Swivel tool

Abstract

A swivel tool is described herein for use in wireline gas and oil operations. The swivel tool includes a bearing housing, a tool housing, a mandrel, and a series of bearing sets. The bearing housing defines a bearing cavity. The tool housing defines a tool cavity and is configured to couple with the bearing housing. The mandrel is disposed within the bearing cavity and the tool cavity. The series of bearing sets is disposed within the bearing cavity and between the mandrel and the bearing housing. The series of bearing sets includes a first, second, and third bearing set. A wireline tool string assembly and a wireline tool string including the swivel tool are also provided.

Description

SWIVEL TOOLTECHNICAL FIELD

[0001] The present invention relates to a swivel tool for use in oil and gas wireline operations.BACKGROUND

[0002] In oil and gas exploration and production, perforating guns are used to create pathways in reservoir bedrock, allowing hydrocarbons to flow into the wellbore. Perforating guns are commonly deployed on a wireline and require proper orientation to ensure effective perforation. As wireline operations have transitioned from conventional exposed wire cables to greaseless or coated cables, wirelines have become more susceptible to torsionally induced damage, particularly in extended-reach and deep horizontal wellbores. During run-in and runout of the well, friction between the wireline and the wellbore can cause torque to accumulate along the wireline, resulting in twisting or misalignment of the perforating guns. To release trapped torque and reduce torsional loading, a swivel tool is included in the wireline tool string to permit relative rotation between the wireline and attached tools, thereby reducing mechanical stress.

[0003] Swivel tools are configured to withstand extreme downhole conditions, including elevated pressures and temperatures, and exposure to corrosive fluids. Swivel tools generally comprise alloys, bearings, and friction-reducing elements (e.g., rotational seals). Swivel tools also include mechanisms to control movement and are designed to minimize equipment stress and facilitate adaptability of wirelines. Unfortunately, conventional swivel tools include weak electrical connections, require frequent replacements, and have poor external seals. Therefore, there remains a need to develop a swivel tool for use with perforating gun wirelines having superior electrical connections, durability, and excellent external seals.SUMMARY OF THE INVENTION

[0004] A swivel tool for use in wireline oil and gas operations is disclosed. The swivel tool comprises a bearing housing, a tool housing, a mandrel, and a series of bearing sets. The bearing housing defines a bearing cavity. The tool housing defines a tool cavity and isconfigured to couple with the bearing housing. The mandrel is disposed within the bearing cavity and the tool cavity. The series of bearing sets is disposed within the bearing cavity between the mandrel and the bearing housing. The series of bearing sets comprises a first bearing set, a second bearing set, and a third bearing set.

[0005] A wireline tool string assembly is also disclosed. The wireline tool string assembly comprises an upper weighted sub, the swivel tool, and a casing collar locator tool. The swivel tool is disposed between and coupled with the upper weighted sub and the casing collar locator tool.

[0006] A wireline tool string for downhole operations is also disclosed. The wireline tool string comprises an upper wireline portion. The wireline tool string further includes the swivel tool connected to the upper wireline portion. The wireline tool string also includes a lower downhole portion connected to the swivel tool.BRIEF DESCRIPTION OF THE DRAWING

[0007] FIG. 1 is a perspective view of the swivel tool according to one embodiment.

[0008] FIG. 2 is a side view of the swivel tool.

[0009] FIG. 3 is a side cross-section view of the swivel tool.

[0010] FIG. 4 is a side cross-section view of the swivel tool according to a second embodiment where the tool housing comprises a tool body and a bottom sub.

[0011] FIG. 5 is a zoomed side cross-section view of a bearing cavity of the swivel tool.

[0012] FIG. 6 is a zoomed side cross-section view of the swivel tool according to a third embodiment where a first biasing member is disposed between and contacts a spring base disposed within the tool cavity and the internal pin contact such that a restoring force acts against the internal pin contact in a direction opposite the electrical conductor.

[0013] FIG. 7 is a perspective view of a wireline tool string assembly including the swivel tool according to embodiment.

[0014] FIG. 8 is a side view of the wireline tool string assembly.

[0015] FIG. 9 is a side cross-section view of the wireline tool string assembly.

[0016] FIG. 10 is a schematic depiction of a wireline tool string for use for downhole operations.DETAILED DESCRIPTION

[0017] A swivel tool according to one embodiment is provided for use in wireline oil and gas operations and is generally designated 10. The swivel tool 10 is depicted generally in FIGS.1-6. The swivel tool includes a bearing housing 20, a tool housing 40, a mandrel 60, and a series of bearing sets 70. The bearing housing 20 defines a bearing cavity 22. The tool housing 40 defines a tool cavity 42 and is configured to couple with the bearing housing 20. The mandrel 60 is disposed within the bearing cavity 22 and the tool cavity 42. The series of bearing sets 70 is disposed within the bearing cavity 22 between the mandrel 60 and the bearing housing 20. The series of bearing sets 70 includes a first bearing set 72, a second bearing set 74, and a third bearing set 76.

