A coiled tubing injector system including a trolley track and trolley for support thereof

Abstract

A coiled tubing injector system and a well system are disclosed. The system, in one aspect, includes a coiled tubing frame having a first side and a second opposing side, as well as a coiled tubing injector positioned at least partially within the coiled tubing frame, the coiled tubing injector configured to assist in a placement of a coiled tubing string within a wellbore, in addition to a coiled tubing guide arch aligned with the coiled tubing injector and extending away from the first side of the coiled tubing frame, the coiled tubing guide arch configured to guide the coiled tubing string into the coiled tubing injector. The coiled tubing injector system, in one aspect, further includes a trolley track or trolley coupled proximate the second opposing side of the coiled tubing frame, the trolley track or trolley configured to counteract reel tension force associated with the coiled tubing string.

Description

A COILED TUBING INJECTOR SYSTEM INCLUDING A TROLLEY TRACK AND TROLLEY FOR SUPPORT THEREOFCROSS-REFERENCE TO RELATED APPLICATION

[0001] This application claims priority to U.S. Application Serial No. 18 / 921,380, filed on October 21, 2024, entitled “A COILED TUBING INJECTOR SYSTEM INCLUDING A TROLLEY TRACK AND TROLLEY FOR SUPPORT THEREOF,” commonly assigned with this application and incorporated herein by reference in its entirety.BACKGROUND

[0002] Coiled tubing may be used in a variety of wellbore servicing operations, including drilling operations, completion operations, stimulation operations, workover and other operations. Coiled tubing generally refers to relatively flexible, continuous small diameter cylindrical tubing having a thin wall made of metal or composite material that can be run into the wellbore from a large spool which may be mounted on a truck or other support structure (e.g., rig platform). Coiled tubing may be used, for example, to inject gas or other fluids into the wellbore or pipeline, to inflate or activate bridges and packers, to transport tools downhole (such as logging tools), to perform remedial cementing and clean-out operations in the bore, to deliver drilling tools downhole, for electric wireline logging and perforating, drilling, wellbore cleanout, fishing, setting and retrieving tools, for displacing fluids, and for transmitting hydraulic power into the wellbore. The flexible, lightweight nature of coiled tubing makes it particularly useful in deviated wellbores.BRIEF DESCRIPTION

[0003] Reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which:

[0004] FIGs. 1 through 4 illustrate different enlarged views of an embodiment of a well system designed, manufactured and / or operated according to one or more alternative embodiments of the disclosure, for example employing a coiled tubing injector system according to one embodiment of the disclosure;

[0005] FIGs. 5 and 6 illustrate different enlarged views of an alternative embodiment of a well system designed, manufactured and / or operated according to one or more alternativeembodiments of the disclosure, for example employing a coiled tubing injector system according to an alternative embodiment of the disclosure;

[0006] FIGs. 7 and 8 illustrate different enlarged views of an alternative embodiment of a well system designed, manufactured and / or operated according to one or more alternative embodiments of the disclosure, for example employing a coiled tubing injector system according to an alternative embodiment of the disclosure;

[0007] FIGs. 9 and 10 illustrate different enlarged views of an alternative embodiment of a well system designed, manufactured and / or operated according to one or more alternative embodiments of the disclosure, for example employing a coiled tubing injector system according to an alternative embodiment of the disclosure; and

[0008] FIGs. 11 and 12 illustrate different enlarged views of an alternative embodiment of a well system designed, manufactured and / or operated according to one or more alternative embodiments of the disclosure, for example employing a coiled tubing injector system according to an alternative embodiment of the disclosure.DETAILED DESCRIPTION

[0009] In the drawings and descriptions that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. The drawn figures are not necessarily to scale. Certain features of the disclosure may be shown exaggerated in scale or in somewhat schematic form and some details of certain elements may not be shown in the interest of clarity and conciseness. The present disclosure may be implemented in embodiments of different forms.

[0010] Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of the principles of the disclosure, and is not intended to limit the disclosure to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed herein may be employed separately or in any suitable combination to produce desired results.

[0011] Unless otherwise specified, use of the terms “connect,” “engage,” “couple,” “attach,” or any other like term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described.

[0012] Unless otherwise specified, use of the terms “up,” “upper,” “upward,” “uphole,” “upstream,” or other like terms shall be construed as generally away from the bottom, terminal end of a well, regardless of the wellbore orientation; likewise, use of the terms “down,” “lower,” “downward,” “downhole,” “downstream,” or other like terms shall be construed as generally toward the bottom, terminal end of a well, regardless of the wellbore orientation. Use of any one or more of the foregoing terms shall not be construed as denoting positions along a perfectly vertical or horizontal axis. Unless otherwise specified, use of the term “subterranean formation” shall be construed as encompassing both areas below exposed earth and areas below earth covered by water, such as ocean or fresh water.

