Apparatus and method for cutting through or deforming a sidewall wall of a downhole tube

Abstract

An apparatus (102) for cutting through or deforming a sidewall of a downhole pipe. The apparatus (102) comprises a housing (1) having a cylinder (18) disposed therein, and at least one radially movable body member (15) located within the cylinder and radially movable. The housing (1) comprises a fluid port (11) to allow fluid to flow into and out of a fluid chamber (13) of the housing (1). The body member (15) is radially movable from a retracted position to an expanded position by introducing fluid through the fluid port (11) into the fluid chamber (13). The body member (15) is radially movable from the expanded position to the retracted position by withdrawing fluid from the fluid chamber (13) through the fluid port (11).

Description

Technical Field

[0001] The present invention relates to an apparatus and method for circumferentially deforming and / or cutting through the side wall of a downhole tubular (such as a production tubing or other downhole tubular, such as a drilling pipe or casing) at a specific axial or vertical position. More specifically, but not exclusively, the present invention relates to an apparatus and method for circumferentially deforming and / or cutting through the side wall of a downhole tubular, wherein the cutting comprises a 360-degree cut with the same starting and ending circumferential positions, so that the downhole tubular is cut into two parts that are no longer connected, the two parts comprising an upper tubular part and a lower tubular part. Background Art

[0002] In the exploration and / or production of hydrocarbons (such as oil and / or natural gas), it is often necessary to deform a downhole pipe (such as production tubing, drill pipe or casing) radially outwardly and / or cut through the side wall of the downhole pipe in order, for example, to cut the downhole pipe into two, which now constitute an upper part or length of the downhole pipe and a lower part or section of the downhole pipe, and the two parts are separated at the cutting point, for example, so that the upper part can be removed from the wellbore.

[0003] Various methods for deforming a downhole tubular are known to those skilled in the art, such as pushing or pulling a deformable cone through the interior of a through-hole of the downhole tubular.

[0004] With respect to performing horizontal cuts so as to cut through the sidewall of a downhole pipe over the entire 360 ​​degree circumference of the pipe, several techniques are known to those skilled in the art, many of which use lathe type cutting tools that require power from the surface via, for example, an e-line, wherein the lathe type cutting tool comprises a cutting element, such as a circular saw, which rotates at a relatively high speed and abuts against a point on the inner surface of the through hole of the downhole pipe so that the circular blade cuts through the sidewall of the downhole pipe at one point on the circumference and then moves (i.e., rotates) around the inner circumference to cut the sidewall over the entire 360 ​​degree circumference of the pipe. However, such lathe circular blade tools require a large amount of power to be delivered from the surface via the e-line; this is not a particular problem, but due to the relatively high current and voltage levels involved, the e-line is relatively expensive to operate and requires an extensive safety program.

[0005] It is an object of the present invention to provide multiple embodiments of downhole deformation and / or cutting tools that can be operated downhole using a wireline, more preferably a slickline (which is a much lower cost, safer and more direct method of operating downhole tools than an e-wire) (or another working string that does not require the transmission of power), and require less power so that they can be operated and powered by batteries (included in a power control module that operates with the bottom hole assembly at the lower end of the slickline, which also includes the deformation and / or cutting tool). Embodiments of the present invention can provide a deformation and / or cutting tool that is less expensive (by an order of magnitude or more) than deformation and / or cutting tools of the prior art. Summary of the invention

[0006] According to a first aspect of the present invention, there is provided an apparatus for cutting through or deforming a side wall of a downhole tubular, the apparatus comprising:

[0007] a housing having a cylinder disposed therein;

[0008] at least one radially movable body member having a contact surface formed on an outer surface thereof, wherein the body member is located within the cylinder and is radially movable within the cylinder so that the contact surface is movable between a retracted position and an extended position to contact at least the inner surface of the through hole of the downhole pipe,

[0009] wherein the contact surface includes an arc length extending from one end to the other end, the arc length being greater than 18 degrees;

[0010] The main body component includes a piston;

[0011] The housing includes a fluid chamber defined by at least one inner surface of the cylinder and an innermost surface of the piston;

[0012] The housing further includes a fluid port to allow fluid to flow into and out of the fluid chamber;

[0013] the body member being radially movable from the retracted position to the extended position by introducing a fluid into the fluid chamber through the fluid port; and

[0014] The body member is radially movable from the extended position to the retracted position by withdrawing fluid from the fluid chamber through the fluid port.

[0015] Advantageously, the introduction and withdrawal of fluid through the same fluid port provides a greatly simplified device for the operator compared to similar devices described in the prior art, since only one fluid chamber and piston face are required to move the body member back and forth between the retracted position and the extended position. In addition, this maximizes the potential travel of the body member between the retracted position and the extended position.

[0016] Typically, the piston is used to seal the outer end of the chamber between the main body member and the inner surface of the cylinder, wherein the piston preferably includes a seal, which is preferably slidable and acts between the outer surface of the main body member and the inner surface of the cylinder. Optionally, the piston is arranged at the innermost end of the main body member or towards the innermost end, and more preferably, the main body member includes a piston, which is arranged at the innermost end. This has the advantage of maximizing the potential travel of the main body member between the retracted position and the extended position.

[0017] Typically, the device is provided with an independent fluid reservoir in fluid communication with the fluid chamber, typically through the fluid port. Typically, the body member is radially movable from a retracted position to an extended position by introducing fluid from the independent fluid chamber through the fluid port into the fluid chamber. Typically, the body member is radially movable from an extended position to a retracted position by withdrawing fluid from the fluid chamber through the fluid port and into the independent fluid chamber.

[0018] Typically, the separate fluid reservoirs, fluid chambers, and components connected therebetween (preferably including fluid ports) form a closed system that typically has a fixed volume of fluid therein. In other words, during operation of the device, there is no fluid exchange between the closed system and its surroundings, such as the outer wellbore in which the downhole tubular is located. In particular, during operation, fluid is neither released from the closed system nor introduced into the closed system.

[0019] Typically, fluid introduced into the fluid chamber will act on the inner piston face of the piston.

[0020] Typically, the body member includes a biasing mechanism configured to bias the body member radially inwardly.

