Patent Grant
10808481
The present disclosure generally relates to apparatus and method for cutting casing in a wellbore.
A wellbore is formed to access hydrocarbon bearing formations, for example crude oil and/or natural gas, by the use of drilling. Drilling is accomplished by utilizing a drill bit that is mounted on the end of a tubular string, such as a drill string. To drill within the wellbore to a predetermined depth, the drill string is often rotated by a top drive or rotary table on a surface platform or rig, and/or by a downhole motor mounted towards the lower end of the drill string. After drilling to a predetermined depth, the drill string and drill bit are removed and a section of casing is lowered into the wellbore. An annulus is thus formed between the string of casing and the formation. The casing string is temporarily hung form the surface of the well. The casing string is cemented into the wellbore by circulating cement into the annulus defined between the outer wall of the casing and the borehole. The combination of cement and casing strengthens the wellbore and facilitates the isolation of certain areas of the formation behind the casing for the production of hydrocarbons.
It is common to employ more than one string of casing in a wellbore. In this respect, the well is drilled to a first designated depth with the drill string. The drill string is removed. A first string of casing is then run into the wellbore and set in the drilled-out portion of the wellbore, and cement is circulated into the annulus behind the casing string. Next, the well is drilled to a second designated depth, and a second string of casing or liner, is run into the drilled-out portion of the wellbore. If the second string is a liner string, the liner is set at a depth such that the upper portion of the second string of casing overlaps the lower portion of the first string of casing. The liner string may then be fixed, or “hung” off of the existing casing by the use of slips which utilize slip members and cones to frictionally affix the new string of liner in the wellbore. If the second string is a casing string, the casing string may be hung off of a wellhead. This process is typically repeated with additional casing/liner strings until the well has been drilled to total depth. In this manner, wells are typically formed with two or more strings of casing/liner of an ever-decreasing diameter.
From time to time, for example once the hydrocarbon-bearing formations have been depleted, the wellbore must be plugged and abandoned (P&A) using cement plugs. This P&A procedure seals the wellbore from the environment, thereby preventing wellbore fluid, such as hydrocarbons and/or salt water, from polluting the surface environment. This procedure also seals sensitive formations, such as aquifers, traversed by the wellbore from contamination by the hydrocarbon-bearing formations. Setting of a cement plug when there are two adjacent casing strings lining the wellbore is presently done by cutting a window in each of the adjacent casing strings and squeezing cement into the windows to provide a satisfactory seal.
After the wellbore has been plugged, the sub-sea wellhead may be retrieved. A tool is lowered down and secured to the wellhead. A casing cutter of the tool is used to make a cut through the casing strings attached to the wellhead. The wellhead and the portion of the casing strings attached to the wellhead above the cut are then retrieved to the surface with the tool.
A casing cutter is used to make a cut above the placement of the cement plug and separate the casing into a first or upper portion and a second or lower portion. Conventional casing cutters have straight blades extending diagonally outwards towards the casing string(s), such as the casing cutter 5 shown in
A tool for cutting a tubular in a wellbore includes a housing, a first blade having a first cutting surface, and a second blade having a second cutting surface. The first blade and the second blade are configured to move between an extended position and a retracted position. The first blade and the second blade are disposed in the housing in the retracted position. The first cutting surface and the second cutting surface overlap in the retracted position.
A tool for cutting a tubular in a wellbore includes a housing and a blade configured to move between an extended position and a retracted position. The blade includes a curved portion having a cutting surface disposed on at least a part of the curved portion. The radius of curvature of the curved portion is substantially similar to an outer diameter of the housing.
A tool for cutting a tubular in a wellbore includes a housing having a first window and a second window formed through a wall of the housing, a pin disposed adjacent the first window, and a blade configured to rotate about the pin between an extended position and a retracted position, the blade having a curved portion disposed adjacent the second window in the retracted position.
A method for cutting a tubular includes positioning a rotatable cutting tool in the tubular, the cutting tool having a housing and a blade with a cutting surface disposed thereon. The method includes rotating the blade about a pin through a window formed in the housing.