[0013] Various values and / or ranges may be explicitly disclosed in certain embodiments herein. However, values / ranges from any lower limit may be combined with any upper limit to recite a range not explicitly recited. Similarly, values / ranges from any lower limit may be combined with any other lower limit to recite a range not explicitly recited. In the same way, values / ranges from any upper limit may be combined with any other upper limit to recite a range not explicitly recited. Additionally, whenever a numerical range with a lower limit and an upper limit is disclosed, any number and any included range falling within the range are specifically disclosed. In particular, every range of values (of the form, “from about a to about b,” or, equivalently, “from approximately a to b,” or, equivalently, “from approximately a-b”) disclosed herein is to be understood to set forth every number and range encompassed within the broader range of values even if not explicitly recited. Thus, every point or individual value may serve as its own lower or upper limit combined with any other point or individual value or any other lower or upper limit, to recite a range not explicitly recited. Similarly, an individual value disclosed herein may be combined with another individual value or range disclosed herein to form another range.

[0014] The present disclosure is based, at least in pail, on the acknowledgement that in order for a coiled tubing string to spool on and off of the coiled tubing reel, the coiled tubing reel must maintain coiled tubing tension on the coiled tubing string. This coiled tubing tension results in a horizontal coiled tubing tension force component (e.g., side pull) on the coiled tubing injector system and / or wellbore components associated therewith. In traditional onshore applications, this horizontal coiled tubing tension component may be counteracted with tie down cables affixed between the coiled tubing injector system and anchors on the ground. In this example,the tie down cables are a constant length, thus the coiled tubing injector system must remain in a stable position relative to the surroundings.

[0015] The present disclosure, for the first time, has recognized that in offshore applications, especially if a lift frame with motion compensation is being used, the coiled tubing injector system does not maintain a stable position relative to the rig platform and / or rig derrick. Instead, the coiled tubing injector system has vertical movement relative to the rig platform and / or rig derrick. The present disclosure has recognized that without a support system to counteract the horizontal coiled tubing tension force component created by the coiled tubing reel tension force, stresses in certain components associated with the coiled tubing injector (e.g., components located below the coiled tubing injector) could reach unacceptable levels, for example resulting in either deformation and / or failure. Accordingly, the present disclosure has recognized that a system is needed that will couple proximate the coiled tubing injector frame (e.g., couple to the coiled tubing injector frame or couple to the coiled tubing guide arch), and provide a counter force (e.g., a known constant force) on the coiled tubing injector system to counteract the horizontal coiled tubing tension force component created by the coiled tubing reel tension force.

[0016] In at least one embodiment, for example to address the above recognitions, the present disclosure has developed a coiled tubing injector system that employs a trolley track or trolley coupled proximate the coiled tubing frame, as well as an other of the trolley or trolley track slidingly engaged with the trolley track or trolley, for example to counteract the horizontal coiled tubing tension force component created by the coiled tubing reel. In at least one embodiment, the trolley is substantially fixed in position using one or more tension lines, each having a horizontal trolley tension force component, coupled between the trolley and the rig platform (e.g., floating rig platform, floating rig derrick, etc.). In this embodiment, the trolley track is configured to slidingly engage with the trolley to counteract the reel tension force associated with the coiled tubing string as the coiled tubing frame moves up and down. In yet another embodiment, however, the trolley track is substantially fixed in position using one or more tension lines, and trolley is configured to slidingly engage with the trolley track to counteract the reel tension force associated with the coiled tubing string as the coiled tubing frame moves up and down.

[0017] The present disclosure, in one or more embodiments, envisions one or more tension line tensioners positioned inline with the one or more tension lines between the trolley and the rigplatform. In at least one embodiment, on an opposite end of the one or more tension line tensioners will be an adjustable cable or chain that will allow the user to tension or preload the tensioner in the anchoring system.

[0018] Turning to FIG. 1, illustrated is a well system 100 designed, manufactured and / or operated according to one or more embodiments of the disclosure. FIG. 1 illustrates an elevation view in partial cross-section of well system 100 utilized to produce hydrocarbons from wellbore 112 extending through various earth strata in a subterranean formation 114 located below the earth's surface 116. The wellbore 112 may be formed of a single or multiple bores 112a, 112b, . . . 112n, extending into the subterranean formation 114, and disposed in any orientation, such as the horizontal wellbore 112b illustrated in FIG. 1.

[0019] The well system 100 generally utilizes a coiled tubing string 118 to conduct various drilling and production operations. The coiled tubing string 118 includes a distal end 118a and includes an inner annulus or flowbore 119. The coiled tubing string 118 is stored on a coiled tubing reel 120 (e.g., the coiled tubing string 118 wound thereabout) positioned adjacent a wellhead 121. A coiled tubing guide arch 122 guides the coiled tubing string 118 into a coiled tubing injector system 124 designed, manufactured and / or operated according to one embodiment of the disclosure. The coiled tubing injector system 124, in the illustrated embodiment, is positioned above the rig platform 144 (e.g., supported by a rig derrick 125 or crane) and above the wellhead 121, and is used to feed and direct the coiled tubing string 118 into and out of the wellbore 112.

[0020] In one or more embodiments, the coiled tubing injector system 124 is hoisted above the rig platform 144 using a rig derrick 125, and as discussed in greater detail below, a trolley is substantially fixed in position using a tension line affixed between the trolley and the rig derrick 125 positioned on the rig platform 144. In this embodiment, a coiled tubing frame of the coiled tubing injector system 124 is configured to move up and down within the rig derrick 125. As used herein the term “coiled tubing string” will include any continuous or endless pipe string that may be wound on a spool or otherwise deployed rapidly including continuous metal tubulars such as low-alloy carbon-steel tubulars, composite coiled tubulars, capillary tubulars and the like.