[0021] Typically, the device is configured to be connected to a hydraulic actuator tool. Typically, the hydraulic actuator tool is configured to introduce fluid into a fluid chamber and typically withdraw fluid from the fluid chamber. Typically, the hydraulic actuator tool is configured to introduce fluid into a fluid reservoir and typically withdraw fluid from the fluid reservoir. Typically, the hydraulic actuator tool is configured to introduce fluid withdrawn from a fluid chamber into a fluid reservoir and typically withdraw fluid from the fluid reservoir and introduce the fluid into the fluid chamber. Typically, the independent fluid reservoir is disposed within the hydraulic actuator tool.

[0022] According to a second aspect of the present invention, there is provided a method for cutting through or deforming the side wall of a downhole pipe, the method comprising the following steps:

[0023] a) inserting the device according to the first aspect of the present invention into a through hole of a downhole pipe;

[0024] b) moving the at least one radially movable body member from the retracted position to the extended position by introducing a fluid from the fluid port into the fluid chamber so that the contact surface contacts at least an inner surface of the through-hole of the downhole tubular;

[0025] c) moving the at least one radially movable body member from the extended position to the retracted position by withdrawing fluid from the fluid chamber through the fluid port; and

[0026] d) rotating the at least one radially movable body member about a longitudinal axis of the radially movable body member.

[0027] Preferably, the method further comprises repeating the steps b), c) and d) as many times as necessary until the contact surface is in contact with the inner surface of the through hole of the downhole pipe at 360 degrees.

[0028] Typically, the body member is movable radially outwardly so as to move the contact surface into contact with the interior of the through hole of the downhole tubular by introducing fluid into the fluid chamber. Typically, the body member is movable radially inwardly so as to move the contact surface away from the interior of the through hole of the downhole tubular by withdrawing fluid from the fluid chamber.

[0029] Preferably, the multiple ends of the contact surface coincide with the same partial circumferential surface (i.e., a plane perpendicular to the longitudinal axis of the device) so that when the contact surface rotates (which can be achieved by operation of an indicator device), one end of the multiple ends will be aligned with the position of the other ends that previously contacted the inner surface of the through hole of the downhole pipe.

[0030] Preferably, the plurality of ends of the contact surface include a first endpoint and a second endpoint, wherein the first endpoint and the second endpoint are different from each other and are located at two opposite ends of the arc length. In a preferred embodiment, all points on the arc length, including the two endpoints, preferably coincide on the same plane (the plane is perpendicular to the longitudinal axis of at least one of the radially movable body member and the downhole pipe, preferably perpendicular to the longitudinal axes of both).

[0031] Preferably, the arc length of the contact surface is in the range of 20 to 180 degrees, more preferably in the range of 30 to 90 degrees, most preferably 60 degrees.

[0032] Preferably, said radially movable body member is rotated in said step d) through an arc length which is equal to the arc length of said contact surface.

[0033] Typically, the contact surface comprises a radius that is substantially the same as the radius of the downhole tubular that the contact surface contacts. Optionally, the contact surface comprises a radius that is different from the radius of the downhole tubular that the contact surface contacts.

[0034] Typically, the contact surface comprises a knife edge surface adapted to cut through the side wall of the downhole tubular.

[0035] Optionally, the contact surface comprises a deformation surface adapted to deform the side wall of the downhole pipe radially outward.

[0036] Preferably, the device is adapted to rotate in the through hole of the downhole pipe about the longitudinal axis of the device, more preferably the device is adapted to rotate in the through hole of the downhole pipe about the longitudinal axis of the device through an arc length equal to the length of the contact surface. Typically, the device is adapted to rotate in the through hole of the downhole pipe about the longitudinal axis of the device so that the contact surfaces remain in the same circumferential plane. (Preferably perpendicular to the longitudinal axis of the device). Typically, when the contact is in the retracted position, the device is adapted to rotate in the through hole of the downhole pipe about the longitudinal axis of the device. Typically, the device is adapted to rotate in the through hole of the downhole pipe about the longitudinal axis of the device by an indicator tool connected thereto.

[0037] Typically, the device is adapted to enter the through hole of the downhole pipe via a wireline when the contact surface is in the retracted position, so as to reach a desired position downhole.

[0038] Typically, the device is adapted to be run into the through hole of the downhole pipe on a work string. Preferably, the work string is preferably a slender member, more preferably a cable or wire, more preferably a wireline, and most preferably a slickline.

[0039] Preferably, the apparatus is disposed within a bottom hole assembly, more preferably comprising a power source located within the bottom hole assembly, thereby eliminating the need to transmit power from the surface. Preferably, the bottom hole assembly comprises the hydraulic actuator tool, preferably powered by the power source, more preferably actuable using a linear actuator tool powered by the power source. Preferably, the linear actuator tool actuates the hydraulic actuator tool by providing power to the hydraulic actuator tool. Preferably, the bottom hole assembly comprises the indicator tool. Preferably, the hydraulic actuator tool is configured to actuate the indicator tool. Preferably, the bottom hole assembly further comprises an anchor assembly, adapted to anchor the bottom hole assembly, thereby anchoring the apparatus in an axial position within the wellbore. Preferably, the linear actuator tool is configured to actuate the anchor assembly.

[0040] More preferably, the contact surface includes an arc length extending from one end to the other end, and the arc length is in the range of from 20 degrees (which will result in the rotatable movable main body component requiring 18 rotations to make 360-degree contact with the inner surface of the through hole of the downhole pipe) to 180 degrees (which will result in 2 rotations being required), even more preferably in the range of from 30 degrees (which will result in 12 rotations being required) to 90 degrees (which will result in 4 rotations being required), preferably in the range of from 45 degrees (which will result in 8 rotations being required) to 72 degrees (which will result in 5 rotations being required), and most preferably in the range of 60 degrees (which will result in 6 rotations being required).

[0041] Preferably, the retracted position of the contact surface has a contact surface spaced apart from the inner surface of the through-hole of the downhole pipe, and typically, when in the retracted position, the contact surface is completely located within the device (such that it does not extend further from the device than other parts of the device).

[0042] Preferably, the extended position of the contact surface makes the contact surface contact the inner surface of the through hole of the downhole pipe.

[0043] The accompanying drawings illustrate current exemplary embodiments of the present disclosure and, together with the general description given above and the detailed description of the embodiments given below, serve to explain the principles of the present disclosure by way of example.