A method of cutting a tubular includes positioning a rotatable cutting tool in the tubular, the cutting tool having a housing and a blade with a cutting surface disposed thereon. The method includes moving the blade between a retracted position, wherein at least a portion of the cutting surface is disposed on a first side of a longitudinal axis of the housing, and an extended position wherein at least a portion of the cutting surface is disposed on a second side of the longitudinal axis. The method further includes rotating the cutting tool relative to the tubular and cutting the tubular using the cutting surface.
In another embodiment, a tool for cutting a tubular in a wellbore, includes a housing having a longitudinal axis; a pin connected to the housing and disposed on a first side of the longitudinal axis; and a blade configured to move between an extended position and a retracted position about the pin, wherein the blade includes a cutting surface disposed thereon, the cutting surface disposed at least in part on a second side of the longitudinal axis in the retracted position.
In another embodiment, a method of cutting a tubular includes positioning a rotatable cutting tool in the tubular, the cutting tool having a housing and a blade, the blade including a cutting surface disposed thereon; moving the blade between a retracted position, wherein at least a portion of the cutting surface is disposed on a first side of a longitudinal axis of the housing, and an extended position, wherein the portion of the cutting surface is disposed on a second side of the longitudinal axis; rotating the cutting tool relative to the tubular; and cutting the tubular using the blade.
In yet another embodiment, a method of cutting a tubular includes positioning a rotatable cutting tool in the tubular, the cutting tool having a housing and a blade, the blade including a cutting surface; moving a portion of the cutting surface of the blade between a first side of a longitudinal axis of the housing and a second side of the longitudinal axis; rotating the cutting tool relative to the tubular; and cutting the tubular using the blade.
So that the manner in which the above recited features of the present invention can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments of this invention and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments.
In the description of the representative embodiments of the invention, directional terms, such as “above”, “below”, “upper”, “lower”, etc., are used for convenience in referring to the accompanying drawings. In general, “above”, “upper”, “upward” and similar terms refer to a direction toward the earth's surface along a longitudinal axis of a wellbore, and “below”, “lower”, “downward” and similar terms refer to a direction away from the earth's surface along the longitudinal axis of the wellbore.
The actuation assembly 30 acts to extend blades 116a,b of the blade assembly 40. The actuation assembly may be at least partially disposed in the bores of the housing sections 15b-d. In one embodiment, actuation assembly 30 includes a retaining member 102 having at least one aperture 106 and a bore therethrough, as seen in
The blade assembly 40 includes at least one blade 116 in a respective recess 118 of the housing section 15d, as shown in
The tool 10 may optionally include a stabilizer assembly 70, as shown in
An exemplary embodiment of the blade 116 is shown in
The cutting surface 206 may be configured to cut a tubular, such as the inner tubular 50. In some embodiments, the cutting surface 206 is configured to cut through a tubular, thereby making a full-thickness cut. In some embodiments, the blade 116 includes a pivot pin in aperture 201 along axis A. In some embodiments, as the blade 116 extends radially outward from the longitudinal axis of cutting tool 10, the cutting surface 206 moves upward within the nested tubulars. Consequently, the amount of extension of the blade 116 from the cutting tool 10 may be expressed as a measurement of rotation angle about axis A. The cutting surface 206 cuts the inner tubular 50 when the blade 116 is in an extended position. An edge 212 of the cutting surface 206 may engage the inner tubular 50. The edge 212 may be disposed at an end of the corner 210 opposite the curved portion 204. The sweep of the tool 10 is the diameter of a circle formed by the edge 212 as the tool 10 rotates about its longitudinal axis. The edge 212 may include an initial engagement point configured to engage a surrounding tubular. The edge 212 of the cutting surface 206 may make initial contact with a surrounding tubular.
In cutting to the fully extended position, the blades 116a,b may remove material substantially equivalent to a hemisphere having a radius equivalent to the radius of curvature 204r minus the volume of the borehole of the wellbore and minus half the volume of a toroid having a minor radius equivalent to the radius of curvature 206r and a major radius equivalent to the sum of the distance from the longitudinal axis of the tool 10 to the pin 120 and the radius of curvature 206r.
