Abstract:
An apparatus for performing well intervention work using coiled tubing. The apparatus includes a structural frame. The upper portion of the frame include two winches for suspending well interventions tools including a coiled tubing injector head. The winches may be selective reciprocated by a hydraulic cylinder to either bring the first or second winch into operative alignment into or out of alignment with a subsea wellhead.

Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
       [0001]    This application claims the benefit of and priority to U.S. provisional application No. 61/307,693, filed Feb. 24, 2010, which is incorporated herein by reference. 
     
    
     BACKGROUND OF THE INVENTION 
       [0002]    The present invention relates to a coiled tubing inline motion eliminator apparatus and method. 
       SUMMARY OF THE INVENTION 
       [0003]    The present invention is drawn to a unique apparatus for deploying coiled tubing on an offshore or other platform that may not have a derrick or other support structure available for running a tool downhole. Such platforms may include, for example, an offshore production platform. The apparatus comprises a frame assembly including a base frame, a lower frame member and an upper frame member detachably secured together. A monorail is positioned on the upper frame member. A winch assembly is operatively connected to the monorail. The winch assembly comprises a first winch and a second winch. Each of the first and second winches includes a hoisting means. A hydraulic cylinder is operatively associated with the winch assembly. Actuation of the hydraulic cylinder causes reciprocation of the winch assembly to move either the first or second winch into or out of operative alignment with a wellhead. 
         [0004]    The first winch may have a lighter load capability than the second winch. 
         [0005]    The apparatus may further comprise a motion compensator. The motion compensator is suspended by the hoisting means of the second winch. 
         [0006]    The apparatus may further comprise a coiled tubing injector head. The injector head is detachably affixed to the motion compensator. 
         [0007]    The coiled tubing injector head may be in operative alignment with the wellhead. 
         [0008]    The apparatus may further comprise a hydraulic pin positioned on the upper frame member. The hydraulic pin is selectively actuated to engage a pin retaining receptacle of the motion compensator. 
         [0009]    The apparatus may further comprise a well intervention tool suspended by the hoisting means of the first winch. The tool is out of operative alignment with the wellhead. 
         [0010]    The frame assembly may be modular and include a plurality of stackable frame units. 
         [0011]    In another embodiment, the apparatus includes a frame assembly having a base frame, a lower frame member and an upper frame member detachably secured together. A reciprocating plate is positioned on the upper frame member. A winch assembly is operatively connected to the reciprocating plate. The winch assembly comprises a first winch and a second winch. Each of the first and second winches includes a hoisting means. The hoisting means are each capable of being extending through an aperture in the reciprocating plate. A hydraulic cylinder is operatively associated with the reciprocating plate. Actuation of the hydraulic cylinder causes reciprocation of the reciprocating plate to move either the first or second winch into or out of operative alignment with a wellhead. 
         [0012]    In the alternative apparatus, the first winch has a lighter load capability than the second winch. 
         [0013]    The alternative apparatus may further comprise a motion compensator. The motion compensator is suspended by the hoisting means of the second winch. 
         [0014]    The alternative apparatus may further comprise a coiled tubing injector head. The injector head is detachably affixed to the motion compensator. 
         [0015]    In the alternative apparatus, the coiled tubing injector head is in operative alignment with the wellhead. 
         [0016]    The alternative apparatus may further comprise a hydraulic pin positioned on the upper frame member. The hydraulic pin is selectively actuated to engage a pin retaining receptacle of the motion compensator. 
         [0017]    The alternative apparatus may further comprise a well intervention tool suspended by the hoisting means of the first winch. The tool is out of operative alignment with the wellhead. 
         [0018]    In the alternative apparatus, the frame assembly is modular and includes a plurality of stackable frame units. 
