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FIELD OF THE INVENTION 
       [0001]    The field of the disclosure is directed to coiled tubing drilling applications, and more specifically extending the reach of coiled tube piping in lateral sections of the wellbore. 
       BACKGROUND OF THE INVENTION 
       [0002]    Currently, the coiled tubing industry needs a technology that may enhance the reach of the tubing in the lateral section of the wellbore. The inability to rotate the tubing limits its reach in the lateral section of the wellbore. Past and current extended-reach techniques for coiled tubing have not been sufficient, individually, in increasing significantly the reach of the tubing in the wellbore. Often, four or five extended-reach methods are combined to have significant reach in the wellbore, which is quite expensive to do. 
         [0003]    Consequently, there is a need for a single inexpensive method to extend the reach of coiled tubing in lateral wellbores. With the drive of exploiting oil and gas resources from deep wells increasing today, the reach of coiled tubing in the wellbore needs to be increased to meet this growing demand. The application of this technique may enhance the use of coiled tubing in drilling very deep flowing wells. Similarly, the method may be applied for increasing the reach of the tubing for other coiled-tubing well intervention applications. 
       BRIEF SUMMARY OF SOME OF THE PREFERRED EMBODIMENTS 
       [0004]    These and other needs in the art are addressed in one embodiment by a method of drilling laterally with coiled tubing, wherein the method involves attaching a drill assembly to a coiled tubing, and attaching a second motor assembly to the drill assembly. The method also includes inserting the second motor assembly, the drill assembly, and the coiled tubing downhole, and attaching a first motor assembly to the coiled tubing. The method further includes inserting the first motor assembly downhole, rotating the coiled tubing with the first motor assembly, and rotating the drill assembly with the second motor assembly. 
         [0005]    Further embodiments are addressed by a dynamic torque arrestor comprising a casing, an adaptor, and connector, wherein the casing houses an inner casing, a spindle, a machined spring, an upper plate, and a lower plate. 
         [0006]    The foregoing has outlined rather broadly the features and technical advantages of the present disclosure so that the detailed description that follows may be better understood. Additional features and advantages of the disclosure will be described hereinafter that form the subject of the claims. It should be appreciated by those skilled in the art that the conception and the specific embodiments disclosed may be readily utilized as a basis for modifying or designing other embodiments for carrying out the same purposes of the present disclosure. It should also be realized by those skilled in the art that such equivalent embodiments do not depart from the spirit and scope of the disclosure as set forth in the appended claims. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0007]    For a detailed description of the preferred embodiments of the disclosure, reference will now be made to the accompanying drawings in which: 
           [0008]      FIG. 1  illustrates a cut away view of the coiled tubing downhole assembly; 
           [0009]      FIG. 2  illustrates an embodiment of a stabilizer; 
           [0010]      FIG. 3  illustrates an embodiment of a dynamic torque arrestor; 
           [0011]      FIG. 4  illustrates an embodiment of a drill assembly; 
           [0012]      FIG. 5  illustrates an embodiment of a second motor assembly with stabilizers; and 
           [0013]      FIG. 6  illustrates an embodiment of a downhole electric motor. 
       
    
    
     DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS 
       [0014]    Disclosed embodiments of a downhole assembly may extend the lateral reach of coiled tubing. Embodiments may include systems and methods of operation to extend the reach of coiled tubing laterally. These systems and methods may be used in drilling extended reach well and/or used for workovers in extended reach wells. 