During operation, the tool 10 may be lowered into the inner tubular 50 with the blades 116a,b in the retracted position. In one embodiment, the blades 116a,b may be completely disposed in the housing 15 in the retracted position. An outer diameter of the housing section 15d may be substantially similar (within +/− thirty percent) to the radius of curvature 204r of the blade 116, such that the blades 116a,b are at least partially disposed in the housing section 15d in the retracted position. The blades 116a,b may laterally overlap in the retracted position, as shown in
Actuation assembly 30 may act to extend blades 116a,b of the blade assembly 40. In some embodiments, actuation assembly 30 is hydraulic. To actuate the blades 116a,b into an extended position, fluid is injected through the tool 10. A first portion of the injected fluid enters the bore of the movable member 104 before entering the larger bore of the actuator piston 112. Thereafter, the first portion of fluid passes through the mandrel 124, through a bore of the blade piston 126, and exits the tool 10 through the recess 18 of the housing 15. A second portion of the injected fluid passes through the apertures 106 of the retaining member 102 and may act on the packing seal 114 of the actuator piston 112. Fluid pressure in the housing 15 is increased, thereby moving the movable member 104 downward and compressing the spring 108 against the retaining member 102. In turn, the movable member 104 urges the actuator piston 112 downward. In turn, the actuator piston 112 urges the mandrel 124 and blade piston 126 downward, thereby compressing the spring acting on the blade piston 126. The blade piston 126 acts on the blades 116a,b, thereby actuating the blades 116a,b into an extended position.
In one embodiment, the tool 10 provides an indication at the surface of the wellbore 20 that the blades 116a,b have cut through the inner tubular 50. For example, the actuation assembly 30 is configured such that the movable member 104 and the actuator piston 112 disengage when the blades 116a,b cut through the wall of the inner tubular 50. Upon cutting through the inner tubular 50, the movable member 104 reaches a stop and the fluid acting on the piston surface of the actuator piston 112 causes the actuator piston 112 to move downward relative to the movable member 104. As a result, the actuator piston 112 disengages from the bottom surface of the movable member, as shown in
Upon indication that the blades 116a,b have completed the cutting operation, the blades 116a,b are returned to the retracted position. In some embodiments, to return the blades 116a,b to the retracted position, fluid pressure in the housing 15 may be decreased. As a result, the spring acting on the blade piston 126 may overcome the fluid force acting on the packing seal 114. The blade piston 126 is urged upwards, thereby engaging the blades 116a,b with the lower lips of the shoulder 126a. In turn, the actuator piston 112 is urged upwards into engagement with the bottom surface of the movable member 104. By moving upwards, the blade piston 126 urges the blades 116a,b into the retracted position. The blades 116a,b pivot about the pin 120 to the retracted position, as shown in
In another embodiment, the stabilizer assembly 70, the mandrel 124, the blade piston 126, and the spring acting on the blade piston 126 may be omitted. The actuator piston 112 may include a shoulder substantially similar to shoulder 126a of the blade piston 126. The actuator piston 112 may be biased upwards against the bottom surface of the movable member 104 by a spring. The actuator piston 112 may be configured to move the blades 116a,b between the extended position and the retracted position. The actuator piston 112 acts on the blades 116a,b, thereby actuating the blades 116a,b into the extended position. The upper lips of the shoulder of the actuator piston 112 act on a corresponding shoulder of the blades 116a,b, thereby causing each blade 116a,b to rotate about its respective pin 120. In some embodiments, to return the blades 116a,b to the retracted position, fluid pressure in the housing 15 may be decreased. As a result, the spring of the actuator piston 112 may overcome the fluid force acting on the packing seal 114. The actuator piston 112 is urged upwards into engagement with the bottom surface of the movable member 104. In turn, the actuator piston 112 urges the blades 116a,b into the retracted position. The blade 116a may pivot about the pin 120 to the retracted position. The blades 116a,b may scissor together and overlap in the retracted position. In one embodiment, the first blade may move laterally towards the second blade while moving from the extended position to the retracted position. The first blade may move laterally past at least a portion of the second blade when moving from the extended position to the retracted position. The cutting surface of the first blade may move laterally past at least a portion of the cutting surface of the second blade when the blades move from the extended position to the retracted position.