[0018] The swivel tool 10 includes a bearing housing 20. The bearing housing 20 defines a bearing cavity 22. The bearing cavity 22 extends at least partially through the bearing housing 20. The bearing cavity 22 is configured to receive one or more bearing elements that permit relative rotational movement between an upper wireline portion UWP and a lower downhole tool assembly LDTA.

[0019] Generally, the bearing cavity 22 includes a lubricant disposed within the bearing cavity 22. Suitable lubricants include, without limitation, oils, greases, semi-fluid greases, synthetic lubricants, mineral-based lubricants, silicone-based lubricants, fluorinated lubricants, ester-based lubricants, polyglycol-based lubricants, and combinations thereof. In certain embodiments, the lubricant comprises grease. As used herein, “grease” refers to a semi-solid lubricant comprising a base oil combined with a thickener (e.g., a soap thickener or non-soap thickener) and, optionally, one or more additives (e.g., anti-wear additives, corrosion inhibitors, oxidation inhibitors, extreme-pressure additives, tackifiers, and / or solid lubricants). In specific embodiments, the lubricant comprises oil. As used herein, “oil” refers to a flowable liquid lubricant, including mineral oils and synthetic oils, and mixtures thereof, optionally including one or more additives. In general, oil exhibits lower apparent viscosity and is more readily flowable than grease, which tends to remain in place due to its thickened structure. Accordingly, grease may be advantageous where retention of lubricant in the bearing cavity 22 is desirable, whereas oil may be advantageous where circulation, flushing, or distribution oflubricant within the bearing cavity 22 is desired. In certain embodiments, oil is retained within the bearing cavity 22 using one or more seal assemblies, while in certain embodiments grease is retained by packing and / or by seal arrangements suitable for semi-solid lubricants.

[0020] In some embodiments, the grease may be a hydrophobic grease. In these embodiments, the swivel tool 10 may exclude seals, with the hydrophobic grease providing a fluid barrier that resists ingress of wellbore fluids into internal cavities and bearing regions. The hydrophobic grease may be packed into one or more annular clearances, interfaces, or chambers to displace or repel water-based wellbore fluids and to maintain lubrication of the swivel tool components during operation. In certain embodiments, bearing cavity 22 comprises a hydrophobic grease and excludes seals from the bearing cavity 22 and / or the tool cavity 42.

[0021] The bearing housing 20 further includes a lubricant flush 24 in fluid communication with the bearing cavity 22. The lubricant flush 24 is configured to selectively release the lubricant from the bearing cavity 22. The lubricant flush 24 defines a port 24P extending through the bearing housing 20 and opening into the bearing cavity 22. In specific embodiments, the port is selectively opened and closed via a removable plug or fitting 24F.

[0022] In certain embodiments, the swivel tool 10 includes a pair of seal assemblies 26 disposed within the bearing cavity 22 such that the series of bearing sets 50 are disposed between the pair of seal assemblies 26. Each seal assembly 26 comprises a sealing element 26SE and a backup ring 26R. In such embodiments, the seal assemblies 26 define, in cooperation with adjacent components, a substantially closed lubricant chamber configured to retain lubricant within the bearing cavity 22 and to inhibit entry of wellbore fluids, debris, and other contaminants into the bearing cavity 22.

[0023] It will be appreciated that the foregoing seal assemblies 26 are particularly well suited to embodiments where the lubricant comprises oil. In oil-lubricated embodiments, the sealing element may comprise any pressure-capable dynamic seal configured to seal between a relatively rotating surface and a relatively stationary surface, including without limitation an elastomeric O-ring, a lip seal, a U-cup seal, a chevron (V-ring) packing set, a spring-energized polymer seal, a T-seal, or combinations thereof. The backup ring 26R may comprise a polymeric or metallic anti-extrusion ring positioned on a low-pressure side and / or a high-pressure side of the sealing element 26SE to resist extrusion of the sealing element 26SE into clearances during high differential pressure conditions. In certain embodiments, a plurality ofbackup rings 26R are used. In specific embodiments, the seal assemblies 26 are oriented to tolerate high pressure from the wellbore side while maintaining oil retention within the bearing cavity 22. In some embodiments, the seal assemblies 26 are configured to tolerate pressure reversals and may include opposed sealing elements 26SE and / or opposed backup rings 26R. In certain embodiments, the seal assemblies 26 are configured to tolerate pressure differentials associated with downhole environments, including pressures in excess of 5,000 psi, in excess of 10,000 psi, or in excess of 15,000 psi.

[0024] It will be further understood that alternative seal arrangements may be used in embodiments where grease is used as the lubricant. In grease-lubricated embodiments, the seal assemblies may be configured primarily to retain a semi-solid lubricant and to exclude particulate contamination rather than to retain a low-viscosity fluid under substantial differential pressure. Accordingly, in certain embodiments the sealing element 26 comprises one or more wiper-type seals, scraper seals, or lip seals configured to wipe and / or scrape rotating surfaces to inhibit migration of grease out of the bearing cavity 22 and to inhibit ingress of sand or other debris. In certain embodiments, the seal assemblies 26 comprise a plurality of wiper or lip seals arranged in series. In some embodiments, one or more of the seal assemblies 26 comprises a labyrinth seal feature, a close-clearance bushing, and / or a tortuous flow path to impede grease migration and contaminant intrusion. In certain embodiments, the grease seal arrangement includes a vent, relief, or purge feature configured to permit excess grease and / or entrained contaminants to be displaced during packing or servicing while maintaining grease retention during operation. In grease embodiments, the backup ring 26R may be omitted, or may be included for durability or extrusion resistance depending on expected pressures and clearances.