[0044] In the following description, similar parts are respectively marked with the same reference numerals throughout the entire specification and the drawings of the specification. The illustrations are not necessarily drawn to scale. For the sake of clarity and brevity, certain features of the present invention may be scaled up or shown in a schematic form, and some details of traditional elements may not be shown. The present invention allows for different forms of embodiments. Specific embodiments of the present invention are shown in the drawings of the specification, and they will be described in detail herein, but it should be understood that the present disclosure will be regarded as an example of the principles of the present invention and is not intended to limit the present invention to what is shown and described herein. It should be fully recognized that the different teachings of the embodiments discussed below can be used alone or in any suitable combination to produce the desired results.

[0045] The following definitions will be followed in the specification. As used herein, the term "wellbore" refers to a wellbore or wellbore provided or drilled in a manner known to those skilled in the art. The wellbore may be an "open hole" or "cased", a tubular string with a lining. For the purpose of description, the following terms will be used to refer to the upper or lower, the term "above", "up", "upward", "upward" or "upstream" refers to the longitudinal axis of the work string away from the bottom of the wellbore towards the ground, "below", "down", "downward", "lower" or "downstream" refers to the longitudinal axis of the work string towards the bottom of the wellbore, away from the ground and deep into the well, whether the well referred to is a traditional vertical well or an inclined well, thus including the typical situation where the drilling equipment is located above the wellhead and the well extends downward from the wellhead to the formation, but it can also be a horizontal well, where the formation is not necessarily located below the wellhead. Likewise, "work string" refers to any elongated member (such as a wire or cable) or tubular device used to transport fluids and / or tools from the surface into a wellbore. In the present invention, wireline is the preferred work string.

[0046] As will be appreciated by those skilled in the relevant art, various aspects of the present invention can be practiced separately or in combination with one or more other aspects. Various aspects of the present invention can optionally be provided in combination with one or more optional features of other aspects of the present invention. In addition, in different embodiments of the present invention, the optional features associated with an embodiment can usually be combined separately or in combination with other features. In addition, any feature disclosed in the specification can be combined separately or in combination with other features in the specification to form the present invention.

[0047] Various embodiments and aspects of the present invention will now be described in detail with reference to the accompanying drawings. Other aspects, features and advantages of the present invention are readily apparent from the entire description of the present invention, including the accompanying drawings (which illustrate multiple exemplary embodiments, multiple aspects and multiple implementations). The present invention can also have other and different embodiments and multiple aspects, and its respective details can be modified in various aspects without departing from the spirit and scope of the present invention.

[0048] Any discussion of documents, acts, materials, devices, articles or the like is included in the specification solely for the purpose of providing a context for the present invention. It is not suggested or represented that any or all of these matters form part of the prior art base or are common general knowledge in the field relevant to the present invention.

[0049] Therefore, the description of the drawings and the description of the specification should be regarded as illustrative in nature, rather than restrictive. In addition, the terms and wordings used herein are only for descriptive purposes and should not be interpreted as limitations on the scope of rights. Languages ​​such as "including, comprising", "having", "containing" or "involving" and their variations are intended to be broad, covering the subject matter, equivalents and uncited additional subject matter listed hereafter, and are not intended to exclude other additives, components, wholes or steps. In the present disclosure, whenever the conjunction "including / comprising" is used in front of a component, element or element group, it should be understood that it is also considered to use the conjunction "essentially consisting of...", "consisting...", "selected from the group of consisting of...", "including / comprising" or "is / is" to describe the same component, element or element group before the component, element or or element group, and vice versa. In this disclosure, the words “generally” or “optionally” should be understood as intended to indicate optional or non-essential features of the invention, which are present in some examples but may be omitted in other examples without departing from the scope of the invention.

[0050] All numerical values ​​in this disclosure are understood to be modified to mean “about.” All singular elements or any other components described herein, including but not limited to plural components of the devices described herein, are understood to include the plural form thereof and vice versa. BRIEF DESCRIPTION OF THE DRAWINGS

[0051] Embodiments of the present invention will now be described, by way of example only, with reference to the accompanying drawings, in which:

[0052] Figure 1 is a perspective side view of a cutter bottom hole assembly (BHA) 100, wherein in use, the cutter bottom hole assembly 100 will be connected at its uppermost end to the lowermost end of a working string (e.g., a cable), which is preferably a wireline, which can be Figure 1 The cutter bottom hole assembly is run into the wellbore in the configuration shown, and consists from top to bottom of a:

[0053] Power Control Module (PCM) and Linear Actuator Tool 106;

[0054] Anchor tool 105;

[0055] Hydraulic actuator tool 104;

[0056] Indexer tool 103;

[0057] a guillotine tool 102; and

[0058] Bull nose tool101.

[0059] Figure 2 yes Figure 1 A cross-sectional side view of the linear actuator tool 104 is shown;

[0060] Figure 3 yes Figure 1 A cross-sectional side view of a cutter tool 102;

[0061] Figure 4 yes Figure 1 A cross-sectional side view of a round end tool 101;

[0062] Figure 5 yes Figure 1 and Figure 3 1 , wherein the cutter tool 102 is shown in a running in configuration (the cutter cutting edge 3 is in a radially retracted position);

[0063] Figure 6 yes Figure 1 and Figure 3 A perspective side view of the cutter tool 102 shown in FIG. 1 , but now showing the cutter cutting edge 3 in a radially extended (cutting) position;

[0064] Figure 7 yes Figure 6 An end view of the cutter tool 102 also shows the cutter cutting edge 3 in a radially expanded (cutting) position;

[0065] Figure 8 yes Figure 1 and Figure 3 An exploded perspective side view of a cutter tool of FIG. 1 , wherein the components are shown only in an exploded configuration for ease of understanding by those skilled in the art;

[0066] Fig. 9 yes Figure 1 and Figure 3 1 , showing a cross-sectional side view of a cutter tool 102 in more detail and also showing the cutter cutting edge 3 in a radially retracted configuration;

[0067] Fig.10 yes Figure 1 and Figure 3 , but wherein the cutter cutting blade 3 is now shown in a radially expanded (cutting) position for cutting a sidewall 111 of a downhole pipe 110 (such as a production tubing string);

[0068] Fig.11 is a perspective side view of a cutter tool 102 located in a downhole pipe 110 (e.g., a production tubing string 110), wherein the cutter cutting edge 3 has cut through a partial circular cross-section 112 of a sidewall 111 of the production tubing string 110;