In one embodiment, the tool 10 is rotated relative to the inner tubular 50 while the blades 116a,b are extending toward the inner tubular 50. In one embodiment, a mud motor rotates the tool 10.
In one embodiment, the actuation assembly 30 provides an evenly distributed cut by actuating the blades 116a,b into an extended position, as shown in
In one embodiment, the blades 116a,b may be mechanically retracted from the extended position. In some instances, the blades 116a,b may become stuck or pinched during a cutting operation. For example, one of the nested tubulars may fall and pinch or land on the blades 116a,b, causing a lockup and preventing further cutting. In certain instances, the spring acting on the blade piston 126 may not be able to overcome the frictional force on the blades 116a,b to move the blades 116a,b from the extended position to the retracted position. In one embodiment, a longitudinal force may be applied to the tool 10 in order to retract the blades 116a,b. For example, the tool 10 may be lifted or pulled upwards from the surface to free the blades 116a,b from the stuck or pinched condition and move the blades from the extended position to the retracted position. In turn, the uncut material (e.g., tubulars, cement) adjacent the blades 116a,b will urge the blades 116a,b towards the retracted position. The spring acting on the blade piston 126 may assist the longitudinal force on the tool 10 in retracting the blades 116a,b.
In one embodiment, the blades 116 may be retracted and the cutting operation described herein may be repeated any number of times. For example, the tool 10 may be moved axially upward in the wellbore 20 and the nested tubulars may be cut at the new position.
In one or more of the embodiments described herein, a tool for cutting a tubular in a wellbore includes a housing, a first blade having a first cutting surface, and a second blade having a second cutting surface.
In one or more of the embodiments described herein, the first blade and the second blade are configured to move between an extended position and a retracted position.
In one or more of the embodiments described herein, the first blade and the second blade are disposed in the housing in the retracted position.
In one or more of the embodiments described herein, the first cutting surface and the second cutting surface overlap in the retracted position.
In one or more of the embodiments described herein, the first blade includes a first curved portion, the first cutting surface disposed on at least a part of the first curved portion.
In one or more of the embodiments described herein, the second blade includes a second curved portion, the second cutting surface disposed on at least a part of the second curved portion.
In one or more of the embodiments described herein, the first curved portion and the second curved portion are substantially semi-circular.
In one or more of the embodiments described herein, the first curved portion extends laterally past the second curved portion in the retracted position.
In one or more of the embodiments described herein, the first curved portion is an arcuate segment.
In one or more of the embodiments described herein, the second curved portion is an arcuate segment.
In one or more of the embodiments described herein, the first blade is configured to rotate about a first pin.
In one or more of the embodiments described herein, the second blade is configured to rotate about a second pin.
In one or more of the embodiments described herein, the tool further includes a window formed through a wall of the housing, the first blade configured to extend at least partially through the first window in the extended position.
In one or more of the embodiments described herein, the first cutting surface and the second cutting surface overlap laterally in the retracted position.
In one or more of the embodiments described herein, a tool for cutting a tubular in a wellbore includes a housing and a blade configured to move between an extended position and a retracted position.
In one or more of the embodiments described herein, the blade includes a curved portion having a cutting surface disposed on at least a part of the curved portion.
In one or more of the embodiments described herein, the radius of curvature of the curved portion is substantially similar to an outer diameter of the housing.
In one or more of the embodiments described herein, the radius of curvature is substantially uniform.
In one or more of the embodiments described herein, the cutting surface includes a radius of curvature, the radius of curvature of the curved portion greater than the radius of curvature of the cutting surface.
In one or more of the embodiments described herein, the blade further includes an initial engagement point configured to engage the tubular.
In one or more of the embodiments described herein, the cutting surface faces laterally inward of the housing in the retracted position.