[0025] In specific embodiments, the bearing housing 20 comprises a first bearing adaptor 28BA1 and a second bearing adaptor 28BA2 that form at least a portion of the bearing housing 20. The first bearing adaptor 28BA1 defines an uphole end of the bearing housing 20 and is configured to threadedly couple with an uphole tool (e.g., a wireline head, rope socket, cable termination, sinker bar, or other uphole component associated with the upper wireline portion UWP). The second bearing adaptor 28BA2 defines a downhole end of the bearing housing 20 and is configured to threadedly couple with a tool housing 40.

[0026] In certain embodiments, the first bearing adaptor 28B Al is generally a bearing male adaptor. In such embodiments, the first bearing adaptor 28BA1 includes an external threadedportion configured to engage a corresponding internal threaded portion of the uphole tool. In certain embodiments, the second bearing adaptor 28BA2 is generally a bearing female adaptor. In such embodiments, the second bearing adaptor 28BA2 includes an internal threaded portion configured to engage a corresponding external threaded portion of the tool housing 40. It will be appreciated that the threaded configurations may be reversed in alternative embodiments, while maintaining the functional coupling described herein.

[0027] In specific embodiments, the first bearing adaptor 28BA1 and the second bearing adaptor 28BA2 are configured to be assembled to and / or relative to one another to permit assembly and service of internal components received within the bearing cavity 22, including installation and replacement of seal assemblies 26 and / or other components associated with lubrication retention. In certain embodiments, one or both of the first bearing adaptor 28BA1 and the second bearing adaptor 28BA2 include one or more internal shoulders, counterbores, or retaining features that axially locate components within the bearing cavity 22. In some embodiments, one or both adaptors include external wrenching features (e.g., flats, spanner features, or tool-engagement profiles) to facilitate make-up and break-out during assembly and maintenance.

[0028] In certain embodiments, the bearing housing 20 includes a threaded ring interface 30 at an uphole end portion of the bearing housing 20 configured to couple with a mandrel seal. In such embodiments, the threaded ring interface 30 comprises a threaded section of the bearing housing 20 that is configured to receive and retain a seal ring, gland, retainer, or other threaded mandrel-seal component. The mandrel seal is positioned to form a seal between the bearing housing 20 and the mandrel extending through the bearing housing 20, thereby inhibiting ingress of wellbore fluids into the bearing cavity 22.

[0029] In certain embodiments, make-up of the mandrel seal via the threaded ring interface 30 axially compresses one or more sealing elements of the mandrel seal to establish a desired sealing engagement with the mandrel. In some embodiments, the threaded ring interface 30 further defines an axial stop and / or seal shoulder against which the mandrel seal seats, and may additionally include one or more anti-rotation features (e.g., flats, spanner recesses, a set screw, or a locking feature) to maintain the mandrel seal in a desired axial position. In certain embodiments, the mandrel seal is removable through the threaded ring interface 30 to facilitate servicing, replacement, and / or conversion between lubricant types.

[0030] The swivel tool 10 includes a tool housing 40. The tool housing 40 defines a tool cavity 42. The tool cavity 42 extending longitudinally through at least a portion of the tool housing 40. The tool cavity 42 may be generally cylindrical and coaxial with a longitudinal axis of the swivel tool 10, and may be configured to receive, support, and at least partially enclose one or more internal components of the swivel tool 10. In some embodiments, the tool cavity 42 includes one or more sections having differing internal diameters, such as enlarged or reduced diameter portions, shoulders, or stepped regions, which may be configured to locate, retain, or cooperate with internal components disposed therein. The tool cavity 42 may be formed as a continuous bore or as a plurality of interconnected cavity portions formed from one or more machining operations.

[0031] An internal pin contact 44 is disposed within the tool cavity 42 of the tool housing 40 and is configured to electrically contact an electrical conductor disposed within the mandrel 60 of the swivel tool 10. The internal pin contact 44 may be formed from an electrically conductive material, such as brass or another suitable metal or alloy, and may be configured to provide a reliable electrical interface while accommodating relative movement within the tool cavity 42. A stationary rod 46 is also disposed within the tool cavity 42. A first biasing member 48S1 is disposed within the tool cavity 42 between the stationary rod 46 and the internal pin contact 44. The first biasing member 48S1 may comprise a spring, such as a coil spring, wave spring, or other resilient member. The first biasing member 48S 1 is arranged to contact both the stationary rod 46 and the internal pin contact 44 such that a restoring force is applied to the internal pin contact 44 in a direction toward the electrical conductor, which in some embodiments corresponds to an uphole direction. In certain embodiments, the first biasing member 48S 1 is configured such that a restoring force is applied to the internal pin contact 44 in a direction opposite the electrical conductor, which in some embodiments corresponds to a downhole direction. Such embodiments are associated with the benefit of not having to pump oil through the tool cavity 42 and / or bearing cavity 22 to vacate air pockets.