         [0019]    The present invention is also drawn to a method of conducting well intervention work using coiled tubing. The method comprising the steps of assembling the apparatus of the present invention or the alternative apparatus described herein above. The method includes the step of suspending a motion compensator from the hoisting means of the second winch. The method includes the step of detachably connecting a coiled tubing injector head to the motion compensator. The method includes the step of actuating the hydraulic cylinder to reciprocate the winch assembly or reciprocating plate to bring the second winch into operative alignment with a subsea wellhead. The method includes the step of operatively connecting the coiled tubing injector head to the subsea wellhead. The method includes the step of running coiled tubing into the coiled tubing injector head and down through the subsea well head and into a section of a well where well intervention work is desired to be performed. The method includes the step of performing the well intervention work. 
         [0020]    In the method, the apparatus may further comprises a hydraulic pin positioned on the upper frame member. The hydraulic pin is selectively actuated to engage a pin retaining receptacle of the motion compensator. The method may further comprise the step of actuating the hydraulic pin to engage the pin retaining receptacle of the motion compensator. 
         [0021]    The method may further comprise the step of suspending a well intervention tool to the hoisting means of the first winch. The method may further include the steps of removing the coiled tubing from the well and the coiled tubing injector head. The method may further include the steps of reciprocating the winch assembly or reciprocating plate to move the second winch out of operative alignment with the subsea wellhead and the first winch into alignment with the subsea wellhead. The method may further include the step of operatively connecting the well intervention tool to the well. The method may further include the step of performing additional well intervention work on the well using the well intervention tool. 
         [0022]    The method may further comprise the step of disconnecting the well intervention tool from the well. The method may further comprise the step of removing the well intervention tool from the hoisting means of the first winch. The method may further include the steps of removing the motion compensator and coiled tubing injector head from the hoisting means of the second winch. The method may further include the step of disassembling the apparatus. 
         [0023]    An advantage of the present invention is the elimination of unsafe overhead crane operations. 
         [0024]    Another advantage of the present invention is the ability to conduct coiled tubing operations on platforms without a derrick or other supporting structure. 
         [0025]    Yet another advantage of the present invention is the ease and efficiency of assembling a frame structure that supports a coiled tubing injector head over the wellhead to carryout coiled tubing operations. 
         [0026]    Yet another advantage of the present invention is the ability to quickly and easily move the coiled tubing injector head out of alignment with the wellhead during temporary cessation of coiled tubing operations. 
         [0027]    Yet another advantage of the present invention is the ability to suspend two tools at one time and to selectively move the tools into and out of alignment with the wellhead to perform well intervention tasks. 
         [0028]    Yet another advantage of the present invention is the ability to compensate for the vertical movement of the platform. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0029]      FIG. 1  is a side view of one embodiment of the present invention. 
           [0030]      FIG. 2  is a cross-sectional view of the device shown in  FIG. 1  taken along plane A-A. 
           [0031]      FIG. 3  is a cross-sectional top view of the device shown in  FIG. 1  taken along plane B-B. 
           [0032]      FIG. 4  is a cross-sectional top view of the device shown in  FIG. 1  taken along plane C-C. 
           [0033]      FIG. 5  is an isometric view of another embodiment of the present invention. 
           [0034]      FIG. 6  is a side view of the device shown in  FIG. 5 . 
           [0035]      FIG. 7  is a front view of the device shown in  FIG. 5 . 
           [0036]      FIG. 8  is a back view of the device shown in  FIG. 5 . 
           [0037]      FIG. 9  is a perspective view of an embodiment of the present invention deployed on an offshore platform. 
       
    
    
     DETAILED DESCRIPTION OF THE INVENTION 
       [0038]    As shown in  FIGS. 1-4 , coiled tubing inline motion eliminator apparatus  10  includes frame assembly  12 , which may be positioned over a wellhead (not shown). Frame assembly  12  includes base frame  14  for supporting lower frame member  16  and upper frame member  18 . Frame assembly  12  may be a modular frame. For example, frame assembly  12  may be formed of a plurality of sub-frame units that may be detachably affixed together to form frame assembly  12 . Frame assembly  12  may be made of any material suitable for structural support. For example, frame assembly  12  may be made of metal such as steel. Fixation of sub-frame units may be undertaken by any means capable of suitable connection such as pins, bolts or the like. Frame assembly  12  may be any shape such as rectangular-shaped or square-shaped. Frame assembly  12  may have a height of about 55.5 feet. Base frame  14  and lower frame member  16  may have a width of about 13.0 feet. Each sub-frame unit forming base frame  14  and lower frame members  16  may have a height of about 8.0 feet and a width of about 13.0 feet. Upper frame member  18  may have a width of about 20.0 feet and a height of about 7.5 feet. 