[0021] In the illustrated embodiment, the coiled tubing string 118 extends through a blowout preventer (BOP) stack 126 connected to wellhead 121 for pressure control of the wellbore 112.Positioned atop the blowout preventer (BOP) stack 126 is a lubricator mechanism or stripper 127, which provides the primary operational seal about the outer diameter of the coiled tubing string 118 for the retention of any pressure that may be present at or near the surface of the wellbore 112. Although an offshore coiled tubing system is depicted in FIG. 1, the coiled tubing string 118 can be deployed onshore just the same.

[0022] For offshore operations, as shown in FIG. 1, the well system 100 may be mounted on a rig platform 144, such as the offshore platform as illustrated, semi-submersibles, drill ships, and the like (not shown). For offshore operations, one or more subsea conduits or risers 146 extend from deck 150 of rig platform 144 to the wellhead 121. In the illustrated embodiment, the coiled tubing string 118 extends down from the rig platform 144, through the subsea conduits or risers 146 and blowout preventer (BOP) stack 126 into the wellbore 112.

[0023] A fluid source 148 (e.g., working or service fluid source), such as a storage tank or vessel, may supply a working fluid 151 to the coiled tubing string 118. In particular, the fluid source 148 is in fluid communication with a fluid swivel 152 secured to the coiled tubing reel 120 and in fluid communication with the interior of coiled tubing string 118. Fluid source 148 may supply any fluid utilized in coiled tubing operations, including without limitation, drilling fluid, cementitious slurry, acidizing fluid, liquid water, steam or some other type of fluid. Various examples of fluids that may be provided by fluid source 148 and employed in the drilling and production operation described herein include air, water, oil, lubricant, friction reducer, natural gas, mist, foam, surfactant, nitrogen, various gases, drilling mud, acid, etc., or any combination thereof, which are flowed through the coiled tubing string 118 during a downhole operation. Moreover, the fluid source 148 may be disposed to provide the working fluid at a select pressure, such as high pressure pumping operation, or may be utilized to adjust the pressure of the pumped fluid. The fluid source 148 may likewise be in communication with other surface equipment 149, such as mixers, blenders and the like, utilized to prepare fluids for pumping downhole via the fluid source 148. In one or more embodiments, the fluid source 148 and / or surface equipment 149 may be adjustable in real time responsive to communications during various coiled tubing operations from the wellbore 112.

[0024] The well system may also include a power supply 154 and a communications hub 156 for sending signals and / or power and otherwise controlling the coiled tubing operations via electric and / or optic cable deployed within coiled tubing string 118.

[0025] The well system 100 may generally be characterized as having a pipe system 158. For purposes of this disclosure, the pipe system 158 may include casing, risers, tubing, drill strings, completion or production strings, subs, heads or any other pipes, tubes or equipment that couples or attaches to the foregoing, such as the coiled tubing string 118, subsea conduits or risers 146, collars, and joints, as well as the wellbore 112 and laterals in which the pipes, casing and strings may be deployed. In this regard, the pipe system 158 may include one or more casing strings 160 that may be cemented in the wellbore 112, such as the surface, intermediate and production casing strings 160 shown in FIG. 1. An annulus 162 is formed between the walls of sets of adjacent tubular components, such as casing strings 160 (e.g., concentric casing strings) or the exterior of the coiled tubing string 118 and the inside wall of wellbore 112 or casing strings 160, as the case may be.

[0026] A bottom hole assembly (BHA) 172 having one or more cable connectors or terminals (not shown) is attached to the distal end 118a of the coiled tubing string 118. The well system 100 is employed to pass a fluid down the flowbore 119 of the coiled tubing string 118 to the BHA 172. The return fluid will then pass up the annulus 162 formed between coiled tubing string 118 and casing strings 160 (or inside wall if uncased). Fluids, cuttings and other debris returning to the earth’s surface 116 from the wellbore 112 are directed by a flow line 174 to storage tanks 176 (or fluid source 148) and / or processing systems 178, such as shakers, centrifuges and the like.

[0027] The BHA 172 generally includes at least one analytic tool 180 and at least one intervention tool 182. In one or more embodiments, the analytic tool 180 is positioned between the connector head and the intervention tool 182. It will be appreciated that in many cases, because of the nature of the tool function (such as milling or drilling), the intervention tool 182 must be positioned at the distal end 172a of the BHA 172. As used herein, analytic tool 180 refers to any type of sensor, observation or measurement device that can be utilized to monitor a condition of the wellbore 112, wellbore fluid or surrounding subterranean formation 114. Nonlimiting examples of analytic tools 180 include casing collar locators, cement bond tools, cement bond tools, sonic and ultrasonic tools, accelerometers, resistivity tools, nuclear tools, gamma ray tools, flow meters, calipers, cameras, integrated computational elements, fiber optic sensors (such as distributed acoustic sensors), and the like. As used herein, intervention tool 182 refers to any type of tool that modifies the wellbore or materials within it. Non-limiting examples ofintervention tools include drill bit, a milling bit, a cleaning tool, a stimulation tool, a fishing tool, a recovery tool, perforating tool, jetting tool, pipe cutters, settable plugs and packers, downhole valves, and the like.

