Patent Abstract:
A method of removing produced fluid from a well producing both gas and liquid comprises utilising produced gas flowing from a formation to power a produced liquid pump. The produced liquid from the pump and the produced gas are carried towards surface in separate fluid streams, and may be commingled closer to surface.

Full Description:
CROSS-REFERENCE TO RELATED APPLICATIONS  
         [0001]    This application claims foreign priority benefits under 35 U.S.C. §119 to co-pending British patent application no. GB 0227394.4, filed Nov. 23, 2002. This related patent application is herein incorporated by reference.  
         BACKGROUND OF THE INVENTION  
         [0002]    1. Field of the Invention  
           [0003]    This invention relates to removal of produced fluids from well bores, and in particular to the removal of multiple phases of fluids from well bores. Embodiments of the invention relates to the removal of natural gas and water from a natural gas-producing well.  
           [0004]    2. Description of the Related Art  
           [0005]    In the oil and gas production industry, and more specifically in the production of natural gas, water encroachment into the well bore which extends from the gas-producing formation to surface presents significant difficulties in maintaining production output. Where the produced fluid contains only a small proportion of water, the water will typically remain in droplet form and the velocity of the produced gas flowing from the formation into the well bore and up to surface will often be sufficient to entrain the water droplets and carry the droplets to surface.  
           [0006]    However, as the proportion of water in the produced fluid increases, the density of the gas\water droplet column in the well bore rises. The resulting increase in hydrostatic pressure reduces the pressure gradient between the gas-producing formation and the section of well bore which intersects the formation, which may eventually kill the well.  
           [0007]    Furthermore, the point may also be reached where the level of water production increases, or the gas velocity decreases, to a point where the velocity of the gas is not sufficient to carry the water droplets out of the well.  
           [0008]    One temporary solution to such problems is to install velocity strings in the well bore to restrict the flow area and thus increase the velocity of the produced gas as it travels up the well. However, such velocity strings create significant flow restrictions in the well bore, thus reducing production rates. Also, the point will be reached where the velocity of the gas within the restricted area strings drops below the rate necessary to carry the water droplets to surface, and the well is again killed.  
           [0009]    All of these problems are particularly acute in depleted wells; that is, wells which have been producing for some time, and in which the formation pressure has diminished to a level of economic or physical unfeasibility.  
           [0010]    To overcome these difficulties it is known to employ artificial lift systems, which may be in the form of compressors or pumps which are located in the well.  
         SUMMARY OF THE INVENTION  
         [0011]    According to the present invention there is provided a method of removing produced fluid from a well producing both gas and liquid, the method comprising:  
           [0012]    utilising produced gas flowing from a formation to power a produced liquid pump; and  
           [0013]    carrying produced gas and produced liquid towards surface in separate fluid streams.  
           [0014]    According to another aspect of the present invention there is provided apparatus for location in a well bore for use in removing produced fluid from a well producing both gas and liquid, the apparatus comprising:  
           [0015]    a produced liquid pump for location in a well bore and adapted to be powered by produced gas flowing from a producing formation to surface; and  
           [0016]    a conduit for carrying produced liquid from the pump towards surface.  
           [0017]    In these aspects of the invention, the use of produced gas to drive the produced liquid pump obviates the need to run a power transmission conduit from surface. Thus, there is minimal restriction in the available flow area of the bore, and a corresponding minimal reduction in the production capability of the well bore. Furthermore, in preferred embodiments of the invention there is no obstruction of the safety valve; this avoids the need to modify the well to allow installation of the apparatus, and in particular to change the location or configuration of the safety valve such that a power transmission cable or conduit may pass down through the well bore without having to pass through the safety valve. This feature also facilitates retrofitting of the apparatus in an existing well bore, as once the apparatus is run into the well bore there is no requirement for additional apparatus, such as a power supply, on surface. In other aspects of the invention, the safety valve may include provision for control lines, that is control lines may pass around rather than through the valve, and in such wells the produced liquid pump may be driven by means other than produced gas, for example the pump may be electrically powered, or powered by re-injected water. In still further embodiments, it may be acceptable for a control line to pass through the safety valve, or it may not be necessary to pump the produced liquid towards surface, for example the liquid may be pumped into another formation, rather than carried to surface.  
           [0018]    Preferably, the separate fluid streams are co-mingled in the well bore. Carrying the gas and liquid streams separately towards surface, and then co-mingling the streams closer to surface, reduces the height of the column of liquid-carrying gas in the well bore, allowing the well to produce at a higher rate. Furthermore, as the point where the fluid streams are co-mingled is closer to surface, the gas pressure at this point will be lower and its velocity higher, such that the gas velocity should be more than sufficient to carry the liquid to surface. Also, in a preferred arrangement, the gas and liquid are co-mingled below the safety valve, increasing well safety and facilitating other operations, which require temporary isolation of the well bore from surface.  