[0069] Fig.12 yes Fig.11 1 is a perspective side view of a cutter tool 102, but for ease of understanding by those skilled in the art, half of the production tubing 110 has been cut away;

[0070] Fig.13 yes Fig.12 A side view of a partially cut-away production tubing 110 with a cutter tool 102 positioned therein and forming a cut 113 of a partially circular cross-section 112 through the production tubing string 110;

[0071] Fig.14 is a second embodiment of a cutter tool 202 that can be used in a cutter bottom hole assembly 100 as an alternative to the first embodiment of the cutter tool 102, wherein the second embodiment of the cutter tool 202 includes a cutter deforming blade 203 (instead of the cutter cutting blade 3 provided in the first embodiment of the cutter tool 102) and can be used to deform a downhole tubular 110 (instead of cutting the downhole tubular 110 as with the first embodiment of the cutter tool 102);

[0072] Fig.15aA third embodiment of a cutter tool 302 is shown that may be used within the cutter bottom hole assembly 100 as an alternative to the cutter tool 102, wherein the cutter tool 302 includes a cutter cutting edge 303 of a different shape and form than the cutter cutting edge 3 of the first embodiment of the cutter tool 102, and wherein the cutter cutting edge 303 is shown in a radially expanded (cutting) position; and

[0073] Fig.15b An end view of a third embodiment of a cutter tool 302 is shown, with the cutter cutting edge 303 also shown in a radially expanded (cutting) position. DETAILED DESCRIPTION

[0074] Figure 1 A cutter bottom hole assembly (BHA) 100 is shown, wherein the upper end of the cutter bottom hole assembly 100 is shown on the left, and is typically connected to the lower end of a work string, such as a preferred wireline work string (not shown). In use, the cutter bottom hole assembly 100 is arranged to be Figure 1 In the illustrated operating configuration, the tubular is fed into a wellbore (not shown) through a through hole of a downhole tubular 110 (eg, a production tubing string 110).

[0075] The cutter bottom hole assembly 100 is moved from top to bottom (eg Figure 1 shown, from left to right) include:

[0076] A suitable power control module (PCM) containing a suitable power source, such as one or more battery packs and a linear actuator means which, when powered by the power control module, will linearly push a rod or piston upward or downward as required (in this example, upward) to provide power to at least one or more tools located below it in the cutter bottom hole assembly 100. The power control module and linear actuator means 106 may be any suitable power control module and linear actuator means 106, such as the K-Set supplied by Kaseum Technology Ltd. of Discovery Drive, Aberdeen, UK. TM Tools and / or tools described in International Patent Application Publication No. WO2019 / 180462;

[0077] The upper end of the anchor tool 105 is attached to the lower end of the power control module and linear actuator tool 106, wherein the anchor tool 105 can be actuated by the power control module and linear actuator tool 106 (when required) to move a set of anchors radially outward, thereby clamping and anchoring both the anchor tool 105 and the rest of the cutter bottom hole assembly 100 to the inner surface of the downhole tubular 110, which will then be deformed or cut as required. Any suitable anchor tool 105 can be used. An example of a suitable anchor tool 105 is the K-FISH™ anchor tool provided by Kaseum Technology Ltd. of Discovery Drive, Aberdeen, UK. However, it should be noted that the anchor tool 105 may not need to be included in the cutter bottom hole assembly 100 in some cases if the operator does not actually require anchoring;

[0078] The upper end of the hydraulic actuator tool 104 is securely attached to the lower end of the anchor tool 105, wherein the hydraulic actuator tool 104 is also actuated by the power control module and the linear actuator tool 106, wherein it also has a rod 104R passing through it from the lower end of the power control module and the linear actuator tool 106, wherein when the rod 104R moves upward through the hydraulic actuator tool 104, the hydraulic fluid contained in the annular chamber 104C (which is coaxially disposed between the inner surface of the housing of the hydraulic actuator tool and the outer surface of the rod 104R, and is further defined by the upper seal 1 04US and piston 104P, piston 104P having a lower seal 104LS set at the lower end of rod 104R) to very high pressure, for example in the range of 10,000 to 30,000 psi (68.95 to 206.84 MPa), in particular in the range of 15,000 to 16,000 psi (103.42 to 110.32 MPa), when necessary, the hydraulic actuator tool 104 supplies very high pressure hydraulic fluid to the cutter tool 102 through the central hydraulic fluid conduit 104H, as will be described subsequently.

[0079] The upper end of the indicator tool 103 is securely connected to the lower end of the hydraulic actuator tool 104, wherein the indicator tool 103 can be actuated by supplying high pressure hydraulic fluid from the hydraulic actuator tool 104 to rotate the cutter tool 102 (which is connected at the lower end) through a specific rotation angle, such as 30 degrees, 60 degrees or 90 degrees, as required and predetermined by the operator; in this embodiment, 60 degrees is preferred, so that the indicator tool 103 needs to be rotated 6 times in order to rotate the cutter tool 102 360 degrees (as will be described in detail later). Any suitable indicator tool 103 can be used, but two examples thereof are as follows:

[0080] Hydraulic Indicator Tools provided by TOMS and Interenergy, Inc. (also known as Ties, Inc.), 15902 Hollister Street, Houston, Texas 77066, USA; or

[0081] High torque index tools supplied by Downhole Tools International, 2 Allen Lane, Poole, BH16 5DA, United Kingdom;

[0082] The upper end of the cutter tool 102 according to the present invention is attached to the lower end of the indicator tool 103, wherein, as will be described later, the cutter tool 102 will be actuated by means of a high-pressure hydraulic fluid delivered from a hydraulic actuator tool 104 to force the cutter cutting blade 3 to easily cut outward through the part-circular cross-section 112 of the side wall 111 of the downhole pipe (such as the production tubing 110);

[0083] The upper end of the round tip tool 101 is securely connected to the lower end of the cutter tool 102, wherein the round tip tool 101 in use guides and directs the lower end of the cutter bottom hole assembly 100 through the through hole of the downhole tubular 110 when running in the downhole tubular 110, and also serves to provide the release of high pressure hydraulic fluid when the cutter bottom hole assembly 100 is pulled out of the wellbore, as will be described in more detail later.

