| (11) | EP 3 538 739 B1 |
| (12) | EUROPEAN PATENT SPECIFICATION |
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| (54) | PRODUCTION TUBING CONVERSION DEVICE AND METHODS OF USE VORRICHTUNG ZUR UMWANDLUNG VON FERTIGUNGSROHREN UND VERFAHREN ZUR VERWENDUNG DISPOSITIF DE CONVERSION DE COLONNE DE PRODUCTION ET SES PROCÉDÉS D'UTILISATION |
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| Note: Within nine months from the publication of the mention of the grant of the European patent, any person may give notice to the European Patent Office of opposition to the European patent granted. Notice of opposition shall be filed in a written reasoned statement. It shall not be deemed to have been filed until the opposition fee has been paid. (Art. 99(1) European Patent Convention). |
[0001] US2013/269948 discloses a method for abandonment of a subsea well includes: fastening a pressure control assembly (PCA) to a subsea wellhead; and deploying a tool string into the PCA. The tool string includes a packer and an upper perforator located above the packer. The method further includes: closing a bore of the PCA above the tool string with a solid barrier; and setting the packer against an inner casing hung from the subsea wellhead. The method further includes, while the PCA bore is closed, perforating a wall of the inner casing by operating the upper perforator. The method further includes injecting cement slurry into an inner annulus formed between the inner casing and an outer casing hung from the subsea wellhead.
SUMMARY
[0003] There is disclosed, a method comprising cutting a production tubing disposed in a wellbore to form a lower production tubing section and an upper production tubing section, displacing the upper production tubing section away from the lower production tubing section, installing a production tubing conversion device within the upper production tubing section, and injecting a sealant into the wellbore through the upper production tubing section, through the production tubing conversion device, and through the bottom hole assembly. The production tubing conversion device is coupled to a bottom hole assembly disposed below the production tubing conversion device.
[0004] There is also disclosed, a method comprising cutting a production tubing disposed in a wellbore to form a lower production tubing section and an upper production tubing section, displacing the upper production tubing section away from the lower production tubing section, installing a production tubing conversion device within the upper production tubing section, milling away a casing section using the section milling tool, injecting a sealant into the wellbore through the upper production tubing section and through the production tubing conversion device, and forming a sealant plug within the wellbore at the location at which the casing section is milled away. The production tubing conversion device is coupled to the section milling tool disposed below the production tubing conversion device.
[0005] There is also disclosed, a method comprising cutting a production tubing disposed in a wellbore to form a lower production tubing section and an upper production tubing section, displacing the upper production tubing section away from the lower production tubing section, perforating a casing section below the upper production tubing section to form perforations in the casing section, installing a production tubing conversion device within the upper production tubing section, wherein the production tubing conversion device is coupled to a bottom hole assembly disposed below the production tubing conversion device, and injecting a sealant into the wellbore through the upper production tubing section and through the production tubing conversion device, wherein the sealant passes through the perforations in the casing section.
[0006] There is also disclosed, a method comprising installing a production tubing conversion device within a production tubing section disposed in a wellbore that is coupled to a bottom hole assembly disposed below the production tubing conversion device, and performing a workover procedure in the bottom assembly coupled to the production tubing conversion device. The production tubing conversion device comprises a central mandrel, one or more seals disposed between the central mandrel and an interior surface of the production tubing section, and one or more slips engaging the interior surface of the production tubing section, wherein the one or more slips are configured to mechanically couple the central mandrel to the production tubing section.
[0007] There is also disclosed, a workover system comprising a production tubing section disposed in a wellbore, a production tubing conversion device disposed within the production tubing section at or near an end of the production tubing section, and a bottom hole assembly coupled to the production tubing conversion device. The production tubing conversion device comprises a central mandrel, one or more seals disposed between the central mandrel and an interior surface of the production tubing section, and one or more slips engaging the interior surface of the production tubing section. The one or more slips are configured to mechanically couple the central mandrel to the production tubing section, and the bottom hole assembly is mechanically and fluidly coupled to the production tubing section through the production tubing conversion device..
[0008] These and other features will be more clearly understood from the following detailed description taken in conjunction with the accompanying drawings and claims.
BRIEF DESCRIPTION OF THE DRAWINGS
[0009] For a more complete understanding of the present disclosure, reference is now made to the following brief description, taken in connection with the accompanying drawings and detailed description, wherein like reference numerals represent like parts.
FIG. 1 illustrates a schematic cross-sectional view of an embodiment of a wellbore operating environment.
FIG. 2 illustrates a schematic partial cross-sectional view of an embodiment of a production tubing conversion device installed in a production tubing section.
FIGS. 3A-3F illustrate schematic partial cross-sectional views of embodiments of a variety of bottom hole assemblies that can be used with a production tubing conversion device installed in a production tubing section.
FIGS. 4A-4B illustrate schematic partial cross-sectional views of embodiments of a production tubing coupled to a lower completion assembly in an exemplary wellbore.
FIGS. 5A-5B illustrate schematic partial cross-sectional view of embodiments of a production tubing conversion device installation in a production tubing section.
FIG. 6 illustrates a schematic partial cross-sectional view of an embodiment of a production tubing conversion device coupled to a bottom hole assembly installed in a production tubing section.
FIGS. 7A-7C illustrate schematic partial cross-sectional progressive views of an embodiment of an abandonment procedure using a production tubing conversion device coupled to a bottom hole assembly.
FIGS. 8A-8D illustrate schematic partial cross-sectional progressive views of another embodiment of an abandonment procedure using a production tubing conversion device coupled to one or more bottom hole assemblies.
DETAILED DESCRIPTION
[0010] It should be understood at the outset that although illustrative implementations of one or more embodiments are illustrated below the invention is as defined in the claims. The disclosed systems and methods may be implemented using any number of techniques, whether currently known or not yet in existence. The disclosure should in no way be limited to the illustrative implementations, drawings, and techniques illustrated below, but may be modified within the scope of the appended claims along with their full scope of equivalents.
[0011] Unless otherwise specified, any use of any form of the terms "connect," "engage," "couple," "attach," or any other term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described. In the following discussion and in the claims, the terms "including" and "comprising" are used in an open-ended fashion, and thus should be interpreted to mean "including, but not limited to ... ". Reference to up or down will be made for purposes of description with "up," "upper," "upward," or "upstream" meaning toward the surface of the wellbore and with "down," "lower," "downward," or "downstream" meaning toward the terminal end of the well, regardless of the wellbore orientation. Reference to in or out will be made for purposes of description with "in," "inner," or "inward" meaning toward the center or central axis of the wellbore, and with "out," "outer," or "outward" meaning toward the wellbore tubular or tubing and/or wall of the wellbore. Reference to "longitudinal," "longitudinally," or "axially" means a direction substantially aligned with the main axis of the wellbore and/or wellbore tubing. Reference to "radial" or "radially" means a direction substantially aligned with a line between the main axis of the wellbore and/or wellbore tubing and the wellbore wall that is substantially normal to the main axis of the wellbore and/or wellbore tubing, though the radial direction does not have to pass through the central axis of the wellbore and/or wellbore tubing. The various characteristics mentioned above, as well as other features and characteristics described in more detail below, will be readily apparent to those skilled in the art with the aid of this disclosure upon reading the following detailed description of the embodiments, and by referring to the accompanying drawings.
[0012] A producing well can have a number of completion configurations, which can include at least a production tubing extending between the production assembly and the surface of the wellbore. The production tubing can be similar to other tubing, and is generally intended to provide a sealed fluid communication pathway between the completion assembly or completion assemblies and the surface. In order to perform various services on the wellbore, the production tubing can be removed, and a variety of tools can be used with a workover tubing or workover string to perform the services. The removal of the production tubing can require a relatively heavy lifting rig, which can be expensive and consume valuable resources.
[0013] Disclosed herein are systems and methods that allow for various workover procedures to be performed without removing the production tubing from the wellbore. As described in more detail herein, the production tubing can be cut or separated above a completion assembly so that the production tubing can be raised while leaving the completion assembly in position. A production tubing conversion device that can be similar to a packer element can be placed at or near the end of the production tubing to allow the production tubing to be used as a workover string. Various tools can be coupled to the production tubing conversion device when it is disposed in the production tubing so that a variety of jobs can be performed using the production tubing. For example, an abandonment procedure or a plug and recompletion procedure can then be performed using the production tubing without ever removing the production tubing from the wellbore.
