Spoolable connector assemblies for connecting separate coiled tubing strings at a wellsite

Abstract

A spoolable CT connector assembly includes a first connector body for connecting with a first CT string, a second connector body for connecting with a second CT string that is separate from the first CT string, and a pivotable connector pivotably coupled between the first connector body and the second connector body wherein the pivotable connector slidably connects the first connector body with the second connector body.

Description

SPOOLABLE CONNECTOR ASSEMBLIES FOR CONNECTING SEPARATE COILED TUBING STRINGS AT A WELLSITECROSS-REFERENCE TO RELATED APPLICATIONS

[0001] This application claims benefit of U.S. provisional patent application Serial No.63 / 775,807 filed March 21, 2025, and entitled "Spoolable Connector Assemblies for Connecting Separate Coiled Tubing Strings at a Wellsite," which is hereby incorporated herein by reference in its entirety for all purposes.STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT

[0002] Not applicable.BACKGROUND

[0003] Coiled tubing (CT) systems are used to run continuous pipe into and out of wellbores. Continuous pipe may be referred to as CT because it is stored and transported on a coiled tubing reel. Coiled tubing can be used for drilling operations and is likewise well-suited for servicing and / or producing hydrocarbons from existing wells. CT can be inserted into and removed from a wellbore extending through a subterranean earthen formation without having to first erect a complex drilling rig or other structure at a well site at which the wellbore is located. Instead, the CT may be conveniently unreeled from its associated storage reel and run into the wellbore with the assistance of additional surface equipment. Similarly, the CT may be conveniently reeled back onto the storage reel at the conclusion of the CT operation rather than needing to be broken down at the surface into a plurality of separate pipe joints or stands as with well operations that utilize drill pipe instead of CT. Further, during operation, CT may be subjected to bending and associated bending strains at varying bending radii.BRIEF SUMMARY OF THE DISCLOSURE

[0004] An embodiment of a spoolable CT connector assembly comprising a first connector body configured to connect with a first CT string, a second connector body configured to connect with a second CT string that is separate from the first CT string, and a pivotable connector pivotably coupled between the first connector body and thesecond connector body wherein the pivotable connector slidably connects the first connector body with the second connector body. In some embodiments, the first connector body comprises one or more indentions positioned along an outer surface of the first connector body and configured to receive at least a portion of the first CT string. In certain embodiments, the second connector body comprises one or more indentions positioned along an outer surface of the second connector body and configured to receive at least a portion of the second CT string. In certain embodiments, the spoolable CT connector comprises one or more annular first seals along with one or more annular second seals positioned along an outer surface of the first connector body configured to seal against an inner surface of the first CT string. In some embodiments, one or more annular seals are positioned along an outer surface of the second connector body configured to seal against an inner surface of the second CT string. In some embodiments, the pivotable connector comprises an outer surface matingly received within a receptacle in the spoolable CT connector. In certain embodiments, the spoolable CT connector assembly comprises a first joint body pivotably connecting the pivotable connector with the first connector body, and a second joint body pivotably connecting the second connector body with the pivotable connector. In certain embodiments, the first connector body comprises a slip positioned between an inner surface of the first CT string and an outer surface of the first connector body, and wherein the slip comprises a plurality of locking teeth configured to bite into the inner surface of the first CT string to secure the first connector body to the first CT string. In some embodiments, the second connector body comprises a slip positioned between an inner surface of the second CT string and an outer surface of the second connector body, and wherein the slip comprises a plurality of locking teeth configured to bite into the inner surface of the second CT string to secure the second connector body to the second CT string.

[0005] An embodiment of a spoolable CT connector assembly comprising a first connector body configured to connect with a first CT string, the first connector body having a first central axis, a second connector body configured to connect with a second CT string that is separate from the first CT string, the second connector body having a second central axis, and a pivotable connector pivotably coupled between the first connector body and the second connector body wherein the pivotable connector permits the second connector body to rotate freely relative to the first connector body. In some embodiments, the first connector body comprises one ormore indentions positioned along an outer surface of the first connector body and configured to receive at least a portion of the first CT string. In certain embodiments, the second connector body comprises one or more indentions positioned along an outer surface of the second connector body and configured to receive at least a portion of the second CT string. In certain embodiments, the spoolable CT connector comprises one or more annular first seals along with one or more annular second seals positioned along an outer surface of the first connector body configured to seal against an inner surface of the first CT string. In some embodiments, one or more annular seals are positioned along an outer surface of the second connector body configured to seal against an inner surface of the second CT string. In some embodiments, the pivotable connector comprises an outer surface matingly received within a receptacle in the spoolable connector assembly. In certain embodiments, the spoolable CT connector comprises a first joint body pivotably connecting the pivotable connector with the first connector body, and a second joint body pivotably connecting the second connector body with the pivotable connector. In certain embodiments, the first connector body comprises a slip positioned between an inner surface of the first CT string and an outer surface of the first connector body, and wherein the slip comprises a plurality of locking teeth configured to bite into the inner surface of the first CT string to secure the first connector body to the first CT string. In some embodiments, the second connector body comprises a slip positioned between an inner surface of the second CT string and an outer surface of the second connector body, and wherein the slip comprises a plurality of locking teeth configured to bite into the inner surface of the second CT string to secure the second connector body to the second CT string.

[0006] An embodiment of a spoolable CT connector assembly comprises a first connector body configured to connect with a first CT string, the first connector body having a first central axis, a second connector body configured to connect with a second CT string that is separate from the first CT string, the second connector body having a second central axis, and a joint body having a first end coupled to the second connector body whereby relative movement is restricted therebetween, and a second end defining a pivotable connector that pivotably connects the joint body with the first connector body to permit relative movement therebetween. In some embodiments, the first connector body comprises one or more indentions positioned along an outer surface of the first connector body and configured to receive at least a portion of thefirst CT string. In certain embodiments, the second connector body comprises one or more indentions positioned along an outer surface of the second connector body and configured to receive at least a portion of the second CT string. In certain embodiments, the spoolable CT connector comprises one or more annular first seals along with one or more annular second seals positioned along an outer surface of the first connector body configured to seal against an inner surface of the first CT string. In some embodiments, one or more annular seals are positioned along an outer surface of the second connector body configured to seal against an inner surface of the second CT string. In some embodiments, the pivotable connector comprises an outer surface matingly received within a receptacle in the spoolable connector assembly.