[0028] Turning to FIG. 2, illustrated is an enlarged view of a portion of the well system 100 of FIG. 1. For example, FIG. 2 illustrates a more detailed view of the coiled tubing injector system 124, as well as the coiled tubing string 118 being conveyed from the coiled tubing reel 120 over the coiled tubing guide arch 122 and into an inside of the coiled tubing injector system 124.

[0029] Turning to FIG. 3, with brief references to FIG. 4, illustrated is an enlarged view of a portion of the well system 100 of FIG. 2, and particularly an enlarged view of the coiled tubing injector system 124 of FIG. 2. As shown in FIG. 3, the coiled tubing injector system 124 includes a coiled tubing frame 310 having a first side 315a, and a second opposing side 315b. In the illustrated embodiment, the coiled tubing frame 310 additionally includes a third side 315c (e.g., out of the page) that is transverse to the first and second sides 315a, 315b, as well as a fourth opposing side (e.g., into the page and not shown) opposing the third side 315c. In the illustrated embodiment, the coiled tubing frame 310 additionally includes a height (h).

[0030] In at least one embodiment, such as that shown in FIG. 3, the coiled tubing injector system 124 additionally includes a coiled tubing injector 320 positioned at least partially within the coiled tubing frame 310. As discussed above, in one or more embodiments, the coiled tubing injector 320 is configured to assist in a placement of the coiled tubing string 118 within a wellbore. The coiled tubing injector 320 may comprise any currently known or hereafter discovered coiled tubing injector 320 and remain within the scope of the present disclosure.

[0031] In one or more embodiments, the coiled tubing injector system 124 additionally includes the coiled tubing guide arch 122 aligned with the coiled tubing injector 320 and extending away from the first side 315a of the coiled tubing frame 310. Accordingly, in one or more embodiments, the coiled tubing guide arch 122 is configured to guide the coiled tubing string 118 into the coiled tubing injector 320. The coiled tubing guide arch 122 may comprise any currently known or hereafter discovered coiled tubing guide arch 122 and remain within the scope of the disclosure. For example, in at least one embodiment, such as that shown, the coiled tubing guide arch 122 is coupled to the coiled tubing frame 310 (e.g., coupled directly to the coiled tubing frame 310). In yet another embodiment, however, the coiled tubing guide arch 122 is coupled to the coiled tubing injector 320 (e.g., coupled directly to the coiled tubing injector320), among other locations. Accordingly, the present disclosure should not he limited to any particular positioning and / or coupling of the coiled tubing guide arch 122.

[0032] In one or more embodiments, the coiled tubing injector system 124 additionally includes a trolley track 340 coupled proximate the second opposing side 315b of the coiled tubing frame 310. The term “proximate,” as used with regard to a position of the trolley track 340 (e.g., or trolley 350), means that the trolley track 340 is coupled more near the second opposing side 315b of the coiled tubing frame 310 than the first side 315a. In at least one embodiment, such as that shown, the trolley track 340 is coupled (e.g., directly coupled) to the first opposing side 315b of the coiled tubing frame 310. In yet another embodiment, the trolley track 340 is coupled (e.g., directly coupled) to the coiled tubing guide arch 122.

[0033] In the illustrated embodiment of FIG. 3, the trolley track 340 has a length (1), the trolley track 340 configured to slidingly engage with a trolley 350 (e.g., a substantially fixed position trolley) to counteract reel tension force associated with the coiled tubing string 118. In at least one embodiment, the length (1) of the trolley track 340 is at least 25 percent of the height (h) of the coiled tubing frame 310. In at least one other embodiment, the length (1) of the trolley track 340 is at least 50 percent of the height (h) of the coiled tubing frame 310. In even yet another embodiment, the length (1) of the trolley track 340 is at least 75 percent of the height (h) of the coiled tubing frame 310, if not 100 percent or more of the height (h) of the coiled tubing frame 310. Notwithstanding, in at least one embodiment, the length (1) of the trolley track 340 is at least as long as the coiled tubing frame 310 would need to move up and down during its operation.

[0034] In the illustrated embodiment of FIG. 3, the trolley track 340 is a substantially straight vertical trolley track. The term “substantially straight,” as used herein with regard to the trolley track 340, means that no portion of the trolley track 340 deviated more than 20 degrees from an axial centerline of the trolley track 340. In yet another embodiment, the trolley track 340 is an ideally straight vertical trolley track. The term “ideally straight,” as used herein with regard to the trolley track 340, means that no portion of the trolley track 340 deviated more than 10 degrees from an axial centerline of the trolley track 340. In even yet another embodiment, the trolley track 340 is a perfectly straight vertical trolley track. The term “perfectly straight,” as used herein with regard to the trolley track 340, means that no portion of the trolley track 340 deviated more than 5 degrees from an axial centerline of the trolley track 340. While theembodiment of FIG. 3 illustrates that the trolley track 340 is substantially straight, other embodiments may exist wherein the trolley track 340 is not substantially straight. For example, as discussed below, the trolley track 340 may be a curved trolley track and remain within the scope of the disclosure.

[0035] In one or more embodiments, the coiled tubing injector system 124 additionally includes the trolley 350 coupled to the trolley track 340. In one or more embodiments, the trolley track 340 is configured to slidingly engage with the trolley 350 to counteract the reel tension force associated with the coiled tubing string 118 as the coiled tubing frame 310 moves up and down.