         [0015]    In embodiments, as illustrated in  FIG. 1 , a downhole assembly  5  may comprise coiled tubing  10 , a first motor assembly  15 , a dynamic torque arrestor  20 , as stabilizer  25 , a second motor assembly  30 , and a drill assembly  35 . Downhole assembly  5  may be employed to extend the reach of coiled tubing  10  in downhole operations, more specifically lateral drilling operations. Coiled tubing  10  may comprise of a single tube that may be spun around as reel, not illustrated, and straightened before entering a well. During operations, a single coiled tube  10  may be used or a plurality of coiled tubing  10  may be used in conjunction with each other. Coiled tubing  10  may be any diameter suitable for drilling operations. A suitable diameter may be between about half an inch to about five inches, about an inch to about three inches, about two inches to about four inches, or about three inches to about five inches. To withstand a downhole environment, coiled tubing  10  may be any suitable material. Suitable material may be stainless steel, steel, carbon fiber, iron, black iron, or any combination thereof. As illustrated in  FIG. 1 , coiled tubing  10  may be disposed downhole and connect to stabilizer  25  and first motor assembly  15 . In embodiments, additional coiled tubing  10  may be used to connect first motor assembly  15  to second motor assembly  30  and drill assembly  35 . During operations, first motor assembly  15  and second motor assembly  30  may create rotational threes. Rotational forces created by fist motor assembly  15  may prevent coiled tubing  10  from rubbing against a rock formation. Additionally, preventing coiled tubing  10  from twisting and rotating into a rock formation, stabilizers  25  may be disposed along coiled tubing  10 , first motor assembly  15 , and/or second motor assembly  30 . 
         [0016]    Stabilizer  25  may prevent coiled tubing  10  from touching the subterranean formation downhole. Additionally, stabilizers  25  may also prevent twisting and rotation of downhole assembly  5 . In embodiments, as illustrated in  FIG. 2 , stabilizer  25  may comprise a base  28  and/or a blade  26 . Blade  26  may further comprise an elastomeric pads  27 . Stabilizer  25  may have any number of blades  26  with any number of elastomeric pads  27 . Elastomeric pads  27  may be disposed on the outside of blades  26 . Blades  26  and elastomeric pads  27  may press against a subterranean rock formation, preventing torque. Blades  26  may also push coiled tubing  10  away from the subterranean formation rocky surface downhole. In embodiments, there may be a plurality of stabilizers  25  used during downhole operations. Stabilizers  25  may be connected in series and/or be separated by additional downhole devices. In embodiments, the number of stabilizers  25 , and their spacing, may be based on the diameter of coiled tubing  10 . A smaller diameter may require larger amounts of stabilizers  25  that are spaced closer together. This may prevent coiled tubing  10  from contacting the rocky surface of a subterranean formation. A large diameter may require less stabilizers  25  that are spaced farther apart. Referring to  FIG. 5 , a stabilizer  25  may be positioned below a first motor assembly  15 , and a plurality of stabilizer  25  may be positioned above first motor assembly  15 . In an embodiment, not illustrated, there may be a plurality of stabilizers  25  below fist motor assembly  15  and a plurality of stabilizers  25  above first motor assembly  15 . Stabilizer  25  may connect directly or indirectly with first motor assembly  15 . First motor assembly  15  and stabilizer  25  may be connected by any suitable means. Suitable means may be, but are not limited to, a press fitting, nuts and bolts, threaded connector, or any combination thereof. 
         [0017]    As illustrated in  FIG. 2 , a plurality of stabilizers  25  may be connected by coiled pipe  10 . Coiled pipe  10  may rotate freely between stabilizers  25 . To prevent slipping and/or keep coiled pipe  10  centered downhole, stabilizer  25  may be made of any suitable material. Suitable material may be steel, stainless steel, black iron, plastic, or any combination thereof. In embodiments, base  28  may be any suitable length to prevent stabilizer  25  from slipping. A suitable length may be about one foot to about six feet, about two feet to about four feet, about three feet to about six feet, or about one foot to about three feet. Blades  26  may traverse base  28  any suitable length to prevent stabilizer  25  from slipping. In embodiments, stabilizers  25  may be disposed about second motor assembly  30  and drill assembly  35 . Additionally, stabilizers  25  may be disposed about other downhole devices. 