[0014] Such a system has a number of advantages. First, a heavy lifting rig may not be needed as the production tubing is not removed from the wellbore and the use of a longer workover string of workover tubing is avoided. Rather, a lighter workover rig can be used to raise the production tubing once it is separated. In addition, the production tubing conversion device can be installed in the production tubing using a wireline, slick line, or coiled tubing, which do not require complicated workover rig operations to use. The production tubing conversion device can also be installed at almost any point within the production tubing, which can provide flexibility in the installation and workover locations. Thus the present systems and methods may provide a lower cost, faster, and more efficient workover procedure for a variety of wellbore operations.
[0015] Turning to FIG. 1, an example of a wellbore operating environment in which the present systems and methods can be used is shown. As depicted, the operating environment comprises a workover rig 106 that is positioned on the earth's surface 104 and extends over and around a wellbore 114 that penetrates a subterranean formation 102 for the purpose of recovering hydrocarbons. At least the upper portion of the wellbore 114 may be lined with casing 125 that is cemented into position against the formation 102 using a sealant such as cement 127 in a conventional manner. Alternatively, the operating environment can include an uncased well bore 120.
[0016] The wellbore 114 may be drilled into the subterranean formation 102 using any suitable drilling technique. The wellbore 114 extends substantially vertically away from the earth's surface 104 over a vertical wellbore portion 116, deviates from vertical relative to the earth's surface 104 over a deviated wellbore portion 136, and transitions to a horizontal wellbore portion 118. In alternative operating environments, all or portions of a wellbore may be vertical, deviated at any suitable angle, horizontal, and/or curved. The wellbore may be a new wellbore, an existing wellbore, a straight wellbore, an extended reach wellbore, a sidetracked wellbore, a multi-lateral wellbore, and other types of wellbores for drilling and completing one or more production zones. Further the wellbore may be used for both producing wells and injection wells. In an embodiment, the wellbore may be used for purposes other than or in addition to hydrocarbon production, such as uses related to geothermal energy and/or the production of water (e.g., potable water).
[0017] A wellbore tubing string (e.g., a production tubing string, a workover tubing string, etc.) may be lowered into the subterranean formation 102 for a variety of drilling, completion, workover, and/or treatment procedures throughout the life of the wellbore. The embodiment shown in FIG. 1 illustrates the wellbore tubing 120 in the form of a completion string comprising a production tubing disposed within the subterranean formation. In general, production tubing and workover tubing can be somewhat similar. However, production tubing tends to be lighter (e.g., thinner) while also incorporating threads designed to transfer torque from the surface of the wellbore 114 to an end of the workover tubing string. As described herein, the use of the production tubing string to perform a workover may not require a heavy lifting rig as is needed when the production tubing string is removed and replaced with a workover string.
[0018] In some embodiments, the workover rig 106 can comprise a derrick 108 with a rig floor 110 through which the wellbore tubing 120 extends downward into the wellbore 114. The workover rig 106 can comprise a motor driven winch and other associated equipment for extending the wellbore tubing 120 into the wellbore 114 to position the wellbore tubing 120 at a selected depth. While the operating environment depicted in FIG. 1 refers to a stationary drilling rig 106 for lowering and setting the wellbore tubing 120 within a land-based wellbore 114, in alternative embodiments, mobile workover rigs, wellbore servicing units (such as coiled tubing units), and the like may be used to lower the wellbore tubing 120 into a wellbore. It should be understood that a wellbore tubing 120 may alternatively be used in other operational environments, such as within an offshore wellbore operational environment. In alternative operating environments, a vertical, deviated, or horizontal wellbore portion may be cased and cemented and/or portions of the wellbore may be uncased.
[0019] Regardless of the type of operational environment in which the systems and method described here are used, it will be appreciated that the use of the production tubing conversion device can allow the production tubing to be used as a workover string without the need to remove the production tubing string from the wellbore or use a corresponding heavy lifting rig to perform the workover procedure. In some instances, the systems and methods described herein can be used to abandon a wellbore and/or a zone within a wellbore. The use of the production tubing conversion device can then allow the abandonment to be performed quickly and inexpensively.
[0020] FIG. 2 illustrates an embodiment of a production tubing conversion device 202. The production tubing conversion device 202 can serve to mechanically couple a bottom hole assembly to the production tubing 120. The production tubing conversion device 202 can also serve to establish a flow path through the tubing to one or more bottom hole assemblies and/or an annulus between a casing (or wellbore wall in an open hole completion) and the interior of the production tubing. In some embodiments, the production tubing conversion device 202 can be the same as or similar to a packer set within the production tubing. For example, the production tubing conversion device 202 can be set at or near an end of the production tubing once the production tubing is separated or cut.
[0021] While the production tubing conversion device 202 can take a variety of forms, the production tubing conversion device 202 illustrated in FIG. 2 can comprise a central mandrel 240, one or more seal elements 242, and one or more slips 244 or contacts. The central mandrel can comprise a tubing element having a flow path disposed therethrough. An upper end of the central mandrel 240 can have a profile or other connection member to allow a wireline, or coiled tubing to connect to the production tubing conversion device 202 and set the production tubing conversion device 202 within the production tubing 120. The same profile or other connection member can allow a wireline or coiled tubing to connect to the production tubing conversion device 202 and retrieve the production tubing conversion device 202 from the production tubing 120 when it is set. In some embodiments, the central mandrel can comprise two or more moveable portions that can move relative to each other to allow the seals 242 and/or slips 244 to be set through axial or rotational motion between the portions of the central mandrel 240.
[0022] The one or more seal elements 242 can comprise deformable elements that can be expanded into contact with an interior surface of the production tubing 120 to form a seal between the production tubing conversion device 202 and the interior of the production tubing 120. The seals can comprise elastomeric elements such as those used with packers. The slips can 244 generally comprise teeth or other features that can engage an interior surface of the production tubing 120. The teeth can penetrate (e.g., dig into) a short distance into the production tubing to thereby form a mechanical coupling between the production tubing conversion device 202 and the production tubing 120. The slips are generally designed to prevent relative axial and/or rotation motion between the production tubing 120 and the production tubing conversion device 202. In some embodiments, the production tubing conversion device 202 can be reversibly set within the production tubing such that the production tubing conversion device 202 can be mechanically and sealingly coupled within the production tubing 202 to perform a task or procedure and then decoupled from production tubing 120 and removed from the wellbore.
[0023] The one or more seal elements 242 can prevent fluid from channeling around the production tubing conversion device 202. As shown in FIG. 2, a flowpath can be formed through the production tubing conversion device 202 (e.g., as shown by the arrows in FIG. 2). Thus, the fluid can enter one or more inlets above the one or more seals 242 and pass through an interior channel in the production tubing conversion device 202 before passing out of the production tubing conversion device 202 below the one or more seals 242. While illustrated as passing through an interior of the central mandrel 240, the flowpath can pass through various flowpaths or even an exterior of the production tubing conversion device 202 in some configurations. Controlling the flow path may be useful in some instances to allow the fluid to be used to actuate various tools within a bottom hole assembly.
[0024] As also shown in FIG. 2, a lower end of the production tubing conversion device 202 can comprise a connection for coupling a bottom hole assembly to the production tubing conversion device 202. For example, a threaded connection can be used to threadedly couple a bottom hole assembly to the production tubing conversion device 202. The connection may allow a continuous fluid flowpath between the central mandrel of the production tubing conversion device and an interior flowpath through a bottom hole assembly. This configuration may allow various devices such as hydraulic motors, setting devices, and the like to be used to actuate the bottom hole assemblies.
[0025] The use of the connection on the production tubing conversion device 202 can allow a variety of bottom hole assemblies to be used with the systems and methods described herein. The bottom hole assemblies can be coupled to the production tubing conversion device 202 prior to insertion of the production tubing conversion device 202 into the production tubing 120. As a result, the diameter of the component or components used to form the bottom hole assembly can be less than the interior diameter of the production tubing to allow the bottom hole assembly to pass through the production tubing to the location at which the production tubing conversion device 202 is set within the production tubing 120. Any suitable thru-tubing tools (e.g., highly expandable tools) that use coiled tubing or wireline can be used. These devices can expand once passed through the production tubing and function in the larger diameter bore hole (e.g., in the casing, in an open hole, etc.) below the production tubing.