[0084] The cutter tool 102 comprises a generally cylindrical shape 1. Fig. 9 As shown, the cutter body 15 is located in a cylindrical recess formed radially at the approximate midpoint of the housing 1, wherein the cutter blade 3 is formed on the outermost surface of the cutter body 15, and a flange 17 is formed on the innermost end of the cutter body 15 (advantageously maximizing the potential travel of the cutter body 15 between the retracted and extended positions), and the flange 17 is circular and has a diameter greater than the axial width of the cutter body 15. A (primary) slidable O-ring 6 is arranged around the outer periphery of the flange 17 so that the O-ring 6 is sealed on the inner surface of the cylindrical recess 18. An O-ring support 5 is also provided to prevent the extrusion of the primary O-ring 6. The fixing plate 2 is fixed around the outer end of the cylindrical recess 18 by suitable fixing means (such as cap screws 9, 10, etc.), wherein the fixing plate 2 includes a hole 19 formed around its midpoint, the hole 19 being wide enough (i.e., it includes an axial width wider than the axial width of the cutter body 15) to allow the cutter blade 3 to extend radially outward when the cutter tool 102 is actuated but narrow enough (i.e., its axial width is less than the diameter of the flange 17) to allow the cutter blade 3 and a major part of the cutter body 15 to pass therethrough, thereby preventing the flange 17 from passing therethrough, so that the fixing plate 2 always functions to retain at least the flange 17 of the cutter body 15 in the cylindrical recess 18.

[0085] By means of a suitable biasing means (such as a set of compression springs 4), the cutter body 15 is biased to Fig. 9 In the retracted position shown, the compression spring 4 acts between the inner surface of the fixing plate 2 and the outermost surface of the flange 17. Therefore, in order for the cutter blade 3 to extend radially outward, the cutter body 15 must move outward against the spring force provided by the spring 4. Therefore, the spring 4 will help to retract the cutter body 15 when necessary. Fig. 9 The retracted position is shown as described subsequently.

[0086] The cutter tool 102 is arranged so that when high pressure hydraulic fluid (e.g. in the range of 10000 to 30000 psi (68.95 to 206.84 MPa), in particular in the range of 15000 to 16000 psi (103.42 to 110.32 MPa)) is supplied from the hydraulic actuator tool 104 into the fluid port 11, the high pressure hydraulic fluid will act on the inner piston face 12 (in particular from the O-ring seals 5, 6), and the continued supply of high pressure hydraulic fluid through the fluid port 11 will begin to accumulate in the hydraulic fluid chamber 13, thereby forcing the inner piston face 12, the flange 17, the cutter body 15 and the cutter blade 3 to move radially outwards, causing them to move from the inner piston face 12 to the inner piston face 12. Fig. 9 The retracted position shown moves to Fig.10 Radially expanded position shown. Continued pumping of high pressure hydraulic fluid into fluid port 11 will continue to move cutter body 15 radially outward until the outermost surface of flange 17 abuts the inner surface of retainer plate 2, at which point retainer plate 2 prevents cutter body 15 from further outward movement.

[0087] Thus, withdrawing the high pressure hydraulic fluid from the hydraulic fluid chamber 13 will allow the cutter body 15 to be moved from the Fig.10 The extended position shown moves radially inward, back to Fig. 9104H and back into the annular chamber 104C within the hydraulic actuator means 108). The introduction and withdrawal of fluid from the single hydraulic fluid chamber 13 through the same fluid port 11 advantageously simplifies the cutter tool 102 by providing an apparatus that requires only a single fluid chamber 13 and piston face 12 to extend and retract the cutter body 15. Furthermore, this maximises the travel available to move the cutter body 15 relative to the overall outer diameter of the cutter bottom hole assembly 100. The spring 4 will assist in the radially inward movement of the cutter body 15, as will the hydrostatic pressure provided by the wellbore fluid external to the cutter bottom hole assembly 100, as this will act on the outermost surface of the flange 17, particularly when the hydrostatic pressure is greater than the pressure of the hydraulic fluid within the hydraulic fluid chamber 13.

[0088] The annular chamber 104C of the hydraulic actuator tool can be regarded as another fluid reservoir 104C that is independent of and in fluid communication with the fluid chamber 13 of the cutter tool 102. It will be understood by those skilled in the art that the fluid reservoir 104C of the hydraulic actuator tool 104, the fluid chamber 13 of the cutter tool 102, and the components connected therebetween constitute a closed system with a fixed volume (and therefore a fixed volume of fluid, such as a substantially incompressible hydraulic fluid contained therein), so that in operation, there is no fluid exchange between the closed system and its surroundings (i.e., moving the cutter body radially inward or radially outward). In particular, during operation, fluid is neither released from nor introduced into the closed system.

[0089] A hydraulic fluid outlet 16 is provided in the cutter tool 102, which leads from the lower end of the hydraulic fluid chamber 13 to the lower end of the cutter tool 102 and can deliver hydraulic fluid to the round end tool 101 located below the cutter tool 102. The round end tool 101 will simply retain the hydraulic fluid supplied to it and will not generally interfere with the operation of the cutter tool 102 or the cutter bottom hole assembly 100. However, a hydraulic fluid release mechanism is provided in the round end tool 101, which can include a burst disc 20 (such as Figure 41. The rupture disc 20 is a tool for the cutter bottom hole assembly 100, which is a device for the cutter bottom hole assembly 100 to be used as a tool for the cutter bottom hole assembly 100. The tool for the cutter bottom hole assembly 100 is a tool for the cutter bottom hole assembly 100, which is a tool for the cutter bottom hole assembly 100 to be used as a tool for the cutter bottom hole assembly 100. The tool for the cutter bottom hole assembly 100 is a tool for the cutter bottom hole assembly 100, which is a tool for the cutter bottom hole assembly 100, which is a tool for the cutter bottom hole assembly 100, and a tool for the cutter bottom hole assembly 100. The tool for the cutter bottom hole assembly 100 is a tool for the cutter bottom hole assembly 100, which is a tool for the cutter bottom hole assembly 100, and a tool for the cutter bottom hole assembly 100, which is a tool for the cutter bottom hole assembly 100, ...

[0090] Those skilled in the art will further appreciate that by withdrawing the high pressure hydraulic fluid from the hydraulic fluid chamber 13, the action is similar to attempting to draw a vacuum within the hydraulic fluid chamber 3, and thus this action will force and pull the cutter body 15 out of the hydraulic chamber 13. Fig.10 The radial expansion position shown is Fig. 9 Radially retracted position shown.

