You are an expert at summarizing long articles. Proceed to summarize the following text:

You are an expert at summarizing long articles. Proceed to summarize the following text: 
BACKGROUND OF THE INVENTION  
         [0001]    1. Field of the Invention  
           [0002]    This invention is directed toward artificial lift systems used to produce fluids from boreholes such as oil and gas wells. More particularly, the invention is directed toward an improved downhole progressive cavity pump that is inserted and operated within a borehole, and subsequently removed from the borehole, using a coiled or conventional sucker rod, or other rotatable strings that may be used to transmit torque to the pump.  
           [0003]    2. Background of the Related Art  
           [0004]    Modern oil and gas wells are typically drilled with a rotary drill bit and a circulating drilling fluid or “mud” system. The mud system (a) serves as a means for removing drill bit cuttings from the well as the borehole is advanced, (b) lubricates and cools the rotating drill bit, and (c) provides pressure within the borehole to balance internal pressures of formations penetrated by the borehole. Rotary motion is imparted to the drill bit by rotation of a drill string to which the bit is attached. Alternately, the bit is rotated by a mud motor which is attached to the drill string just above the drill bit. The mud motor is powered by the circulating mud system. Subsequent to the drilling of a well, or alternately at intermediate periods during the drilling process, the borehole is cased typically with steel casing, and the annulus between the borehole and the outer surface of the casing is filled with cement. The casing preserves the integrity of the borehole by preventing collapse or cave-in. The cement annulus hydraulically isolates formation zones penetrated by the borehole that are at different internal formation pressures.  
           [0005]    Numerous operations occur in the well borehole after casing is “set”. All operations require the insertion of some type of instrumentation or hardware within the borehole. Examples of typical borehole operations include:  
           [0006]    (a) setting packers and plugs to isolate producing zones;  
           [0007]    (b) inserting tubing within the casing and extending the tubing to the prospective producing zone; and  
           [0008]    (c) inserting, operating and removing pumping systems from the borehole.  
           [0009]    Fluids can be produced from oil and gas wells by utilizing internal pressure within a producing zone to lift the fluid through the well borehole to the surface of the earth. If internal formation pressure is insufficient, artificial fluid lift means and methods must be used to transfer fluids from the producing zone and through the borehole to the surface of the earth.  
           [0010]    The most common artificial lift technology utilized in the domestic oil industry is the sucker rod pumping system. A sucker rod pumping system consists of a pumping unit that converts a rotary motion of a drive motor to a reciprocating motion of an artificial lift pump. A pump unit is connected to a polish rod and a sucker rod “string” which, in turn, operationally connects to a rod pump in the borehole. The string can consist of a group of connected, essentially rigid, steel sucker rods sections (commonly referred to as “joints”) in lengths of 25 or 30 feet (ft), and in diameters ranging from ⅝ inches (in.) to 1-¼ in. Joints are sequentially connected or disconnected as the string is inserted or removed from the borehole, respectively. Alternately, a continuous sucker rod (hereafter referred to as COROD) string can be used to operationally connect the pump unit at the surface of the earth to the rod pump positioned within the borehole. A delivery mechanism rig (hereafter CORIG) is used to convey the COROD string into and out of the borehole.  
           [0011]    Prior art borehole pump assemblies of sucker rod operated artificial lift systems typically utilize a progressive cavity (hereafter PC) pump positioned within wellbore tubing. A typical prior art insertable PC pump system will be described, and includes a pump subsection consisting of a rotor operating within a stator. A tag bar/no-turn subsection is connected below the stator/rotor assembly. Typically, a flush tube extension is connected above the stator/rotor assembly, with a seating/no-go assembly and a cloverleaf pick-up positioned above the flush tube extension. The prior art insertable PC pump assembly requires a special joint of tubing containing a pin protruding into the interior of the tube. A pump seating nipple is also required above the special joint of tubing. It should be understood that the discussed prior art system is used as an example, and that variations of the discussed system using, as examples, different hold down systems and different torque stopping devices are in the prior art.  
           [0012]    The prior art PC pump rotor and stator, flush extension tube, cloverleaf pick-up and seating/no-go components are all assembled prior to insertion into the borehole tubing thereby creating an insertable PC pump assembly.  