[0032] In certain embodiments, as depicted in Figure 6, the first biasing member 48S1 is disposed between a spring base 49 disposed within the tool cavity and the internal pin contact 44. The first biasing member 48S1 contacts a spring base 49 and the internal pin contact 44 such that a restoring force acts against the internal pin contact 44 in a direction opposite the electrical conductor.

[0033] The swivel tool 10 further comprises an external pin contact 50 disposed at adownhole end of the swivel tool 10 and at least partially accessible from outside the tool housing 40. The external pin contact 50 is electrically coupled to the internal pin contact 44 through one or more conductive elements disposed within the tool cavity 42. A second biasing member 48S2 is disposed within the tool cavity 42 between the stationary rod and the external pin contact 50. The second biasing member 48S2 may comprise a spring, such as a coil spring, wave spring, or other resilient member. The second biasing member 48S2 is configured to contact the external pin contact 50 such that a restoring force acts on the external pin contact 50 in a direction opposite the electrical conductor, which in some embodiments corresponds to a downhole direction. The first and second biasing members 48S1, 48S2 may cooperate to maintain electrical engagement of the internal and external pin contacts 44, 50 under varying axial loads, vibration, and rotational movement encountered during operation of the swivel tool 10.

[0034] In certain embodiments, the tool housing 40 is of unitary or one-piece construction. In such embodiments, the tool housing 40 defines a first tool adaptor 52TA1 and a second tool adaptor 52TA2 formed integrally with the tool housing 40. The first tool adaptor 52TA1 and the second tool adaptor 52TA2 may be disposed at axially opposite ends of the tool housing 40. In specific embodiments, the first tool adaptor 52TA1 comprises a first male adaptor and the second tool adaptor 52TA2 comprises a second male adaptor, each configured for threaded or other mechanical engagement. The first tool adaptor 52TA1 is configured to interface with the second bearing adaptor 28BA2 such that threaded engagement therebetween retainably couples the bearing housing 20 to the tool housing 40. The second tool adaptor 52TA2 is configured to interface with a downhole tool (e.g., a case collar locator), thereby enabling the swivel tool 10 to be operably connected within a downhole tool string.

[0035] In specific embodiments, the tool housing 40 comprises a tool body 54 and a bottom sub 56 that are formed as separate components and assembled together. This embodiment is depicted in FIG. 5. In such embodiments, the tool body 40 defines the first tool adaptor 52TA1 and further defines a tool body intermediate adaptor 58IA1 positioned axially between the first tool adaptor 52TA1 and the bottom sub 56. The bottom sub 56 defines the second tool adaptor 52TA2 and further defines a bottom sub intermediate adaptor 58IA2 positioned axially between the second tool adaptor 52TA2 and the tool body 54. The tool body intermediate adaptor 58IA1 and the bottom sub intermediate adaptor 58IA2 are configured to threadedly couple together, thereby retainably securing the bottom sub 56 to the tool body 54 to form the tool housing 40.

[0036] In certain embodiments, the tool body intermediate adaptor 58IA1 comprises a female adaptor and the bottom sub intermediate adaptor 58IA2 comprises a corresponding male adaptor, although other mating configurations may be employed. Engagement between the tool body intermediate adaptor 58IA1 and the bottom sub intermediate adaptor 58IA2 may provide axial retention, torque transmission, and alignment between the tool body 54 and the bottom sub 56, while permitting internal components disposed within the tool cavity 42 to extend across the interface between the tool body 54 and the bottom sub 56.

[0037] The swivel tool 10 includes a mandrel 60 extending longitudinally through the swivel tool 10. The mandrel 60 is disposed at least partially within the bearing cavity 22 and the tool cavity 42 and is configured to extend across one or more housing sections of the swivel tool 10. The mandrel 60 defines a conductor cavity 62 extending therethrough. An electrical conductor 64 is disposed within the conductor cavity 62 of the mandrel 60 and is configured to transmit electrical signals and / or electrical power through the swivel tool 10. In some embodiments, the electrical conductor 64 comprises a wire, although other electrically conductive elements may be used. The electrical conductor 64 is positioned to electrically contact the internal pin contact disposed within the tool cavity, thereby establishing an electrical connection between the mandrel 60 and the electrical system of the swivel tool 10.

[0038] In certain embodiments, the conductor cavity 62 is configured to at least partially isolate the electrical conductor 64 from mechanical loads transmitted through the mandrel 60 and from fluids present in the wellbore environment. The mandrel 60 may be configured to rotate relative to the tool housing 40 while maintaining electrical continuity between the electrical conductor 64 and the internal pin contact 44 during operation of the swivel tool 10.

[0039] The mandrel 60 includes an upper adaptor 66A positioned at an uphole end of the mandrel 60. The upper adaptor 66A is configured to threadedly couple with an uphole tool, such as an uphole portion of a tool string or a wireline component. In certain embodiments, the upper adaptor 66A comprises a female adaptor, although other adaptor configurations may be employed. The mandrel 60 may further include an upper contact 66C positioned proximate the upper adaptor 66A and configured to establish electrical communication with an upper wireline portion UWP. The upper contact 66C may be electrically coupled to the electrical conductor 64 disposed within the conductor cavity 62 of the mandrel 60 to facilitate transmission of electrical signals and / or power between the swivel tool 10 and the uphole tool.