[0007] Embodiments described herein comprise a combination of features and characteristics intended to address various shortcomings associated with certain prior devices, systems, and methods. The foregoing has outlined rather broadly the features and technical characteristics of the disclosed embodiments in order that the detailed description that follows may be better understood. The various characteristics and features described above, as well as others, will be readily apparent to those skilled in the art upon reading the following detailed description, and by referring to the accompanying drawings. It should be appreciated that the conception and the specific embodiments disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes as the disclosed embodiments. It should also be realized that such equivalent constructions do not depart from the spirit and scope of the principles disclosed herein.BRIEF DESCRIPTION OF THE DRAWINGS

[0008] For a detailed description of exemplary embodiments of the disclosure, reference will now be made to the accompanying drawings in which:

[0009] FIG. 1 is a schematic view of an embodiment of a well system in accordance with principles disclosed herein;

[0010] FIG. 2 is a schematic view of an embodiment of a surface assembly of the well system of FIG. 1 in accordance with principles disclosed herein;

[0011] FIGS. 3-8 are additional schematic views of the surface assembly of FIG. 2 in accordance with principles disclosed herein;

[0012] FIGS. 9-10 are side cross-sectional views of an embodiment of a spoolable CT connector in accordance with principles disclosed herein; and

[0013] FIGS. 11-12 are side cross-sectional views of another embodiment of a spoolable CT connector in accordance with principles disclosed herein.DETAILED DESCRIPTION OF EXEMPLARY EMBODIMENTS

[0014] The following discussion is directed to various exemplary embodiments. However, one skilled in the art will understand that the examples disclosed herein have broad application, and that the discussion of any embodiment is meant only to be exemplary of that embodiment and not intended to suggest that the scope of the disclosure, including the claims, is limited to that embodiment.

[0015] Certain terms are used throughout the following description and claims to refer to particular features or components. As one skilled in the art will appreciate, different persons may refer to the same feature or component by different names. This document does not intend to distinguish between components or features that differ in name but not function. The drawing figures are not necessarily to scale. Certain features and components herein may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in interest of clarity and conciseness. Unless the context dictates the contrary, all ranges set forth herein should be interpreted as being inclusive of their endpoints, and open-ended ranges should be interpreted to include only commercially practical values. Similarly, all lists of values should be considered as inclusive of intermediate values unless the context indicates the contrary.

[0016] 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...” Also, the term “couple” or “couples” is intended to mean either an indirect or direct connection. Thus, if a first device couples to a second device, that connection may be through a direct engagement between the two devices, or through an indirect connection that is established via other devices, components, nodes, and connections. In addition, as used herein, the terms “axial” and “axially” generally mean along or parallel to a particular axis (e.g., central axis of a body or a port), while the terms “radial” and “radially” generally mean perpendicular to a particular axis. For instance, an axial distance refers to a distance measured along or parallel to the axis, and a radial distance means a distance measured perpendicularto the axis. Any reference to up or down in the description and the claims is made for purposes of clarity, with “up”, “upper”, “upwardly”, “uphole”, or “upstream” meaning toward the surface of the borehole and with “down”, “lower”, “downwardly”, “downhole”, or “downstream” meaning toward the terminal end of the borehole, regardless of the borehole orientation. As used herein, the terms “approximately,” “about,” “substantially,” and the like mean within 10% (i.e., plus or minus 10%) of the recited value. Thus, for example, a recited angle of “about 80 degrees” refers to an angle ranging from 72 degrees to 88 degrees.

[0017] As previously described, coiled tubing (CT) systems utilized as part of well systems may include a reel assembly and a length of CT which may be spooled or stored on a core of the reel assembly. Particularly, the CT comprises a single length of continuous, unjointed tubing, typically unwound from the reel assembly and deployed into a wellbore using a specialized injector head, which controls the speed and tension of the CT as it is fed into the wellbore. Once a desired depth is reached, various tools and equipment can be run through the CT to perform tasks or services associated with the wellbore. Circulating, pumping, coiled tubing drilling, production, logging, completion, and perforating may utilize CT systems.

[0018] In some applications, multiple separate lengths or CT strings may be run into the wellbore of a given well system, such as in the case of extended reach wellbores that extend across relatively large distances. In such applications, a first or downhole CT string may be deployed into the wellbore using a first reel assembly. Once the downhole CT string has been successfully run into the wellbore, an uphole end of the downhole CT string may be cut and subsequently connected to a downhole end of a separate second or uphole CT string. Particularly, the uphole CT string may be deployed from a separate, second reel assembly that is spaced from the first reel assembly such that an angle is formed between the first and second reel assemblies and the wellbore of the well system. Given that the uphole CT string is installed at an angle relative to the downhole CT string, residual stress or torsion may be built within the pair of CT strings as the uphole CT string is subsequently run into the wellbore given that the CT connector connecting the pair of CT strings may not permit relative rotation therebetween.

[0019] This residual torsional stress present in the pair of connected CT strings may result in at least some helical coiling of the CT strings within the wellbore. More importantly, such residual torsional stress may prevent the pair of connected CTstrings from being reeled onto a single reel assembly following their removal from the wellbore of the well system. Particularly, the residual torsional stress present in the pair of connected CT strings may prevent the CT strings from wrapping uniformly about the reel assembly as they are retracted from the wellbore, with the CT strings instead wrapping erratically and haphazardly about the reel assembly to relieve at least some of the residual torsional stress present therein. This haphazard wrapping of the pair of connected CT strings may make it impractical to wrap both of the connected uphole and downhole CT strings about the same reel assembly, instead potentially forcing the operator to cut the pair of CT strings and wrap them individually about separate reel assemblies - increasing the amount of time and expense associated with operating the CT system.

[0020] Further, conventional CT connectors typically provide for only a limited degree of bending along a longitudinal axis thereof, resulting in the formation of a bulge about the reel assembly by the CT connector as the pair of connected CT strings are reeled onto a reel assembly. This bulge formed by the relatively rigid CT connector may also prevent both the pair of uphole and downhole CT strings from being reeled onto the same reel assembly, undesirably requiring instead the CT strings to be reeled individually onto separate reel assemblies.

[0021] Accordingly, embodiments of spoolable CT connectors are disclosed herein which permit the pair of CT strings connected thereby to relieve residual torsional stresses present therein to permit the uniform wrapping of the pair of CT strings about a single, shared reel assembly. Additionally, embodiments of spoolable CT connectors disclosed herein also provide a greater degree of flexibility than conventional CT connectors to prevent or inhibit the formation of a bulge along the reel assembly as the pair of CT strings connected thereby are reeled onto the shared reel assembly.

[0022] Referring initially to FIG. 1, an embodiment of a well system 1 including a wellbore 4 extending into an earthen subterranean formation 2 to a terminal end or “toe” 5 from a terranean surface 3 is shown. In this exemplary embodiment, well system 1 comprises a system for servicing or completing the wellbore 4; however, in other embodiments, well system 1 may comprise a system for drilling wellbore 4 or a system for producing hydrocarbons from wellbore 4. Initially, it should be appreciated that the terranean surface 3 may be a land surface, a sub-sea surface (e.g., a seabed), or other underwater surface. Additionally, subterranean earthen formation 2may comprise a plurality of discrete subterranean layers within the subterranean earthen formation 2. Further, while wellbore 4 is shown in FIG. 1 as initially substantially vertical and then deviating at a substantially 90 degrees angle, it should be appreciated that in other embodiments, wellbore 4 may be deviated, horizontal, and extended at an incline relative to the direction of gravity along one or more sections of the deviated or horizontal wellbore. The wellbore 4 may be formed with various dimensions (e.g., diameters) and depths using a drilling system which may include, among other things, a support structure (e.g., a derrick, a mast) located at the terranean surface 3, and a drilling assembly including a drill bit for cutting into the subterranean earthen formation 2.