         [0018]    As illustrated in  FIG. 1 , stabilizers  25  may be disposed about and/or connect to a dynamic torque arrester  20 . In embodiments, there may be a plurality of dynamic torque arrestors  20  used in downhole operations. Dynamic torque arrestor  20  may connect directly or indirectly with first motor assembly  15  and/or second motor assembly  30  by any suitable means. Suitable means may be, but are not limited to, a press fitting, nuts and bolts, threaded connector, or any combination thereof. Dynamic torque arrestor  20  may prevent torque produced by first motor assembly  15  and/or second motor assembly  30  from twisting, moving, and/or breaking downhole assembly  5  within the wellbore. As illustrated in  FIG. 3 , dynamic torque arrestor  20  may comprise a casing  40 , an adapter  41 , a lower plate  42 , an elastomeric pad  43 , a machined spring  44 , an inner casing  45 , an axial roller bearing  46 , a thrust ball bearing  47 , a spindle  48 , a high viscous fluid  49 , an upper plate  50 , perforations  51 , and connector  60 . Casing  40  may act as an outer shell that protects internal parts from the downhole environment which may include, but is not limited to, mud, rock, water, and other subterranean elements. Casing  40  may comprise any suitable material. Suitable material may include, but is not limited to, carbon steel, stainless steel, plastic, or any combination thereof. Located at one end of dynamic torque arrestor  20 , adapter  41 , may attach coiled tubing  10 , first motor assembly  15 , second motor assembly  30 , and/or stabilizer  25  to dynamic torque arrestor  20 . Adapter  41  may attach to any downhole device by any suitable means. Suitable means may be, but are not limited to, a press fitting, nuts and bolts, threaded connector, and/or any combination thereof. In embodiments, adapter  41  may rotate about its axis which may help dissipate lateral movement that may be produced by first motor assembly  15  and/or second motor assembly  30 . 
         [0019]    Disposed inside casing  40 , above adapter  41 , is lower plate  42 . Lower plate  42  may act to hold machined spring  44  in place. There may be any number of lower plates  42  that may hold and guide machined spring  44 . Lower plate  42  may be secured to casing  40  by any suitable means which may include, but is not limited to, any form of welding, nuts and bolts, press fitting, and/or any combination thereof. 
         [0020]    Elastomeric pad  43  may be attached to lower plate  42  along the inner most edge adjacent to machined spring  44 . Elastomeric pad  43  may be attached by any suitable means which may include, but is not limited to adhesive, press fitting, screws, and/or any combination thereof. Elastomeric pad  43  may comprise any suitable material that may act as a buffer to prevent wear and tear between machined spring  44  and lower plate  42 . Suitable material may be, but is not limited to, any form of plastic, leather, neoprene, rubber, and/or any combination thereof. 
         [0021]    Machined spring  44  may be disposed upon adapter  41  and may be held in place by lower plate  42  and elastomeric pad  43 . Machined Spring  44  may comprise any suitable material. Suitable material may include, but is not limited to, carbon steel, stainless steel, plastic, or any combination thereof. Machined spring  44  may be of any resistance and length necessary to withstand torsional and axial loads that may be produced and transmitted through adapter  41  by first motor assembly  15  and/or second motor assembly  30 . Machined spring  44  may move vertically within casing  40  to help dissipate torsional and axial loads. Spindle  48  may be placed upon machine spring  44  to prevent machined spring  44  from moving the entire vertical length of casing  40 . 
         [0022]    Spindle  48  may be of any suitable length to prevent machine spring  44  from moving the entire vertical length of casing  40 . A suitable length may be about two inches to about twelve inches, about four inches to about ten inches, about six inches to about eight inches, or about six inches to about twelve inches. Spindle  48  may be of any suitable material which may be, but is not limited to, stainless steel, plastic, carbon steel, and/or any combination thereof. Spindle  48  may be of any suitable diameter to withstand forces placed upon it by machined spring  44 . A suitable diameter may be about half a centimeter to about ten centimeters, about two centimeter to about eight centimeters, about four centimeters to about six centimeters, or about five centimeters to about ten centimeters. Spindle  48  may rest upon machined spring  44  at one end and at the opposite end be disposed in inner casing  45 . 
