Abstract:
A method of running a bore-lining tubing string into a bore includes running a tubing string, typically a liner string, into a bore while agitating the string. The agitation of the string reduces the friction between the string and the bore wall and thus facilitates the translation of the string into the bore. The agitation may also take place while the tubing is being cemented in the bore. Pressure pulses may be applied to fluid in the bore, which fluid may be cement slurry.

Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
       [0001]    This application is a continuation of prior U.S. application Ser. No. 10/576,884, filed Mar. 29, 2007, which was the National Stage filing under 35 U.S.C. 371 of International Application No. PCT/GB2004/004503, filed Oct. 25, 2004, which International Application was published by the International Bureau in English on May 12, 2005 and which International Application claims priority to United Kingdom Application No. GB 0324744.2, filed on Oct. 23, 2003, all of which are hereby incorporated by reference herein in their entirety. 
     
    
     FIELD OF THE INVENTION 
       [0002]    This invention relates to apparatus and methods for use in running tubing strings into drilled bores. Aspects of the invention also relate to cementing tubing in drilled bores. 
       BACKGROUND OF THE INVENTION 
       [0003]    Bores drilled to access subterranean formations, and in particular hydrocarbon-bearing formations, are typically lined with metallic tubing, known as casing or liner. After the tubing is run into the bore, the annulus between the tubing and the surrounding bore wall is filled with cement slurry which sets to seal the annulus to prevent, for example, flow of fluid through the annulus from a high pressure formation intersected by the bore into a lower pressure formation intersected by another portion of the bore. 
         [0004]    Casing and liner tend to be run into bores as strings of conjoined tubing sections, which strings may be up to several thousand metres long. The outer diameter of the strings will be only slightly less than the bore inner diameter and thus, particularly in extended reach and highly deviated bores, there may be considerable friction between the string and the bore tending to resist movement of the string through the bore. Also, deposits of loose material in the bore, ledges and doglegs may all serve to hinder an attempt to run a tubing string into a bore. 
         [0005]    The end of the casing or liner string may be provided with a shoe provided with cutting or reaming elements which serve, through axial or rotational movement of the string, to dislodge, rasp or cut through bore obstructions. However, it may prove difficult to apply torque from surface to rotate such a shoe, as the connectors between adjacent sections of the string are generally not capable of withstanding any significant torque. 
         [0006]    As noted above, once the tubing string is in place in the bore cement slurry is run down through the tubing string and into the annulus. This is achieved by pumping a slug of cement slurry of appropriate volume from surface to the leading end of the tubing, the cement slurry being isolated from other fluid in the well by appropriate leading and trailing darts or plugs. To achieve an effective cement seal between the tubing and the bore wall it is important that the fluid and any other deposits in the annulus are substantially completely displaced by the cement. This may be facilitated by rotating the string as the cement is pumped into the annulus, however as noted above it may be difficult to apply the torque necessary to rotate the string from surface, due to the frictional forces acting between the string and the bore wall. 
         [0007]    It is among the objectives of embodiments of the invention to facilitate running in of casing and liner strings and also to facilitate cementation of such strings and thus obviate or mitigate a number of the abovementioned difficulties. 
       BRIEF SUMMARY OF THE INVENTION 
       [0008]    According to a first aspect of the present invention there is provided a method of running a bore-lining tubing string into a bore, the method comprising running a tubing string into a bore while agitating the string to reduce the friction between the string and the bore wall. 
         [0009]    Other aspects of the invention relate to apparatus for use in agitating a bore-lining tubing string. 
         [0010]    The agitation or movement of the string as it is run into the bore has been found to facilitate the translation of the string into the bore, and is particularly useful in extended reach or highly deviated wells, and in running in the last string of bore-lining tubing into a bore. This may be due in part to the avoidance or minimising of static friction, to the relative movement induced between the string and the bore wall by the agitation. Also, the movement of the string may also serve to prevent or minimise gellation of fluid in the well which is in contact with the string and to fluidise sediments lying on the low side of deviated bores. In certain aspects of the invention fluid pressure pulses may be applied to the fluid in the well, which fluid may be inside or surrounding the string, and the pressure pulses, which may be applied in addition to or separately of the agitation, may also serve to prevent or minimise gellation of fluid in the well. 
         [0011]    The tubing string may be translated solely axially, or may also be rotated as it is advanced into the bore. In both cases the agitation of the string has been found to reduce the drag experienced by the string. 