[0023] In general, well system 1 includes a CT system 10 comprising a surface assembly 50 and one or more CT strings deployable into and from the wellbore 4 using the surface assembly 50. Particularly, CT system 10 includes a first or downhole CT string 20 extending between a downhole end 21 and an opposing uphole end 23 thereof, and a second or uphole CT string 30 coupled to the downhole CT string 20 and extending from a downhole end 31 to the terranean surface 3.

[0024] Additionally, in this exemplary embodiment, CT system 10 includes one or more downhole CT tools 12 coupled to CT strings 20 and 30. Particularly, CT system 10 is shown in FIG. 1 as including a first downhole CT tool 12 coupled to the downhole end 21 of downhole CT string 20, and a second downhole CT tool 12 coupled between the uphole end 23 of downhole CT string 20 and the downhole end 31 of uphole CT string 30. It should be noted that while CT system 10 includes a pair of downhole CT tools 12 in this exemplary embodiment, in other embodiments, CT system 10 may include one, or any number / combinations of downhole CT tool 12 depending on the particular application. Additionally, while in this exemplary embodiment CT system 10 includes an uphole CT string 30 and a downhole CT string 20, CT system 10 may include more than two separate CT strings depending on the application.

[0025] The CT strings 20 and 30 each comprise a continuous length of spoolable tubing defining an internal throughbore or central passage through which fluid may flow between the respective uphole and downhole ends thereof. In some embodiments, downhole CT string 20 and uphole CT string 30 may be in fluid communication with downhole CT tools 12 such that fluid may be pumped from the surface assembly 50 into and through uphole CT string 30, the second downhole CTtool 12, the downhole CT string 20, and into the first downhole CT tool 12 connected to the downhole end 21 of the downhole CT string 20. The downhole CT tools 12 of CT system 10 may include any combination of tools or equipment for performing specific tasks associated with wellbore 4. For example, downhole CT tool 12 may include any combination of fishing tools, packers / bridge plugs, perforating guns, well cleanup tools, cutting tools, drills, mills, and stimulation tools depending on the needs of the given application.

[0026] In this exemplary embodiment, surface assembly 50 of CT system 10 is configured to deploy and / or retrieve continuous lengths of tubing (e.g., downhole CT string 20 and uphole CT string 30), which are spooled onto a reel, into and / or from wellbore 4 while performing specific tasks associated with wellbore 4 as will be disclosed further herein. Unlike wireline and slickline units that use a winch drum and cable that lacks a central passage for communicating fluid flow and / or pressure, surface assembly 50 includes a coiled tubing reel which stores and feeds the continuous tubing into wellbore 4, an injector head that grips and pushes the coiled tubing downhole under controlled pressure and tension, pressure control equipment, and fluid handling systems, allowing the continuous coil of tubing to be run in and out of wellbore 4 while maintaining well control. The surface assembly 50 may be powered by hydraulic systems, electrical systems, or a combination thereof depending on the application.

[0027] Referring to FIG. 2, an embodiment of the surface assembly 50 of CT system 10 is shown. In this embodiment, surface assembly 50 is generally configured to inject or run coiled tubing (e.g., downhole CT string 20, 30 shown in FIG. 1) into wellbore 4 and / or pull or retract downhole CT string 20, 30 from wellbore 4. Additionally, surface assembly 50 may be used to provide fluid flow and / or pressure to CT strings 20, 30 and downhole CT tools 12, and for communicating signals (e.g., electrical signals, optical signals) and / or applying axial loads to CT strings 20, 30 and downhole CT tools 12 as needed to facilitate their downhole operation.

[0028] In this exemplary embodiment, surface assembly 50 generally includes a CT truck or transporter 94 that may include an accumulator or other equipment such as hydraulic units and safety devices, a CT reel 95 rotatable by a CT motor 96 (each positioned on the CT transporter 94), a CT control center or unit 98 (also positionable on the CT transporter 94) for transmitting signals from the surface to / from equipment deployed in wellbore 4, a wellhead 52, a Christmas tree 56, a blowout preventer (BOP)60 installed above the wellhead 52 and comprising separate BOP rams 62, 64, and 66 for providing well control, a service platform 70 for supporting rig personnel involved in performing various tasks associated with wellbore 4, a lubricator 80, an injector head 85, a tubing guide 92 for aligning downhole CT string 20 as it is deployed or retrieved from the wellbore, and a crane 90 (shown only partially in FIG. 2) for physically supporting the injector head 85 and lubricator 80. The configuration of surface assembly 50 may, in other embodiments, vary from that shown in FIG. 2. For instance, in other embodiments, surface assembly 50 may include equipment in addition to that shown in FIG. 2.

[0029] To illustrate operational features of CT system 10, surface assembly 50 is shown in FIG. 2 deploying downhole CT string 20 into the wellbore 4. Particularly, during operation of CT system 10, downhole CT string 20 may be unwound from CT reel 95 in response to the operation of CT motor 96. The unwinding from, and winding onto, CT reel 95 of downhole CT string 20 may be performed or assisted by a tubing tensioner (not shown) of CT transporter 94 that is powered by a hydraulic unit. The deployment of downhole CT string 20 into and out of wellbore 4 may also be facilitated by the tubing guide 92 extending from injector head 85. The injector head 85 is suspended from a crane 90 such that the crane 90 may be used to control the positioning of injector head 85 relative to wellbore 4. In this manner, crane 90 may align injector head 85 with wellhead 52 and BOP 60 to ensure smooth feeding of downhole CT string 20 into and out of wellbore 4. As will be discussed further herein, crane 90 may also be operated to vertically lift the injector head 85 and lubricator 80 from BOP 60 (i.e. , when the lubricator 80 is decoupled from the BOP 60) as desired to expose a segment of the downhole CT string 20 located vertically above BOP 60.

[0030] Wellhead 52 is positioned at the terranean surface 3 of wellbore 4 and physically supports Christmas tree 56 and BOP 60, which is mounted or otherwise coupled to Christmas tree 56. Christmas tree 56 comprises a system of valves and fittings for controlling the flow of fluids from wellbore 4. Along with Christmas tree 56, BOP 60 may be used to control the circulation of fluids from wellbore 4 and the surrounding environment at the terranean surface 3 to prevent blowouts during drilling and / or intervention operations. BOP rams 62, 64, and 66 (e.g., pipe rams, blind rams, and shear rams) of BOP 60 are configured to selectably isolate fluid communication across BOP 60. For example, BOP rams 62 and 64 may comprise blind and pipe rams respectively while BOP ram 66 may comprise a shear ram configured to cut thedownhole CT string 20 when present therein. In this exemplary embodiment, lubricator 80 of surface assembly 50 extends from BOP 60 to injector head 85, where lubricator 80 provides pressure control and mechanical guidance for downhole CT string 20 as downhole CT string 20 is extended into or retracted from wellbore 4.