         [0023]    Inner casing  45  may be of any suitable material which may be, but is not limited to, stainless steel, plastic, carbon steel, and/or any combination thereof. Inner casing  45  may comprise highly viscous fluid  49 , thrust ball bearing  47 , and axial roller bearing  46 . Inner casing  45  may have a flanged end in which to attach to upper plate  50 . Inner casing  45  may be attached to upper plate  50  by any suitable means which may use, but is not limited to, nuts and bolts, adhesives, any form of weld, press fitting, and/or any combination thereof. Opposite the flanged end of inner casing  45  may be a capped end with a point of entry  52  for spindle  48  to pass through. Within inner casing  45 , high viscous fluid  49  may comprise, but is not limited to, glycerine, heavy motor oils, axial grease, marine grease, magneto-rheological fluids, electro-rheological fluids, and/or any combination thereof. High viscous fluid  49  may provide resistance to prevent the rapid and/or upward movement of spindle  48 . Spindle  48  may move as machined spring  44  reacts to torsional and axial loads produced by adapter  41 . High viscous fluid  49  may further help dissipate torsional and axial loads experienced by spindle  48 , preventing torsional and axial loads from transferring to dynamic torque arrestor  20 . 
         [0024]    Point of entry  52  may be of any suitable diameter that may accommodate spindle  48 . A suitable diameter may be about half a centimeter to about ten centimeters, about two centimeter to about eight centimeters, about four centimeters to about six centimeters, or about five centimeters to about ten centimeters. Point of entry  52  may comprise any form of buffer material to prevent wear and tear on spindle  48 . Buffer material may be, but is not limited to, any form of plastic, leather, neoprene, rubber, and/or any combination thereof. Point of entry  52  may also guide spindle  48  and prevent any lateral movement. 
         [0025]    Axial roller bearing  46  may also guide spindle  48  and prevent any lateral movement. Axial roller bearing  46  may comprise any number of roller bearings within a housing. Roller bearings may be of any radius suitable to prevent lateral movement of spindle  48 . Roller bearings may be any suitable material which includes, but is not limited to, carbon steel, stainless steel, plastic, or any combination thereof. Any form of lubricant may be used to allow for roller bearings to move freely in axial roller bearing housing  60 . Lubricant may be, but is not limited to, axial grease or marine grease. Axial roller bearing  46  may attach within inner casing  45  above point of entry  52 . Axial roller bearing  46  may be attached by any suitable means which may include, but is not limited to, any form of welding, nuts and bolts, or press fitting. 
         [0026]    Thrust ball bearing  47  may also guide spindle  48  and prevent any lateral movement. Thrust ball bearing  47  may comprise any number of roller bearings within a housing. Thrust ball bearing  47  may be of any radius suitable to prevent lateral movement of spindle  48 . Thrust ball bearing  47  may be any suitable material which includes, but is not limited to, carbon steel, stainless steel, plastic, and/or any combination thereof. Any form of lubricant may be used to allow for thrust hall bearing  47  to move freely in axial roller bearing housing  60 . Lubricant may be, but is not limited to, axial grease, marine grease, and/or any combination thereof. Thrust ball bearing  47  may attach within inner casing  45  above point of entry  52  and axial roller bearing  46 . Thrust all bearing  46  may be attached by any suitable means which may include, but is not limited to, any form of welding, nuts and bolts, press fitting, and/or any combination thereof. 
         [0027]    Inner casing  45  may be separated into two distinct areas by separator  53 . Separator  53  may comprise any suitable material. Suitable material may include, but is not limited to, carbon steel, stainless steel, plastic, and/or any combination thereof. The lower separated area  65  may house thrust ball bearing  47  and axial roller bearing  46 . The upper separated area  70  may house highly viscous fluid  49 . Highly viscous fluid  49  may act to prevent the rapid lateral movement of spindle  48 . Spindle  48  enters the upper separated area  70  through a second point of entry  54 . 