[0026] FIGS. 3A-3F illustrate a variety of bottom hole assembly devices that can be used. For example, FIG. 3A illustrates an injection assembly comprising a plurality of seal elements. In some instances, the bottom hole assembly illustrated in FIG. 3A can comprise a jetting assembly. As described in more detail herein, the seal elements can be expanded into contact with an interior surface of a wellbore and/or casing section to allow a zone between the seal elements to be isolated. A wash fluid can then be injected into the zone to treat the zone of interest. A lower end of the bottom hole assembly illustrated in FIG. 3A can be used to wash the zone prior and/or after a procedure.
[0027] FIG. 3B illustrates a tubing or casing cutting tool. The cutting elements can be recessed within the tool and expanded into contact with a surface during use. A rotation of the tool can then be used cut a tubing or casing at a desired location. FIG. 3C illustrates a wash sub having a plurality of nozzles located at an angle along the lower portion of the sub. A pressurized fluid (e.g., passing through the production tubing conversion device 202) can be used to wash or abrade (e.g., when an abrasive fluid is used) a wellbore wall, tubing, or casing. FIG. 3D illustrates an underreamer assembly. In this assembly, the underreaming teeth or blades can be retained in recesses in the tool and extended in response to an activation signal (e.g., a pressuraization of a fluid). When extended, the underreamer can be used to ream a tubing such as a tubing, casing, or other tool from a lower side. The underreamer can also or alternatively be used to ream cement, and/or a formation material from an area that has been milled to clean or provide a rock interface face. FIG. 3E illustrates a fishing tool which can be used to couple to a variety of devices within the wellbore. A removal of the production tubing may then allow the device coupled to the fishing tool to be removed from the wellbore. In some embodiments, the fishing tool can be retrieved through the production tubing to allow a retrieval of the device through the production tubing. FIG. 3F illustrates a section milling tool coupled to a motor (e.g., a hydraulic motor, etc.). As described in more detail herein, the section milling tool can comprise milling blades useful in milling or removing a portion of a casing, tubing, or other device installed within the wellbore.
[0028] In use, the production tubing conversion device 202 can be installed in a production tubing within a wellbore. FIG. 4A illustrates an embodiment of a completion assembly with which the production tubing conversion device 202can be used. As shown, the completion assembly can comprise a zonal isolation device 204 used to isolate a production zone below the zonal isolation device 204. In some embodiments, the zonal isolation device 204 can comprise a packer, a bridge plug, a valve, a production sleeve, or the like, and can be set within a casing 125 and/or against a formation wall. The production tubing 120 can be coupled to the zonal isolation device 204 to provide a production pathway for fluids from the production zone below the zonal isolation device 204 and the surface of the wellbore. As shown, the production tubing can comprise one or more joints 202 used to couple (e.g., threadedly connect, etc.) adjacent sections of the production tubing 120. Thus, FIG. 4A represents an embodiment of a production assembly in place within a wellbore.
[0029] In order to perform a workover on the wellbore, the production tubing 120 can be cut or separated at a cut point 210 to form an upper production tubing section 220 and a lower production tubing section 222. In some embodiments, the production tubing can be otherwise separated to form at least an upper production tubing section 220. For example, the production tubing can be decoupled from the zonal isolation device 204 to form the upper production tubing section. In an embodiment, a wireline or coiled tubing based cutter can be used to cut the production tubing from within the production tubing. While illustrated as forming a single cut in the production tubing, a plurality of cut points can be used to effectively produce a plurality of short production tubing sections. The shorter sections may fall within the space to the bottom or the wellbore or into a lower assembly such as the zonal isolation device 204.
[0030] Once the upper production tubing section is separated from a lower production tubing section or a lower completion assembly, the upper production tubing section can be raised upwards in the wellbore as needed to provide an interval over which a produced is to be performed. This interval can be adjusted during the workover procedures as needed. While the production tubing can be moved within the wellbore, it should be noted that the workover procedure can be performed without removing substantially all (or even a substantial portion of) the production tubing string.
[0031] Once the production tubing has been separated, a variety of procedures can be optionally performed as described in more detail herein. For example, various logging procedures, circulation procedures, perforating procedures, and the like can be performed using tools passing through the production tubing.
[0032] Referring to FIG. 5A, the production tubing conversion device 202 can be installed in the upper production tubing section 220 using a setting tool 502 that can be conveyed on a wireline or coiled tubing 504. As shown, the production tubing conversion device 202 can be conveyed to the desired position within the upper production tubing section 220. While a bottom hole assembly is not shown in FIG. 5A, any suitable bottom hole assembly can be coupled to the production tubing conversion device 202 as the production tubing conversion device 202 is positioned within the upper production tubing section 220. For example, any of the bottom hole assemblies described with respect to FIGS. 3A-3F can be coupled to the production tubing conversion device 202 as it is positioned within the upper production tubing section 220. Once the production tubing conversion device 202 is disposed in position at the desired location in the upper production tubing section 220, an actuation signal or force can be applied to the production tubing conversion device 202 to set the one or more seals and the slips and mechanically couple the production tubing conversion device 202 to the upper production tubing section 220. At this point, the conveyance 504 and setting tool 502 can be released from the production tubing conversion device 202 and retrieved from the wellbore. The production tubing can then appear as shown in FIG. 5B with the production tubing conversion device 202 set within the upper production tubing section 220. While not illustrated in FIG. 5B, a bottom hole assembly can also be coupled to a lower end of the production tubing conversion device 202 to allow one or more workover procedures to be performed.
[0033] Once the workover procedures are complete, the production tubing conversion device 202 can be retrieved from the upper production tubing section 220 along with any bottom hole assembly coupled thereto. In some embodiments, such as when an abandonment procedure is performed, the production tubing completion assembly 202 can be left within the upper production tubing section 220 along with any bottom hole assembly. If another completion is being performed, the production tubing can be cut or separated above the production tubing conversion device 202 and raised. The process can then be repeated as needed.
[0034] The production tubing conversion device can be used with a variety of workover procedures to allow the production tubing to be used as a workover string during the procedures. In an embodiment, the production tubing conversion device 202 can be used to perform an abandonment procedure. This type of procedure is typically carried out at the end of the useful life of a wellbore, at which time costs are generally be minimized. In some embodiments, only a portion of a wellbore may be abandoned, and another completion above the abandoned completion zone can be prepared. Such procedures can be used when water levels within a wellbore reach unacceptable levels. In this instance, a lower production zone can be filled or capped with a sealant and the well can be recompleted higher in the formation to avoid excess water production.
[0035] Further, the various elements of the wellbore may need to be disposed during the abandonment procedure. This can include production tubing that is removed from the wellbore. In some instances, if insufficient funds are available to abandon the wellbore, no abandonment procedure may be carried out, or an insufficient abandonment procedure that does not verify the integrity of the casing and cement bond behind the case may be used. The production tubing conversion device as described here can be used to convert the production tubing into a workover string for an abandonment procedure. This may reduce the overall abandonment procedure costs by avoiding the need for the heavy lifting rig while also allowing the production tubing to remain in the wellbore to be disposed of as part of the abandonment procedure.
[0036] During an abandonment procedure, whether of the entire wellbore or one or more zones, most regulations require that a certain length of proper cement bonding exist between the casing and the formation. If the required bonding length is not present, a workover procedure to provide the minimum bonding length can be performed as part of the abandonment procedure, thereby providing a properly bonded casing as well as a cement plug within the casing (e.g., within the annulus, the production tubing, and the like) suitable to meet the abandonment regulations within each jurisdiction.
[0037] In general, an abandonment procedure comprises checking the cement bonding between the casing and the wellbore wall. If the cement bonding integrity is less than that needed to abandon the wellbore, one or more procedures can be implemented to allow access to the areas or zones in which the cement bonding is not adequate. Cement can then be placed between the casing and the wellbore wall as an individual procedure or as part of also filling the casing with a sealant plug. While the sealant used in abandonment procedures is generally cement, other types of sealants can also be used such as clays, polymers, concrete and the like. When a suitable seal is formed in the wellbore, the wellbore can be considered abandoned.