[0031] A variety of downhole CT tools 12 may be coupled to the terminal end of downhole CT string 20 for performing various operations in wellbore 4 as previously disclosed. For example, a mill tool may be coupled to the terminal end of downhole CT string 20 for selectably drilling or milling out downhole plugs (e.g., bridge plugs) previously installed in wellbore 4 to permit fluid communication between the toe 5 of wellbore 4 and the terranean surface 3. CT transporter 94 may include or support the CT control unit 98 for transmitting signals to and receiving signals from (e.g., electronic signals and / or data) downhole tools or equipment attached to the terminal end of downhole CT string 20 such as the first downhole CT tool 12 shown in FIG. 1. Additionally, fluids may be pumped between CT transporter 94 and tools attached to the terminal end of downhole CT string 20 via the central passage extending through downhole CT string 20.

[0032] Referring to FIG. 3, another view of the surface assembly 50 of CT system 10 is shown. Particularly, FIG. 3 illustrates the use of the service platform 70 of surface assembly 50, which is located near a vertical upper end of the BOP 60 of surface assembly 50. Service platform 70 provides access to rig personnel 72 of CT system 10 to the area vertically above BOP 60 as shown in FIG. 3. For instance, service platform 70 includes a deck 74 (e.g., a human-accessible deck 74) located vertically above the terranean surface 3 and over the wellhead 52 and Christmas tree 56. The deck 74 of service platform 70 may be accessed by rig personnel 72 via a ladder, lift or other mechanism. As will be discussed further herein, rig personnel 72 may access a desired segment of the downhole CT string 20 (or other CT strings) at a location between the injector head 85 and the BOP 60 by lifting (e.g., via crane 90) the injector head 85 and lubricator 80 vertically upwards away from the BOP 60.

[0033] In this exemplary embodiment, surface assembly 50 is shown in FIG. 3 with downhole CT string 20 being deployed into wellbore 4 with at least a portion of downhole CT string 20 suspended above BOP 60 in lubricator 80. In some embodiments, prior to running the downhole end 21 of downhole CT string 20 into wellbore 4, a downhole CT tool (e.g., downhole CT tool 12 shown in FIG. 1) is coupled to the downhole end 21 of downhole CT string 20 and deployed through BOP 60 andinto wellbore 4. As previously described, different lengths of CT string may be placed between downhole CT tools 12, depending on the application. For example, in some embodiments, downhole CT string 20 comprises a relatively short length of CT referred to as a CT stinger placed between a first downhole CT tool 12 and a second downhole CT tool 12, such that, once the desired length of CT stinger has been run into wellbore 4, the CT stinger is cut and another CT string (e.g., uphole CT string 30 shown in FIG. 1) is attached to the CT stinger. In other embodiments, the downhole CT string 20 may be directly connected to another CT string (e.g, uphole CT string 30) via a CT connector coupled directly therebetween. In still other embodiments, other members, strings, and / or tools may be coupled between downhole CT string 20 and an uphole CT string such as uphole CT string 30.

[0034] Referring to FIG. 4, another view of surface assembly 50 of CT system 10 is shown with both downhole CT string 20 and uphole CT string 30 positioned adjacent the wellbore 4. Particularly, FIG. 4 illustrates the deployment of downhole CT string 20 into wellbore 4 from a first CT transporter 94-1 while the uphole CT string 30 is positioned or staged adjacent wellbore 4 and positioned on a separate, second CT transporter 94-2. Downhole CT string 20 is shown in FIG. 4 in the process of being run into wellbore 4 from first CT transporter 94-1 as uphole CT string 30 awaits the completion of said running of downhole CT string 20 whereby downhole CT string 20 may be cut and the downhole end 31 of uphole CT string 30 may be connected therewith. In this manner, uphole CT string 30 is readied for installation in wellbore 4 with the downhole end 31 thereof located proximal to central axis 55 as the downhole CT string 20 is run into the wellbore 4, thereby minimizing the amount of time required for installing the pair of CT strings 20 and 30 in the wellbore 4.

[0035] To physically accommodate both CT transporters 94-1 and 94-2 at the wellsite, the second CT transporter 94-2 is circumferentially spaced about a central or longitudinal axis 55 of the surface assembly 50 (aligned with a longitudinal axis of the wellhead 52) by an azimuthal offset angle 57. While azimuthal offset angle 57 is shown as generally 180 degrees in FIG. 4, the magnitude of azimuthal offset angle 57 may vary depending on the given application, including the amount of space available at the given wellsite and the size and configuration of the CT transporters 94-1 and 94-2. For instance, CT transporters 94-1 and 94-2 may be positioned as close together as feasible in order to minimize the azimuthal offset angle 57. However, given that CT transporters 94-1 and 94-2 must occupy some physical space, azimuthal offset angle57 may not be reduced to zero when CT strings 20 and 30 are installed using separate CT transporters 94-1 and 94-2.

[0036] In this exemplary embodiment, downhole CT string 20 may be unwound from CT reel 95-1 in response to the operation of CT motor 96-1. The unwinding from, and winding onto, CT reel 95-1 of downhole CT string 20 may be performed or assisted by a tubing tensioner (not shown) of CT transporter 94-1 that is powered by a hydraulic unit. The deployment of downhole CT string 20 into wellbore 4 may also be facilitated by the tubing guide 92-1 extending from injector head 85. The injector head 85 is suspended from a crane 90 such that the crane 90 may be used to control the positioning of injector head 85 relative to wellbore 4. In this manner, crane 90 may align injector head 85 with wellhead 52 and BOP 60 to ensure smooth feeding of downhole CT string 20 into wellbore 4.

[0037] As previously described, when the desired length of downhole CT string 20 has been deployed into the wellbore 4, the downhole CT string 20 may be cut to define the uphole end 23 thereof which may be attached to the downhole end 31 of uphole CT string 30 to continue the operation of CT system 10. The downhole CT string 20 may be connected to uphole CT string 30 either directly via one or a pair of CT connectors connected directly together, or across one or more downhole tools connected between the pair of CT strings. Following connecting of the uphole end 23 of downhole CT string 20 with the downhole end 31 of uphole CT string 30, the uphole CT string 30 is unreeled from the CT reel 95-2 of the separate CT transporter 94-2 and threaded successively through the tubing guide 92-2, injector head 85, and lubricator 80.

[0038] Referring now to FIGS. 5-8, additional views of the surface assembly 50 of CT system 10 are shown during different stages of the operation of CT system 10 including exemplary cutting, aligning, and connecting operations of the downhole CT string 20 and / or uphole CT string 30.

[0039] As previously described, once a desired length of downhole CT string 20 has been run into the wellbore 4, it may be desired to cut the downhole CT string 20 and couple the downhole CT string 20 to a downhole CT tool (e.g., a downhole CT tool 12) or directly to another, separate CT string (e.g., uphole CT string 30). As shown particularly in FIG. 5, to initiate the process of cutting the downhole CT string 20 (or another tubular member extending centrally through CT system 10), the lubricator 80 is raised by the operation of crane 90 to expose a desired portion of the downhole CT string 20 which extends between a lower end 81 of the lubricator 80 and an upper end61 of the BOP 60. In this manner, the exposed portion of downhole CT string 20 is directly accessible (e.g., by rig personnel 72 in FIG. 3) such that rig personnel 72 may apply a cutting element to the exposed portion of downhole CT string 20. In some embodiments, safety checks are performed to ensure adequate well control and proper functioning of all tools, and associated equipment prior to decoupling the lower end 81 of lubricator 80 from the upper end 61 of BOP 60 and lifting injector head 85 and lubricator 80 therefrom. For example, an inflow test may be performed, whereby the downhole CT string 20 is opened to the atmosphere and observed to ensure there is no fluid flow through the downhole CT string 20. Subsequently, in some embodiments, BOP 60 is closed whereby one or more of BOP rams 62, 64, and 66 are closed around the downhole CT string 20, and a negative or inflow test is again performed to ensure all equipment are functioning as desired.

