at least two rollers. Still another feature of the apparatus is that the apparatus may further comprise a secondary cutting assembly, wherein the cutting assembly and the secondary cutting assembly each include at least two linear charges. A further feature of the apparatus is that the recovery assembly may include a magnet and an actuating member for moving the magnet radially outward to engage and remove the segment from the casing. Another feature of the apparatus is that the deforming member may be operatively associated with a piston disposed within a piston chamber, a lower portion of the piston being operatively associated with a conically shaped deforming member housing. An additional feature of the apparatus is that the lower portion of the piston may include a conically shaped drive wedge, the drive wedge being slidingly engaged with the conically shaped deforming member housing. Still another feature of the apparatus is that the piston and drive wedge may include a bore, the bore having disposed therein a ball seat, a ball, and a ball release. A further feature of the apparatus is that the piston chamber may include hydraulic fluid. Another feature of the apparatus is that the piston chamber may further include a vent port.
  • In another aspect, one or more of the foregoing advantages is achieved by an apparatus for forming an opening in casing in a well in which the apparatus comprises a cutting assembly for lowering into a casing of a well, the cutting assembly having at least one linear shaped charge for cutting at least one slot in the casing to define a segment for removal; a piston movable by high pressure against a wedge member to radially expand a deforming member carried with the cutting assembly, the deforming member being selectively actuated by the piston for deforming outward at least two portions of the casing adjacent the slot; and a recovery assembly carried with the cutting assembly for engaging and removing the segment from the casing, the recovery assembly having a radially moveable magnet.
  • A further feature of the apparatus is that the piston and wedge member each may include a bore, the bore having disposed therein a ball seat, a ball, and a ball release. Another feature of the apparatus is that the piston may be disposed within a piston chamber having an upwardly biased spring and hydraulic fluid. An additional feature of the apparatus is that the piston chamber may further include a vent port.
  • In an additional aspect, one or more of the foregoing advantages is achieved by a method of cutting and removing a segment of casing disposed in a well to form an opening in the casing in which the method comprises the steps of: (a) lowering a casing cutting tool into a bore of a casing; (b) cutting at least one slot in the casing with the casing cutting tool to define a segment of casing to be removed; (c) with the casing cutting tool, forcing outward at least two portions of the casing adjacent the slot, thereby freeing the segment from the casing; then (d) removing the segment, thereby leaving an opening in the casing.
  • A further feature of the method is that the method may further comprise the step of: (e) raising the casing cutting tool with the segment of the casing from the bore of the casing. Another feature of the method is that step (c) may be performed by applying downward pressure on a piston disposed within casing cutting tool causing the piston to move downward, the downward movement of the piston causing at least two expansion members to move radially outward to engage each of the at least two portions of the casing adjacent the slots to force outward each of the at least two portions of the casing against the slot. An additional feature of the method is that the downward pressure may be created by fluid pumped into a bore within casing cutting tool, the bore being in fluid communication with the piston. Still another feature of the method is that step (d) may be performed by actuating an actuating member to move a magnet radially outward to engage the segment o the casing and withdraw the segment of casing into the bore of the casing.
  • BRIEF DESCRIPTION OF DRAWINGS
  • FIG. 1 is a partial cross-sectional view of one specific embodiment of a casing cutting and recovery tool, or system, of the present invention shown in its run-in position.
  • FIG. 2 is an elevational perspective view of the exterior of wellbore casing showing primary longitudinal and primary latitudinal cuts made in the wellbore casing by the casing cutting and recovery tool shown in FIG. 1.
  • FIG. 3 is a cross-sectional view of the wellbore casing shown in FIG. 2 taken along line 3-3.
  • FIG. 4 is an elevational view of the exterior of the wellbore casing of FIGS. 2-3 showing the expanded casing portions formed by the casing cutting and recovery tool shown in FIG. 1.
  • FIG. 5 is a cross-sectional view of the wellbore casing shown in FIG. 4 taken along line 5-5.
  • FIG. 6 is an elevational view of the exterior of the wellbore casing of FIGS. 2-5 showing secondary cuts made in the wellbore casing by the casing cutting and recovery tool shown in FIG. 1.
  • FIG. 7 is a cross-sectional view of the wellbore casing shown in FIG. 6, taken along line 7-7.