[0038] In an embodiment, a first abandonment procedure can use a reamer when a loss of cement bonding is detected between the casing and the wellbore wall. Typically, the wellbore may be in the configuration shown in FIG. 4A, where a production zone is isolated by a zonal isolation device 204 and the production tubing 120 provides a fluid pathway between the production zone and the surface of the wellbore. In order to perform the abandonment procedure, the production tubing can be cut or separated as described with respect to FIGS. 4A-4B to form at least an upper production tubing section 220.
[0039] When the production tubing 120 is cut, both an upper production tubing section 220 and a lower production tubing section 222 can be formed. Once the production tubing 120 is cut, the upper production tubing section can be raised away from the lower production tubing section and/or the lower completion assembly. The upper production tubing section 220 can generally be raised above an abandonment zone taking into account an additional working space for tools and the installation of the production tubing conversion device with the bottom hole assembly. The abandonment zone would include a section of the wellbore and/or casing having a sufficient axial length to form a plug meeting the regulations for abandoning a well or a section of a well. For example, if one thousand feet of sealant are needed, the upper production tubing section may be raised at least one thousand feet above the lower production tubing section and/or the production assembly to allow for the formation of the sealant plug to be formed. In some instances, the upper production tubing section 220 may be raised higher to provide additional working room for the logging and workover tools. In still other embodiments, the upper production tubing section may be at or below the abandonment zone interval.
[0040] Once the upper production tubing section 220 is positioned above the abandonment zone, the casing within the abandonment zone can be logged to determine the cement bond quality within the abandonment zone. The logging tools can be passed through the upper production tubing section into the abandonment zone below the upper production tubing section. An exemplary casing section that can be logged is shown in FIG. 6. As shown, the casing 125 can be positioned within the formation 102, and cement 127 can be present in the annulus between the casing 125 and the wellbore wall formed by the formation 102. When the cement is placed in the annulus during the drilling and completion of the wellbore, the cement is intended to be present as a consistent layer that is bonded to both the casing and the formation without any voids or loss of bonding. However, the cement may have voids due to various reasons during the completion process and during production. In some embodiments, the poor cement bonding can also be due to a loss of bonding between the cement and the casing and/or the wellbore wall. The loss of bonding can result in cracks or channels that can create a pathway for potential fluid flow up the wellbore.
[0041] If the cement is bonded over the appropriate length, then no further action may be needed, and a production tubing conversion device having a sealant injection tool can be used to fill the casing with the sealant. However, if the required length of adequate cement bonding is not present, the logging can be used to identify a target section having the poor cement bonding between the casing and the wellbore wall. As shown in the exemplary embodiment of FIG. 6, a number of voids can be present between the cement. The logging of the wellbore in the abandonment zone can identify these voids and/or loss of bonding.
[0042] Once the abandonment zone is logged and a target zone is identified in which the cement quality is to be addressed, the production tubing conversion device can be installed within the upper production tubing section as described herein. In an embodiment, the production tubing conversion device 202 can be coupled to a section milling tool 602 that is coupled to and disposed below the production tubing conversion device 202. The upper production tubing section 220 can be positioned at a depth that allows the section milling tool to contact and mill a desired section of the casing before or after the production tubing conversion device 202 is installed with the section milling tool 602. In some embodiments, an optional cementing tool having an optional agitator can be included in the bottom hole assembly (e.g., in series with the section milling tool). The optional cementing tool can be used to cement after milling without removing the production tubing conversion device 202 from the upper production tubing section 220 to change the bottom hole assembly.
[0043] As shown in FIG. 6, the section milling tool 602 can have milling blades that can initially be folded or recessed within the tool body such that the section milling tool 602 has a diameter that is less than an interior diameter of the upper production tubing section. This can allow the section milling tool 602 to be passed through the interior of the upper production tubing section 220 with the production tubing conversion device 202. Once the production tubing conversion device 202 is properly positioned within the upper production tubing section 220, the section milling tool 602 may extend below a lower end of the upper production tubing section 220. The section milling tool 602 can then be opened so that the milling blades extend outwards into contact with the casing 125, as shown in FIG. 7A.
[0044] The section milling tool 602 can then be used to mill the casing and remove at least a portion of the casing and/or cement to produce a milled section 702 as shown in FIG. 7B. It can be noted that the production tubing conversion device 202 with the section milling tool 602 illustrated in FIG. 7A does not have a motor. In this instance, the milling process can rely on the mechanical coupling of the production tubing conversion device 202 to the upper production tubing section 220 to allow a rotation of the upper production tubing section 220 to cause a rotation in the section milling tool. In order to mill the casing, the upper production tubing section 220 can be rotated and lowered to allow the cutting blades or bits to contact the casing and remove the casing. The casing that is removed can fall downwards in the wellbore. The remaining structure is that of an open hole section 702 in the milled section as shown in FIG. 7B, where the casing is removed, potentially along with some amount of any original cement.
[0045] While illustrated in FIG. 7A as having the section milling tool 602 directly coupled to the production tubing conversion device 202, a motor assembly such as a hydraulic motor can also be used. Such an assembly would be similar to the assembly shown and described with respect to FIG. 3F. In this embodiment, the motor can convert a hydraulic pressure of a fluid into a rotation motion of the milling blades or bits. Thus, a fluid can be passed through the upper production tubing section 220, through the production tubing conversion device 202, and through the hydraulic motor to cause a rotation of the section milling tool. The fluid passing out of the hydraulic motor can be circulated to the surface for pumping and recycling down the production tubing. The rotating blades can then be contacted with the casing, for example by lowering the upper production tubing section while rotating the blades, to create the open hole section 702.
[0046] Once the open hole section 702 is created, a sealant such as cement can be injected into the wellbore through the upper production tubing section to create a plug within the wellbore having sufficient length to properly abandon the well or the desired production zone. In some embodiments, the production tubing conversion device 202 and the associated section milling tool 602 can be removed prior to injecting the sealant. The sealant can then be injected through the upper production tubing section directly or another assembly comprising a production tubing conversion device 202 coupled to a cement injection tool can be disposed in the upper production tubing section 220 first. In some embodiments, a cement injection tool can be used that serves to inject the cement and create vibrations during the injection process to reduce the occurrence of voids in the resulting plug.
[0047] In some embodiments, the sealant can be injected directly through the section milling tool (e.g., directly or through an optional cementing tool). In this embodiment, the production tubing conversion device 202 and the section milling tool 602 may be filled with cement at the end of the process and left in the wellbore. Some portion of the upper production tubing section 220 and/or an annulus between the casing and the upper production tubing section 220 can also be filled with the sealant. This may allow the production tubing to be abandoned in the wellbore rather than needing to remove and dispose of the production tubing.
[0048] At the end of the injection process, a sealant plug 704 as shown in FIG. 7C can be formed within the wellbore. The sealant plug can be formed in the casing section that has been milled away as well as potentially a portion of the wellbore above and/or below the casing section. This can include filling a portion of the production tubing.
[0049] In an embodiment, an abandonment procedure can be carried out by perforating the casing in an area identified as having poor cement bonding quality followed by cementing through the perforations. An optional acid wash can be used to clean out the existing cement and the formation wall to prepare the surfaces for receiving and bonding to new cement.
[0050] The abandonment procedure may begin in the same way as described above with respect to the milling process, and similar steps are not discussed in detail in the interest of brevity. Briefly, the production tubing that is coupled to a lower completion assembly can be cut or separated to form at least an upper production tubing section. The upper production tubing section can be raised away from the lower completion assembly to allow for optional logging of the abandonment zone, which can be used to identify a target section having poor cement bonding between a cement layer and the casing and/or formation wall.
[0051] Once the target zone is identified, the casing in the target section can be perforated. Any suitable perforation tool can be used and can be passed through the upper production tubing into the target zone. In general, a perforation tool comprises a sealed housing containing a plurality of shaped charges that are coupled to a detonator. The perforation tool can be conveyed on a wireline tool, which can also provide the ignition signal to a detonator within the housing. Upon detonation, the shaped charges can form a plurality of holes or perforations through the housing, the casing, the cement, and potentially into the formation. The resulting holes or perforations can then provide fluid communication between the interior of the casing and the annulus between the casing and the formation. After perforating the casing in the target zone, the perforation gun can be retrieved from the wellbore.