           [0019]    In certain embodiments of the invention the stream of produced liquid may include a gas component, to reduce the density of the liquid stream. The gas may be produced gas, or may be a gas, such as nitrogen, injected from surface.  
           [0020]    Typically, the produced gas will be natural gas, and the produced liquid will be water. Alternatively, the liquid may be oil, or a mixture of oil and water.  
           [0021]    The produced liquid may be liquid which has gathered in a lower portion or sump of the well bore, and a stinger may extend from the pump into this lower portion. Alternatively, or in addition, the invention may further comprise separating the produced liquid from produced gas, and then pumping the separated produced liquid to surface. The separation may be achieved by any appropriate means, such as a cyclone separator, or an arrangement which reduces the temperature of the produced gas, causing the liquid to condense. A cyclone separator is preferred as the separator also tends to separate solids from the fluid, with a resulting decrease in wear of downstream components. From the separator, the liquid may flow downwards to a sump, from which the liquid is drawn by the pump, perhaps via a stinger.  
           [0022]    The produced liquid pump may take any appropriate form. However, the pump must of course be compact, robust and reliable. A preferred pump is a reciprocal piston pump, in which the piston reciprocates axially relative to the bore axis. Alternatively, a downhole rotary pump may be utilized. Such a pump may operate on the principle of the Archimedes screw. The pump may be a positive displacement pump. In one embodiment the pump may operate according to the Moineau principle, and may include co-operating sinusodial surfaces on both the rotor and stator of the pump, the shape of which in use allows for operation of moving cavity pumping elements.  
           [0023]    If considered desirable or appropriate the pump may operate in combination with appropriate valving, most preferably appropriate one-way valves.  
           [0024]    The produced liquid pump is preferably turbine-driven. The output from a turbine in these situations is likely to be high speed, low torque and thus it is preferred that the turbine is coupled to the pump via an appropriate gearbox, most preferably by a harmonic drive gearbox, which will convert the high speed, low torque input to a relatively low speed, high torque output (reduction ratios of around 100:1 are typical). The harmonic drive gearbox, which is compact, is preferably co-axial with the turbine. The pump may be a single or multi-stage axial flow pump, or a rotary pump, but as noted above it is most preferably a reciprocating pump, and thus the apparatus may comprise a mechanism for converting rotary motion to reciprocal motion. Any appropriate means may be employed, however it is preferred to utilise a series of selectively rotatable and axially movable cams such as described in GB 2219958A, WO93\11910, WO02\14028, and WO02\46564, the disclosures of which are incorporated herein by reference. The cams may be arranged and configured to provide a selected degree of axial movement, depending on the optimum throw required to operate the pump. Furthermore, the cam profiles may be selected to provide a desired pattern of movement. One or more pumps may be provided, and the pumps may be provided in series or in parallel. Pumps may be provided in series to allow access to deeper wells, in which the hydrostatic pressure experienced at the lower end of the well will be correspondingly higher. For such applications, two or more pumps, or two or more apparatus, may be provided at spaced intervals in the well bore. Thus, the liquid may be pumped from the lowermost or first pump to the second pump, and then from the second pump to the third pump, and so on. Providing two or more pumps in parallel, or two or more apparatus in parallel, improves reliability and may provide for redundancy. The outputs of the two or more pumps may be manifolded together.  
           [0025]    As noted above, the liquid pump may be turbine driven, in which case the turbine will most likely be located adjacent the pump, and in use will likely be located towards the lower end of the bore. Other means of obtaining energy from the produced gas may be provided. Furthermore, in alternative embodiments of the invention a turbine, or other means for obtaining energy from the produced gas, may be located remote from the pump, that is closer to surface, and coupled to the pump by any appropriate means, including a mechanical linkage. Alternatively, a turbine or the like may be utilised to generate electricity or drive a hydraulic pump, and the electrical energy or hydraulic fluid may be conveyed to the pump by appropriate control lines to power the pump.  
           [0026]    In one embodiment the produced liquid pump may be activated or deactivated when the liquid within the well reaches predetermined levels. This provides the added advantage of preventing the pump from running dry and further may reduce pump running time, thereby increasing pump life span. Activation and de-activation may be achieved by any appropriate means, including liquid level sensors operatively associated with means for switching the pump on and off.  