[0040] In some embodiments, prior to cutting of the exposed portion of downhole CT string 20 by the rig personnel 72 via a cutting element (e.g., a handheld saw and the like), an alignment tool (not shown) may be secured to the desired segment of the downhole CT string 20 to facilitate cutting, aligning, and / or coupling of the downhole CT string 20 to an uphole CT string (e.g., uphole CT string 30), tool (e.g., BHA 12). For instance, once safety tests have been satisfactorily completed, rig personnel 72 may signal the injector head 85 be moved to disengage lubricator 80 from the BOP 60 (e.g., via the operation of crane 90) providing access to the area around the desired segment of the downhole CT string 20 for installing the alignment tool. With the alignment tool secured to the downhole CT string 20, a controlled cut (indicated by arrow S in FIG. 6) is made to the downhole CT string 20 while ensuring that the downhole CT string 20, lubricator 80, and injector head 85 are unable to swing uncontrollably which could otherwise jeopardize the safety of rig personnel 72. The controlled cut of downhole CT string 20 defines the uphole end 23 thereof which is separated from a remaining segment 20’ of the downhole CT string 20 that remains coupled to CT reel 95-1. The remaining segment 20’ may be retracted through the lubricator 80 and to the CT reel 95-1 of surface assembly 50 such that only the downhole CT string 20 terminating at uphole end 23 remains positioned above BOP 60. In some embodiments, after the cutting of downhole CT string 20, lubricator 80 may be raised and moved away from wellbore 4 using a crane (e.g., crane 90 of FIG.2), allowing redress of the portion of the downhole CT string 20 above BOP 60 for subsequent operation.

[0041] As shown particularly in FIG. 7, once the remaining segment 20’ is retracted through the injector head 84, tubing guide 92-1 may be decoupled from injector head 85 and the separate tubing guide 92-2 may be coupled to injector head 85. With tubing guide 92-2 coupled to injector head 85, the downhole end 31 of uphole CT string 30 may be unreeled from the CT reel 95-2 of the separate CT transporter 94-2 and threaded successively through the injector head 85, and lubricator 80 such that the downhole end 31 of uphole CT string 30 is located vertically above and proximal the uphole end 23 of the downhole CT string 20. The downhole end 31 of uphole CT string 30 may be connected or coupled to the uphole end 23 of the downhole CT string 20 using one or more spoolable CT connector assemblies as will be disclosed further herein. Said spoolable CT connector assemblies in accordance with principles disclosed herein may permit the coupling of uphole CT string 30 with downhole CT string 20 while permitting the relief of residual torsional stress in the CT strings 20 and 30 result of the non-zero azimuthal offset angle 57 formed between CT strings 20 and 30 as they were originally connected together and run, in concert, into the wellbore 4 Additionally, the one or more spoolable CT connectors provide a pivotable and rotatable connection between CT strings 20 and 30 such that the spoolable CT connector may not form a hump along the CT reel 95-2 which could otherwise prohibit the reeling of both CT strings 20 and 30 about the CT reel 95-2.

[0042] In an example, and as shown specifically in FIG. 8, the downhole end 31 of uphole CT string 30 is shown directly coupled to the uphole end 23 of downhole CT string 20 via a spoolable CT connector assembly 100 in accordance with principles disclosed herein. In this exemplary embodiment, spoolable CT connector assembly 100 permits uphole CT string 30 to rotate relative downhole CT string 20 about a longitudinal axis 105 (shown in FIG. 9) of spoolable CT connector assembly 100. For instance, downhole CT string 20 may rotate freely about the longitudinal axis of spoolable CT connector assembly a generally unlimited number of times to continually relieve residual torsional stress in the downhole CT string 20 as the downhole CT string 20 is retracted from the wellbore 4. As used herein, the term ‘rotate freely” means rotation resulting from a slidable connection formed between two members whereby a connecting member is not forced to twist (as like a torsion spring) in order to permit relative rotation. For instance, free rotation permits multiple revolutions of the two connected members without the gradual buildup of residual torsional stress in the connected members. Additionally, spoolable CT connectorassembly 100 may permit downhole CT string 20 to pivot relative uphole CT string 30 about a plurality of separate axes including, for example, one or more lateral axes extending orthogonal to the central axis of spoolable CT connector assembly 100.

[0043] As another example, a downhole CT tool (e.g., downhole CT tool 12) and / or other tools may be connected between the downhole end 31 of uphole CT string 30 and the uphole end 23 of the downhole CT string 20 via at least a pair of spoolable CT connector assemblies 100 coupled between uphole and downhole ends of the BHA and the CT strings 30 and 20, respectively.

[0044] Referring to FIGS. 9 and 10, an embodiment of a spoolable CT connector assembly 100 is shown. In this exemplary embodiment, spoolable CT connector assembly 100 comprises a first or uphole connector body 102, a second or downhole connector body 120, and one or more intermediate connector bodies 150. Uphole connector body 102 has an uphole central or longitudinal axis 105 and extends between a first or uphole end 104 and a longitudinally opposed second or downhole end 106. Additionally, uphole connector body 102 has a central passage 108 defined by a generally cylindrical inner surface 110 extending between ends 104 and 106, and a generally cylindrical outer surface 112 extending between ends 104 and 106. Uphole connector body 102 is shown in FIG. 9 as comprising a pair of tubular members connected end-to-end (e.g., threadably connected); alternatively, uphole connector body 102 may comprise a single, integral or monolithically formed tubular member or more than two separate tubular members.

[0045] The inner surface 110 of uphole connector body 102 defines a curved receptacle or socket 114 such as a ball socket and the like located proximal to the downhole end 106 thereof. In this exemplary embodiment, socket 114 is defined by a curved, hemispherical inner surface to facilitate a pivotable connection between uphole connector body 102 and intermediate connector body 150 as will be discussed further herein. Additionally, one or more uphole indentions 116 are positioned along the outer surface 112 of uphole connector body 102. In this exemplary embodiment, uphole indentions 116 comprise one or more circumferentially spaced indents (e.g., hemispherical indents) and / or annular grooves that extend circumferentially around the uphole central axis 105 of uphole connector body 102. Alternatively, uphole indentions 116 may not comprise annular grooves and instead may comprise dimples of varying shapes and sizes circumferentially spaced about uphole central axis 105 in other embodiments. As will be discussed further herein, uphole CT string 30 may beplastically deformed or crimped into the uphole indentations 116 of uphole connector body 102 to couple or lock the uphole connector body 102 to the uphole CT string 30 whereby relative longitudinal movement is restricted between uphole CT string 30 and the uphole connector body 102. Further, in this exemplary embodiment, one or more annular uphole seals 118 are positioned along the outer surface 112 of uphole connector body 102 for sealing against an inner surface of the uphole CT string 30. In this configuration, uphole seals 118 restrict fluid communication across the annular interface formed between uphole CT string 30 and uphole connector body 102.