[0040] In some embodiments, the mandrel 60 further comprises a debris barrier seal ring 68 positioned to limit ingress of debris, particulate matter, or wellbore fluids into the bearing cavity 22 and / or tool cavity 42. The debris barrier seal ring 68 may comprise a material that is chemically resistant to wellbore fluids and capable of withstanding downhole temperatures and pressures. Suitable materials may include polymers or elastomers such as polytetrafluoroethylene (PTFE), polyether ether ketone (PEEK), fluoroelastomers (FKM), hydrogenated nitrile butadiene rubber (HNBR), or other chemically resistant materials. In certain embodiments, the debris barrier seal ring 68 is threaded such that it is threadedly couplable with a threaded ring interface 30 of the bearing housing 20, thereby permitting secure installation and, if desired, removal or replacement of the debris barrier seal ring 68 during assembly or maintenance of the swivel tool 10.

[0041] The swivel tool 10 includes a series of bearing sets 70. The bearing sets 70 are depicted in particular in FIG. 4. The series of bearing sets 70 is disposed within the bearing cavity 22 between the mandrel 60 and the bearing housing 20. The series of bearing sets 70 includes a first bearing set 72, a second bearing set 74, and a third bearing set 76. In certain embodiments the first bearing set 72 is a set of ball bearings, the second bearing set 74 is a set of roller bearings, and the third bearing set 76 is a set of roller bearings. The second bearing set 74 may be a set of needle roller bearings (or thrust bearings) and the third bearing set 76 is a set of tapered roller bearings. As used herein, a “needle roller bearing” refers to a rollingelement bearing having a plurality of generally cylindrical rollers disposed in a single circumferential layer (single row) between complementary raceway surfaces, wherein each roller has a length-to-diameter ratio of about 3:1 to about 10:1, such that the bearing is configured to support relative rotation between the raceway surfaces and to carry primarily radial loading. As used herein, a “tapered roller bearing” refers to a rolling-element bearing having a plurality of generally frustoconical rollers disposed between complementary conical raceway surfaces such that the bearing is configured to carry combined radial and axial (thrust) loading during relative rotation of the raceway surfaces. In some embodiments the second bearing set 74 is disposed between the first bearing set 72 and the third bearing set 76.

[0042] The swivel tool 10 comprises a retaining ring 78 disposed within the bearing cavity 22 of the swivel tool 10. As illustrated in FIG. 4, the retaining ring 78 is positioned radially between the bearing housing 20 and the mandrel 60 and is located axially between a second bearing set 74 and a third bearing set 76 disposed within the bearing cavity 22. The retainingring 78 is configured to engage one or more opposing surfaces of the bearing housing 20 and / or the mandrel 60 to define an axial stop within the bearing cavity 22.

[0043] In certain embodiments, the retaining ring 78 limits axial movement of one or more bearing components relative to the mandrel 60 and the bearing housing 20, thereby maintaining a desired axial spacing between the second bearing set 74 and the third bearing set 76 during operation of the swivel tool 10. The retaining ring 78 may further distribute axial loads transferred through the bearing sets 70 and may assist in maintaining alignment of the mandrel 60 within the bearing housing 20 while permitting relative rotational movement therebetween. In some embodiments, the retaining ring 78 is received within a circumferential groove 80 formed in the bearing housing 20, the mandrel 60, or both.

[0044] A wireline string assembly according to one embodiment is provided for use in wireline oil and gas operations and is generally designated 200. The wireline tool string assembly 200 is depicted in FIGS. 7-9. The wireline tool string assembly generally includes an upper weighted sub 210, the swivel tool 10, and a casing collar locator tool 250. The swivel tool 10 is disposed between and coupled with the upper weighted sub 210 and the casing collar locator tool 250.

[0045] The wireline tool string assembly 200 includes an upper weighted sub 210 at an upper end of the wireline tool string assembly 200. The upper weighted sub 210 is configured to mechanically couple the wireline tool string assembly 200 to a wireline conveyed from surface equipment and to transfer tensile loads from the wireline to the wireline tool string assembly 200. In certain embodiments, the upper weighted sub 210 provides a predetermined mass to maintain the wireline tool string assembly 200 in tension and to promote stable operation of a swivel tool positioned downhole of the upper weighted sub 210.

[0046] The upper weighted sub 210 includes a generally elongate body 212. The body 212 defines an internal cavity 214 extending longitudinally therethrough. A fish neck 216 is disposed within the internal cavity 214 of the body 212. The fish neck 216 is configured to fit over and be mechanically coupled with a cable head housing 218 positioned within the internal cavity 214. The coupling between the fish neck 216 and the cable head housing 218 may provide axial retention and load transfer between the upper weighted sub 210 and the cable head housing 218 during deployment, operation, and retrieval of the swivel tool 10.