           [0027]    The switching means may comprise means for coupling and decoupling pump-drive means, and in one preferred embodiment provides for coupling and decoupling of a magnetic drive of a pump-driving turbine. The coupling/decoupling means may be mechanically or electrically operated.  
           [0028]    The conduit for carrying the produced liquid may take any appropriate form, but will typically be of a relatively small diameter conduit of jointed or continuous form. Preferably, the conduit is in the form of a “macaroni” string, having a diameter of approximately 1¼ inches.  
           [0029]    Where there is co-mingling of the gas and liquid this will preferably take place below a subsurface safety valve (SSSV). Thus, the apparatus may be installed in a well bore without obstructing or otherwise interfering with the operation of the SSSV. Co-mingling may be achieved by providing a throttle or other restriction in the bore adjacent to the outlet of the produced liquid conduit. The restriction accelerates the gas flow and also reduces the gas pressure, thus tending to draw the liquid from the conduit, and the relatively low pressure assisting in dispersing the liquid in droplet form through the flowing gas.  
           [0030]    Aspects of the invention may also be utilised where it is desired to bullhead or restart a well that has already been killed by water ingress. This may be achieved by pumping gas into the well to force the water which has gathered in the well bore back into the formation. The well is then allowed to produce back, initiating the method as described above.  
           [0031]    An alternative method of restarting a flooded well is to position the apparatus within the well and then pressure up the well with gas. The pressure build up within the well will cause the water collected within the well to be forced to the surface via the apparatus. Gas may be injected into the well until the well is dry. Thereafter, the well is allowed to produce, initiating the method as described above.  
           [0032]    The gas injection may be carried out while the liquid pump is still coupled to a running tubular, and the water forced to the surface may pass through one or both of the running tubular or the conduit. Once the well is dry, the apparatus may be hung in the well, the running tubular retrieved, and the well allowed to produce.  
           [0033]    Further aspects of the invention relate to a downhole pump in which a rotary drive is utilised to actuate a reciprocating pump. The rotary drive may be a turbine, or any other appropriate drive means, such as an electric motor. The pump may take any appropriate form, but is preferably a reciprocating piston pump. The pump may include appropriate gearing, most preferably in the form of a harmonic drive. The conversion of rotary drive to reciprocating motion may be achieved by any appropriate mechanism, but most preferably utilises a series of selectively rotatable and axially translatable cams and cam followers. The number and configuration of the cams may be selected to provide a desired degree of movement, with the capability to multiply up the movement produced. The pump may be positively driven in both directions, or may utilise a spring or pressure return. 
       
    
    
     BRIEF DESCRIPTION OF THE DRAWINGS  
       [0034]    So that the manner in which the above recited features of the present invention can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments of this invention and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments.  
         [0035]    These and other aspects of the present invention will now be described, by way of example, with reference to the accompanying drawings, in which:  
         [0036]    [0036]FIG. 1 is a schematic sectional view of apparatus for use in removing fluid from a well producing both natural gas and water, in accordance with a preferred embodiment of the present invention;  
         [0037]    [0037]FIG. 2 is an enlarged view of area  2  of FIG. 1;  
         [0038]    [0038]FIG. 3 is a sectional view on line  3 - 3  of FIG. 2;  
         [0039]    [0039]FIG. 4 is an enlarged sectional view of part of the apparatus of FIG. 1;  
         [0040]    [0040]FIG. 5 is an enlarged exploded view showing components of a pump assembly of the apparatus of FIG. 1;  
         [0041]    [0041]FIG. 6 is a view of a number of the components shown in FIG. 5; and  
         [0042]    [0042]FIG. 7 is a schematic sectional view of apparatus for use in removing fluid from a well producing both natural gas and water, in accordance with a further embodiment of the present invention. 
     
    
     DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT  
       [0043]    Reference is first made to FIGS. 1, 2 and  3  of the drawings, which illustrates apparatus  10  located in a well bore, for removing gas and water from the well. The Figure illustrates various well components including a section of completion or production tubing  14  which extends into a section of perforated liner  16 . The liner  16  intersects a natural gas and water-producing formation (not shown). A self-closing sub-surface safety valve (SCSSSV)  18  is located at the upper end of the completion tubing  14  and the tubing  14  is located and sealed relative to the liner  16  by an appropriate packer  20 .  
         [0044]    In use, the apparatus  10  is used to facilitate the production of natural gas and water form the well. To this end the apparatus  10  includes a pump assembly  22  which is driven, via a reduction gearbox  24 , by a produced gas-driven turbine  26 . The turbine  26 , gearbox  24  and pump assembly  22  are coupled together to form an elongate cylindrical unit  28  which is located relative to the lower end of the production tubing  14  by a suitable nipple  30  and tubing shoe  32 .  