[0052] As shown in FIG. 8A, the production tubing conversion device 202 can be installed in the upper production tubing section 220 once the perforations are formed. An injection assembly 802 can be coupled to the production tubing conversion device 202 and disposed to extend below the end of the upper production tubing section 220. As described with respect to FIG. 3A, the injection assembly 802 can comprise a plurality of seal elements 804, and optionally one or more jetting assemblies, wash assemblies, and the like. The seal elements 804 can be expandable or inflatable to contact an interior surface of the casing 125. For example, the seal elements 804 can be expanded based on a fluid pressure supplied through the upper production tubing section and through the production tubing conversion device. Other activation mechanisms can be based on flow rate, mechanical manipulation, or any other suitable force on the injection assembly 802.
[0053] The seal elements 804 can be spaced apart such that when the seal elements are expanded into contact with the interior of the casing, a zone between the seal elements 804 can be isolated. The seal elements can be used to isolate one or more perforations through the casing such as perforations 806. A stimulation or injection fluid can then be passed into the isolated zone to prepare the casing for remedial treatment. For example, an acid wash can be used to remove at least a portion of the existing cement between the casing 125 and the formation to provide room for new sealant to be injected. The injected fluid can be supplied under pressure to pass through the perforations. In some embodiments, a jetting assembly can be used to pass the fluid under pressure to the perforations in addition to be supplied as a jet into the sealed zone between the seal elements 804.
[0054] As shown in FIG. 8C, the resulting treatment can treat the existing cement layer and a portion of the formation to provide a pocket or cavity for receiving new sealant. In some embodiments, the injection assembly can be reset and moved to a different interval and the treatment procedure repeated. This can include moving the upper production tubing section 220 so as to position the injection assembly at the desired interval.
[0055] Once all of the desired treatment intervals are treated, a sealant is injected into the wellbore through the upper production tubing section 220 and through the production tubing conversion device 202. The sealant (such as cement, clays, or the like) is injected into the casing, it can pass through the perforations and fill the annulus between the casing 125 and the formation, thus creating the desired bonding between the casing and the formation.
[0056] In some embodiments, the sealant can be used with the injection assembly in place. In other embodiments, a different bottom hole assembly can be used. In order to change the bottom hole assemblies, the production tubing conversion device 202 can be retrieved through the upper production tubing section and then repositioned with a new bottom hole assembly. In an embodiment, a cement injection tool can be used during the sealant injection process. The cement injection tool can include one or more ports for cement to pass from the upper production tubing section 220 into the casing section while optionally creating vibrations, jetting, or other fluid motion to properly distribute the sealant. The sealant can be supplied under pressure so that the sealant fills the casing and passes through the perforations into the cavities formed during the treatment process.
[0057] The resulting configuration can be as shown in FIG. 8D where the casing, and the cavities are filled with the sealant to form a plug in the wellbore suitable to allow the wellbore and/or the desired zone to be abandoned. As shown in FIG. 8D, the production tubing, the production tubing conversion device 202, and the sealant injection tool can all be filled with the sealant and left within the wellbore. This may be useful when the production tubing is to be abandoned within the wellbore. In other embodiments, the production tubing, the production tubing conversion device 202, and/or the injection tool can be removed from the wellbore after injection of the sealant.
[0058] While generally discussed herein as being used to abandon a wellbore, the abandonment processes described herein can also be used to abandon a zone within a wellbore. For example, a lower production zone can be abandoned in favor of a recompletion higher in the wellbore to avoid excessive water production (e.g., a high water cut). The recompletion process can generally begin with the abandonment processes as described herein. After the completion of the abandonment processes, the production tubing can be cut or separated above a point that is filled with sealant, or the production tubing can be raised above the sealant if not left to be encased within the sealant. The recompletion can then proceed using the production tubing conversion device. For example, the tubing can be cut above the abandoned zone, the resulting upper production tubing section can be raised at or above a desired recompletion location, and a production tubing conversion device can be installed with a new completion assembly. The completion assembly can include any number of desired components such as a completion packer and production assembly below the completion packer. The well can then continue to be produced through the new completion assembly using the same production tubing previously in the wellbore. Thus, the recompletion process can be performed without removing the production tubing from the wellbore. In some embodiments, this can include abandoning the production tubing in the abandonment zone in the wellbore. This can result in remove none of or very little of the existing production tubing during the recompletion process.
[0059] While described in various embodiments as being used for performing abandonment procedures, the use of the existing production tubing as a work string through the deployment of the production tubing conversion device can allow a number of workover procedures to be performed using the existing production tubing. Such procedures may be useful in avoiding the need for heavy lifting rigs as well as reducing the overall time to remove and replace the production tubing with a work string in most workover procedures.
[0060] Having described various devices and methods, certain aspects or embodiments can include, but are not limited to:
[0061] In a first aspect, a method comprises cutting a production tubing disposed in a wellbore to form a lower production tubing section and an upper production tubing section; displacing the upper production tubing section away from the lower production tubing section; installing a production tubing conversion device within the upper production tubing section, wherein the production tubing conversion device is coupled to a bottom hole assembly disposed below the production tubing conversion device; and injecting a sealant into the wellbore through the upper production tubing section, through the production tubing conversion device, and through the bottom hole assembly.
[0062] There is disclosed a method, wherein cutting the production tubing uses a wireline or coiled tubing cutting tool.
[0063] There is disclosed a method further comprising: logging the wellbore between the upper production tubing section and the lower production tubing section after displacing the upper production tubing section and before installing the production tubing conversion device.
[0064] There is disclosed a method, wherein installing the production tubing conversion device within the upper production tubing section comprises: placing the production tubing conversion device at the desired location in the upper production tubing section; setting seals against an interior surface of the upper production tubing section; engaging slips with the interior surface of the upper production tubing section; and establishing a flowpath from an interior of the upper production tubing section through at least a portion of the production tubing conversion device.
[0065] There is disclosed a method, wherein the slips are configured to mechanically couple the production tubing conversion device with the upper production tubing section.
[0066] There is disclosed a method wherein the seals are configured to prevent flow of a fluid between the production tubing conversion device and the interior surface of the upper production tubing section.
[0067] There is disclosed a method comprising: removing the production tubing conversion device and the bottom hole assembly from the wellbore.
[0068] There is disclosed a method, wherein removing the production tubing conversion device and the bottom hole assembly from the wellbore is performed with a wireline or coiled tubing retrieval tool.
[0069] There is disclosed a method that comprises: cutting a production tubing disposed in a wellbore to form a lower production tubing section and an upper production tubing section; displacing the upper production tubing section away from the lower production tubing section; installing a production tubing conversion device within the upper production tubing section, wherein the production tubing conversion device is coupled to a section milling tool disposed below the production tubing conversion device; milling away a casing section using the section milling tool; and injecting a sealant into the wellbore through the upper production tubing section and through the production tubing conversion device.
[0070] There is disclosed a method comprising: logging a cement quality behind a casing prior to installing the production tubing conversion device; and identifying a target section.
[0071] There is disclosed a method comprising: positioning the upper production tubing section at a depth configured to allow the section milling tool to contact the casing section.
[0072] There is disclosed a method, wherein the section milling tool comprises a hydraulic motor, and wherein milling away the casing section comprises: passing a fluid through the hydraulic motor; rotating the section milling tool in response to the fluid passing through the hydraulic motor; and contacting the casing section with the rotating section milling tool.
[0073] There is disclosed a method, wherein the production tubing conversion device is mechanically coupled to the upper production tubing section, and wherein milling away the casing section comprises: rotating the upper production tubing section; rotating the section milling tool in response to the rotation of the upper production tubing section; and contacting the casing section with the rotating section milling tool.
[0074] There is disclosed a method further comprising: opening the section milling tool after installing the production tubing conversion device and the section milling tool, wherein the section milling tool is configured to have a diameter less than an interior diameter of the upper production tubing section while being installed through the upper production tubing section.
[0075] There is disclosed a method, wherein injecting the sealant into the wellbore occurs while the production tubing conversion device and the section milling tool remain installed in the upper production tubing section.