[0047] The cable head housing 218 is configured to receive and house a cable head pincontact 220. The cable head pin contact 220 is electrically coupled to the electrical conductor 64 extending through the mandrel 60 and is positioned to establish electrical communication with an upper wireline portion UWP. In this manner, the cable head pin contact 220 provides an electrical interface between the mandrel 60 of the swivel tool 10 and the wireline. The internal cavity 214 of the upper weighted sub 210 may further provide protection for the cable head housing 218 and the cable head pin contact 220 while permitting limited axial movement to maintain reliable electrical engagement.

[0048] In certain embodiments, the cable head housing 218 includes an upper weighted sub adaptor 222 positioned at a downhole end of the cable head housing 218. The upper weighted sub adaptor 222 is configured to couple with the upper adaptor 66A of the mandrel 60 to mechanically and electrically connect the upper weighted sub 210 to the mandrel 60. In some embodiments, the upper weighted sub adaptor 222 comprises a threaded male adaptor configured to threadedly engage a corresponding female upper adaptor 66A of the mandrel 60, although other coupling configurations may be employed.

[0049] The body of the upper weighted sub 210 further includes a weighted sub body adaptor 224 positioned at a downhole end of the body 212. The weighted sub body adaptor 224 is configured to threadedly couple with the first bearing adaptor 28BA1 of the swivel tool 10 to retainably connect the upper weighted sub 210 to the bearing housing 20. In certain embodiments, the weighted sub body adaptor 224 comprises a female adaptor configured to engage the corresponding male first bearing adaptor.

[0050] The body of the upper weighted sub 210 and the fish neck 216 together define a wireline through cavity 226 extending longitudinally through the upper weighted sub 210. The wireline through cavity 226 is configured to receive and guide a wireline therethrough, allowing the wireline to extend from the upper wireline portion UWP, through the upper weighted sub 210, and into electrical communication with the electrical conductor of the mandrel 60. The wireline through cavity 226 may further provide strain relief, alignment, and protection for the wireline during operation of the swivel tool.

[0051] The wireline tool string assembly 200 further includes a casing collar locator tool 250 disposed downhole of the swivel tool 10. The casing collar locator tool 250 includes a locator body 252, a top locator sub 254, and a bottom locator sub 256 arranged in an axially stacked configuration. The locator body 252 defines an internal coil cavity 258 configured tocontain sensing components of the casing collar locator tool 250 and includes a first locator body adaptor 260LA1 at an uphole end of the locator body 252 and a second locator body adaptor 260LA2 at a downhole end of the locator body 252.

[0052] The top locator sub 254 is positioned at an uphole end of the locator body 252 and includes a first locator top sub adaptor 262TSA1 and a second locator top sub adaptor 262TSA2. The first locator top sub adaptor 262TSA1 is configured to threadedly couple with the second tool adaptor 52TA2 of the swivel tool 10, thereby connecting the casing collar locator tool 250 to the swivel tool 10 within the wireline tool string assembly 200. The second locator top sub adaptor 262TSA2 is configured to threadedly couple with the first locator body adaptor 260LA1 to retainably secure the top locator sub 254 to the locator body 252.

[0053] The bottom locator sub 256 is positioned at a downhole end of the locator body 252 and includes a first locator bottom sub adaptor 264BSA1 and a second locator bottom sub adaptor 264BSA2. The first locator bottom sub adaptor 264BSA1 is configured to threadedly couple with the second locator body adaptor 260LA2 to secure the bottom locator sub 256 to the locator body 252. The second locator bottom sub adaptor 264BSA2 is configured to threadedly couple with a downhole tool positioned below the casing collar locator tool 250 within the wireline tool string assembly 200.

[0054] In specific embodiments, the first locator body adaptor 260LA1 and the second locator body adaptor 260LA2 each comprise female threaded adaptors. In such embodiments, the first locator top sub adaptor 262TSA1 may comprise a female adaptor and the second locator top sub adaptor 262TSA2 may comprise a male adaptor, and the first locator bottom sub adaptor 264BSA1 may comprise a male adaptor while the second locator bottom sub adaptor 264BSA2 may comprise a female adaptor. Other adaptor configurations may be employed without departing from the scope of the disclosure. The adaptor arrangements described herein permit modular assembly of the casing collar locator tool 250.

[0055] Generally, the locator body 252 of the casing collar locator tool 250 defines an internal coil cavity 258 extending longitudinally within the locator body 252. The internal coil cavity 258 is configured to receive and house an internal coil 266 of the casing collar locator tool 250. An internal coil 266 is disposed within the internal coil cavity 258 and is positioned to generate and / or sense electromagnetic fields associated with casing collars or other features of a wellbore tubular. The internal coil 266 may be electrically coupled to one or moreconductors extending through the wireline tool string assembly to transmit signals to surface equipment.

[0056] In certain embodiments, the internal coil cavity 258 is configured to maintain the internal coil 266 in a fixed radial and axial position relative to the locator body 252 while isolating the internal coil 266 from mechanical loads, vibration, and wellbore fluids. The internal coil cavity 258 may further include insulating materials, spacers, or potting compounds to support and protect the internal coil during operation of the casing collar locator tool.