           [0013]    Before the PC pump is positioned and operated down hole, the previously mentioned special joint of tubing with pin and attached seating nipple must be installed in the tubing string so that the pump will be positioned to lift from a particular producing zone of interest. If the pump assembly is subsequently positioned at a shallower or at a deeper zone of interest within the well, this can be accomplished by removing the tubing string, or by adding or subtracting joints of tubing. This repositions the special joint of tubing as required.  
           [0014]    Once the special tubing and seating nipple are installed in the tubing string, the insertable PC pump assembly is run, from surface of the earth, downhole inside of the tubing by a COROD or a conventional sucker rod system. When reaching the special tubing joint, a forked torque slot at the lower end of the insertable PC pump assembly tag bar/no-turn subsection aligns with the pin protruding near the bottom in the special tubing joint. Once the torque fork aligns with and engages the pin, the insertable PC pump assembly is locked radially within the tubing and can not spin within the tubing when the pump is operated. After the torque fork and pin have aligned, the seating/no-go assembly located at the top of the PC pump then slides into and seals in the seating nipple until it is stopped by the no-go. The prior art insertable PC Pump is now completely installed down hole.  
           [0015]    The prior art insertable PC pump is removed by lifting the sucker rod string until a coupling on the top of the rotor shoulders out on the clover leaf located on the top of the extension tube just below the seating/no-go assembly. The seating/no-go assembly is then extracted from the seating nipple, and the insertable PC pump assembly can be pulled, using COROD or conventional sucker rod string, to surface for servicing or repositioning. Once pulled, a new insertable PC pump of identical length and identical outside diameter can be installed as outline above.  
           [0016]    The operating envelope of an insertable PC pump is dependent upon pump length, pump outside diameter and the rotational operating speed. In the prior art system, the pump length is essentially fixed by the distance between the seating nipple and the no turn pin in the special joint of tubing. Pump diameter is essentially fixed by the seating nipple size. Stated another way, these factors define the operating envelope of the pump. For a given operating speed, production volume can be gained by lengthening stator pitch and decreasing the total number of pitches inside the fixed operating envelope. Volume is gained at the expense of decreasing lift capacity. On the other hand, lift capacity can be gained within the fixed operating envelope by shortening stator pitch and increasing the total number of pitches. Production volume can only be gained, at a given lift capacity, by increasing operating speed. This, in turn, increase pump wear and decreases pump life. For a given operating speed and a given seating nipple sizes, the operating envelope of the prior art system can only be changed by pulling the entire tubing string and adjusting the operating envelope by changing the distance between the seating nipple and the special joint of tubing containing the locking pin. Alternately, the tubing can be pulled and the seating nipple can be changed thereby allowing the operating envelope to be changed by varying pump diameter. Either approach requires that the production tubing string be pulled at significant monetary and operating expense.  
           [0017]    During operation, it is possible that the insertable PC pump assembly may need to be flushed to remove sand and other debris from the stator/rotor subsection. To perform this flushing operation, the rotor component is pulled upward from the stator by means of the sucker rod string. In order to avoid disengaging the entire pump assembly from the seating nipple, the rotor is moved upward only until it is located in the flush tube between the seating/no-go assembly and the stator/rotor subassembly. The pump may now be flushed, and then the rotor reinstalled without completely reseating the entire pump assembly. Since the prior art insertable PC pump assembly is picked up from the top of the rotor, the flush tube extension assembly is required. Furthermore, the length of the flush tube extension must be at least as long as the rotor, for reasons that will become apparent in a subsequent section of this disclosure. The entire assembly will then be at least twice as long as the stator. This presents a problem in optimizing stator length within the operation, and clearly illustrates a major deficiency in prior art insertable PC pump systems.  
           [0018]    In summary, the prior art insertable PC pump system described above requires a special joint of tubing containing a welded, inwardly protruding pin for radial locking and a seating nipple. The seating nipple places some restrictions upon the inside diameter of the tubing in which the pump assembly can be operated. This directly constrains the outside diameter of the insertable pump assembly. The overall distance between the pin and the seating nipple constrains the length of the pump assembly. In order to change the length of the pump assembly to increase lift capacity (by adding stator pitches) or to change production volume (by lengthening stator pitches), (1) the entire tubing string must be removed and (2) the distance between the seating nipple and the locking pin must be adjusted accordingly before the tubing is reinserted into the well. Axial repositioning of the pump without changing length can be done by adding or subtracting tubing joints to reposition the seating nipple and the locking pin as a unit. The prior art PC pump assembly requires a flush tube assembly so that the rotor can be removed from the stator for flushing. This increases the length of the assembly, and also adds to the mechanical complexity and the manufacturing cost of the assembly.  