  • FIG. 8 is cross-sectional view of the casing cutting and recovery tool shown in FIG. 1 disposed within the wellbore casing shown in FIGS. 2-7 showing the expanded casing portions formed by the casing cutting and recovery tool shown in FIG. 1 and showing the section of the wellbore casing to be engaged by the recovery assembly of the casing cutting and recovery tool shown in FIG. 1.
  • FIG. 9 is cross-sectional view of the casing cutting and recovery tool shown in FIG. 1 disposed within the wellbore casing shown in FIGS. 2-7 showing the section of the wellbore casing engaged by the recovery assembly of the casing cutting and recovery tool shown in FIG. 1.
  • FIG. 10 is cross-sectional view of the casing cutting and recovery tool shown in FIG. 1 disposed within the wellbore casing shown in FIGS. 2-7 showing the section of the wellbore casing engaged and withdrawn into the bore of the wellbore casing by the recovery assembly of the casing cutting and recovery tool shown in FIG. 1.
  • FIG. 11 is an elevational view of the exterior of the wellbore casing shown in FIGS. 2-7 showing the window made in the wellbore casing by the casing cutting and recovery tool shown in FIG. 1.
  • FIG. 12 is a cross-sectional view of the wellbore casing shown in FIG. 11 taken along line 11-11.
  • While the invention will be described in connection with the preferred embodiments, it will be understood that it is not intended to limit the invention to that embodiment. On the contrary, it is intended to cover all alternatives, modifications, and equivalents, as may be included within the spirit and scope of the invention as defined by the appended claims.
  • DETAILED DESCRIPTION OF INVENTION
  • Referring now to FIGS. 1-12, casing cutting and recovery tool 10, or tool 10 or downhlole tool 10, comprises upper end 12, lower end 14 and housing 16. Upper end 12 and lower end 14 both include threads 18 for securing tool 10 to a casing, drill pipe, tubing string, or wireline (not shown) or other downhole tools (not shown). Housing 16 includes housing bore 20 longitudinally disposed at least partially through housing 16 and outer wall surface 22.
  • Tool 10 includes at least one cutting assembly 21. In the embodiment shown in FIG. 1, Cutting assembly 21 includes linear charges 24, 26, 28, 30, 32, 34 disposed along a radial arc of outer wall surface 22. Linear charges are known in the art and may be obtained from Accurate Arms Company, Inc. located in McEwen, Tenn. Briefly, linear charges 24, 26, 28, 30, 32, 34 are shaped explosive devices having a substantially V or U cross-section. When detonated, the explosive force is expelled out of an opening along the top of the V or U cross-section so that the explosive force is directed in a desired direction. As shown in FIG. 1, linear charges 24, 26, 28, 30, 32, 34 are arranged in such a way that there is a left upper horizontal linear charge 24, a left vertical linear charge 26, a left lower horizontal linear charge 28, a right upper horizontal linear charge 30, a right vertical linear charge 32, and a right lower horizontal linear charge 34. It is to be understood, however, that a single linear charge may be shaped to have the same arrangement as shown in FIG. 1. Preferably, each linear charge 24, 26, 28, 30, 32, 34 is disposed along outer wall surface 22 such that the tops of each linear charge 24, 26, 28, 30, 32, 34 are flush with outer wall surface 22. In other embodiments (not shown), cutting assembly 21 include devices for abrasive jetting, milling, electronic discharge machining, chemical jetting or erosion, flame cutting, broaching, scarring, wheel cutting, perforating, slotting, or other device, or using any method, known to persons skilled in the art. Further, linear charges 24, 26, 28, 30, 32, 34 do not have to provide straight cuts or parallel cuts. Instead, linear charges 24, 26, 28, 30, 32, 34 can be arranged to cut one or more arcuate shaped cuts, including circular shaped cuts.