[0036] The trolley 350 may comprise a variety of different trolleys and remain within the scope of the disclosure. In at least one embodiment, such as that shown in FIG. 4, the trolley 350 includes one or more anti-friction devices 360, the one or more anti-friction devices 360 configured to allow the trolley track 340 to easily slide relative to the trolley 350. In the embodiment of FIG. 4, the one or more anti-friction devices 360 are one or more trolley wheels 365, and thus the trolley is a rolling trolley. In yet another embodiment, however, the one or more anti-friction devices 360 are one or more low friction slide inserts, as might be comprised of a low friction material, or another anti-friction device known to one skilled in the art that would allow the trolley track 340 to easily slide along the trolley 350, and thus the trolley is a sliding trolley.

[0037] In the illustrated embodiment of FIGs. 3 and 4, the coiled tubing string 118 includes a reel tension force 370, for example as might be applied via the coiled tubing reel 120. As shown, in one or more embodiments, the reel tension force 370 includes a horizontal reel tension force component 370a and a vertical reel tension force component 370b. The values for each of the horizontal reel tension force component 370a and the vertical reel tension force component 370b will vary based upon the reel tension force 370, as well as the angle that the coiled tubing string 118 enters the coiled tubing guide arch 122.

[0038] As further illustrated in FIGs. 3 and 4, the coiled tubing injector system 124 additionally includes a tension line 380 positioned between the trolley 350 and a fixed device, such as for example the rig platform 144. Accordingly, the tension line 380 is physically coupled to the fixed device (e.g., by way of one or more types of anchors 382) and holds the trolley 350 in a substantially fixed position, such that the trolley track 340 and associated coiled tubing frame 310 may slide up and down along the trolley 350. The term “substantially fixed position,” asused herein with regard to the tension line 380, means that the trolley 350 is fixed such that it may move in a horizontal direction or vertical direction a distance no more than a largest dimension of the trolley 350. In yet another embodiment, the tension line 380 holds the trolley 350 in an ideally fixed position. The term “ideally fixed position,” as used herein with regard to the tension line 380, means that the trolley 350 is fixed such that it may move in a horizontal direction or vertical direction a distance no more than 50 percent of the largest dimension of the trolley 350. In yet another embodiment, the tension line 380 holds the trolley 350 in a perfectly fixed position. The term “perfectly fixed position,” as used herein with regal'd to the tension line 380, means that the trolley 350 is fixed such that it may move in a horizontal direction or vertical direction a distance no more than 5 percent of the largest dimension of the trolley 350.

[0039] As shown, the tension line 380 thus creates a trolley tension force 385 configured to counteract the reel tension force 370. In one or more embodiments, the trolley tension force 385 should include a horizontal trolley tension force component 385a sufficient to counteract the horizontal reel tension force component 370a of the reel tension force 370. In the embodiment of FIGs. 3 and 4, a single tension line 380 is coupled between the trolley 350 and the rig platform 144 (e.g., the rig derrick 125 in the embodiment shown) using the anchor 382. In this one embodiment, the single tension line 380 is horizontally positioned, and thus only includes the horizontal trolley tension force component 385a. While a single tension line 380 is employed in the embodiment of FIGs. 3 and 4, as discussed below, other embodiments may exist wherein two or more tension lines (e.g., two or more angled tension lines) are employed.

[0040] In at least one embodiment, such as that shown, a tension line tensioner 390 may be positioned inline with the tension line 380 between the trolley 350 and the rig platform 144. The tension line tensioner 390, in this embodiment, is configured to set the appropriate trolley tension force 385 (e.g., horizontal trolley tension force component 385a) sufficient to counteract the reel tension force 370 (e.g., horizontal reel tension force component 370a). In at least one embodiment, the tension line tensioner 390 is a mechanical tensioner. In at least one other embodiment, the tension line tensioner 390 is a spring member, a hydraulic cylinder member, a pneumatic cylinder member, or a live tensioner circuit, among any other tensioner known or hereafter discovered. Unless otherwise required, the present disclosure should not be limited to an specific mechanism for setting the trolley tension force 385.

[0041] The well system 100 of FIGs. 1 through 4, in one or more embodiments, may be configured such that the trolley track 340, trolley 350, and one or more tension lines 380 arc employed to create the trolley tension force 385 sufficient to counteract the reel tension force 370. In one embodiment, this includes one or more of the following steps: 1) assembling the coiled tubing injector system 124, the coiled tubing injector system 124 including the coiled tubing frame 310, the coiled tubing injector 320, the coiled tubing guide arch 122, trolley track 340 and trolley 350; 2) determining the high and low points for the coiled tubing injector system 124 relative to the rig platform 144 (e.g., this will be help determine the midpoint for travel of the coiled tubing injector system 124); 3) coupling the tension line 380 and optional tension line tensioner 390 to the trolley 350 (e.g., this may include one or more constant length cables, one or more adjustable length cables, etc.); 4) fixing an opposing end of the tension line 380 to the rig platform using the anchor 382; 5) positioning the trolley 350 at the midpoint, and then tighten the tension line 380, for example using the tension line tensioner 390 (e.g., if a single tension line 380 is employed this is simple, but if multiple tension lines 380 are employed this would include evenly tightening the tension line tensioners 390 associated with each of the tension lines 380 to apply a desired trolley tension force 385); 6) verifying that the trolley 350 is in the correct location.