           [0019]    As noted previously, other prior art insertable PC pump systems are commercially available. All systems, however, comprise the above discussed limitations of fixed seating nipple inside diameter, fixed length between seating nipple and a rotational locking device, pick up from the top of the rotor, and an extension tube.  
         SUMMARY OF THE INVENTION  
         [0020]    The present invention is an improved insertable progressive cavity (PC) borehole pump assembly for use in any rotational operated artificial lift systems. The PC pump subsection consists of a rotor operating within a stator. The lower end of the rotor is terminated with a retaining structure that will hereafter be referred to as an “arrowhead”. A torque restraining tool subsection is connected to the stator/rotor assembly. A seating/no-go pick up housing and floating ring subassembly is connected above the stator/rotor assembly. Alternately, the seating/no go can be located below the stator but the floating ring subassembly must always be above the stator. A pump seating nipple is used in the tubing string to receive and seat the pump assembly at the seating subassembly.  
           [0021]    The PC pump subsection containing (a) the arrowhead attached to the rotor, (b) the torque restraining subsection, and (c) the seating/no-go pick up housing and floating ring assembly are assembled at the surface thereby creating the insertable PC pump unit. Before the insertable PC pump is installed downhole, the seating nipple is first installed in the tubing string. After seating nipple installation, the insertable PC pump assembly is then inserted in the borehole, inside of the tubing, preferably by means of COROD or conventional sucker rod system from surface of the earth. Other rotatable string means, such as tubing, can be used for insertion and operation. Furthermore, the system does not necessarily have to be operated inside production tubing, but can operate in other tubular strings such as casing. In one embodiment, all components of the pump assembly, including the torque restraining subassembly, pass through the seating nipple with the exception of the seating/no-go pick up housing and floating ring assembly. In other embodiments, some components can pass through or stay above the seating nipple, depending upon the location of the mandrel and the no-go. If the system is configured so that the seating nipple is at the bottom of the pump, the stator will not pass through the seating nipple but the torque restraining “no-turn” may or may not pass through. If the seating nipple is at the top of the assembly, the stator will pass through the seating nipple but the no-turn may or may not pass through the seating nipple. The no-turn is positioned at the top or the bottom thereby determining if it must pass through the seating nipple or not. The housing seats and seals in the seating nipple, and is stopped by the no-go. Pump intake and exhaust are isolated by the seal. At this point, the insertable PC pump assembly is completely installed.  
           [0022]    The insertable PC pump assembly is removed from the wellbore by lifting the sucker rod string thereby pulling the rotor through the stator and through the floating ring, until the arrowhead on the bottom of the rotor reaches the floating ring. The arrowhead is sized so that it can not pass through the floating ring, but will freely move through the stator. When the rotor is lifted to a point where the arrowhead engages the floating ring, continued lifting of the sucker rod pulls the entire insertable PC pump assembly from the seating nipple. The pump can now be conveyed to surface by a COROD rig, by conventional sucker rod pulling means and procedures, or by other rotatable tubular pulling means. In an alternate embodiment, the tubular can be non-rotating. In this embodiment, the non-rotating tubular is terminated downhole with a rotating drive means which, in turn, provides the needed rotational motion to operate the pump system.  
           [0023]    As with prior art PC pumps, it is possible that the insertable PC pump assembly set forth in this disclosure may need to be flushed of sand and other debris. This is accomplished by pulling, by means of the sucker rod string, the rotor out of the stator and through the pick up housing until the arrowhead is positioned between the top of the stator rubber and the floating ring. This positions the stator and rotor so that the pump can be effectively flushed. After flushing, the procedure is essentially reversed so that the rotor is again positioned within the stator for pump operation.  