  • Housing 16 also includes piston chamber 36 disposed within housing 16. In the embodiment shown in FIG. 1, piston chamber 36 is disposed below linear charges 24, 26, 28, 30, 32, 34. Piston chamber 36 includes vent port 38 and piston 40 slidingly engaged within piston chamber 36. In a preferred embodiment, hydraulic fluid is disposed within piston chamber 36 and vent port 38 includes a plug (not shown) for maintaining the hydraulic fluid within piston chamber 36 during run. The plug is easily dislodged from vent port 38 during operation of piston 40 (discussed in greater detail below). Piston 40 includes piston seals 42, piston rod 43, and piston bore 44 extending through piston rod 43 and piston 40. Vent port 38 is always below piston seals 42. Spring 46 acts to force piston 40 in the upward direction (arrow 47). In other words, piston 40 is upwardly biased. Piston rod 43 can also include fastener hole 48 through its side wall for receiving a fastener (not shown) such as a screw (not shown).
  • The lower end of piston rod 43 is secured by a fastener (not shown) to drive wedge 50 by inserting the lower end of piston rod 43 into upper bore portion 52 of wedge bore 54 of drive wedge 50. Alternatively, drive wedge 50 and piston rod 43 can be a single component. Wedge bore 54 includes lower bore portion 56 that has a smaller inner diameter compared to the inner diameter of upper bore portion 52.
  • Drive wedge 50 has a conical shape with the narrow end at the bottom of drive wedge 50. The outer surface of drive wedge 50 is in sliding engagement with expansion assembly 60. As illustrated in FIG. 1, expansion assembly 60 includes expansion assembly housing 62. In one specific embodiment, the outer surface of drive wedge 50 has lands and grooves (not shown) and expansion assembly housing 62 has reciprocal lands and grooves (not shown) so that upward and downward movement of wedge driver 50 pushes or pulls expansion assembly housing 62 through the connecting lands and grooves.
  • Expansion assembly housing 62 includes expansion assembly housing chamber 64 for receiving drive wedge 50. Expansion assembly 60 also includes at least two expansion members shown in FIG. 1 as expansion rollers 66. In this arrangement, as drive wedge 50 moves downward, in the direction of arrow 51, expansion assembly housing 62 is forced outward radially, in the direction of arrows 68, 69, so that expansion rollers 66 engage the wellbore casing to bend or force “open” the wellbore casing as discussed in greater detail below. Ball seat 70 is disposed within wedge upper bore portion 52. Ball seat 70 includes ball 72 that initially blocks the downward flow of fluid through piston bore 44. As discussed in greater detail below, after piston 40 has been forced downward (arrow 51) to radially expand expansion rollers 66, ball release 74 having stem 75 and head 76 engages ball 72 and forces ball 72 off of ball seat 70 so that fluid is permitted to flow downward through piston bore 44 and into expansion assembly housing chamber 64. As a result, drive wedge 50 can be forced upward, in the direction of arrow 47, so that each expansion rollers 66 can be retracted into housing 16 of tool 10 (discussed in greater detail below). In a preferred embodiment, head 76 is disposed within chamber 78 of housing 16 such that head 76 can move slightly within chamber 78.
  • Disposed below expansion assembly 60 is recovery assembly 80. Recovery assembly 80 includes housing 82 that is operatively associated with a source of movement, i.e., an actuating member of device such as a motor or a solenoid 85 (FIGS. 8-10). The outer surface of housing 82 includes magnet 84. In this specific embodiment, outer surface of housing 82 also includes a second cutting assembly made up of upper horizontal linear charge 86 and lower horizontal linear charge 88. Housing 82 is radially moveable relative to housing 16 by solenoid 85. Although housing 82 is shown as being flush with outer wall surface 22 of housing 16, it is to be understood that housing 82 may be slightly recessed within housing 16 during the period of time that recovery assembly 80 is not in use, i.e., during run-in of the tool 10 or during operation of Cutting assembly 21 or expansion assembly 60.
  • Referring now to FIGS. 2-12, in operation, tool 10 is lowered through wellbore casing 90 by a work string (not shown) to the desired location where a window is to be cut in wellbore casing 90. Wellbore casing has casing bore 91 defined by inner casing wall surface 92 and casing outer wall surface 93. Once properly located within wellbore casing 90, linear charges 24, 26, 28, 30, 32, 34 are initiated using known devices and techniques, such as detonator and prima cord activated electronically from the surface of the well. In the embodiment shown in FIGS. 2-12, the explosive force from linear charges 24, 26, 28, 30, 32, 34 creates primary longitudinal cuts 95, 98 and primary horizontal cuts 94, 96, 97, 99 in wellbore casing 90 (FIGS. 2-3).