[0057] Although illustrated as a casing collar locator tool 250, in alternative embodiments the tool 250 may comprise or be replaced by other depth-correlation or position-sensing devices, including but not limited to gamma ray tools, casing-based correlation sensors, acoustic sensors, induction-based sensors, or combinations thereof, without departing from the scope of the present disclosure.

[0058] In certain embodiments, the wireline tool string assembly further includes a release tool RT positioned downhole of the casing collar locator tool 250. The release tool RT is configured to selectively disconnect an uphole portion of the wireline tool string assembly from a downhole portion in response to a predetermined release condition. The release tool RT may include a releasable coupling mechanism and, in some embodiments, an energetic device such as a pyrotechnic charge or squib operatively coupled to the releasable coupling mechanism and actuatablc by an electrical signal transmitted through the wireline. Upon actuation, the energetic device is configured to sever, shear, or disengage one or more retaining members to permit separation of the tool string, while maintaining electrical continuity through the release tool RT prior to activation.

[0059] In certain embodiments, the wireline tool string assembly further includes a perforating gun PG positioned downhole of the release tool RT. The perforating gun PG is configured to create one or more perforations through a casing and into a surrounding formation and may include a gun housing, one or more shaped charges, and an initiator operatively coupled to the shaped charges. The initiator may be actuatable in response to an electrical firing signal transmitted through the wireline to selectively detonate the shaped charges at a desired depth. Prior to actuation, the perforating gun PG is configured to maintain electrical communication with uphole tools, and upon detonation, the shaped charges generate perforation tunnels extending through the casing to facilitate fluid communication between theformation and the wellbore.

[0060] In certain embodiments, the wireline tool string assembly further includes a plug setting tool PST positioned downhole of the perforating gun PG. The plug setting tool PST is configured to set a downhole plug at a selected depth within the wellbore and may include a setting mechanism configured to apply an axial force, hydraulic force, or energetic force to actuate the plug. The plug setting tool PST may be actuated in response to an electrical signal transmitted through the wireline and is configured to maintain electrical continuity with uphole tools prior to actuation, thereby enabling controlled setting of the plug within the casing.

[0061] In certain embodiments, the wireline tool string assembly further includes a fracturing plug FP positioned downhole of the plug setting tool PST. The fracturing plug FP is configured to be set within a wellbore to isolate a lower portion of the wellbore during a hydraulic fracturing operation and may include a plug body, one or more sealing elements, and anchoring members configured to engage a casing wall when set. The fracturing plug FP is configured to be set by the plug setting tool PST in response to a setting force applied by the plug setting tool and, once set, is operable to prevent fluid communication past the fracturing plug FP during subsequent fracturing treatment of an uphole formation interval.

[0062] A wireline toolstring 1000 for downhole operations according to one embodiment is also provided herein. The wireline toolstring 1000 is generally depicted in FIG. 10. The wireline toolstring 1000 includes an upper wireline portion UWP configured to transmit electrical signals from a surface control system SCS. The swivel tool 10 is connected to the upper wireline portion UWP. A lower downhole tool assembly LDTA is connected to the swivel tool 10. The upper wireline portion UWP, the swivel tool 10, and the lower downhole tool assembly LDTA are all connected via a wireline cable WLC.

[0063] The upper wireline portion UWP may include an electrical conductor cable and associated telemetry or power modules configured to transmit electrical control signals, data, and power from the surface control system SCS to the swivel tool 10. The upper wireline portion UWP provides both mechanical support for the toolstring and electrical communication for control and monitoring of the swivel tool 10 and any connected downhole instruments. In some embodiments, the upper wireline portion UWP may further include tension subs, weak points, or centralizers to facilitate safe deployment and retrieval of the toolstring 1000 within a wellbore.

[0064] The lower downhole tool assembly LDTA is mechanically coupled to the swivel tool 10 and may include any suitable downhole instrument, such as a casing collar locator tool, logging tool, perforating gun, setting tool, or sampling device. The lower downhole tool assembly LDTA is configured to perform one or more downhole operations in response to signals transmitted through the upper wireline portion and the release tool 10. In some embodiments, the swivel tool 10 selectively rotates the lower downhole tool assembly LDTA relative to the upper wireline portion UWP upon actuation of the swivel tool 10. Generally, the lower downhole tool assembly LDTA comprises the casing collar locator tool 250, the release tool RT, the perforating gun PG, the plug setting tool PST, and the fracturing plug FP.

[0065] As used here, the terms “above” and “below”; “up” and “down”; “upper” and “lower”; “upwardly” and “downwardly”; and other like terms indicating relative positions above or below a given point or element are used in this description to more clearly describe some embodiments. However, when applied to equipment and methods for use in wells that are deviated or horizontal, such terms may refer to a left to right, right to left, or diagonal relationship as appropriate.