           [0024]    Prior art insertable PC systems require a special tubing joint with an internally protruding welded pin to insure that the assembly does not rotate. The pin to seating nipple distance limits the length of the pump assembly. The improved insertable PC pump assembly requires no special tubing joint with an internally protruding, welded pin to insure that the assembly does not rotate. The torque restraining subassembly, which is an integral part of the insertable pump unit, is used to releasably grip the interior of the tubing thereby preventing rotation of the stator assembly during operation. The improved insertable PC pump assembly can be removed, the length can be varied thereby allowing changes in volumetric displacement and/or lift capacity, and the assembly can be reinstalled in the same seating nipple as long as the outside diameter of the insertable PC pump assembly is compatible with the dimensions of the seating nipple. This is possible because the torque restraining assembly can releasably grip the interior of tubing at any axial position. No restraining pin is required. The pump can be removed and adjustments in volumetric displacement and/or lift capacity can be made by varying pump length and without having to remove tubing and altering the spacing between a seating nipple and a no turn pin as in prior art systems.  
           [0025]    Since the previously discussed prior art insertable PC pump assembly picks up from the top of the rotor, the flush extension tube is required. Furthermore, the flush tube must be at least as long as the rotor. The stator/rotor subsection must, therefore, be at least twice as long as the stator. The improved PC pump assembly picks up from the bottom of the rotor, therefore no flush tube is required. When configured for flushing, the rotor extends substantially into the production tubing thereby allowing the length of the improved pump assembly to be reduced to almost half the length of the prior art system. The improved insertable PC pump can therefore be fabricated for larger production volumes and higher lifts within a tightly constrained operating envelope defined by outside diameter and length.  
           [0026]    The improved insertable PC pump assembly contains fewer special parts and therefore is less costly to manufacture, to operate, and to maintain. 
       
    
    
     BRIEF DESCRIPTION OF THE DRAWINGS  
       [0027]    So that the manner in which the above recited features, advantages and objects of the present invention are attained and can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to the embodiments thereof which are illustrated in the appended drawings.  
         [0028]    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.  
         [0029]    [0029]FIG. 1 illustrates a prior art insertable PC pump system.  
         [0030]    [0030]FIG. 2 a  illustrates the prior art PC pump system being inserted into a borehole.  
         [0031]    [0031]FIG. 2 b  illustrates the prior art PC pump system being seated within the borehole.  
         [0032]    [0032]FIG. 2 c  illustrates the prior art PC pump system being operated within the borehole.  
         [0033]    [0033]FIG. 2 d  illustrates the prior art PC pump system being flushed.  
         [0034]    [0034]FIG. 2 e  illustrates the prior art PC pump system being removed from the borehole;  
         [0035]    [0035]FIG. 3 illustrates an improved insertable PC pump system.  
         [0036]    [0036]FIG. 4 a  illustrates the improved PC pump system being inserted into a borehole.  
         [0037]    [0037]FIG. 4 b  illustrates the improved PC pump system being seated within the borehole.  
         [0038]    [0038]FIG. 4 c  illustrates the improved PC pump system being operated within the borehole.  
         [0039]    [0039]FIG. 4 d  illustrates the improved PC pump system being flushed.  
         [0040]    [0040]FIG. 4 e  illustrates the improved PC pump system being removed from the borehole.  
     
    
     DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT  
       [0041]    The present invention is an improved insertable progressive cavity (PC) borehole pump assembly for use in sucker rod operated artificial lift systems. The pump assembly will operate equally effectively using any type of preferably rotatable string for imparting rotation to the pump. Alternately, a non-rotating string can be used with the downhole end of the string being terminated by a drive means that, in turn, imparts rotation to the pump. The assembly will operate in any type of tubular string, although the most common operation is within production tubing.  
         [0042]    To fully illustrate the mechanical and operational improvements of the disclosed insertable PC pump system, a typical prior art PC pump apparatus and operation will be described in detail.  
       Prior Art System  
       [0043]    Attention is directed to FIG. 1, which illustrates a prior art insertable PC pump assembly denoted as a whole by the numeral  10 . It should be understood that the prior art contains other PC pump systems, but the system illustrated in FIG. 1 is typical in that it exhibits limitation present in all other known prior art systems.  