         [0012]    In some cases, the string may be provided with a drill bit, reaming shoe or other cutting structure tool at its leading end, primarily to remove or displace bore obstructions which would otherwise impede the progress of the tubing string through the bore. The rotation of the drill bit may be provided by means of a downhole motor or by rotation from surface. As noted above, agitation of the string facilitates axial and rotational movement of the string in the bore and also allows for more effective transfer of weight to the drill bit: testing has demonstrated that, without agitation, typically only 10% of the weight applied to a tubing string at surface is transferred to the string nose, whereas with appropriate agitation 90% of the applied weight may be available at the nose, providing for far more effective cutting or reaming of bore obstructions. 
         [0013]    Preferably the string is agitated by provision of an agitator in the string, and most preferably by provision of an agitator towards a leading end of the string. Alternatively, or in addition, one or more agitators may be provided at other locations in the string. 
         [0014]    Preferably, the agitator is fluid actuated, and in particular may be actuated by fluid which is pumped through the tubing string. The actuating fluid may be conventional drilling fluid or “mud” or may be cement slurry or treating fluid. In a preferred embodiment the agitator is adapted to be actuated by both drilling fluid and cement slurry. Preferably, the fluid acts on a downhole motor, most preferably a positive displacement motor. This offers the advantage that the speed of the motor, and thus the rate of agitation, may be controlled by varying the fluid flow rate. Thus, the agitation frequency may be selected to suit local conditions and parameters, for example to match or to avoid a natural frequency of the string assembly. 
         [0015]    Preferably, agitation is provided by means of an arrangement such as described in applicant&#39;s U.S. Pat. No. 6,508,317, the disclosure of which is incorporated herein by reference. The preferred agitator form includes a valve element that is movable to vary the dimension of a fluid passage. Preferably, the fluid passage dimension controls flow of fluid through the string, or at least a portion of the string, which fluid may be circulated down through the string and then up through the annulus between the string and the bore wall. Ideally, the fluid passage is never completely closed; rather the passage flow area is varied between a larger open area and a smaller open area, and most preferably includes a flow passage portion that remains open. The preferred agitator form provides positive pressure pulses in the fluid above the valve and negative pressure pulses in the fluid below the valve, that is the pressure in the fluid rises above the valve and falls below the valve as the flow passage area is restricted. Pressure pulses, and in particular positive pressure pulses, may act on a shock tool or the like which is arranged to axially extend and contract in response to the pressure pulses. The shock tool may be provided at any appropriate location in the tubing string, and may be above or below the agitator, but is preferably located directly above the agitator. In other embodiments the shock tool may be omitted. 
         [0016]    Preferably, the agitator comprises a driven valve element. Thus the valve element is moved positively to vary the flow passage area. The valve element may be driven by any appropriate means but is preferably coupled to the rotor of a fluid driven motor, most preferably the rotor of a positive displacement motor. The rotor may provide rotational, transverse or axial movement and, in a preferred embodiment, as described in U.S. Pat. No. 6,508,317, the rotor is of a Moineau principle motor and is directly coupled to the valve member and provides both rotational and transverse movement to the valve member. As noted above, the frequency of pulses and thus of string agitation provided by a positive displacement motor-driven valve element is directly proportional to the fluid flow rate through the motor, and in addition in the preferred agitator form the pulse amplitude may also be controlled in this manner. 
         [0017]    Preferably, the method further comprises cementing the tubing string in the bore while operating the agitator. 
         [0018]    In preferred embodiments, the operation of the agitator will thus continue to agitate the tubing string and will also apply pressure pulses to the cement as it flows into and through the annulus. The agitation of the string will facilitate movement or manipulation of the tubing string. This movement is believed to facilitate displacement of fluid and other deposits from the annulus and ensure uniform distribution of the cement through and around the annulus. In other embodiments the movement of the tubing string induced by the agitation of the string may be sufficient to provide a similar effect. It is also believed that the application of pressure pulses to the cement, preferably negative pressure pulses in contrast to the positive pressure pulses experienced above the agitator, and the pulsed advancement of the cement slurry through the annulus, will also assist in displacing material from the annulus ahead of the cement and in breaking up or dislodging any deposits in the annulus. It is also believed that the pressure pulses assist in maintaining the cement in a fluid state before setting commences and thus facilitate flow of the cement into and through the annulus. 