[0042] By way of example and in regard to step 5), if the user is using a spring tension line tensioner, and the user wants to apply a given tension force (K), the user can calculate the number of millimeters (N) that the spring must be stretched to achieve the given tension force (K) based upon the spring constant and geometry of the spring tension line tensioner. Accordingly, the user then could adjust the one or more adjusters in the tension lines 380 until the spring tension line tensioner is (N) millimeters long.

[0043] Turning to FIG. 5 and FIG. 6, illustrated are different enlarged views of an alternative embodiment of a well system 500 designed, manufactured and / or operated according to one or more alternative embodiments of the disclosure. The well system 500 is similar in many respects to the well system 100 of FIGs. 1 through 4. Accordingly, like reference numbers are used to indicate similar, if not identical, features. The well system 500 differs, for the most part from the well system 100, in that the well system 500 employs a coiled tubing injector system 524 employing a curved vertical trolley track 540. In the illustrated embodiment, the curved verticaltrolley track 540 has an apex 542 that extends away from the second opposing side 315b of the coiled tubing frame 310.

[0044] Turning to FIG. 7 and FIG. 8, illustrated are different enlarged views of an alternative embodiment of a well system 700 designed, manufactured and / or operated according to one or more alternative embodiments of the disclosure. The well system 700 is similar in many respects to the well system 100 of FIGs. 1 through 4. Accordingly, like reference numbers are used to indicate similar, if not identical, features. The well system 700 differs, for the most part from the well system 100, in that the well system 700 and coiled tubing injector system 724 employ first and second tension lines 780a, 780b coupling the trolley 750 to the rig platform 144 via first and second anchors 782a, 782b and first and second tension line tensioners 790a, 790b. In the illustrated embodiment of FIGs. 7 and 8, the first and second tension lines 780a, 780b are first and second angled tension lines (e.g., first and second oppositely angled tension lines), for example having a first trolley tension force 785 (e.g., with a first trolley horizontal tension force component 785a and a first trolley vertical tension force component 785b) and a second trolley tension force 787 (e.g., with a second trolley horizontal tension force component 787a and a second trolley vertical tension force component 787b).

[0045] The well system 700 further differs from the well system 100 in that the trolley 750 employs one or more anti-friction devices 760, the one or more anti-friction devices 760 configured to allow the trolley track 340 to easily slide relative to the trolley 750. The one or more anti-friction devices 760, in the illustrated embodiment of FIGs. 7 and 8, are one or more low friction slide inserts 765 (e.g., as opposed to the one or more trolley wheels 365 of FIGs. 1 through 4).

[0046] Turning to FIG. 9 and FIG. 10, illustrated are different enlarged views of an alternative embodiment of a well system 900 designed, manufactured and / or operated according to one or more alternative embodiments of the disclosure. The well system 900 is similar in many respects to the well system 700 of FIGs. 7 and 8. Accordingly, like reference numbers are used to indicate similar, if not identical, features. The well system 900 differs, for the most part from the well system 700, in that the well system 900 and coiled tubing injector system 924 employ one or more first cable pullies 910a coupled with the first angled tension line 780a and one or more second cable pullies 910b coupled with the second angled tension line 780b. The one or more first cable pullies 910a and one or more second cable pullies 910b may be positioned at anylocation along the first angled tension line 780a and second angled tension line 780b, respectively, so as to redirect them based upon an intervening feature. Accordingly, the first and second angled tension lines 780a, 780b, may consist of one or more angled portions and / or one or more straight (e.g., vertical or horizontal) portions and remain within the scope of the disclosure. In the embodiment of FIGs. 9 and 10, however, each of the first and second angled tension lines 780a, 780b include two different angled portions.

[0047] Turning to FIG. 11 and FIG. 12, illustrated are different enlarged views of an alternative embodiment of a well system 1100 designed, manufactured and / or operated according to one or more alternative embodiments of the disclosure. The well system 1100 is similar in many respects to the well system 100 of FIGs. 1 through 4. Accordingly, like reference numbers are used to indicate similar, if not identical, features. The well system 1100 differs, for the most part from the well system 100, in that the well system 1100 rigidly fixes the coiled tubing frame 310 of the coiled tubing injector system 1124 to the lift frame legs 1145 about the third side 315c and the fourth side (not shown) of the coiled tubing frame 310. Accordingly, the coiled tubing frame 310 and the lift frame legs 1145 move up and down in unison. In contrast, the lift frame legs 1145 are fixed to the rig derrick 125 in a way so as to counteract reel tension force associated with the coiled tubing string 118 as the coiled tubing frame 310 and the lift frame legs moves up and down. Essentially, the larger lift frame legs 1145 prevent the coiled tubing frame 310 from rotating (e.g., about a rotation point created by the coiled tubing guide arch 122 and the coiled tubing 118) to counteract the reel tension force.