         [0044]    Still referring to FIG. 1, a seating mandrel  20  containing a pick-up insert  22  is positioned at the top of the assembly  10 . A pony rod  12  is connected to the top of a rotor  18  by means of a pick-up coupling  16 . The top of the pony rod is connected to a COROD string (not shown) or to a conventional sucker rod string (not shown) by means of a connector  14 . The pony rod  12  and rotor  18  are inserted within a tubular section comprising a pick-up assembly  24  with a seating/no-go assembly  20  and a cloverleaf pick-up  22 , a flush extension tube  26 , and a stator  30  which is connected to the flush extension tube  26  by means of a barrel connector  28 . As shown,  24  illustrates the top of the extension tube that keeps the cloverleaf in place between the seating mandrel and the tube. The elements  20 ,  22  and  24  as a group could alternately be defined as the pickup assembly. A tag bar/no-turn subsection  32  terminating with a fork  34  (mechanical hold down) is connected below the stator/rotor assembly.  
         [0045]    Still referring to FIG. 1, the prior art pump assembly  10  requires a special joint or “locking” tubing  40  containing a pin  42  protruding into the interior of the tubing. A pump seating nipple  36  is connected to the top of the locking tubing joint  40  by means of a collar  38 . The prior art insertable PC pump subassembly, flush extension tube, cloverleaf pick-up and seating/no-go components are all assembled prior to insertion into the borehole tubing thereby creating an insertable PC pump assembly.  
         [0046]    The pump assembly  10  is operated within the tubing joint  40  as will be described in the following paragraphs. The locking joint  40  of tubing with the pin  42  and the seating nipple  36  must be installed in the tubing string so that the pump assembly  10 , when installed downhole, will be positioned to lift from a particular producing zone of interest.  
         [0047]    Once the special tubing and seating nipple are installed down hole in the tubing string, the insertable PC pump assembly is now run down hole inside of the tubing using a COROD or conventional sucker rod system. This step is illustrated in FIG. 2 a.    
         [0048]    When reaching the special locking tube joint  40 , the forked torque slot  34  at the lower end of the assembly tag bar/no-turn subsection  32  aligns with the pin  42  as shown in FIG. 2 b . Once the torque fork slot  34  aligns with and engages the pin  42 , the PC pump assembly  10  is locked radially within the tubing  40  and can not spin within the tubing when the pump is operated. After the torque fork  34  and pin  42  have aligned and engaged, the seating/no-go assembly  20  located at the top of the PC pump will then slide into and seal in the seating nipple  36  until it is stopped by the no-go. The prior art insertable PC Pump  10  is now completely installed down hole.  
         [0049]    [0049]FIG. 2 c  illustrates the prior art pump system  10  in operation, where the rotor  18  is moved up and down within the stator  30  by the action of the pony rod  12  and connected sucker rod string (not shown). After compensating for sucker rod stretch, the sucker rod string is slowly lifted a distance “A”, designated as  52 , off of the tag bar/no-turn subassembly  42 . This positions the rotor  18  in a proper operating position with respect to the stator  30 .  
         [0050]    [0050]FIG. 2 d  shows the system configured for flushing. The rotor  18  is lifted out of the stator  30  as indicated by the distance “B” at  54 . The rotor and stator elements can then be flushed of debris using methods known in the art.  
         [0051]    [0051]FIG. 2 e  illustrates the pump assembly being removed from the locking tubing  40  and seating nipple  36 . The sucker rod string is lifted until a coupling  16  on the top of rotor  18  shoulders out on the clover leaf pick-up insert  22  located just below the seating/no-go assembly  20 . The seating/no-go assembly  20  is then extracted from the seating nipple  36  by further upward movement of the sucker rod string, and the PC pump assembly  10  is conveyed to the surface as the sucker rod string is withdrawn from the borehole.  