  • Thereafter, tool 100 is raised up in wellbore casing 90 until rollers 66 of expansion assembly 60 are disposed on the inner wall surface 92 of wellbore casing 90 parallel to primary longitudinal cuts 95, 98 and in between primary horizontal cuts 94, 96, 97, 99. Referring to FIG. 1, fluid (not shown), such as wellbore fluid or hydraulic fluid, is then pumped down the work string and into housing bore 20 to actuate piston 40. Once actuated, piston 40 is forced downward in the direction of arrow 51 causing drive wedge 50 to radially expand expansion assembly housing 62 and, thus, expansion rollers 66 outwards in the direction of arrows 68, 69. In so doing, the plug is forced out of vent port 38 causing piston chamber 36 to be in fluid communication with the wellbore. Thus, the hydraulic fluid within piston chamber 36 is forced out of piston chamber 36 allowing piston 40 to move downward. Further, the pressure within piston chamber 36 is hydrostatic pressure.
  • Piston 40 is forced downward until ball release 74 engages ball 72 and removes ball 72 from ball seat 70. As a result, fluid being pumped down work string and housing bore 20 is permitted to flow through piston bore 44 and wedge bore 54 alongside ball release 74 and into expansion assembly housing chamber 64. Fluid is continued to be pumped resulting in pressure equilibrium being established above and below piston 40, i.e., within housing bore 20, piston chamber 36, and expansion assembly housing chamber 64. Due to the equilibrium established in these spaces, expansion rollers 66 remain extended to contact inner wall surface 92 of wellbore casing 90 and force outward two portions of wellbore casing 90, referred to herein as expanded casing portions 100, 102 (FIG. 5). Tool 10 is then either raised or lowered as appropriate so that expansion rollers 66 move along the entire longitudinal length of primary longitudinal cuts 95, 98 in between primary horizontal cuts 94, 96, 97, 99. As a result, longitudinal openings 101, 103 are formed in wellbore casing 90 (FIGS. 4-5).
  • After longitudinal openings 101, 103 are formed, expansion rollers 66 are retracted into housing 16 by decreasing or eliminating the pumping of fluid down housing bore 20 (FIG. 1). The reduced or elimination of pumping pressure down housing bore 20 allows spring 46 to force piston 40 upward in the direction of arrow 47. As piston 40 moves upwards in the direction of arrow 47, fluid within expansion assembly chamber 64 flows upwards past ball seat 70, through piston bore 44, and through housing bore 20. Also, wellbore fluid (not shown) flows into piston chamber 36 through vent port 38. The flow of fluid flows upwards past ball seat 70, through piston bore 44, and through housing bore 20 and/or through vent port 38 can also assist in the movement of piston 40 upward. As piston 40 moves upwards (arrow 47), drive wedge 50 also moves upwardly causing expansion assembly housing 62 and, thus, expansion rollers 66 to retract into housing 16.
  • Tool 10 is then raised further up wellbore casing 90 until magnet assembly 80 is disposed between primary longitudinal cuts 95, 98 and in between primary horizontal cuts 94, 96, 97, 99. A top cross-sectional view of the location of tool 10 at this stage of operation is shown in FIG. 8. Tool 10 may include verification tools to ensure that tool 10 is properly located and expanded casing portions 100, 102 are properly formed. The verification tools can include one or more video, acoustic, ultrasonic, or tactile system known in the art that can easily be adapted for these functions. If expanded casing portions 100, 102 are not in their correct position, tool 10 can be repositioned so that expansion assembly 60 can be re-engaged to expand expanded casing portions 100, 102.
  • The second cutting assembly, linear charges 86, 88 in FIG. 1, is initiated using known devices and techniques, such as prima cord activated electronically from the surface of the well. The explosive force from linear charges 86, 88 creates secondary horizontal cuts 112, 114 in wellbore casing 90 (FIG. 6). In a preferred embodiment, motor or solenoid 85 radially moves magnet housing 82 outward in the direction of arrow 130 until magnet 84 and linear charges 86, 88 contact casing inner wall surface 92 (FIG. 9). It is to be understood, however, that linear charges 86, 88 do not have to be in contact with inner wall surface 92. It is also to be understood that magnet 84 does not have to be in contact with inner wall surface 92 at the time linear charges 86, 88 or activated.