[0066] The above description is that of current embodiments of the invention. Various alterations and changes can be made without departing from the spirit and broader aspects of the invention as defined in the appended claims, which are to be interpreted in accordance with the principles of patent law including the doctrine of equivalents. Any reference to elements in the singular, for example, using the articles “a,” “an,” “the,” or “said,” is not to be construed as limiting the element to the singular.REFERENCE NUMERALS Swivel tool 10 Bearing housing 20 Bearing cavity 22 Lubricant flush 24 Port 24P Plug / Fitting 24F Seal assemblies 26 Sealing element 26SE Backup ring 26R First bearing adaptor 28BA1 Second bearing adaptor 28BA2 Threaded ring interface 30 Tool housing 40 Tool cavity 42 Internal pin contact 44 Stationary rod 46 First biasing member 48S1 Second biasing member 48S2 Spring base 49 External pin contact 50 First tool adaptor 52TA1 Second tool adaptor 52TA2 Tool body 54 Bottom sub 56 Tool body intermediate adaptor 58IA1 Bottom sub intermediate adaptor 58TA2 Mandrel 60 Conductor cavity 62 Electrical conductor 64 Upper adaptor 66A Upper contact 66C Debris barrier seal ring 68 Series of bearing sets 70 First bearing set 72 Second bearing set 74 Third bearing set 76 Retaining ring 78 Circumferential groove 80 Wireline string assembly 200 Upper weighted sub 210 Body 212 Internal cavity 214 Fish neck 216 Cable head housing 218 Cable head pin contact 220 Upper weighted sub adaptor 222 Weighted sub body adaptor 224 Wireline through cavity 226 Casing collar locator tool 250Locator body 252 Top locator sub 254 Bottom locator sub 256 Internal coil cavity 258 First locator body adaptor 260LA1 Second locator body adaptor 260LA2 First locator top sub adaptor 262TSA1 Second locator top sub adaptor 262TSA2 First locator bottom sub adaptor 264BSA1 Second locator bottom sub adaptor 264BSA2 Internal coil 266 Wireline toolstring 1000 Upper wireline portion UWP Lower downhole tool assembly LDTA Release Tool RT Perforating Gun PG Plug setting tool PST Fracturing plug FP Surface control system SCS Wireline Cable WLC

Claims

CLAIMS1. A swivel tool for use in wireline oil and gas operations, the swivel tool comprising:a bearing housing defining a bearing cavi ty;a tool housing defining a tool cavity and configured to couple with the bearing housing;a mandrel disposed within the bearing cavity and the tool cavity; and a series of bearing sets disposed within the bearing cavity between the mandrel and the bearing housing, the series of bearing sets comprising:a first bearing set;a second bearing set; anda third bearing set.

2. The swivel tool of claim 1, wherein:the first bearing set is a set of ball bearings;the second bearing set is a set of roller bearings; andthe third bearing set is a set of roller bearings.

3. The swivel tool of claim 2, wherein:the second bearing set is a set of thrust bearings; andthe third bearing set is a set of tapered roller bearings.

4. The swivel tool of any one of claims 1 -3, wherein the second bearing set is disposed between the first bearing set and the third bearing set.

5. The swivel tool of claim 4, wherein the swivel tool comprises a retaining ring disposed within the bearing cavity, the retaining ring being disposed radially between the bearing housing and the mandrel and axially between the second bearing set and the third bearing set.

6. The swivel tool of any one of claims 1-5, wherein the bearing cavity comprises a hydrophobic grease and excludes seals from the bearing cavity and / or the tool cavity.

7. The swivel tool of any one of claims 1-5, wherein the bearing cavity comprises oil.

8. The swivel tool of any one of claims 1-5 or 7, wherein the swivel tool comprises a pair of seal assemblies disposed such that the series of bearing sets are disposed between the pair of seal assemblies, and each seal assembly comprises a sealing element and a backup ring.

9. The swivel tool of any one of claims 1-8, wherein the swivel tool comprises an electrical conductor disposed within a conductor cavity defined by the mandrel, the electrical conductor in electrical contact with an internal pin contact disposed within the tool cavity.

10. The swivel tool of claim 9, wherein a first biasing member is disposed between and contacts a spring base disposed within the tool cavity and the internal pin contact such that a restoring force acts against the internal pin contact in a direction opposite the electrical conductor.

11. The swivel tool of claim 10, wherein the swivel tool comprises an external pin contact and a second biasing member disposed between the external pin contact and the stationary rod such that a restoring force acts against the external pin contact in a direction opposite the electrical conductor.

12. The swivel tool of any one of claims 1-11, wherein the tool housing comprises a tool body and a bottom sub.

13. The swivel tool of any one of claims 1-11, wherein the bearing housing comprises a bearing male adaptor and a bearing female adaptor, the tool housing defines a tool first male adaptor and a tool second male adaptor, and the bearing female adaptor of the bearing housing is configured to retainably couple with the tool first male adaptor of the tool housing.

14. A wireline tool string assembly comprising:an upper weighted sub comprising a cablehead disposed within a wireline through cavity defined by the upper weighted sub, the cablehead coupled with a wireline cable;the swivel tool of any one of claims 1-13; anda casing collar locator tool;wherein the swivel tool is disposed between and coupled with the upper weighted sub and the casing collar locator tool via the wireline cable.

15. A wireline tool string for downhole operations comprising:an upper wi reline portion;a swivel tool according to any one of claims 1-13 connected to the upper wireline portion; anda lower downhole portion connected to the swivel tool.

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