       Improved PC Pump System  
       [0052]    Attention is directed to FIG. 3, which illustrates the improved insertable PC pump assembly  100  set forth in this disclosure. A rotor  118  is terminated at a lower end by an “arrowhead” structure  119 , and connected at an upper end to a pony rod  12  by means of a slim hole coupling  116 . Alternately, the rod can be an integral part of the rotor  118 . The top of the pony rod is connected to a COROD string (not shown) or a conventional sucker rod string (not shown) by means of a connector  14 . Other rotatable means can be used to operate the system, such as tubing. The pony rod  12  and rotor  118  are inserted within a tubular section closed at the top with a seating mandrel assembly, comprising a mandrel/no-go top housing  120 , a floating ring  122 , and a bottom housing  121 . Moving down the assembly  100 , the seating mandrel assembly is connected to an upper extension tube  124 , a stator  130  and a lower extension tube  132  containing a tag bar  127 . Functions of the upper and lower extension tubes will become apparent in subsequent sections of this disclosure, and the tubes are considerably shorter in length than the flush extension tube  26  (see FIG. 1) of the previously described prior art PC pump system. The tubular section is terminated at the lower end by a torque restraining assembly  135 . The assembly  135  is illustrated specifically as a dual acting no-turn assembly, which is connected to the lower extension tube  132  by means of a swage  134 . Other types of operationally removable torque restraining assemblies such as packers can be used. It is also emphasized that the torque restraining assembly  135  can be positioned elsewhere in the pump assembly, such as above the stator assembly.  
         [0053]    Still referring to FIG. 3, the PC pump assembly  100  is inserted into conventional wellbore tubing  140  through a seating nipple  136  attached to the tubing by means of a standard collar  138 . The seating mandrel and seating nipple cooperate to form a seal to isolate the PC pump intake from the pump discharge. No special tubing section is required to install and operate the improved insertable PC pump assembly  100 . The elements and assemblies of the pump  100  are assembled at the surface prior to insertion into the borehole tubing  140  thereby forming an insertable PC pump assembly.  
         [0054]    [0054]FIGS. 4 a - 4   e  illustrate all phases of the operation of the improved insertable PC pump system  100 .  
         [0055]    [0055]FIG. 4 a  illustrates the insertion of the pump assembly  100  within a well borehole. The seating nipple  136  is first positioned in the tubing string at the desired depth within the borehole. The pump assembly  100  is attached at the surface to a sucker rod string (not shown) by means of the connector  14 . As an example, for 4-½ inch (in.) tubing, a 4-½ inch seating nipple would be positioned in the tubing string so that the intake of the pump is at the desired depth. With the seating nipple  136  properly positioned down hole, the pump assembly  100  is lowered inside the tubing string  140  using a conventional or a COROD string (not shown). It is good practice to insert a rod shear (not shown) approximately one joint of sucker rod above the pump  100 , or at an equivalent distance in a COROD string. This permits easier remedial action if the pump system abnormally malfunctions.  
         [0056]    Pump seating is illustrated in FIG. 4 b . The pump assembly  100  attached to the sucker rod string is lowered into the borehole until the weight of the assembly, measured at the surface, decreases to near zero. When this occurs, the seating mandrel assembly  120  should be seated within the seating nipple  136 . Allowances must me made depending upon whether the pump is fully extended or on a tag bar  127 . It is desirable to fill the tubing string with fluid to ensure that the pump  100  is seated properly. This will also help to prevent unseating of the pump when trying to properly position the rotor  118  for operation. If the tubing string holds fluid under pressure, a proper seal has been made with the seating assembly and the nipple  136 . Stated another way, a verification of proper seating can be obtained by monitoring fluid level within the tubing. If the tubing string does not fill or the level drops, a proper seal has not been made between the seating mandrel  120  and the seating nipple  136 . This can usually be remedied by tapping down lightly on the rotor  118  attached to the sucker rod string to contact the tag bar  127  and thereby ensure that the mandrel  120  is seated properly inside the nipple  136 . The torque restraining assembly tool  135  is then engaged thereby gripping the inside wall of the tubing  140 . This prevents the housing components of the pump  100  from rotating with the rotor  118  during pump operation. The torque restraining assembly  135 , is shown as a no-turn assembly in FIG. 3. The assembly may be of any design as long as it prevents rotation of the stator section  130  during operation of the pump.  
         [0057]    [0057]FIG. 4 c  illustrates the PC pump system  100  in operation, where the rotor  118  is moved up and down within the stator  130  by the action of the pony rod  12  and connected sucker rod string (not shown). After compensating for sucker rod stretch, the sucker rod string is slowly lifted a distance  150 , off of the tag bar  127 . This positions the rotor  118  in a proper operating position with respect to the stator  130 . The distance  150  is typically about 12 in.  