[0091] The cutter tool 102 is also provided with a (primary) O-ring 8 at its lower end, which seals the inner surface of the upper end of the round end tool 101 , and an O-ring support 7 to prevent extrusion of the primary O-ring 8 .

[0092] For example Figure 5 and Figure 6 In the first embodiment of the cutter tool 102 shown in FIG, the cutter cutting edge 3 has a certain circumferential width (i.e., the width between the two ends 3L, 3R of the arc length defined by the cutting edge 3), and the circumferential width between the ends 3L, 3R is the same as the circumferential width 15W of the cutter body 15. In addition, as shown in FIG. Figure 6 and Figure 7 As shown, the outermost cutting surface of the cutter blade 3 has a radius, so that the cutter blade 3 is a portion of a circle. Figure 6 In the embodiment of the cutter tool 102 shown, the cutter blade 3 extends through a 60 degree arc between the ends 3L, 3R so that when the cutter tool 102 is actuated to extend the cutter blade 3 radially outward to Figure 6 The positions shown, and in particular Figure 7 and Figures 10 to 13As shown, the cutter cutting edge 3 will thus cut through a 60 degree arc circumferentially around the sidewall of the downhole tubular 110 (such as production tubing string 110) to form a partially circular cut portion of the sidewall 112 therein.

[0093] In addition, it is preferred that the outer surface of the cutter cutting edge 3 is a partial circle with a uniform radius. In addition, it is preferred that the uniform radius matches the radius of the inner surface of the downhole pipe 110 to be cut (so that the entire cutting surface of the cutter cutting edge 3 is in contact with the inner surface of the throughbore of the downhole pipe 110 at the same time, thereby forming a uniform cut through the side wall 112). Other embodiments may also have cutter cutting edges of different forms or shapes, and in fact in some embodiments, the outer surface of the cutter cutting edge 3 is not rounded and can actually be a flat surface (planer surface) so that when it expands to Fig.10 In the extended position shown, the outermost edges of the planer cutter blade (not shown) (i.e., the edges corresponding to 3L, 3R) contact the inner surface of the through hole of the downhole pipe 110 at two spaced points, and the further radially outward extension of the cutter body 15 causes the two end cutting contact points to move closer together until the entire length of the planer cutter blade pierces the side wall of the downhole pipe. However, it is preferred that the outer surface of the cutter cutting blade 3 is a part of a circle with a fixed radius, most preferably the fixed radius matches the inner radius of the downhole pipe to be cut, so that the cutter body 15 has a minimum stroke to completely cut through the side wall 112 of the downhole pipe 110.

[0094] The radial length of the cutter body 15 is long enough, and the cutter body 15 is arranged to extend radially outward to a sufficient extent when cutting is required, so that it can extend outward:

[0095] First, the annular gap between the outer cutting surface of the cutter blade 3 and the inner surface of the downhole pipe 110 (such as the production oil pipe string 110) is brought close; and

[0096] Secondly, the entire arc length of the outer cutting surface of the cutter blade 3 (i.e., the entire length between the ends 3L, 3R) is moved through the entire depth of the sidewall 111 of the downhole pipe 110 (such as the production oil tubing string 110), so that the cutter blade 3 cuts through the entire depth of the sidewall 110 of the partial circular cross-section of the sidewall 112 (in this example, the partial circular cross-section of the sidewall 112 extends in a 60-degree arc around the circumference of the production oil tubing string 100).

[0097] Those skilled in the art will appreciate that the entire length between the ends 3L, 3R of the outer cutting surface of the cutter blade 3 need not all lie on the same part circumferential plane, as non-part circumferential cutting edges (e.g., sinusoidal (not shown) or triangular cutting tooth profiles (not shown) etc.) may be provided, but it is important that the ends 3L, 3R of the outer cutting surface of the cutter blade 3 lie or coincide on the same part circumferential plane, so that when the cutter tool 102 is rotated by operation of the index tool 103 (as described subsequently), one of the ends (e.g., 3L) will align with the end of the cut previously formed by the other end (e.g., 3R) through the part circular section of the side wall 112, so that when the cutter body 15 then extends radially outwardly, it cuts through another 60 degree part circular section of the side wall, which is adjacent to the previously formed 60 degree part circular section of the side wall 112, so that a 120 degree cut is now formed through the part circular section of the side wall 112 (and so on). However, it is preferred that the entire length including the ends 3L, 3R of the outer cutting surface of the guillotine cutting edge 3 lies / coincides with the same part of the circumference providing the shortest possible cutting length.

[0098] It should also be noted that although only one cutter body 15 is shown, and therefore each cutter tool 102 has only one cutter cutting edge 3, those skilled in the art will appreciate that the above embodiment may be modified and / or improved, for example by providing two or more cutter bodies 15 located within their respective cylindrical recesses 18 so as to provide each cutter tool 102 with multiple cutter cutting edges 3; in this case, preferably, the respective cutter bodies 15 will be spaced around the housing 1 within the respective cylindrical recesses 18 so that the respective cutting edges 3 will all be located on the same cylindrical face and spaced apart by multiples of the circumferential width 15W (e.g. 1, 2 or 3) so that rotating the cutter tool 102 by the index tool 103, for example, a predetermined rotation arc (e.g. 60 degrees), causes each of the plurality of cutter blades 3 to be rotated around and aligned with the next portion of the circular cross-section of the side wall 112 to be cut, which also results in the index tool 103 requiring less rotation.

[0099] The arc length of the cutter blade 3 (i.e., the circumferential distance between the ends 3L, 3R) may be any suitable arc length, but greater than 18 degrees, so that the number of rotations of the cutter tool 102 by the index tool 103 and the number of radial deformations and retractions of the cutter body 15 are feasible within the power limits of the energy provided by the battery of the power control module, and the time required for a full 360-degree cut around the entire circumference of the side wall 111 is kept to a minimum, wherein greater than 18 degrees means that less than 20 rotations of the cutter tool 102 are required for a full 360-degree cut. In a preferred embodiment, the arc length is in the range of 20 degrees to 180 degrees (requiring 18 or 2 rotations, respectively), in a more preferred embodiment in the range of 30 degrees to 90 degrees (requiring 12 or 4 rotations, respectively), and more preferably in the range of 45 degrees (8 rotations) to 72 degrees (5 rotations), and in a preferred embodiment ... Figures 1 to 15b In the most preferred embodiment shown, the arc length is in the range of 60 degrees so that only 6 rotations of the cutter tool 102 are required to pass the indicator tool 103, as this provides the best compromise between the maximum circumference of the side wall 111 that can be cut in the shortest time per cut or deformation and the minimum energy used by the battery pack in the power control module and linear actuator tool 106.