In one or more of the embodiments described herein, the radius of curvature varies along the curved portion.
In one or more of the embodiments described herein, the blade is substantially semi-circular.
In one or more of the embodiments described herein, the radius of curvature of the cutting surface varies along the cutting surface.
In one or more of the embodiments described herein, a tool for cutting a tubular in a wellbore includes a housing, a first blade having a first cutting surface and configured to move between an extended position and a retracted position, and a second blade having a second cutting surface and configured to move between an extended position and a retracted position, wherein the first cutting surface faces inward of the housing towards the second cutting surface in the retracted position.
In one or more of the embodiments described herein, the first blade and the second blade are disposed adjacent in the housing in the retracted position.
In one or more of the embodiments described herein, a tool for cutting a tubular in a wellbore includes a housing having a first window and a second window formed through a wall of the housing, a pin disposed adjacent the first window, and a blade configured to rotate about the pin between an extended position and a retracted position, the blade having a curved portion disposed adjacent the second window in the retracted position.
In one or more of the embodiments described herein, a method of cutting a tubular includes positioning a rotatable cutting tool in the tubular, the cutting tool having a housing and a blade with a cutting surface disposed thereon, rotating the blade about a pin through a window formed in the housing, rotating the cutting tool relative to the tubular, and cutting the tubular using the cutting surface.
In one or more of the embodiments described herein, a method of cutting a tubular includes positioning a rotatable cutting tool in the tubular, the rotatable cutting tool having a housing and a blade with a cutting surface disposed thereon.
In one or more of the embodiments described herein, the method further includes moving the blade between a retracted position, wherein at least a portion of the cutting surface is disposed on a first side of a longitudinal axis of the housing, and an extended position, wherein the portion of the cutting surface is disposed on a second side of the longitudinal axis.
In one or more of the embodiments described herein, the method further includes rotating the cutting tool relative to the tubular.
In one or more of the embodiments described herein, the method further includes cutting the tubular using the cutting surface.
In one or more of the embodiments described herein, the method further includes stabilizing the cutting tool by engaging the tubular with a stabilizer.
In one or more of the embodiments described herein, the method further includes cutting a second tubular surrounding the tubular.
In one or more of the embodiments described herein, moving the blade further includes rotating the blade about a pin.
In one or more of the embodiments described herein, the pin is disposed in the housing on the second side of the longitudinal axis.
In one or more of the embodiments described herein, the housing has a longitudinal axis.
In one or more of the embodiments described herein, a pin is connected to the housing and disposed on a first side of the longitudinal axis.
In one or more of the embodiments described herein, a blade is configured to move between an extended position and a retracted position about the pin.
In one or more of the embodiments described herein, the blade includes a cutting surface disposed thereon, wherein the cutting surface is disposed at least in part on a second side of the longitudinal axis in the retracted position.
In one or more of the embodiments described herein, a method of cutting a tubular includes positioning a rotatable cutting tool in the tubular, the cutting tool having a housing and a blade, the blade including a cutting surface disposed thereon.
In one or more of the embodiments described herein, the method further includes moving the blade between a retracted position, wherein at least a portion of the cutting surface is disposed on a first side of a longitudinal axis of the housing, and an extended position, wherein the portion of the cutting surface is disposed on a second side of the longitudinal axis.
In one or more of the embodiments described herein, the method further includes rotating the cutting tool relative to the tubular.
In one or more of the embodiments described herein, the method further includes cutting the tubular using the blade.
In one or more of the embodiments described herein, a method of cutting a tubular includes positioning a rotatable cutting tool in the tubular, the cutting tool having a housing and a blade, the blade including a cutting surface disposed thereon; moving a portion of the cutting surface of the blade between a first side of a longitudinal axis of the housing and a second side of the longitudinal axis; rotating the cutting tool relative to the tubular; and cutting the tubular using the blade.
As will be understood by those skilled in the art, a number of variations and combinations may be made in relation to the disclosed embodiments all without departing from the scope of the invention. While the foregoing is directed to embodiments of the present invention, other and further embodiments of the invention may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.
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