[0046] The downhole connector body 120 of spoolable connector assembly 100 has a downhole central or longitudinal axis 125 and extends between a first or uphole end 122 and a longitudinally opposed second or downhole end 124. Additionally, downhole connector body 120 has a central passage 126 defined by a generally cylindrical inner surface 128 extending between ends 122 and 124, and a generally cylindrical outer surface 130 similarly extending between ends 122 and 124. As with uphole connector body 102, downhole connector body 120 may comprise a single tubular member or two or more separate tubular members connected end-to-end.

[0047] In this exemplary embodiment, the inner surface 128 of downhole connector body 120 defines a generally cylindrical receptacle or socket 132 located at the uphole end 122 thereof for receiving a joint for pivotably connecting the downhole connector body 120 with the intermediate connector body 150 as will be discussed further herein. Additionally, one or more downhole indentions 134 are positioned along the outer surface 130 of downhole connector body 120. Like uphole indentations 116 described above, in this exemplary embodiment, downhole indentions 134 comprise one or more circumferentially spaced indents (e.g., hemispherical indents) and / or annular grooves that extend circumferentially around the downhole central axis 125 of downhole connector body 120. Alternatively, downhole indentions 134 may not comprise annular grooves and instead may comprise dimples of varying shapes and sizes circumferentially spaced about downhole central axis 125 in other embodiments. As will be discussed further herein, downhole CT string 20 may be plastically deformed or crimped into the downhole indentations 134 of downhole connector body 120 to couple or lock the downhole connector body 120 to the downhole CT string 20 whereby relative longitudinal movement is restricted between downhole CT string 20 and the downhole connector body 120.

[0048] Further, in this exemplary embodiment, one or more annular first downhole seals 131 along with one or more annular second downhole seals 133 are positioned along the outer surface 130 of downhole connector body 120 for sealing against an inner surface of the downhole CT string 20. In this configuration, downhole seals 131 and 133 restrict fluid communication across an annular interface formed between the downhole CT string 20 and the downhole connector body 120. Particularly, the first downhole seals 131 and second downhole seals 133 may straddle along downhole central axis 125 and a terminal end of the socket 132 to seal the socket 132 from the external environment surrounding downhole CT string 20.

[0049] In this exemplary embodiment, an obturating member receiver or basket 136 for receiving an obturating member or ball 135 (or a dart, etc., in other embodiments) is coupled to the downhole connector body 120 at the downhole end 124 thereof. Obturating member receiver 136 extends between a first or uphole end defining an annular first or uphole seat 138 and a longitudinally opposed second or downhole end defining an annular second or downhole seat 140 each of which is configured to receive the ball 135. Additionally, obturating member receiver 136 has a central passage extending between the seats 138 and 140 thereof which is open at the uphole seat 138 and enclosed at the downhole seat 140. Further, obturating member receiver 136 has one or more radial openings 142 formed therein located between the uphole seat 138 and the downhole seat 140 for permitting fluid flow between the central passage of the obturating member receiver 136 and the central passage of the downhole CT string 20. In some embodiments, spoolable CT connector assembly 100 may not include obturating member receiver 136 and / or may not receive the ball 135.

[0050] The intermediate connector body 150 of spoolable connector assembly 100 has an intermediate central or longitudinal axis 155 and extends between a first or uphole end 152 and a longitudinally opposed second or downhole end 154. Although spoolable CT connector assembly 100 is shown in FIG. 9 as including a single intermediate connector body 150, in other embodiments, spoolable CT connector assembly 100 may include a plurality of separate intermediate connector bodies 150 pivotably connected end-to-end. Additionally, intermediate connector body 150 has a central passage 156 defined by a generally cylindrical inner surface 158 extending between ends 152 and 154. Further, the inner surface 158 of intermediate connector body 150 defines a curved receptacle or socket 160 such as a ball socket and the like located proximal the downhole end 154 thereof. In this exemplary embodiment,socket 160 is defined by a curved, hemispherical inner surface to facilitate a pivotable connection between downhole connector body 120 and intermediate connector body 150 as will be discussed further herein.

[0051] In this exemplary embodiment, spoolable CT connector assembly 100 additionally includes a first or uphole joint body 170 pivotably connecting the intermediate connector body 150 with the uphole connector body 102, and a second or downhole joint body 190 pivotably connecting the downhole connector body 120 with the intermediate connector body 150. Uphole joint body 170 extends along intermediate central axis 155 between a first or distal end 172 and a longitudinally opposed second or proximal end 174. Additionally, uphole joint body 170 has a central passage 176 extending between ends 172 and 174 in fluid communication with the central passage 108 of uphole connector body 102, and an outer surface 178 also extending between ends 172 and 174.

[0052] In this exemplary embodiment, the distal end 172 of uphole joint body 170 defines a first or uphole pivotable connector 180 that is pivotably and matingly received in the socket 114 of uphole connector body 102. In this exemplary embodiment, uphole pivotable connector 180 comprises a member having a convex or hemispherical outer surface. Thus, uphole pivotable connector 180 may also be referred to herein as uphole ball joint or pivotable connector 180. Alternatively, the shape or configuration of uphole pivotable connector 180 may vary from that shown in FIG. 9. For instance, in other embodiments, uphole pivotable connector 180 may instead define a universal joint rather than a ball joint.

[0053] The sliding engagement between mating surfaces of pivotable connector 180 and receptacle 114 permit uphole connector body 102 to rotate about uphole central axis 105 a generally unlimited number of times relative to uphole joint body 170 and the intermediate connector body 150 coupled therewith. Additionally, the sliding engagement between mating surfaces of pivotable connector 180 permits the formation of a non-zero uphole misalignment angle 175 between uphole central axis 105 and the intermediate central axis 155 in a generally unlimited number of directions relative to an orthogonal plane (extending laterally out of the page in FIG. 9) through which the uphole central axis 105 orthogonally projects. Additionally, an annular seal 182 is positioned between the pivotable connector 180 and socket 114 to seal the interface formed therebetween.

[0054] The proximal end 174 of uphole joint body 170 is received within the central passage 156 of intermediate connector body 150 such that the proximal end 174 of uphole joint body 170 couples to the uphole end 152 of intermediate connector body 150 whereby relative movement is restricted therebetween. In this exemplary embodiment, the proximal end 174 of uphole joint body 170 is threaded into the uphole end 152 of intermediate connector body 150; however, the way the uphole joint body 170 connects with intermediate connector body 150 may vary in other embodiments. In still other embodiments, uphole joint body 170 may be formed integrally or monolithically with intermediate connector body 150. Additionally, in this exemplary embodiment, an annular seal 184 is positioned between the proximal end 174 of uphole joint body 170 and the uphole end 152 of intermediate connector body 150 to seal the annular interface formed therebetween.