[0100] Method for cutting through the side wall 111 of a downhole pipe 110 360 degrees

[0101] The cutter bottom hole assembly 100 usually enters the wellbore through a through hole of a downhole pipe 110, which is to be cut into two halves, such as a production tubing string 110. The cutter bottom hole assembly 100 enters until the cutter tool 102 (particularly the cutter blade 3) reaches the depth position where the downhole pipe 110 needs to be cut into two sections. The cutter bottom hole assembly 100 is stopped at this point by stopping the operation of the wireline unit (not shown) at the surface.

[0102] The power control module and the linear actuator tool 106 may then be actuated, typically by wireless command or by waiting for a timer on the power control module to expire, thereby instructing the power control module to operate the linear actuator tool 106, which in turn actuates the anchor tool 105 (if present) to abut against the inner surface of the through-hole of the downhole tubular 110. Continued actuation of the linear actuator tool 106 by the power control module will cause the hydraulic actuator tool 104 to provide high pressure hydraulic fluid into the fluid port 11 of the cutter tool 102, thereby forcing the cutter body 15 and the cutter blade 3 to radially outwardly penetrate a 60 degree arc of the sidewall 111 of the downhole tubular 110, thereby forming a cut of a partially circular cross-section 112 through the sidewall 111. It should be noted that the cutter body 15 will continue to move radially outwardly to cause the cutter cutting blade 3 to penetrate the sidewall 111 of the downhole tubular 110 until the cutter cutting blade 3 completely penetrates the sidewall 111. The abutment surface 14 is provided on one side of the cutter cutting blade 3 and is arranged to abut against the inner surface of the through hole of one half (e.g., the upper half) of the downhole pipe 110, thereby preventing the radial outward movement of the cutter body 15. This helps to ensure that the cutter body 15 does not extend excessively outward and thus does not move too far outward, and helps to prevent the cutter body 15 from getting stuck with the side wall 111 of the downhole pipe 110.

[0103] The power control module can then be activated to draw hydraulic fluid from the hydraulic fluid chamber 13, thereby pulling the cutter body 15 radially inwardly from the Fig.10 Shown in extended configuration position retracted Fig. 9 Shown in retracted position.

[0104] Once the cutter body 15 has moved radially inwards and has fully returned to Fig. 9In the retracted position shown, the power control module and linear actuator means 106 can actuate the indexer means 103 to rotate the cutter means 102 by a predetermined amount, such as the same arc length as the cutter blade 3 (e.g., the arc length between the ends 3L, 3R), which in this example is 60 degrees. Once the indexer means 103 has rotated the cutter means 102 by a predetermined amount (preferably matching the circumferential extent of the arc provided by the cutter cutting blade 3), the power control module and linear actuator means 106 can then actuate the hydraulic actuator means 104 again to supply high pressure hydraulic fluid into the fluid port 11, thereby repeating the cutting of the next 60 degree arc (i.e., the next partial circular section 112 of the sidewall 111) of the downhole tubular 110 by the cutter cutting blade 3. Actuation of the indexer tool 103 may then be performed again, and the process may be repeated until the cutter tool 102 has been rotated 5 times (i.e. 300 degrees) and the cutter cutting blade 3 has been extended the required number of times (i.e. 6 times) to cut through the 360 ​​degree partial circular section 112 of the sidewall 111 of the downhole pipe 110. Furthermore, since the wireline is always locked at the same vertical height, the cutter tool 102 ensures that the 60 degree cut through the partial circular section 112 of the sidewall 111 is formed at exactly the same height / axial position around the circumference of the downhole pipe 110, and the anchor tool 105, if present, further ensures that the separate cuts through the partial circular section 112 of the sidewall 111 are formed at the same vertical height in the well, thereby ensuring that the downhole pipe 110 is cleanly cut into two sections, forming an upper downhole pipe section and a lower downhole pipe section. Once the final (sixth) cut has been made, the anchor 105 can be released and the cutter bottom hole assembly 100 can be pulled out of the wellbore, thereby leaving the cut downhole tubular 110 in the well so that the upper section of the cut downhole tubular 110 can be pulled out of the wellbore in a separate operation (if it is necessary to remove the upper section of the cut downhole tubular 110 from the wellbore).

[0105] Embodiments of the present invention have the great advantage that they use significantly less power than prior art methods and can therefore be operated on a wireline and into a wellbore, which provides significantly lower costs (perhaps an order of magnitude lower) than existing prior art methods of cutting downhole tubulars.

[0106] Fig.14A second embodiment of the cutter tool is shown having a cutter deforming blade 203 instead of the cutter cutting blade 3 provided on the outermost surface of the cutter body 15. In other words, instead of using the cutting edge provided by the cutter cutting blade 3 to cut through the part circular cross section 112 of the side wall 111, the cutter deforming blade 203 includes a part circular but flat outer surface which will contact the inner surface of the through hole of the downhole tubular 110, so that instead of providing a point contact to cut through the downhole tubular 110, the flat cutter deforming blade 203 will act on a larger surface area of ​​the inner surface of the through hole of the downhole tubular 110, so that it will act to deform the side wall 111 of the downhole tubular 110 outwardly instead of cutting through the downhole tubular 110. Thus, the second embodiment of the cutter tool 202 can be used to deform a downhole tubular 110 (thus leaving the sidewall 111 intact rather than cutting through it) so as to deform it into contact with a wellbore located outside the downhole tubular 110, or to deform the downhole tubular 100 into contact with another external downhole tubular 110.

[0107] Fig.15a and Fig.15b A third embodiment of a cutter tool 302 is shown, the cutter tool 302 comprising a cutter cutting blade 303 and comprising a guide point 303LP located at the apex of the partial conical section 303C. Thus, when the cutter cutting blade 303 of the third embodiment of the cutter tool 302 is placed in the cutter bottom hole assembly 100 (rather than the first embodiment of the cutter tool 102), and when the cutter cutting blade 303 is forced radially outward by the high pressure hydraulic fluid concentrated in the hydraulic chamber 13, the guide point 303LP will contact the inner surface of the downhole tubular 110, and further radial deformation of the cutter cutting blade 303 outward will cause the blade 303E to cut through the sidewall 111 of the downhole tubular 110 in a progressive action, so the third implementation of the cutter blade 303 is more suitable for applications where there may be a greater distance of radial deformation and a more highly localized cutting action or force is required.