         [0058]    [0058]FIG. 4 d  shows the system configured for flushing. The rotor  118  is lifted out of the stator  130  as indicated by the distance  160 . This distance is typically the length of the rotor  118 . Lifting the rotor  118  by more that the specified distance  160  may unseat the pump assembly  100  by means of the arrowhead  119  contacting the floating ring  122 . The rotor and stator elements are now positioned to be flushed of debris using methods known in the art.  
         [0059]    [0059]FIG. 4 e  illustrates the removal of the PC pump assembly from the tubing  140 . The sucker rod string is lifted by a distance greater than  160 , with  160  being the overall length of the rotor  118 . Then when the arrowhead structure  119  engages with the floating ring  122 , there will be a sharp increase in sucker rod string weight as detected at the surface. This indicates that the pump assembly  100  is being unseated by the upward force exerted at contact point of the arrowhead  119  and the engagement ring  122 . Once unseated, the pump  100  is raised to surface by a CORIG system or a convention sucker rod pulling unit.  
       Summary  
       [0060]    A typical prior art insertable PC pump system and an improved insertable PC pump system have been described and illustrated in detail. As discussed previously, the prior art system is typical in that it exhibits limitation present in all other known prior art systems. Operational, economic and reliability advantages of the improved PC pump system set forth in this disclosure are summarized below.  
         [0061]    The prior art insertable PC pump system  10  (see FIG. 1) systems require a special tubing joint with an internally protruding, welded pin to insure that the housing assembly does not rotate. This introduces adverse economic, operational and reliability factors. Furthermore, the special tubing limits the length of the pump assembly, since the protruding pin defines assembly length. The seating nipple inside diameter limits the maximum outside diameter of the insertable PC pump assembly. The improved insertable PC pump assembly  100  (see FIG. 3) requires no special tubing joint to insure that the assembly does not rotate. The dual acting torque restraining device  135  (shown as a dual acting no-turn tool for purposes of illustration), which is an integral part of the insertable pump unit  100 , is used prevent rotational movement of the pump housing during operation. The torque restraining assembly  135  can be operationally set and released at any axial position within the tubing. The improved pump assembly  100  can be removed, length can be varied, and the assembly can be reinstalled in the same seating nipple as long as the outside diameter of the seating assembly is compatible with the dimensions of the seating nipple. This can be done without having to remove the tubing string to alter spacing between a seating nipple and a no-turn pin, as is the case in prior art insertable PC pump systems.  
         [0062]    Since the prior art PC pump assembly  10  is picked up from the top of the rotor, the flush extension tube  26  is required. Furthermore, the flush tube must be at least as long as the rotor. The stator/rotor subsection must, therefore, be at least twice as long as the stator. The improved PC pump assembly  100  picks up from the bottom of the rotor when the arrowhead structure  119  contacts the floating ring  122  and then the housing  121 . No flush tube is required in the improved PC pump  100 . When configured for flushing, the rotor extends  118  substantially into the tubing  140  thereby allowing the length of the improved pump assembly to be reduced to almost half the length of the prior art system.  
         [0063]    The improved insertable PC pump assembly  100  contains fewer special parts and therefore should be less costly to manufacture, to operate and to maintain.  
         [0064]    It should be understood that the basic concepts set forth in this disclosure are applicable to other apparatus and methods. As an example, the lifting technique can be adapted to any type of pump operated by a sucker rod string. As another example, the torque restraining assembly can be used to rotationally stabilize other types of downhole pumping systems. This pump system can be driven by means other than sucker rod, such as tubing or any mechanism that can impart rotation to the pump assembly. Alternately, the pump system can be operated by a non-rotating tubular string terminated downhole by a drive means, wherein the drive means can be retrieved by a wireline or other means.  
         [0065]    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.

Summary:
An artificial lift system used to produce fluids from boreholes such as oil and gas wells. The system uses a progressive cavity (PC) downhole pump system which can be inserted into the borehole, seated, operated, flushed and removed using conventional or coiled sucker rod tubing. No special tubing is required to radially anchor the PC pump to the tubing. The PC pump system has improved flushing capabilities which reduces the length of the system. The system is lest costly to manufacture and to maintain than prior art PC pump systems. The pump can be relocated without pulling tubing. Different displacement volumes and lifts can be substituted in existing installations without major changes to equipment installed in the tubing string.