[0055] The downhole joint body 190 of spoolable CT connector assembly 100 extends along downhole central axis 125 between a first or distal end 192 and a longitudinally opposed second or proximal end 194. Additionally, downhole joint body 190 has a central passage 196 extending between ends 192 and 194 in fluid communication with both the central passage 176 of uphole joint body 170 and the central passage 126 of downhole connector body 120, and an outer surface 198 also extending between ends 192 and 194. In this arrangement, the central passages 176 and 196 of joint bodies 170 and 190 provide fluid communication and connectivity between the central passages of downhole CT string 20 and the uphole CT string 30.

[0056] In this exemplary embodiment, the distal end 192 of downhole joint body 190 defines a second or downhole pivotable connector 200 that is pivotably and matingly received in the socket 160 of intermediate connector body 150. In this exemplary embodiment, downhole pivotable connector 200 comprises a member having a convex or hemispherical outer surface. Thus, downhole pivotable connector 200 may also be referred to herein as downhole ball joint or pivotable connector 200. Alternatively, the shape or configuration of downhole pivotable connector 200 may vary from that shown in FIG. 9.

[0057] Similar to the relationship between uphole pivotable connector 180 and socket 114 described above, sliding engagement between mating surfaces of downhole pivotable connector 200 and receptacle 160 permit downhole connector body 120 to rotate about downhole central axis 125 a generally unlimited number of times relative to downhole joint body 190 and the intermediate connector body 150 coupledtherewith. Additionally, the sliding engagement between mating surfaces of pivotable connector 180 permits the formation of a non-zero uphole misalignment angle 195 between downhole central axis 125 and the intermediate central axis 155 in a generally unlimited number of directions relative an orthogonal plane (extending laterally out of the page in FIG. 9) through which the downhole central axis 125 orthogonally projects. Additionally, an annular seal 202 is positioned between the pivotable connector 180 and socket 160 to seal the interface formed therebetween.

[0058] The proximal end 194 of downhole joint body 190 is received within the central passage 156 of intermediate connector body 150 such that the proximal end 194 of downhole joint body 190 couples to the uphole end 152 of intermediate connector body 150 whereby relative movement is restricted therebetween. In this exemplary embodiment, the proximal end 194 of downhole joint body 190 is pinned (e.g., by one or more fasteners) to the uphole end 122 of downhole connector body 120; however, the way the downhole joint body 190 connects with downhole connector body 120 may vary in other embodiments. In still other embodiments, downhole joint body 190 may be formed integrally or monolithically with downhole connector body 120. Additionally, in this exemplary embodiment, an annular seal 204 is positioned between the proximal end 194 of downhole joint body 190 and the uphole end 122 of downhole connector body 120 to seal the annular interface formed therebetween.

[0059] Referring to FIGS. 11 and 12, another exemplary embodiment of a spoolable CT connector assembly 300 is shown. Spoolable CT connector assembly 300 includes features in common with spoolable CT connector assembly 100 shown in FIGS. 9-10, and shared features are labeled similarly. Particularly, Spoolable CT connector assembly 300 comprises a first or uphole connector body 302, a second or downhole connector body 320, and the one or more intermediate connector bodies 150. Uphole connector body 302 has an uphole central or longitudinal axis 305 and extends between a first or uphole end 304 and a longitudinally opposed second or downhole end 306. Additionally, uphole connector body 302 has a central passage 308 defined by a generally cylindrical inner surface 310 extending between ends 304 and 306, and a generally cylindrical outer surface 312 extending between ends 304 and 306. Uphole connector body 302 is shown in FIG. 11 as comprising a pair of tubular members connected end-to-end (e.g., threadably connected); alternatively, uphole connector body 302 may comprise a single, integral or monolithically formed tubular member or more than two separate tubular members.

[0060] The inner surface 310 of uphole connector body 302 defines a curved receptacle or socket 314 such as a ball socket and the like located proximal to the downhole end 306 thereof. In this exemplary embodiment, socket 314 is defined by a curved, hemispherical inner surface to facilitate a pivotable connection between uphole connector body 302 and intermediate connector body 150.

[0061] In this exemplary embodiment, rather than having the uphole CT string 30 crimped onto uphole connector body 302, uphole connector body 302 couples to uphole CT string 30 via an annular uphole slip 316 positioned radially between an inner surface of uphole CT string 30 and a frustoconical outer surface 318 of uphole connector body 302. In this exemplary embodiment, uphole slip 316 comprises a plurality of locking teeth that bite into the inner surface of the uphole CT string 30 to secure the uphole connector body 302 thereto. Particularly, an uphole collar 319 is threaded to the outer surface 312 of uphole connector body 302 such that rotation of the uphole collar 319 slides the frustoconical outer surface 318 of uphole connector body 302 relative to uphole slip 316 to increase the pressure applied by uphole slip 316 to uphole CT string 30 to lock the uphole slip 316 thereto. In other embodiments, the uphole slip 316 may instead be configured to clamp or bite into the outer surface of uphole CT string 30 rather than the inner surface thereof.

[0062] The downhole connector body 320 of spoolable connector assembly 300 has a downhole central or longitudinal axis 325 and extends between a first or uphole end 322 and a longitudinally opposed second or downhole end 324. Additionally, downhole connector body 320 has a central passage 326 defined by a generally cylindrical inner surface 328 extending between ends 322 and 324, and a generally cylindrical outer surface 330 similarly extending between ends 322 and 324. As with uphole connector body 302, downhole connector body 320 may comprise a single tubular member or two or more separate tubular members connected end-to-end.

[0063] In this exemplary embodiment, the inner surface 328 of downhole connector body 320 defines a generally cylindrical receptacle or socket 332 located at the uphole end 322 thereof for receiving a joint for pivotably connecting the downhole connector body 320 with the intermediate connector body 150. In this exemplary embodiment, rather than having the downhole CT string 30 crimped onto downhole connector body 320, downhole connector body 320 couples to downhole CT string 30 via an annular downhole slip 333 positioned radially between an inner surface of downhole CT string 30 and a frustoconical outer surface 334 of downhole connector body 320. In thisexemplary embodiment, downhole slip 333 comprises a plurality of locking teeth that bite into the inner surface of the downhole CT string 30 to secure the downhole connector body 320 thereto. Particularly, a downhole collar 337 is threaded to the outer surface of downhole connector body 320 such that rotation of the downhole collar 337 slides the frustoconical outer surface 334 of downhole connector body 320 relative to downhole slip 333 to increase the pressure applied by downhole slip 333 to downhole CT string 30 to lock the downhole slip 333 thereto. In other embodiments, the downhole slip 333 may instead be configured to clamp or bite into the outer surface of downhole CT string 30 rather than the inner surface thereof.