[0108] Those skilled in the art may design other shapes and forms of the cutter cutting edge and the cutter deformable edge without departing from the scope of the present invention.

[0109] Embodiments of the present invention have further advantages in that they can run on a wireline and can be driven and powered by a relatively low power source, such as a battery pack located in a downhole tool (such as a power control module), and can be operated to cut through a downhole tubular string 110 (such as a production tubing string 110), such embodiments will save operators considerable cost and time.

[0110] Modifications and improvements may be made to the above-described embodiments without departing from the scope of the present invention.

Claims

1. A device for cutting through or deforming the side wall of a downhole pipe, characterized in that: The device comprises: a housing having a cylinder disposed therein; at least one radially movable body member having a contact surface formed on an outer surface thereof; wherein the main body member is located in the cylinder and can move radially in the cylinder so that the contact surface can move between a retracted position and an extended position to at least contact the inner surface of the through hole of the downhole pipe, wherein the contact surface includes an arc length extending from one end to the other end, the arc length being greater than 18 degrees; Wherein the main body component comprises a piston; wherein the housing includes a fluid chamber defined by at least one inner surface of the cylinder and an innermost surface of the piston; wherein the housing further comprises a fluid port to allow fluid to flow into and out of the fluid chamber; wherein the body member is radially movable from the retracted position to the extended position by introducing fluid into the fluid chamber through the fluid port; and Wherein the body member is radially movable from the extended position to the retracted position by withdrawing fluid from the fluid chamber through the fluid port.

2. The device according to claim 1, characterized in that The main body component can be moved radially outward so that the contact surface is moved to contact the internal through hole of the downhole pipe by introducing fluid into the fluid chamber; and the main body component can be moved radially inward so that the contact surface is moved away from the internal through hole of the downhole pipe by extracting fluid from the fluid chamber.

3. The device according to any one of the preceding claims, characterized in that Both ends of the contact surface coincide with the same portion of the circumferential surface.

4. The device according to any one of the preceding claims, characterized in that The two ends of the contact surface include a first endpoint and a second endpoint, wherein the first endpoint and the second endpoint are different from each other and are located at two opposite ends of the arc length, and all points on the arc length, including the two endpoints, coincide on the same plane.

5. The device according to any one of the preceding claims, characterized in that The arc length of the contact surface is between 20 degrees and 180 degrees.

6. The device according to claim 5, characterized in that The arc length of the contact surface is between 30 degrees and 90 degrees.

7. The device according to claim 6, characterized in that The arc length of the contact surface is 60 degrees.

8. Apparatus according to any one of the preceding claims, characterised in that The contact surface includes a radius that is substantially the same as a radius of the downhole tubular that the contact surface contacts.

9. The device according to any one of claims 1 to 7, characterized in that The contact surface includes a radius that is different than a radius of the downhole tubular that the contact surface contacts.

10. The device according to any one of the preceding claims, characterized in that The contact surface includes a knife edge surface adapted to cut through a side wall of the downhole tubular.

11. The device according to any one of claims 1 to 9, characterized in that The contact surface includes a deforming surface adapted to deform the side wall of the downhole tubular radially outward.

12. Apparatus according to any one of the preceding claims, characterised in that The device has a longitudinal axis and is adapted to rotate within the through hole of the downhole pipe about the longitudinal axis with an arc length equal to the length of the contact surface.

13. Apparatus according to any one of the preceding claims, characterised in that The device has a longitudinal axis and is adapted to be rotated about the longitudinal axis within the through hole of the downhole pipe so that the contact surfaces remain in the same circumferential plane.

14. Apparatus according to any one of the preceding claims, characterised in that The device is arranged in a bottom hole drilling tool assembly, and the bottom hole drilling tool assembly includes a power supply, and the power supply is inside the bottom hole drilling tool assembly.

15. Apparatus according to any one of the preceding claims, characterised in that The device is disposed within a bottom hole assembly, the bottom hole assembly comprising an anchor assembly adapted to anchor the bottom hole assembly to thereby anchor the device in an axial position within a wellbore.

16. Apparatus according to any one of the preceding claims, characterised in that The device is suitable for moving into the through hole of the downhole pipe through a wire rope when the contact surface is in the retracted position, so as to reach a required position underground.

17. Apparatus according to any one of the preceding claims, characterised in that The apparatus is provided with a separate fluid reservoir in fluid communication with the fluid chamber.

18. Apparatus according to any one of the preceding claims, characterised in that The body member includes a biasing mechanism configured to bias the body member radially inwardly.

19. Apparatus according to any one of the preceding claims, characterised in that The apparatus is configured to be coupled to a hydraulic actuator tool configured to introduce fluid into and withdraw fluid from the fluid chamber.

20. A method for cutting through or deforming the side wall of a downhole pipe, characterized in that: The method comprises the following steps: a) inserting the device according to any one of claims 1 to 19 into the through hole of the downhole pipe; b) moving the at least one radially movable body member from a retracted position to an extended position by introducing a fluid from the fluid port into the fluid chamber so that the contact surface contacts at least an inner surface of the through-hole of the downhole tubular; c) moving the at least one radially movable body member from the extended position to the retracted position by withdrawing fluid from the fluid chamber through the fluid port; and d) rotating the at least one radially movable body member about a longitudinal axis of the radially movable body member.

21. The method of claim 20, wherein: The method further comprises repeating the steps b), c) and d) as many times as necessary until the contact surface is in contact with the inner surface of the through hole of the downhole pipe at 360 degrees.

22. The method according to any one of claims 20 to 21, characterized in that The radially movable body member is rotated in step d) through an arc length which is equal to the arc length of the contact surface.

23. The method according to any one of claims 20 to 22, characterized in that The arc length of the contact surface is in the range of 20 degrees to 180 degrees.

24. The method of claim 23, wherein: The arc length of the contact surface is in the range of 30 degrees to 90 degrees.

25. The method of claim 24, wherein: The arc length of the contact surface is 60 degrees.

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