         [0039]    Again with reference to  FIGS. 1-4 , upper frame member  18  includes lower support member  20 . Lower support member  20  includes a first pair of opposed side supports  22  and a second pair of opposed side supports  24 . Lateral supports  26  and  28  extend between first pair of opposed side supports  22 . Hydraulic locking pin  30  is affixed to the upper surface of one of side supports  24  and lateral support  22 . Hydraulic locking pin  30  may be affixed in a variety of ways that secure pin  30  to lower support member  20 . For example, hydraulic locking pin  30  may be attached by screws, bolts, clamps, or other suitable means. 
         [0040]    With further reference to  FIGS. 1-4 , upper frame member  18  includes upper support member  32 . Upper support member  32  includes a first pair of opposing side supports  34  and a second pair of opposing side supports  36 . Monorail  38  extends laterally between opposing side supports  34 . Monorail  38  includes upper rail support  40 , four interconnecting side rail supports  42 , and lower rail support  44 . Monorail  38  may be affixed to side supports  34  by a variety of means. For example, ends  48  of monorail  38  may be connected to side supports  34  or ends  48  at upper rail support  40  of monorail  38  may be connected to the underside of side supports  34 . Such connection may be by welding or other suitable fixation means such as screws, bolts, rivets, or the like. Upper frame member  18  also includes winch assembly  50  and hydraulic cylinder  52 . Winch assembly  50  may include first winch  54  and second winch  56 . Winch  56  may have a higher weight capacity than winch  54 . Winches  54 ,  56  each have a pair of rollers  58 , which are movably positioned on monorail  38 . For example, rollers  58  may be contained on or within monorail  38 . 
         [0041]    Again with reference to  FIGS. 1-4 , hydraulic cylinder  52  is operatively connected to winch assembly  50 . When actuated, hydraulic cylinder  52  either selectively moves winch assembly  50  in a first direction along the axis Z-Z of monorail  38  or in a second opposite direction along the axis Z-Z of monorail  38 . Winches  54 ,  56  each contains a hoisting means  62  such as a wire rope, cord, chain or the like capable of supporting tools and other equipment that may be used for well intervention operations, as for example, a coiled tubing injector head. Winches  54 ,  56  may be selectively actuated to lower or lift such tools and equipment, and in conjunction with the actuations of hydraulic cylinder  52 , to move such tools or equipment along axis Z-Z to either place such tools or equipment in line with the wellhead or out of line with the wellhead depending on whether such tools or equipment will be operatively connected to the wellhead and/or well for well intervention operations. 
         [0042]      FIGS. 1 and 2  shows winch  56  supporting motion compensator  64 . Motion compensator  64  may be of the type disclosed in U.S. Pat. No. 6,929,071, which is incorporated herein by reference. 
         [0043]      FIG. 2  shows winch  56  further supporting coiled tubing injector head  66 . Blowout preventer (“BOP”)  68  is operatively connected to injector  66 . Tubular  70  is operatively connected to blowout preventer  68 . Tubular  70  is operatively connected to the wellhead and/or well (not shown). Coiled tubing  71  is run through injector head  66  and into and through blowout preventer  68  and tubular  70  to a location downhole where well intervention work is to be or is being performed. In this operational position, hydraulic pin  30  is actuated to engage compensator  64 . For example, upper end  72  of compensator  64  may contain pin receptacle  74  for receiving pin  30 . When engaged pin  30  is engaged in receptacle  74 , compensator  64  is retained in position along axis  60 . Such retention keeps the tools, such as injector head  66 , in alignment with the wellhead. The retention of upper end  72  of compensator  64  also enables the reciprocation of compensator  64  to compensate for vertical movement of apparatus  10  when operatively positioned on a floating platform due to wave action or changes in the sea level. 