[0064] In this exemplary embodiment, an obturating member receiver or basket 336 for receiving an obturating member or ball 335 (or a dart, etc., in other embodiments) is coupled to the downhole connector body 320 at the downhole end 324 thereof. Obturating member receiver 336 extends between a first or uphole end defining an annular first or uphole seat 338 and a longitudinally opposed second or downhole end defining an annular second or downhole seat 340 each of which is configured to receive the ball 335. Additionally, obturating member receiver 336 has a central passage extending between the seats 338 and 340 thereof which is open at the uphole seat 338 and enclosed at the downhole seat 340. Further, obturating member receiver 336 has one or more radial openings (not shown) formed therein located between the uphole seat 338 and the downhole seat 340 for permitting fluid flow between the central passage of the obturating member receiver 336 and the central passage of the downhole CT string 20. In some embodiments, spoolable CT connector assembly 300 may not include obturating member receiver 336 and / or may not receive the ball 335.

[0065] While exemplary embodiments have been shown and described, modifications thereof can be made by one skilled in the art without departing from the scope or teachings herein. The embodiments described herein are exemplary only and are not limiting. Many variations and modifications of the systems, apparatus, and processes described herein are possible and are within the scope of the disclosure. For example, the relative dimensions of various parts, the materials from which the various parts are made, and other parameters can be varied. Accordingly, the scope of protection is not limited to the embodiments described herein, but is only limited by the claims that follow, the scope of which shall include all equivalents of the subject matter of the claims. Unless expressly statedotherwise, the steps in a method claim may be performed in any order. The recitation of identifiers such as (a), (b), (c) or (1), (2), (3) before steps in a method claim are not intended to and do not specify a particular order to the steps, but rather are used to simplify subsequent reference to such steps.

Claims

AMENDED CLAIMSreceived by the International Bureau on 29 July 2026 (29.06.2026)What is claimed is:

1. A spoolable coiled tubing (CT) connector assembly, comprising:a first connector body configured to connect with a first CT string;a second connector body configured to connect with a second CT string that is separate from the first CT string; anda pivotable connector pivotably coupled between the first connector body and the second connector body wherein the pivotable connector pivotably or slidably connects the first connector body with the second connector body.

2. The spoolable CT connector assembly of claim 1 , wherein the first connector body comprises one or more indentions positioned along an outer surface of the first connector body and configured to receive at least a portion of the first CT string.

3. The spoolable CT connector assembly of claim 2, further comprising one or more annular first seals along with one or more annular second seals positioned along an outer surface of the first connector body configured to seal against an inner surface of the first CT string.

4. The spoolable CT connector assembly of claim 1, wherein the second connector body comprises one or more indentions positioned along an outer surface of the second connector body and configured to receive at least a portion of the second CT string.

5. The spoolable CT connector assembly of claim 4, wherein one or more annular seals are positioned along an outer surface of the second connector body configured to seal against an inner surface of the second CT string.

6. The spoolable CT connector assembly of claim 1 , wherein the pivotable connector comprises an outer surface matingly received within a receptacle in the spoolable CT connector.

7. The spoolable CT connector assembly of claim 1, further comprising a first joint body pivotably connecting the pivotable connector with the first connector body, and a second joint body pivotably connecting the second connector body with the pivotable connector.

8. The spoolable CT connector assembly of claim 1 , wherein the first connector body comprises a slip positioned between an inner surface of the first CT string and an outer surface of the first connector body, and wherein the slip comprises a plurality of locking teeth configured to bite into the inner surface of the first CT string to secure the first connector body to the first CT string.

9. The spoolable CT connector assembly of claim 8, wherein the second connector body comprises a slip positioned between an inner surface of the second CT string and an outer surface of the second connector body, and wherein the slip comprises a plurality of locking teeth configured to bite into the inner surface of the second CT string to secure the second connector body to the second CT string.

10. A spoolable coiled tubing (CT) connector assembly, comprising:a first connector body configured to connect with a first CT string, the first connector body having a first central axis;a second connector body configured to connect with a second CT string that is separate from the first CT string, the second connector body having a second central axis; anda pivotable connector pivotably coupled between the first connector body and the second connector body wherein the pivotable connector permits the second connector body to rotate freely relative to the first connector body.

11. The spoolable CT connector assembly of claim 10, wherein the first connector body comprises one or more indentions positioned along an outer surface of the first connector body and configured to receive at least a portion of the first CT string.

12. The spoolable CT connector assembly of claim 11 , further comprising one or more annular first seals along with one or more annular second seals positioned along an outersurface of the first connector body configured to seal against an inner surface of the first CT string.

13. The spoolable CT connector assembly of claim 10, wherein the second connector body comprises one or more indentions positioned along an outer surface of the second connector body and configured to receive at least a portion of the second CT string.

14. The spoolable CT connector assembly of claim 13, wherein one or more annular seals are positioned along an outer surface of the second connector body configured to seal against an inner surface of the second CT string.

15. The spoolable CT connector assembly of claim 10, wherein the pivotable connector comprises an outer surface matingly received within a receptacle in the spoolable CT connector assembly.

16. The spoolable CT connector assembly of claim 10, further comprising a first joint body pivotably connecting the pivotable connector with the first connector body, and a second joint body pivotably connecting the second connector body with the pivotable connector.

17. The spoolable CT connector assembly of claim 10, wherein the first connector body comprises a slip positioned between an inner surface of the first CT string and an outer surface of the first connector body, and wherein the slip comprises a plurality of locking teeth configured to bite into the inner surface of the first CT string to secure the first connector body to the first CT string.

18. The spoolable CT connector assembly of claim 17, wherein the second connector body comprises a slip positioned between an inner surface of the second CT string and an outer surface of the second connector body, and wherein the slip comprises a plurality of locking teeth configured to bite into the inner surface of the second CT string to secure the second connector body to the second CT string.19-24. (Cancelled)25. A spoolable coiled tubing (CT) connector assembly, comprising:a first connector body configured to connect with a first CT string, the first connector body having a first central axis;a second connector body configured to connect with a second CT string that is separate from the first CT string, the second connector body having a second central axis;a joint body connected between the first connector body and the second connector body wherein the joint body is configured to permit the first connector body to pivot freely about a longitudinal axis of the spoolable CT connector assembly relative to the second connector body; andan obturating member receiver extending between an open end coupled to the first connector body and an enclosed end opposite the open end, wherein one or more fluid openings are formed in the obturating member receiver between the open end and the enclosed end, and wherein an annular seat is formed at the open end for receiving an obturating member that may be landed thereagainst.

26. The spoolable CT connector assembly of claim 25, wherein the joint body comprises a pivotable connector pivotably coupled between the first connector body and the second connector body wherein the pivotable connector permits the second connector body to rotate freely relative to the first connector body.

27. The spoolable CT connector assembly of claim 26, wherein the pivotable connector slidably connects the first connector body with the second connector body.

28. The spoolable CT connector assembly of claim 25, wherein the joint body is configured to permit the first connector body to pivot freely about a plurality of different axes, including the longitudinal axis of the spoolable CT connector assembly, relative to the second connector body.

29. The spoolable CT connector assembly of claim 25, wherein the seat of the obturating member receiver comprises an uphole seat and the obturating member receiver further comprises an annular downhole seat located at the enclosed end of the obturating member receiver.

30. The spoolable CT connector assembly of claim 25, wherein the obturating member receiver comprises an obturating member basket.

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