         [0045]    A macaroni string  34  extends upwards from the unit  28 , through the production tubing  14 , carrying produced water from the pump  22 . The produced gas, after passing through the turbine  26 , passes up through the production tubing  14  separately of the gas stream. A co-mingling and hang-off sub  36  is provided at the top of the macaroni string  34  for locating the upper end of the string  34  in the tubing  14  and such that the water leaving the upper end of the string  34  co-mingles with the gas stream in the tubing  14 . The gas, with the water entrained in droplet form, then passes upwardly through the SCSSSV  18 , and on to surface, where the gas and water may be separated.  
         [0046]    Details of the apparatus  10  will now be described with reference to FIGS.  4  to  6 , which illustrate the unit  28  with the macaroni string  34  extending from the upper end thereof, and with a stinger  38  extending from the lower end of the unit  28 . In use, the open lower end of the stinger  38 , which includes a filter pack to filter out solids, is located within a volume of water  40  lying in the sump of the well (see FIG. 1).  
         [0047]    The unit  28  is located in the tubing shoe  32  such that produced gas flowing from the liner  16  into the production tubing  14  has to pass through the turbine  26 , where the gas impinges on the turbine blades  42 . The passage of the gas through the turbine  26  tends to dry the gas, as the expansion and cooling experienced by the gas as it passes through the turbine  26  tends to cause water carried by the gas to condense out; this condensate will coalesce and then fall to the sump.  
         [0048]    The turbine rotor  44  is mounted on a hollow drive shaft  46  mounted centrally and coaxially of the unit, the shaft  46  extending downwardly into the gearbox  24 , which is in the form of a harmonic drive. Accordingly, the harmonic drive is co-axial with the turbine  26  and changes the output of the turbine  26  from a high speed low torque output, to a low speed high torque output. The hollow gearbox output drive shaft  48  extends into the pump assembly  22 , components of which are illustrated in exploded format in FIGS. 5 and 6 of the drawings.  
         [0049]    The pump assembly  22  includes an arrangement for converting the rotary drive output of the gearbox  24  into reciprocal motion, to drive a reciprocating piston  50 . The gearbox output shaft  48  is mounted in a bearing  52  and passes through a static annular cam  54  which is locked axially and rotatably relative to the housing  56  of the unit  28 . Located below the static cam  54  is a drive cam  58 , which is axially movable on the drive shaft  48 . However, the drive cam  58  is rotatably locked relative to the drive shaft  48  by virtue of the co-operating hexagonal forms  60 ,  62  of the drive shaft  48  and drive cam  58 . Positioned below the drive cam  58  is an output cam  64  which is axially movable within the housing  56  but is prevented from rotating by its interaction with the piston  50 , via co-operating castellations  66 ,  68 .  
         [0050]    The piston  50  is itself axially movable in the housing  56  but is locked against rotation by the interaction of a radially extending piston location pin  70  with a corresponding axial slot  72  in the housing  56 . The piston  50  defines a through bore and the lower end of the piston carries a labyrinth seal  74 .  
         [0051]    Rotation of the drive shaft  48  causes the drive cam  54  to rotate. The sine wave-like forms of the abutting faces of the static cam  54  and the drive cam  58  cause the rotating drive cam  58  to move axially relative to the static cam  54  and the housing  56  between a position in which the troughs and peaks of the cam surfaces coincide, and a position in which the peaks of the surfaces coincide. Similarly, the sine wave form of the abutting faces of the drive cam  58  and the output cam  64  cause the non-rotating output cam  64  to be moved axially as the drive cam  58  is rotated. The cam faces are oriented and arranged such that the initial axial movement of the drive cam  58  induced by the rotation of the drive cam  58  relative to the static cam  54  is amplified by the relative rotational movement between the drive cam  58  and the output cam  64 , this amplified axial movement being transferred to the piston  50 .  
         [0052]    The piston  50  is urged towards an upper or induction position by a light compression spring  78 , such that as the drive shaft  48  is rotated the piston  50  moves, from the position shown in FIG. 4, downwardly against the spring  78 . The piston  50  acts on a volume of water below the piston, in the spring chamber  79 , the water being prevented from passing downwardly out of the chamber  79  through the stinger  38  by a one-way valve  80 , but being permitted to pass from the upper end of the unit  28  via a second one-way valve  82 , which opens when the water pressure within the pump rises to a level above hydrostatic pressure (typically around 3000 psi). Movement of the piston  50  in the opposite direction, that is upwards within the housing  56 , reduces the pressure across the upper valve  82 , such that the valve  82  closes, and allows the lower valve  80  to open, such that the water may be drawn into the spring chamber  79  through the stinger  38 . It will be noted that the cam faces are arranged such that each rotation of the gearbox output shaft  48  will result in two full strokes of the piston  50 .  