  • It is also to be understood that a second cutting assembly such as linear charges 86, 88 is not required. For example, in embodiments in which cutting assembly 21 is capable of abrasive jetting, milling, electronic discharge machining, chemical jetting or erosion, flame cutting, or wheel cutting, second cutting assembly is not needed because cutting assembly 21 can be used to make secondary horizontal cuts 112, 114. Therefore, in these embodiments, a single cutting assembly 21 can be part of tool 10.
  • After secondary horizontal cuts 112, 114, wellbore casing section 110 is now removable from the remainder of wellbore casing 90. If magnet 84 is not already in contact with wellbore casing section 110, magnet 84 is moved into contact with wellbore casing section 110 by motor/solenoid 85. Motor/solenoid 85 may be activated through any device or method known in the art such as through electronic activation from the surface.
  • Wellbore casing section 110, secured by magnet 84 is then moved into wellbore casing bore 91 by moving motor/solenoid 85 in the direction of arrow 132. Tool 10 and wellbore casing section 110 can then be raised up wellbore casing bore 91 by the work string, thereby leaving wellbore casing 90 with window 120 (FIGS. 11-12).
  • Tool 10 provides the advantages of creating a smooth walled window 120 in wellbore casing 90. Thus, potential damage to other downhole tools, components and strings is lessened because window 120 includes few, if any, jagged cuts and sharp edges. Additionally, the possibility of being able to reseal window 120 is raised because there are less irregularly shaped spaces that need to be filled or covered. Further, tool 10 lessens the amount of debris that may be left in the wellbore or that needs to be recovered using recovery fluids or recovery tools. Moreover, tool 10 permits window 120 to be cut and removed using a single tool making a single downhole run. Thus, cost savings are achieved using tool 10.
  • Further, additional components, such as a measurement while drilling component, flow sub, J & shear joint, bottom trip anchor, and/or whipstock may be secured to lower end 14 to facilitate placement or operation of tool 10 or to allow additional components, such as a whipstock, to be placed within wellbore as part of the operation of tool 10 during its single trip downhole.
  • It is to be understood that the invention is not limited to the exact details of construction, operation, exact materials, or embodiments shown and described, as modifications and equivalents will be apparent to one skilled in the art. For example, piston 40 may be actuated using any method or device known to persons of ordinary skill in the art. Additionally, one or more linear charges 24, 26, 28, 30, 32, 34 may be disposed along outer wall surface 22 of housing 16 such that the outer surfaces of linear charges 24, 26, 28, 30, 32, 34 are either recessed into housing 16 or protrude outside of outer wall surface 22. Further, upper horizontal linear charge 86 and lower horizontal linear charge 88 are not required to be disposed on outer surface of magnet housing 82. In other words, upper horizontal linear charge 86 and lower horizontal linear charge 88 are not required to be moveable radially. Instead, upper horizontal linear charge 86 and lower horizontal linear charge 88 may be disposed on outer wall surface 22 of housing 16. Moreover, the primary and secondary cuts may be formed using abrasive jetting, milling, electronic discharge machining, chemical jetting or erosion, flame cutting, perforating, slotting, broaching, scarring, wheel cutting, or using any other device or method known to persons skilled in the art. Further, a single cutting assembly may be included as part of tool 10 to provide all of the primary and secondary cuts. Additionally, the expansion members may be inflatable components shaped to correspond to expanded casing portions 100, 102 that can be inflated to force expanded casing portions 100, 102 outwardly. Alternatively, the expansion member may be swage having a ramp profile. Accordingly, the invention is therefore to be limited only by the scope of the appended claims.

Claims (20)

1. An apparatus for forming an opening in casing in a well, the apparatus comprising:
a cutting assembly for lowering into a casing of a well, the cutting assembly having at least one cutting member for cutting at least one slot in the casing to define a segment for removal;
a deforming member carried with the cutting assembly, the deforming member being selectively actuated from a surface of the well for deforming outward at least two portions of the casing adjacent the slot; and
a recovery assembly carried with the cutting assembly for engaging and removing the segment from the casing.