[0076] There is disclosed a method that comprises: cutting a production tubing disposed in a wellbore to form a lower production tubing section and an upper production tubing section; displacing the upper production tubing section away from the lower production tubing section; perforating a casing section below the upper production tubing section to form perforations in the casing section; installing a production tubing conversion device within the upper production tubing section, wherein the production tubing conversion device is coupled to a bottom hole assembly disposed below the production tubing conversion device; and injecting a sealant into the wellbore through the upper production tubing section and through the production tubing conversion device, wherein the sealant passes through the perforations in the casing section.
[0077] There is disclosed a method comprising: logging the wellbore below the upper production tubing section; and identifying a target section, wherein the perforation of the casing section is in the target section.
[0078] There is disclosed a method wherein the bottom hole assembly comprises a zonal isolation device configured to isolate the casing section after the perforating, and wherein the method further comprises: isolating the casing section after the perforating; injecting a stimulation fluid into the casing section while it is isolated; and treating a formation layer behind the casing section, wherein the formation layer is at least partially filled with the sealant in response to the injecting of the sealant.
[0079] There is disclosed a method, wherein injecting the stimulation fluid comprises injecting an acid wash into the casing section, and wherein the acid wash passes through the perforations during the injection of the acid wash.
[0080] There is disclosed a method, wherein the bottom hole assembly comprises a cement injection tool, and wherein injecting the sealant into the wellbore comprises injecting cement through the cement injection tool into the wellbore.
[0081] There is disclosed a method that comprises: installing a production tubing conversion device within a production tubing section disposed in a wellbore, wherein the production tubing conversion device is coupled to a bottom hole assembly disposed below the production tubing conversion device, wherein the production tubing conversion device comprises: a central mandrel, one or more seals disposed between the central mandrel and an interior surface of the production tubing section, and one or more slips engaging the interior surface of the production tubing section, wherein the one or more slips are configured to mechanically couple the central mandrel to the production tubing section; and performing a workover procedure in the bottom assembly coupled to the production tubing conversion device.
[0082] There is disclosed a workover system comprises: a production tubing section disposed in a wellbore; a production tubing conversion device disposed within the production tubing section at or near an end of the production tubing section, wherein the production tubing conversion device comprises: a central mandrel, one or more seals disposed between the central mandrel and an interior surface of the production tubing section, and one or more slips engaging the interior surface of the production tubing section, wherein the one or more slips are configured to mechanically couple the central mandrel to the production tubing section; and a bottom hole assembly coupled to the production tubing conversion device, wherein the bottom hole assembly is mechanically and fluidly coupled to the production tubing section through the production tubing conversion device.
1. A method comprising:
cutting a production tubing (120) disposed in a wellbore (114) to form a lower production tubing section (222) and an upper production tubing section (220);
displacing the upper production tubing section (220) away from the lower production tubing section (222);
installing a production tubing conversion device (202) within the upper production tubing section (220), wherein the production tubing conversion device (202) is coupled to a bottom hole assembly disposed below the production tubing conversion device (202); and
characterised by injecting a sealant into the wellbore (114) through the upper production tubing section (220), through the production tubing conversion device (202), and through the bottom hole assembly.
2. The method of claim 1, wherein cutting the production tubing (120) uses a wireline or coiled tubing cutting tool.
3. The method of claim 1, further comprising: logging the wellbore (114) between the upper production tubing section (220) and the lower production tubing section (222) after displacing the upper production tubing section (220) and before installing the production tubing conversion device (202).
4. The method of claim 1, wherein installing the production tubing conversion device (202) within the upper production tubing section (220) comprises:
placing the production tubing conversion device (202) at the desired location in the upper production tubing section (220);
setting seals (242) against an interior surface of the upper production tubing section (220);
engaging slips (244) with the interior surface of the upper production tubing section (220); and
establishing a flowpath from an interior of the upper production tubing section (220) through at least a portion of the production tubing conversion device (202).
5. The method of claim 4, wherein the slips (244) are configured to mechanically couple the production tubing conversion device (202) with the upper production tubing section (220).
6. The method of claim 4, wherein the seals (242) are configured to prevent flow of a fluid between the production tubing conversion device (202) and the interior surface of the upper production tubing section (220).
7. The method of claim 1, further comprising:
removing the production tubing conversion device (202) and the bottom hole assembly from the wellbore (114) with a wireline or coiled tubing retrieval tool.
removing the production tubing conversion device (202) and the bottom hole assembly from the wellbore (114) with a wireline or coiled tubing retrieval tool.
8. The method of claim 1, further comprising:
milling away a casing section using a section milling tool (602) of the bottom hole assembly.
milling away a casing section using a section milling tool (602) of the bottom hole assembly.
9. The method of claim 8, further comprising:
logging a cement quality behind a casing prior to installing the production tubing conversion device (202); and
identifying a target section.
10. The method of claim 8, wherein the section milling tool (602) comprises a hydraulic motor, and wherein milling away the casing section comprises:
passing a fluid through the hydraulic motor;
rotating the section milling tool (602) in response to the fluid passing through the hydraulic motor; and
contacting the casing section with the rotating section milling tool (602).
11. The method of claim 8, wherein the production tubing conversion device (202) is mechanically coupled to the upper production tubing section (220), and wherein milling away the casing section comprises:
rotating the upper production tubing section (220);
rotating the section milling tool (602) in response to the rotation of the upper production tubing section (220); and
contacting the casing section with the rotating section milling tool (602).
12. The method of claim 8, further comprising:
opening the section milling tool (602) after installing the production tubing conversion device (202) and the section milling tool (602), wherein the section milling tool (602) is configured to have a diameter less than an interior diameter of the upper production tubing section (220) while being installed through the upper production tubing section (220).
opening the section milling tool (602) after installing the production tubing conversion device (202) and the section milling tool (602), wherein the section milling tool (602) is configured to have a diameter less than an interior diameter of the upper production tubing section (220) while being installed through the upper production tubing section (220).
13. The method of claim 8, wherein injecting the sealant into the wellbore (114) occurs while the production tubing conversion device (202) and the section milling tool (602) remain installed in the upper production tubing section (220).
14. The method of claim 1, further comprising:
perforating a casing section below the upper production tubing section (220) to form perforations in the casing section;
wherein the sealant passes through the perforations in the casing section.
15. The method of claim 14, further comprising:
logging the wellbore (114) below the upper production tubing section (220); and
identifying a target section, wherein the perforation of the casing section is in the target section.
16. The method of claim 14, wherein the bottom hole assembly comprises a zonal isolation device (204) configured to isolate the casing section after the perforating, and wherein the method further comprises:
isolating the casing section after the perforating;
injecting a stimulation fluid into the casing section while it is isolated; and
treating a formation layer behind the casing section, wherein the formation layer is at least partially filled with the sealant in response to the injecting of the sealant.
17. The method of claim 14, wherein the bottom hole assembly comprises a cement injection tool, and wherein injecting the sealant into the wellbore (114) comprises injecting cement through the cement injection tool into the wellbore (114).
18. A workover system comprising:
An upper production tubing section (220) disposed in a wellbore (114);
a production tubing conversion device (202) disposed within the upper production tubing section (220) at or near an end of the upper production tubing section (220), wherein the production tubing conversion device (202) comprises:
a central mandrel (240),
one or more seals (242) disposed between the central mandrel (240) and an interior surface of the upper production tubing section (220), and
one or more slips (244) engaging the interior surface of the upper production tubing section (220), wherein the one or more slips (244) are configured to mechanically couple the central mandrel (240) to the upper production tubing section (220); and
characterised by a bottom hole assembly coupled to the production tubing conversion device (202), wherein the bottom hole assembly is mechanically and fluidly coupled to the upper production tubing section (220) through the production tubing conversion device (202).
1. Verfahren, das Folgendes umfasst:
Schneiden eines in einem Bohrloch (114) angeordneten Förderrohrs (120), um einen unteren Förderrohrabschnitt (222) und einen oberen Förderrohrabschnitt (220) zu bilden;
Verschieben des oberen Förderrohrabschnitts (220) weg von dem unteren Förderrohrabschnitt (222);
Installieren einer Förderrohrumwandlungsvorrichtung (202) innerhalb des oberen Förderrohrabschnitts (220), wobei die Förderrohrumwandlungsvorrichtung (202) mit einer unter der Förderrohrumwandlungsvorrichtung (202) angeordneten Bohrlochsohlenanordnung gekoppelt ist; und
gekennzeichnet durch ein Einspritzen eines Dichtmittels in das Bohrloch (114) durch den oberen Förderrohrabschnitt (220), durch die Förderrohrumwandlungsvorrichtung (202) und durch die Bohrlochsohlenanordnung.