         [0044]    Apparatus  10  may include a second tool hoisted by which  54 . The second tool may be a tool that will be necessary to operatively connect to the wellhead and/or well once coiled tubing operations are completed or partially completed. For example, if coiled tubing operations are completed or partially completed and the second tool must be used to conduct further well intervention, injector head  66  (or injector head  66  and BOP  68 ) is disconnected. Hydraulic pin  30  is removed from receptacle  74 . Actuation of hydraulic cylinder  52  causes winch assembly  50  to move along axis Z-Z so that winch  56  is out of alignment with the wellhead and the winch  54  and the second tool is brought into alignment with the wellhead. The second tool is connected to the wellhead. Hydraulic pin  30  may or may not be activated to retain the second tool. Well intervention work is then carried out using the second tool. The second tool may be any tool used for well intervention purposes. For example, the second tool may be a tool to conduct work-over, snubbing, completion, and/or plug and abandonment. 
         [0045]      FIGS. 5-8  illustrate another embodiment of apparatus  10 . In this embodiment, winches  54 ,  56  are positioned on upper surface  76  of reciprocating plate  78  of upper frame member  18 . Plate  76  contains opening or aperture  80  through which hoisting means  62  may extend to hoist or support a tool or other well intervention equipment such as injector head  66  or a second tool. Hydraulic cylinder  52  is operatively associated with plate  76 . When hydraulic cylinder is actuated, plate  76  containing winches  54 ,  56  moves forward or backwards along axis Y-Y. 
         [0046]      FIG. 9  shows apparatus  10  assembled and in position on floating platform  82 . Winch  56  is supporting compensator  64 , injector head  66 , BOP  68  and tubular  70 . Tubular  70  is fluidly connected to work string  84  that extends to wellhead  86  that is on seabed  88 . Coiled tubing  71  is positioned through injector head  66 , down through to the work string  84  and into well  90  where well intervention operations are being carried out. Inlet and outlines  92  interconnect compensator  64  to power pack means  94  that supplies a power source necessary to operate compensator  66 . The power source may be pneumatic power such a nitrogen gas. Alternatively, the power source could be hydraulic fluid. 
         [0047]    Also as seen in  FIG. 9 , inlet and outlines  96  interconnect hydraulic pin  30  to power pack means  98  that supplies a power source necessary to operate pin  30 . The power source may be hydraulic fluid. Alternatively, pin  30  could be operated by pneumatic means such as a gas source such as air or nitrogen. Inlet and outlet lines  100  interconnect hydraulic cylinder  52  to power pack means  102  that supplies a power source necessary to operate cylinder  52 . The power source may be hydraulic fluid. Alternatively, cylinder  52  could be operated by pneumatic means such as a gas source such as air or nitrogen. It is possible to combine power pack means  98  and  102  so that either pack means  98  or  102  operate both hydraulic pin  30  and hydraulic cylinder  52 . 
         [0048]    With reference to  FIG. 9 , coiled tubing surface equipment  104  provides the coiled tubing and other required equipment to operate same. The equipment may be a tubing reel, a control house, and a power pack. Winch  54  is shown suspending second tool  106  that may have already been operatively connected to well  90  and moved out of alignment with wellhead  86  by actuation of winch assembly  50  upon completion of the work or is standing-by to be placed into alignment with wellhead  86  and operatively connected to well  90  after removal of coiled tubing  71  from injector  66  and actuation of winch assembly  50  to bring second tool  106  into alignment with wellhead  86 . 
         [0049]    Base  14  may be used with stowable and adjustable work platforms that may be added thereto. The platforms permit rig personnel to work safely during rig up and also during the deployment of downhole tools. 
         [0050]    While preferred embodiments of the present invention have been described, it is to be understood that the embodiments are illustrative only and that the scope of the invention includes the many variations and modifications naturally occurring to those skilled in the art from a review hereof.