         [0019]    The preferred form of agitator has, surprisingly, been found to operate well with cement slurry as the actuating fluid and cement has been found to pass through the agitator without difficulty. One known difficulty experienced in handling cement slurry is known as flash setting, which typically occurs when cement slurry encounters a restriction and the particulates in the slurry bridge the restriction and then pack off and solidify. This can take place in a very short time span, and without warning, and is difficult if not impossible to remedy. Without wishing to be bound by theory it is believed that the preferred agitator form avoids this difficulty by one or more of the provision of a flow path which is never completely closed, the provision of a valve member which is positively driven by a motor, and the provision of a valve member which is moved transversely as well as rotated and thus prevents build up of particulates at the valve. However, it may still be preferred to provide for cement bypass above the agitator, such that in the event of a difficulty with the agitator the cement slurry may pass directly into the annulus, without having to pass through the agitator. 
         [0020]    In certain embodiments the agitator may be adapted to permit continued operation after the annulus has been filled with cement, such that agitation of the string may be continued while the cement cures. This may be achieved by providing a bypass path such that fluid may be passed through the agitator following the cement, but the fluid is not directed into the annulus. 
         [0021]    The ability to vary one or more of the agitation frequency and the amplitude of the pressure pulses allows the agitator to be driven at a rate suitable for cementing, which may be different from the rate best suited to running the tubing string into the bore. 
         [0022]    The apparatus of the various aspects of the invention may be left in the bore following cementation. In this case, the apparatus may be adapted to be drillable, such that it is possible to drill the bore beyond the end of the tubing string. In other cases the apparatus may be adapted to be soluble or part soluble such that by passing an appropriate liquid into the bore it is possible to dissolve or weaken the apparatus such that it may be removed from the bore. In other aspects of the invention the apparatus may be adapted to be retrievable, for example by running the apparatus on a separate string or by releasably mounting the apparatus in the tubing string. 
         [0023]    It will be apparent to those of skill in the art that many of the above features have utility separately of the first aspect of the invention, and these features may form separate aspects of the invention. 
     
    
     
       BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWING(S) 
         [0024]    These and other aspects of the present invention will now be described, by way of example, with reference to the accompanying drawings, in which: 
           [0025]      FIG. 1  is a schematic illustration of a string of bore-lining tubing incorporating apparatus in accordance with an embodiment of the present invention; 
           [0026]      FIG. 2  is a sectional illustration of an agitator assembly of the apparatus of  FIG. 1 ; and 
           [0027]      FIG. 3  is an enlarged sectional illustration of part of the agitator assembly of  FIG. 2 . 
       
    
    
     DETAILED DESCRIPTION OF THE INVENTION 
       [0028]    Reference is first made to  FIG. 1  of the drawings, which illustrates the leading end of a string of bore-lining tubing  10  incorporating apparatus  12  in accordance with an embodiment of the present invention. In particular, the tubing is in the form of liner  10  intended to form the last lined section of a drilled bore  14  which has been drilled from surface to intersect a hydrocarbon-bearing formation. In this embodiment the liner has a solid wall, but other embodiments of the invention may involve use of slotted or otherwise perforated tubing. 
         [0029]    The apparatus  12  comprises a shock sub  16 , an agitator  18 , a downhole motor  20  and a drill bit  22  and, as will be described, is used to facilitate running the liner string  10  into the bore  14  and then cementing the liner string  10  in the bore. 
         [0030]    The drill bit  22  and downhole motor  20  are substantially conventional and are used in this embodiment to clear obstructions from the bore  14  as the string  10  is advanced through the bore. The motor is driven by drilling fluid which is pumped through the string  10  from surface, the fluid passing through jetting nozzles in the bit and then passing back to surface through the annulus  30  between the string  10  and the bore wall. 
         [0031]    The agitator  18 , as shown in greater detail in  FIGS. 2 and 3  of the drawings, includes an elongate tubular body having an upper motor section  32  and a lower valve section  34 . The motor section  32  accommodates a Moineau principle motor having a two lobe elastomeric stator  36  and a single lobe rotor  38 . The valve section  34  accommodates first and second valve plates  40 ,  42 , each defining a flow port  44 ,  46 . The first valve plate  40  is directly mounted on the lower end of the rotor  38  via a ported connector  48  defining flow passages  50  which provide fluid communication between the variable geometry annulus defined between the stator  36  and the rotor  38  and the flow port  44 . The second valve plate  42  is mounted on the valve section body  34  directly below the first valve plate  40  such that the respective flow ports  44 ,  46  coincide. As the rotor  38  rotates, due to fluid being pumped down through the motor section  32 , the rotor  38  oscillates from side-to-side and this movement is transferred directly to the valve plate  40  to provide a cyclic variation in the flow area defined by the flow ports  44 ,  46 . 