         [0028]    Second point of entry  54  may be of any suitable diameter that may accommodate spindle  48 . A suitable diameter may be about half a centimeter to about ten centimeters, about two centimeter to about eight centimeters, about four centimeters to about six centimeters, or about five centimeters to about ten centimeters. Second point of entry  54  may comprise any form of buffer material to prevent wear and tear on spindle  48 . Buffer material may be, but is not limited to, any form of plastic, leather, neoprene, rubber, and/or any combination thereof. Buffer material may create an air tight seal to prevent highly viscous fluid  49  from moving into the lower separated area  65  which may house thrust ball bearing  47  and axial roller bearing  46 . Second point of entry  54  may also guide spindle  48  and prevent any lateral movement. 
         [0029]    As discussed above, upper plate  50  may be used for attaching inner casing  45  to dynamic torque arrestor  20 . Upper plate  50  may be located inside casing  40  at the opposite end of adapter  41 . Upper plate  42  may act to hold inner casing  45  in place. Upper plate  50  may comprise any suitable material. Suitable material may include, but is not limited to, carbon steel, stainless steel, plastic, and/or any combination thereof. Upper plate  50  may have perforations  51  which may allow for drilling mud to pass through. There may be a plurality of perforations  51 , which may be of any diameter suitable to allow for mud to flow freely through. A suitable diameter may be about half a centimeter to about ten centimeters, about two centimeter to about eight centimeters, about four centimeters to about six centimeters, or about five centimeters to about ten centimeters. 
         [0030]    Opposite adapter  41  is connector  60  which may be used to attach to dynamic torque arrestor  20 , coiled tubing  10 , first motor assembly  15 , second motor assembly  30 , and/or stabilizer  25 . Connector  60  may attach to any device by any suitable means. Suitable means may be, but are not limited to, press fitting, nuts and bolts, and/or threaded connector. Stabilizer  25  and/or dynamic torque arrestor  20  may be used prevent the rotational movement, produced by first motor assembly  15 , from moving up coiled tubing  10 . A first motor assembly  15  may comprise mud motor  200 , electric motor  100 , and/or turbine motors. As illustrated in  FIG. 6 , first motor assembly  15  may comprise electric motor  100  and/or a mud motor  200 . Electric motor  100  may be used in conjunction with mud motor  200  or as a standalone first motor assembly  15 . Electric motor  100  may comprise a rotor shaft  101 , bearings  102 , annulus gear  103 , and planet carrier  104 . Electric motor  100  may connect to coiled tubing  10 , stabilizers  25 , dynamic torque arrestors  20 , and/or mud motor  200  by any suitable means. First motor assembly  15  may be used to turn coiled tubing  10 , which may further be attached to a second motor assembly  30  and/or a drill assembly  35 . 
         [0031]    In embodiments, as illustrated in  FIG. 4 , drill assembly  35  may comprise a drill bit  36 , connector  37 , and/or directional drilling assembly  38 . In embodiments, drill assembly  35  may attach to a second motor assembly  30 . Drill assembly  35  may connect to second motor assembly  30  by any suitable means. Suitable means may be, but are not limited to, press fitting, nuts and bolts, threaded connector, and/or any combination thereof. Second motor assembly  30  may be used to help turn drill assembly  35 . In embodiments second motor assembly  30  may be an electric motor  100 , mud motor  200 , and/or a turbine motor. 