[0048] Aspects disclosed herein include:A. A coiled tubing injector system, the coiled tubing injector system including: 1) a coiled tubing frame having a first side, a second opposing side and a height (h); 2) a coiled tubing injector positioned at least partially within the coiled tubing frame, the coiled tubing injector configured to assist in a placement of a coiled tubing string within a wellbore; 3) a coiled tubing guide arch aligned with the coiled tubing injector and extending away from the first side of the coiled tubing frame, the coiled tubing guide arch configured to guide the coiled tubing string into the coiled tubing injector; and 4) a trolley track or a trolley coupled proximate the second opposing side of the coiled tubing frame and having a length (1), the trolley track or trolley configured to slidingly engage with a substantially fixed position of an other of the trolley or trolley track to counteract reel tension force associated with the coiled tubing string.B. A well system, the well system including: 1) a rig platform; 2) a coiled tubing reel having a coiled tubing string wound thereabout coupled to the rig platform; and 3) a coiled tubing injector system coupled to the rig platform, the coiled tubing injector system including: ) a coiled tubing frame having a first side, a second opposing side and a height (h); b) a coiled tubing injector positioned at least partially within the coiled tubing frame, the coiled tubing injector configured to assist in a placement of the coiled tubing string within a wellbore; c) a coiled tubing guide arch aligned with the coiled tubing injector and extending away from the first side of the coiled tubing frame toward the coiled tubing reel, the coiled tubing guide arch configured to guide the coiled tubing string into the coiled tubing injector; and d) a trolley track having a length (1), the trolley track coupled to a trolley, wherein one of the trolley track or the trolley is coupled proximate the second opposing side of the coiled tubing frame, and the other of the trolley or trolley track is substantially fixed in position using a tension line having a horizontal trolley tension force component affixed between the other of the trolley or trolley track, the trolley track and the trolley configured to slidingly engage one another to counteract reel tension force associated with the coiled tubing string as the coiled tubing frame moves up and down.

[0049] Aspects A and B may have one or more of the following additional elements in combination: Element 1: wherein the trolley track is coupled proximate the second opposing side of the coiled tubing frame and further wherein the trolley track is configured to slidingly engage with a substantially fixed position trolley. Element 2: wherein the trolley track is a substantially straight vertical trolley track. Element 3: wherein the trolley track is a curved vertical trolley track, the curved vertical trolley track having an apex extending away from the second opposing side of the coiled tubing frame. Element 4: wherein the length (1) of the trolley track is at least 25 percent of the height (h) of the coiled tubing frame. Element 5: wherein the length (1) of the trolley track is at least 50 percent of the height (h) of the coiled tubing frame. Element 6: wherein the length (1) of the trolley track is at least 75 percent of the height (h) of the coiled tubing frame. Element 7: further including a trolley coupled to the trolley track, wherein the trolley track is configured to slidingly engage with the trolley to counteract the reel tension force associated with the coiled tubing string as the coiled tubing frame moves up and down. Element 8: wherein the trolley includes one or more anti-friction devices, the one or more anti-friction devices configured to allow the trolley track to easily slide relative to the trolley. Element 9:wherein one or more anti-friction devices are one or more trolley wheels. Element 10: wherein one or more anti-friction devices arc one or more low friction slide inserts. Element 11: wherein the trolley track is coupled proximate the second opposing side of the coiled tubing frame and further wherein the trolley track is configured to slidingly engage with a substantially fixed position trolley. Element 12: wherein the coiled tubing injector system is hoisted above the rig platform using a rig derrick, and further wherein the trolley is substantially fixed in position using a tension line affixed between the trolley and the rig derrick positioned on the rig platform, and further wherein the coiled tubing frame is configured to move up and down within the rig derrick. Element 13: further including a tension line tensioner positioned inline with the tension line between the trolley and the rig platform. Element 14: wherein the tension line tensioner is a mechanical tensioner. Element 15: wherein the tension line tensioner is a spring member, a hydraulic cylinder member, a pneumatic cylinder member, or a live tensioner circuit. Element 16: wherein the tension line is a first angled tension line having a first horizontal trolley tension force component affixed between the trolley and the rig platform, and further including a second oppositely angled tension line having a second horizontal trolley tension force component affixed between the trolley and the rig platform. Element 17: further including one or more first cable pullies coupled with the first angled tension line and one or more second cable pullies coupled with the second oppositely angled tension line. Element 18: wherein the trolley track is a substantially straight vertical trolley track. Element 19: wherein the trolley track is a curved vertical trolley track, the curved vertical trolley track having an apex extending away from the second opposing side of the coiled tubing frame. Element 20: wherein the trolley includes one or more anti-friction devices, the one or more anti-friction devices configured to allow the trolley track to easily slide relative to the trolley. Element 21: wherein the trolley track is coupled to the coiled tubing frame. Element 22: wherein the trolley track is coupled to the coiled tubing guide arch. Element 23: further including a wellbore extending through a subterranean formation located below the coiled tubing injector system, and further wherein the coiled tubing string extends from the coiled tubing reel, over the coiled tubing guide arch, into the coiled tubing injector, and into the wellbore.

[0050] Those skilled in the art to which this application relates will appreciate that other and further additions, deletions, substitutions and modifications may be made to the described embodiments.

Claims

WHAT IS CLAIMED IS:

1. A coiled tubing injector system, comprising:a coiled tubing frame having a first side, a second opposing side and a height (h);a coiled tubing injector positioned at least partially within the coiled tubing frame, the coiled tubing injector configured to assist in a placement of a coiled tubing string within a wellbore;a coiled tubing guide arch aligned with the coiled tubing injector and extending away from the first side of the coiled tubing frame, the coiled tubing guide arch configured to guide the coiled tubing string into the coiled tubing injector; anda trolley track or a trolley coupled proximate the second opposing side of the coiled tubing frame and having a length (1), the trolley track or trolley configured to slidingly engage with a substantially fixed position of an other of the trolley or trolley track to counteract reel tension force associated with the coiled tubing string.