         [0032]    The fluctuating fluid flow rate and fluid pressure pulses produced by the operation of the valve are, in this embodiment, used to operate the shock sub  16  positioned above the agitator  18 . The shock sub  16  tends to extend in response to the positive pressure pulses it experiences, and tends to retract between the pulses. Furthermore, the pressure pulses are also transmitted upwardly through the string  10 . The action of the shock sub  16  and the pressure pulses agitate the string  10  in the bore  14 , facilitating translation of the string  10  through the bore  14 . The operation of the shock sub  16  and the pressure pulses acting in the drilling fluid below the agitator  18  also provide a hammer drill effect at the bit  22 . Furthermore, it has been found that the agitation of the string  10  facilitates transfer of weight from surface to the bit  22 , allowing the bit  22  to operate far more effectively. 
         [0033]    Once the string  10  has been translated to the bottom of the bore  14 , a slug of cement slurry is pumped down through the string  10 , and then down through the apparatus  12 . The slug of cement is isolated from other fluids by appropriate darts or plugs, the leading plug or dart incorporating a burst disc which bursts when the dart encounters the upper end of the apparatus  12 , to allow the cement slurry to be pumped through the apparatus  12 , out of the bit  22  and into the annulus  30 . The agitator  18  is actuated by the flow of cement slurry such that the string  10  continues to be agitated by the passage of the slurry therethrough. This agitation provides a number of advantages. Firstly, the agitation facilitates manipulation of the string  10  from surface, for example rotation of the string, which may be utilised to improve the distribution of cement through and around the annulus  30 . The agitation also assists in maintaining the drilling fluid in the annulus  30  in a fluid state: some drilling fluids are formulated to gel if left undisturbed, and would be more difficult to displace from the annulus  30  if not maintained in a fluid state by the movement of the string  10 . The agitation also fluidises deposits of drill cuttings and the like lying in the annulus, and thus facilitates displacement of the drill cuttings both during running in of the string  10  and during cementation. 
         [0034]    The operation of the agitator  18  also creates pressure pulses in the cement slurry passing up through the annulus  30 , which pulses are also believed to assist in displacing drilling fluid and any other deposits from the annulus  30 . 
         [0035]    The rate at which the cement slurry is pumped may be varied to provide a desired frequency and amplitude of agitation, selected to enhance the provision of an effective cement seal around the string. 
         [0036]    The configuration of the agitator  18  is such that blockages within the agitator are unlikely to occur, however if desired a bypass facility may be provided above the apparatus  12 , such that the cement slurry may be directed into the annulus  30  without having to pass through the apparatus  12 . 
         [0037]    In this embodiment agitation of the string  10  will cease when the annulus  30  is filled with the cement slurry. However, in other embodiments a fluid bypass or the like may be provided to permit the agitator to continue to operate, actuated by fluid pumped into the bore after the cement slurry, and which fluid is not directed into the annulus; the continued agitation of the string  10  may be useful in achieving a better quality cement seal. 
         [0038]    In other embodiments the shock sub  16  may be omitted, the variation in the drilling fluid and cement slurry flow rate through the agitator, and the resulting pressure pulses, being sufficient to provide the desired degree of movement of the string  10 . 
         [0039]    The above-described embodiment is utilised in facilitating running in and cementing the last section of bore-lining tubing; the apparatus  12  remains in the bore  14  with the cemented string  10 , and would prevent the bore being drilled beyond the end of the string  10 . Thus, as the apparatus is only a “single-use” apparatus, and may therefore be constructed perhaps somewhat less robustly than conventional downhole apparatus intended for multiple uses. In other embodiments the apparatus  12  may be retrievable, for example by mounting the apparatus on an inner string within the liner string  10 , such that the apparatus  12  may be pulled out of the cemented liner  10 . This arrangement is also useful if the bore-lining tubing does not have a solid, fluid-tight wall, for example when embodiments of the invention are utilised in combination with slotted liner. Alternatively, the apparatus  12  may be drillable.