         [0032]    Drilling bit  36  may be of any type suitable to drill through a subterranean formation. Drill bit  36  may attached to connector  37  by any suitable means. Connector  37  is attached to directional drilling assembly  38 , opposite drill hit  36 , by any suitable means. Second motor assembly  30  may attach to directional drilling assembly  38 , opposite connector  37 , by any suitable means. Second motor assembly  30  may connect drilling assembly  35  to coiled tubing  10 . Second motor assembly  30  may connect to coiled tubing  10  by any suitable means. First motor assembly  15  may attach to coiled tubing  10  at any suitable length from second motor assembly  30 . As illustrated in  FIG. 5 , first motor assembly  15  may attach to coiled tubing  10  by any suitable means. Suitable means may be, but are not limited to, clamps, bolts, nuts and bolts, threads, and/or any combination thereof. In embodiments, first motor assembly  15  and second motor assembly  30  may be disposed between different sections of coiled tubing  10 . Second motor assembly  15  may be attached to as stabilizer  25  and/or dynamic torque arrestor  20  by any suitable means. There may be any number of stabilizers  25  and/or dynamic torque arrestors  20  attached to second motor assembly  15 . Depending on the specific application, there may only be a single or multiple stabilizer  25  with a single or multiple dynamic torque arrestor  20 . Stabilizers  25  and dynamic torque arrestors  20  may be attached below or above second first motor assembly  15 . Furthermore, both stabilizer  25  and dynamic torque arrestor  20  may be used together or in any order. 
         [0033]    During downhole operations, a method may be used to properly employ downhole assembly  5 . The method may comprise drilling vertically with coiled tubing  10  and drill assembly  35  to a designated depth. At the designated depth, drill assembly  35  may then be controlled to move laterally across a formation. After drilling laterally to the extent allowed by coiled tubing  10 , drill assembly  35  and coiled tubing  10  may be brought back to the surface. At the surface, coiled tubing  10  is altered to extend the lateral drilling reach of downhole assembly  5 . Coiled tubing  10  may be fitted with drill assembly  35 , a second motor assembly  30 , a first motor assembly  15 , dynamic torque arrestor  20 , and stabilizer  25 . Once fitted, downhole assembly  5  is placed downhole to where drilling operations stopped. 
         [0034]    During operations, first motor assembly  15  may rotate coiled tubing  10 , preventing coiled tubing  10  from dragging along the lower most horizontal surface of the lateral drilled hole  60  and downhole bend  70 , as illustrated in  FIG. 1 . Generally, most lateral drilling is limited in depth due to the amount of pipe that may be in contact with the surface wall of lateral drilled hole  60 . Currently, as drill assembly  35  moves laterally, coiled tubing  10  drags along lateral drilled hole  60 . This creates large amounts of friction along coiled pipe  10 , the friction generated may eventually prevent the lateral movement of drill assembly  35 . As disclosed, to overcome the friction, a first motor assembly  15  rotates the coiled tubing  10  section between first motor assembly  15  and second motor assembly  30 . Rotation of the coiled pipe  10  by first motor assembly  15  may prevent coiled tubing  10  from dragging along lateral drilled hole  60 . Rotation of the pipe prevents friction from being generated along coiled tubing  10 . The reduction in friction may allow for drilling to move further lateral. Second motor assembly  30  may be used to drive drill assembly  35  through the formation laterally. Using the second motor assembly  30  to drill and the first motor assembly  15  to rotate the coiled tubing  10  may allow downhole drilling operations to move laterally across the formation. Coiled tubing  10  may also be prevent from dragging along the surface of drilled hole  60  and downhole bend  70 . Moreover, the reachable drilling length of coiled tubing  10  in downhole operations may be increased. 
         [0035]    Although the present disclosure and its advantages have been described in detail, it should be understood that various changes, substitutions and alterations may be made herein without departing from the spirit and scope of the disclosure.

Summary:
Disclosed is a method to enhance the reach of coiled tubing in the lateral section of a wellbore. The application of this method may enhance the use of coiled tubing in drilling very deep flowing wells. Similarly, the method may be applied in increasing the reach of the tubing for other coiled tubing well intervention applications. The method involves the use of downhole motor assemblies, stabilizers, and dynamic torque arrestors to rotate coiled-tubing string.