2. Verfahren nach Anspruch 1, wobei das Schneiden des Förderrohres (120) ein Drahtseil- oder Spiralrohr-Schneidwerkzeug verwendet.
3. Verfahren nach Anspruch 1, ferner umfassend: Vermessen des Bohrlochs (114) zwischen dem oberen Förderrohrabschnitt (220) und dem unteren Förderrohrabschnitt (222) nach dem Versetzen des oberen Förderrohrabschnitts (220) und vor dem Installieren der Förderrohrumwandlungsvorrichtung (202).
4. Verfahren nach Anspruch 1, wobei das Installieren der Förderrohrumwandlungsvorrichtung (202) in dem oberen Förderrohrabschnitt (220) Folgendes umfasst:
Anordnen der Förderrohrumwandlungsvorrichtung (202) an der gewünschten Stelle im oberen Förderrohrabschnitt (220);
Setzen von Dichtungen (242) gegen eine Innenfläche des oberen Förderrohrabschnitts (220);
Eingreifen von Gleitstücken (244) mit der Innenfläche des oberen Förderrohrabschnitts (220); und
Einrichten eines Strömungswegs von einem Inneren des oberen Förderrohrabschnitts (220) durch mindestens einen Abschnitt der Förderrohrumwandlungsvorrichtung (202).
5. Verfahren nach Anspruch 4, wobei die Gleitstücke (244) konfiguriert sind, um die Förderrohrumwandlungsvorrichtung (202) mechanisch mit dem oberen Förderrohrabschnitt (220) zu koppeln.
6. Verfahren nach Anspruch 4, wobei die Dichtungen (242) konfiguriert sind, um den Fluss eines Fluids zwischen der Förderrohrumwandlungsvorrichtung (202) und der Innenfläche des oberen Förderrohrabschnitts (220) zu verhindern.
7. Verfahren nach Anspruch 1, das ferner Folgendes umfasst:
Entfernen der Förderrohrumwandlungsvorrichtung (202) und der Bohrlochsohlenanordnung aus dem Bohrloch (114) mit einem Drahtseil- oder Spiralrohr-Rückgewinnungswerkzeug.
Entfernen der Förderrohrumwandlungsvorrichtung (202) und der Bohrlochsohlenanordnung aus dem Bohrloch (114) mit einem Drahtseil- oder Spiralrohr-Rückgewinnungswerkzeug.
8. Verfahren nach Anspruch 1, das ferner Folgendes umfasst:
Wegfräsen eines Futterrohrabschnitts unter Verwendung eines Abschnittsfräswerkzeugs (602) der Bohrlochsohlenanordnung.
Wegfräsen eines Futterrohrabschnitts unter Verwendung eines Abschnittsfräswerkzeugs (602) der Bohrlochsohlenanordnung.
9. Verfahren nach Anspruch 8, das ferner Folgendes umfasst:
Vermessen einer Zementqualität hinter einem Futterrohr vor dem Installieren der Förderrohrumwandlungsvorrichtung (202); und
Identifizieren eines Zielabschnitts.
10. Verfahren nach Anspruch 8, wobei das Abschnittsfräswerkzeug (602) einen Hydraulikmotor umfasst und wobei das Wegfräsen des Futterrohrabschnitts Folgendes umfasst:
Hindurchleiten eines Fluids durch den Hydraulikmotor;
Drehen des Abschnittsfräswerkzeugs (602) als Reaktion darauf, dass das Fluid durch den Hydraulikmotor strömt; und
Inkontaktbringen des Futterrohrabschnitts mit dem rotierenden Abschnittsfräswerkzeug (602).
11. Verfahren nach Anspruch 8, wobei die Förderrohrumwandlungsvorrichtung (202) mechanisch mit dem oberen Förderrohrabschnitt (220) gekoppelt ist und wobei das Wegfräsen des Futterrohrabschnitts Folgendes umfasst:
Drehen des oberen Förderrohrabschnitts (220);
Drehen des Abschnittsfräswerkzeugs (602) als Reaktion auf die Drehung des oberen Förderrohrabschnitts (220); und
Inkontaktbringen des Futterrohrabschnitts mit dem rotierenden Abschnittsfräswerkzeug (602).
12. Verfahren nach Anspruch 8, das ferner Folgendes umfasst:
Öffnen des Abschnittsfräswerkzeugs (602) nach dem Installieren der Förderrohrumwandlungsvorrichtung (202) und des Abschnittsfräswerkzeugs (602), wobei das Abschnittsfräswerkzeug (602) so konfiguriert ist, dass es einen Durchmesser hat, der kleiner ist als ein Innendurchmesser des oberen Förderrohrabschnitts (220), während es durch den oberen Förderrohrabschnitt (220) installiert wird.
Öffnen des Abschnittsfräswerkzeugs (602) nach dem Installieren der Förderrohrumwandlungsvorrichtung (202) und des Abschnittsfräswerkzeugs (602), wobei das Abschnittsfräswerkzeug (602) so konfiguriert ist, dass es einen Durchmesser hat, der kleiner ist als ein Innendurchmesser des oberen Förderrohrabschnitts (220), während es durch den oberen Förderrohrabschnitt (220) installiert wird.
13. Verfahren nach Anspruch 8, wobei das Einspritzen des Dichtmittels in das Bohrloch (114) erfolgt, während die Förderrohrumwandlungsvorrichtung (202) und das Abschnittsfräswerkzeug (602) in dem oberen Förderrohrabschnitt (220) installiert bleiben.
14. Verfahren nach Anspruch 1, das ferner Folgendes umfasst:
Perforieren eines Futterrohrabschnitts unterhalb des oberen Förderrohrabschnitts (220), um Perforationen in dem Futterrohrabschnitt zu bilden;
wobei das Dichtmittel durch die Perforationen im Futterrohrabschnitt hindurchtritt.
15. Verfahren nach Anspruch 14, das ferner Folgendes umfasst:
Vermessen des Bohrlochs (114) unterhalb des oberen Förderrohrabschnitts (220); und
Identifizieren eines Zielabschnitts, wobei sich die Perforation des Futterrohrabschnitts in dem Zielabschnitt befindet.
16. Verfahren nach Anspruch 14, wobei die Bohrlochsohlenanordnung eine Zonenisolationsvorrichtung (204) umfasst, die dazu konfiguriert ist, den Futterrohrabschnitt nach dem Perforieren zu isolieren, und wobei das Verfahren ferner umfasst:
Isolieren des Futterrohrabschnitts nach dem Perforieren;
Injizieren einer Stimulationsflüssigkeit in den Futterrohrabschnitt, während dieser isoliert ist; und
Behandeln einer Formationsschicht hinter dem Futterrohrabschnitt, wobei die Formationsschicht als Reaktion auf das Einspritzen des Dichtmittels zumindest teilweise mit dem Dichtmittel gefüllt wird.
17. Verfahren nach Anspruch 14, wobei die Bohrlochsohlenanordnung ein Zementinjektionswerkzeug umfasst und wobei das Injizieren des Dichtmittels in das Bohrloch (114) das Injizieren von Zement durch das Zementinjektionswerkzeug in das Bohrloch (114) umfasst.
18. Workover-System, umfassend:
einen oberen Förderrohrabschnitt (220), der in einem Bohrloch (114) angeordnet ist;
eine Förderrohrumwandlungsvorrichtung (202), die innerhalb des oberen Förderrohrabschnitts (220) an oder nahe einem Ende des oberen Förderrohrabschnitts (220) angeordnet ist, wobei die Förderrohrumwandlungsvorrichtung (202) umfasst:
einen zentralen Dorn (240),
eine oder mehrere Dichtungen (242), die zwischen dem zentralen Dorn (240) und einer Innenfläche des oberen Förderrohrabschnitts (220) angeordnet sind, und
ein oder mehrere Gleitstücke (244), die mit der Innenfläche des oberen Förderrohrabschnitts (220) in Eingriff stehen, wobei das eine oder die mehreren Gleitstücke (244) konfiguriert sind, um den zentralen Dorn (240) mechanisch mit dem oberen Förderrohrabschnitt (220) zu koppeln; und
gekennzeichnet durch eine Bohrlochsohlenanordnung, die mit der Förderrohrumwandlungsvorrichtung (202) gekoppelt ist, wobei die Bohrlochsohlenanordnung durch die Förderrohrumwandlungsvorrichtung (202) mechanisch und fluidisch mit dem oberen Förderrohrabschnitt (220) gekoppelt ist.