2. The apparatus of claim 1, wherein the cutting assembly is disposed above the deforming member.
3. The apparatus of claim 2, wherein the deforming member is disposed above the recovery assembly.
4. The apparatus of claim 1, wherein the deforming member comprises at least two rollers.
5. The apparatus of claim 1, further comprising a secondary cutting assembly, wherein the cutting assembly and the secondary cutting assembly each include at least two linear charges.
6. The apparatus of claim 1, wherein the recovery assembly includes a magnet and an actuating member for moving the magnet radially outward to engage and remove the segment from the casing.
7. The apparatus of claim 1, wherein the deforming member is operatively associated with a piston disposed within a piston chamber, a lower portion of the piston being operatively associated with a conically shaped deforming member housing.
8. The apparatus of claim 7, wherein the lower portion of the piston includes a conically shaped drive wedge, the drive wedge being slidingly engaged with the conically shaped deforming member housing.
9. The apparatus of claim 8, wherein the piston and drive wedge include a bore, the bore having disposed therein a ball seat, a ball, and a ball release.
10. The apparatus of claim 9, wherein the piston chamber includes hydraulic fluid.
11. The apparatus of claim 10, wherein the piston chamber further includes a vent port.
12. An apparatus for forming an opening in casing in a well, the apparatus comprising:
a cutting assembly for lowering into a casing of a well, the cutting assembly having at least one linear shaped charge for cutting at least one slot in the casing to define a segment for removal;
a piston movable by high pressure against a wedge member to radially expand a deforming member carried with the cutting assembly, the deforming member being selectively actuated by the piston for deforming outward at least two portions of the casing adjacent the slot; and
a recovery assembly carried with the cutting assembly for engaging and removing the segment from the casing, the recovery assembly having a radially moveable magnet.
13. The apparatus of claim 12, wherein the piston and wedge member each include a bore, the bore having disposed therein a ball seat, a ball, and a ball release.
14. The apparatus of claim 13, wherein the piston is disposed within a piston chamber having an upwardly biased spring and hydraulic fluid.
15. The apparatus of claim 14, wherein the piston chamber further includes a vent port.
16. A method of cutting and removing a segment of casing disposed in a well to form an opening in the casing, the method comprising the steps of:
(a) lowering a casing cutting tool into a bore of a casing;
(b) cutting at least one slot in the casing with the casing cutting tool to define a segment of casing to be removed;
(c) with the casing cutting tool, forcing outward at least two portions of the casing adjacent the slot, thereby freeing the segment from the casing; then
(d) removing the segment, thereby leaving an opening in the casing.
17. The method of claim 16, further comprising the step of:
(e) raising the casing cutting tool with the segment of the casing from the bore of the casing.
18. The method of claim 16, wherein step (c) is performed by applying downward pressure on a piston disposed within casing cutting tool causing the piston to move downward, the downward movement of the piston causing at least two expansion members to move radially outward to engage each of the at least two portions of the casing adjacent the slots to force outward each of the at least two portions of the casing against the slot.
19. The method of claim 18, wherein the downward pressure is created by fluid pumped into a bore within casing cutting tool, the bore being in fluid communication with the piston.
20. The method of claim 20, wherein step (d) is performed by actuating an actuating member to move a magnet radially outward to engage the segment o the casing and withdraw the segment of casing into the bore of the casing.
US11/728,401 2007-03-26 2007-03-26 Casing profiling and recovery system Abandoned US20080236829A1 (en)

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US10301909B2 (en) 2011-08-17 2019-05-28 Baker Hughes, A Ge Company, Llc Selectively degradable passage restriction
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US9090956B2 (en) 2011-08-30 2015-07-28 Baker Hughes Incorporated Aluminum alloy powder metal compact
US9802250B2 (en) 2011-08-30 2017-10-31 Baker Hughes Magnesium alloy powder metal compact
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US9347119B2 (en) 2011-09-03 2016-05-24 Baker Hughes Incorporated Degradable high shock impedance material
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US9926766B2 (en) 2012-01-25 2018-03-27 Baker Hughes, A Ge Company, Llc Seat for a tubular treating system
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US9605508B2 (en) 2012-05-08 2017-03-28 Baker Hughes Incorporated Disintegrable and conformable metallic seal, and method of making the same
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US9910026B2 (en) 2015-01-21 2018-03-06 Baker Hughes, A Ge Company, Llc High temperature tracers for downhole detection of produced water
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