2. The coiled tubing injector system as recited in Claim 1, wherein the trolley track is coupled proximate the second opposing side of the coiled tubing frame and further wherein the trolley track is configured to slidingly engage with a substantially fixed position trolley.

3. The coiled tubing injector system as recited in Claim 2, wherein the trolley track is a substantially straight vertical trolley track.

4. The coiled tubing injector system as recited in Claim 2, wherein the trolley track is a curved vertical trolley track, the curved vertical trolley track having an apex extending away from the second opposing side of the coiled tubing frame.

5. The coiled tubing injector system as recited in Claim 2, wherein the length (1) of the trolley track is at least 25 percent of the height (h) of the coiled tubing frame.

6. The coiled tubing injector system as recited in Claim 2, wherein the length (1) of the trolley track is at least 50 percent of the height (h) of the coiled tubing frame.

7. The coiled tubing injector system as recited in Claim 2, wherein the length (1) of the trolley track is at least 75 percent of the height (h) of the coiled tubing frame.

8. The coiled tubing injector system as recited in Claim 2, further including a trolley coupled to the trolley track, wherein the trolley track is configured to slidingly engage with the trolley to counteract the reel tension force associated with the coiled tubing string as the coiled tubing frame moves up and down.

9. The coiled tubing injector system as recited in Claim 8, wherein the trolley includes one or more anti-friction devices, the one or more anti-friction devices configured to allow the trolley track to easily slide relative to the trolley.

10. The coiled tubing injector system as recited in Claim 9, wherein one or more antifriction devices are one or more trolley wheels.

11. The coiled tubing injector system as recited in Claim 9, wherein one or more antifriction devices are one or more low friction slide inserts.

12. A well system, comprising:a rig platform;a coiled tubing reel having a coiled tubing string wound thereabout coupled to the rig platform; anda coiled tubing injector system coupled to the rig platform, the coiled tubing injector system including:a coiled tubing frame having a first side, a second opposing side and a height (h); a coiled tubing injector positioned at least partially within the coiled tubing frame, the coiled tubing injector configured to assist in a placement of the coiled tubing string within a wellbore;a coiled tubing guide arch aligned with the coiled tubing injector and extending away from the first side of the coiled tubing frame toward the coiled tubing reel, thecoiled tubing guide arch configured to guide the coiled tubing string into the coiled tubing injector; anda trolley track having a length (1), the trolley track coupled to a trolley, wherein one of the trolley track or the trolley is coupled proximate the second opposing side of the coiled tubing frame, and the other of the trolley or trolley track is substantially fixed in position using a tension line having a horizontal trolley tension force component affixed between the other of the trolley or trolley track, the trolley track and the trolley configured to slidingly engage one another to counteract reel tension force associated with the coiled tubing string as the coiled tubing frame moves up and down.

13. The well system as recited in Claim 12, wherein the trolley track is coupled proximate the second opposing side of the coiled tubing frame and further wherein the trolley track is configured to slidingly engage with a substantially fixed position trolley.

14. The well system as recited in Claim 13, wherein the coiled tubing injector system is hoisted above the rig platform using a rig derrick, and further wherein the trolley is substantially fixed in position using a tension line affixed between the trolley and the rig derrick positioned on the rig platform, and further wherein the coiled tubing frame is configured to move up and down within the rig derrick.

15. The well system as recited in Claim 13, further including a tension line tensioner positioned inline with the tension line between the trolley and the rig platform.

16. The well system as recited in Claim 15, wherein the tension line tensioner is a mechanical tensioner.

17. The well system as recited in Claim 15, wherein the tension line tensioner is a spring member, a hydraulic cylinder member, a pneumatic cylinder member, or a live tensioner circuit.

18. The well system as recited in Claim 13, wherein the tension line is a first angled tension line having a first horizontal trolley tension force component affixed between the trolleyand the rig platform, and further including a second oppositely angled tension line having a second horizontal trolley tension force component affixed between the trolley and the rig platform.

19. The well system as recited in Claim 18, further including one or more first cable pullies coupled with the first angled tension line and one or more second cable pullies coupled with the second oppositely angled tension line.

20. The well system as recited in Claim 13, wherein the trolley track is a substantially straight vertical trolley track.

21. The well system as recited in Claim 13, wherein the trolley track is a curved vertical trolley track, the curved vertical trolley track having an apex extending away from the second opposing side of the coiled tubing frame.

22. The well system as recited in Claim 13, wherein the trolley includes one or more anti-friction devices, the one or more anti-friction devices configured to allow the trolley track to easily slide relative to the trolley.

23. The well system as recited in Claim 13, wherein the trolley track is coupled to the coiled tubing frame.

24. The well system as recited in Claim 13, wherein the trolley track is coupled to the coiled tubing guide arch.

25. The well system as recited in Claim 13, further including a wellbore extending through a subterranean formation located below the coiled tubing injector system, and further wherein the coiled tubing string extends from the coiled tubing reel, over the coiled tubing guide arch, into the coiled tubing injector, and into the wellbore.

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