         [0053]    Thus, the passage of production gas from the producing formation, up through the well bore, drives the turbine  26  which in turn drives the pump unit  22 , which causes water to be drawn up from the sump and pumped towards surface through the macaroni string  34 . Thus, the produced gas and the produced liquid move towards the surface in separate streams, until reaching the co-mingling and hang-off sub  36 . The restriction in the flow area of the gas caused by the sub  36  accelerates the gas stream, and also reduces the pressure of the gas stream. This assists in drawing the water from the upper end of the string  34 , such that the water, in droplet form, is carried upwardly from the end of the string  34  through the upper end of the tubing  14 , and through the SCSSSV  18 , by the produced gas stream.  
         [0054]    The apparatus  10  has a relatively small diameter and thus may be accommodated in smaller diameter well bores, and indeed may be readily retrofitted into an existing well, and subsequently removed if necessary. The volume of water raised to surface by the apparatus is likely to be relatively small (typically below 24 barrels per day), however this can still have a significant impact on a well and can extend the life of a well, or increase production in a well, at relatively low cost.  
         [0055]    Reference is now made to FIG. 7 of the drawings, which illustrates an alternative apparatus  100  in accordance with a further embodiment of the present invention. The apparatus  100  is similar to the apparatus  10  described above, but has the unit  102  containing the turbine  104 , gearbox  106 , and pump unit  108  located wholly within the liner  110 , and the lower end of the macaroni string  112  located relative to the liner  110  by appropriate slips  114 . Accordingly, in order to direct the produced natural gas through the turbine  104 , a restriction  116  is positioned around the turbine  104 .  
         [0056]    The apparatus  100  also further includes a gas/water cyclone separator  118 . A porous pack-off bushing  120  positioned around the lower end of the separator  118  directs the □wet□ gas from the producing formation into the lower end of the separator  118 . The gas is directed upwards through the separator  118  in a helical path, such that heavier material, in particular any solids and water droplets, are thrown outwardly to coalesce and pass through the perforated lower section of the separator housing  122 . The water may then flow downwards to the sump, through the porous bushing  120 .  
         [0057]    The dry gas passes out of the upper end of the separator  118  and is directed through the turbine  104 . The output of the turbine drives the pump unit  108 , via the gearbox  106 , such that water is drawn out of the sump via the stinger  126 , and pumped upwards through the string  112 . At the co-mingling sub  128  the separate water and gas streams are combined, and pass up through the SCSSSV  130  to surface.  
         [0058]    It will be apparent to those of skill in the art that the above-identified embodiments of the invention are merely exemplary, and that various modifications and improvements may be made thereto, without departing from the scope of the present invention. For example, in the embodiments described above only one apparatus  10 ,  100  is provided in the well. In other embodiments, particularly for use in deeper well, two or more apparatus may be provided in a well. The apparatus may be provided in series, that is the produced gas is utilised to drive a first produced liquid pump at the lower end of the well bore, and from which the liquid is pumped part-way up the well bore to a second apparatus. At the second apparatus, the produced gas is again employed to drive a turbine which in turn drives a pump to take the liquid further up the well bore. In other embodiments, two or more apparatus may be connected in parallel, that is the produced liquid outputs of the two or more pumps will be manifolded together. Two or more groups of such apparatus may be provided in series, as described above. Providing apparatus in parallel may improve reliability particularly if some redundancy is built in to the system. Thus, if one apparatus should fail, the remaining apparatus will continue to operate and maintain production.  
         [0059]    In still further embodiments a turbine or the like may be provided closer to surface, for example a short distance below the SCSSSV, and utilised to generate electricity which is relayed to the pump via appropriate cabling. While there is likely to be less energy in the produced gas at this location, the greater gas volume and velocity, and lower gas temperature, may facilitate turbine operation.  
         [0060]    In still further embodiments, a relatively long stinger may be provided, allowing the pump assembly to be located further up the well, for example above the packer  20 . This would facilitate provision of a pump assembly of longer dimensions.  
         [0061]    While the foregoing is directed to embodiments of the present invention, other and further embodiments of the invention may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.

Technology Classification (CPC): 4