1. Procédé comprenant :
la coupe d'un tube de production (120) disposé dans un puits de forage (114) pour former une section de tube de production inférieure (222) et une section de tube de production supérieure (220) ;
le déplacement de la section de tube de production supérieure (220) à distance de la section de tube de production inférieure (222) ;
l'installation d'un dispositif de conversion de tube de production (202) dans la section de tube de production supérieure (220), le dispositif de conversion de tube de production (202) étant accouplé à un ensemble fond du sondage disposé sous le dispositif de conversion de tube de production (202) ; et
caractérisé par l'injection d'un produit d'étanchéité dans le puits de forage (114) à travers la section de tube de production supérieure (220), à travers le dispositif de conversion de tube de production (202), et à travers l'ensemble fond du sondage.
2. Procédé selon la revendication 1, dans lequel la coupe du tube de production (120) utilise un outil de coupe de tube câblé ou enroulé.
3. Procédé selon la revendication 1, comprenant en outre : la diagraphie du puits de forage (114) entre la section de tube de production supérieure (220) et la section de tube de production inférieure (222), après avoir déplacé la section de tube de production supérieure (220) et avant d'installer le dispositif de conversion de tube de production (202).
4. Procédé selon la revendication 1, dans lequel l'installation du dispositif de conversion de tube de production (202) dans la section de tube de production supérieure (220) comprend :
le placement du dispositif de conversion de tube de production (202) à l'emplacement souhaité dans la section de tube de production supérieure (220) ;
le placement des joints d'étanchéité (242) contre une surface intérieure de la section de tube de production supérieure (220) ;
l'entrée en prise des coins de retenue (244) avec la surface intérieure de la section de tube de production supérieure (220) ; et
l'établissement d'un chemin d'écoulement depuis l'intérieur de la section de tube de production supérieure (220) à travers au moins une partie du dispositif de conversion de tube de production (202).
5. Procédé selon la revendication 4, dans lequel les coins de retenue (244) sont conçus pour accoupler mécaniquement le dispositif de conversion de tube de production (202) avec la section de tube de production supérieure (220).
6. Procédé selon la revendication 4, dans lequel les joints d'étanchéité (242) sont conçus pour empêcher l'écoulement d'un fluide entre le dispositif de conversion de tube de production (202) et la surface intérieure de la section de tube de production supérieure (220).
7. Procédé selon la revendication 1, comprenant en outre :
le retrait du dispositif de conversion de tube de production (202) et l'ensemble fond du sondage du puits de forage (114) à l'aide d'un outil de récupération de tube câblé ou enroulé.
le retrait du dispositif de conversion de tube de production (202) et l'ensemble fond du sondage du puits de forage (114) à l'aide d'un outil de récupération de tube câblé ou enroulé.
8. Procédé selon la revendication 1, comprenant en outre :
le fraisage d'une section de boîtier à l'aide d'un outil de fraisage de section (602) de l'ensemble fond du sondage.
le fraisage d'une section de boîtier à l'aide d'un outil de fraisage de section (602) de l'ensemble fond du sondage.
9. Procédé selon la revendication 8, comprenant en outre :
la diagraphie d'une qualité de ciment derrière un boîtier avant d'installer le dispositif de conversion de tube de production (202) ; et
l'identification d'une section cible.
10. Procédé selon la revendication 8, dans lequel l'outil de fraisage de section (602) comprend un moteur hydraulique, et le fraisage de la section de boîtier comprenant :
le passage d'un fluide à travers le moteur hydraulique ;
la rotation de l'outil de fraisage de section (602) en réponse au fluide passant à travers le moteur hydraulique ; et
la mise en contact de la section de boîtier avec l'outil de fraisage de section rotative (602).
11. Procédé selon la revendication 8, dans lequel le dispositif de conversion de tube de production (202) est accouplé mécaniquement à la section de tube de production supérieure (220), et le fraisage de la section de boîtier comprenant :
la rotation de la section de tube de production supérieure (220) ;
la rotation de l'outil de fraisage de section (602) en réponse à la rotation de la section de tube de production supérieure (220) ; et
la mise en contact de la section de boîtier avec l'outil de fraisage de section rotative (602).
12. Procédé selon la revendication 8, comprenant en outre :
l'ouverture de l'outil de fraisage de section (602) après avoir installé le dispositif de conversion de tube de production (202) et l'outil de fraisage de section (602), l'outil de fraisage de section (602) étant conçu pour avoir un diamètre inférieur à un diamètre intérieur de la production supérieure section de tube (220) tout en étant installé à travers la section de tube de production supérieure (220).
l'ouverture de l'outil de fraisage de section (602) après avoir installé le dispositif de conversion de tube de production (202) et l'outil de fraisage de section (602), l'outil de fraisage de section (602) étant conçu pour avoir un diamètre inférieur à un diamètre intérieur de la production supérieure section de tube (220) tout en étant installé à travers la section de tube de production supérieure (220).
13. Procédé selon la revendication 8, dans lequel l'injection du produit d'étanchéité dans le puits de forage (114) se produit tandis que le dispositif de conversion de tube de production (202) et l'outil de fraisage de section (602) restent installés dans la section de tube de production supérieure (220).
14. Procédé selon la revendication 1, comprenant en outre :
la perforation d'une section de boîtier sous la section de tube de production supérieure (220) pour former des perforations dans la section de boîtier ;
le produit d'étanchéité passant à travers les perforations de la section de boîtier.
15. Procédé selon la revendication 14, comprenant en outre :
la diagraphie du puits de forage (114) sous la section de tube de production supérieure (220) ; et
l'identification d'une section cible, la perforation de la section de boîtier se trouvant dans la section cible.
16. Procédé selon la revendication 14, dans lequel l'ensemble fond du sondage comprend un dispositif d'isolement zonal (204) conçu pour isoler la section de boîtier après la perforation, et le procédé comprenant en outre :
l'isolement de la section de boîtier après la perforation ;
l'injection d'un fluide de stimulation dans la section de boîtier pendant qu'elle est isolée ; et
le traitement d'une couche de formation derrière la section de boîtier, la couche de formation étant au moins partiellement remplie du produit d'étanchéité en réponse à l'injection du produit d'étanchéité.
17. Procédé selon la revendication 14, dans lequel l'ensemble fond du sondage comprend un outil d'injection de ciment, et l'injection du produit d'étanchéité dans le puits de forage (114) comprend l'injection de ciment à travers l'outil d'injection de ciment dans le puits de forage (114).
18. Système de reconditionnement comprenant :
Une section de tube de production supérieure (220) disposée dans un puits de forage (114) ;
un dispositif de conversion de tube de production (202) disposé à l'intérieur de la section de tube de production supérieure (220) à ou près d'une extrémité de la section de tube de production supérieure (220), le dispositif de conversion de tube de production (202) comprenant :
un mandrin central (240),
un ou plusieurs joints d'étanchéité (242) disposés entre le mandrin central (240) et une surface intérieure de la section de tube de production supérieure (220), et
un ou plusieurs coins de retenue (244) entrant en prise avec la surface intérieure de la section de tube de production supérieure (220), le ou les coins de retenue (244) sont conçus pour accoupler mécaniquement le mandrin central (240) à la section de tube de production supérieure (220) ; et
caractérisé par un ensemble fond du sondage accouplé au dispositif de conversion de tube de production (202), l'ensemble fond du sondage étant accouplé mécaniquement et fluidiquement à la section de tube de production supérieure (220) à travers le dispositif de conversion de tube de production (202).
REFERENCES CITED IN THE DESCRIPTION
This list of references cited by the applicant is for the reader's convenience only. It does not form part of the European patent document. Even though great care has been taken in compiling the references, errors or omissions cannot be excluded and the EPO disclaims all liability in this regard.
Patent documents cited in the description