Abstract:
A high efficiency fluid pumping apparatus and methods having of an electronic motor controller controlling at least one electric motor that is directly coupled to the input of a hollow helical mechanism. The output of the hollow helical mechanism is directly coupled to the shaft of a reciprocating piston pump. Each moving component of the apparatus is designed with a hollow central bore, so that the apparatus assembly will accept a continuous, stationary, hollow conduit containing electrical through wiring and or fiber optics for power and communication to devices physically positioned below the apparatus.

Description:
FIELD 
       [0001]    This invention generally relates to the testing and evaluation of underground formations or reservoirs. More particularly, this invention relates to maximizing fluid pumping output capacity in situations where limited electrical power is available downhole and where space is also limited as a result of a need for reduced diameter testing tools. 
       BACKGROUND 
       [0002]    Wells drilled into the ground to recover deposits of oil, gas or other desirable minerals trapped in geological formations often need to be evaluated as to the presence and particular characteristics of those deposits or as to the characteristics of the formations in which those deposits are found. After the presence of such deposits has been confirmed and a portion has been produced, additional evaluations may be performed to determine the quantity and condition of that portion of the original deposit remaining within the geological formation. 
         [0003]    One technique for evaluating deposits and formations is to lower an evaluation tool into the well on a wireline. The purpose of some wireline tools is to measure the pressure characteristics of the formation and to retrieve a fluid sample for later analysis in a laboratory. These wireline tools have come to be known as Wireline Formation Testers or WFT&#39;s. Other methods of conveyance also exist. The term Drill Stem Testing or DST is frequently used when drill pipe or coiled tubing is used to convey the formation test tool into the well. WFT&#39;s and DST&#39;s may employ pumps to withdraw fluids from the formation or to inject fluids into the formation. 
         [0004]    WFT&#39;s can be conveyed on a variety of different types of wireline with some standards for wireline sizes and for the number of electrical conductors having developed within the industry. Wireline sizes typically vary from 0.100 inches to 0.520 inches outer diameter, containing between 1 and 7 internal conductors. Normally two layers of external steel armour surround the conductors to provide protection and strength. 
         [0005]    Wireline design options are constrained in several respects. The wireline must be able to fit on a spool that is capable of being mounted on a truck or on a portable skid unit. The spool itself must accommodate a sufficient length of wireline to reach the bottom of deep wells. Together, these two requirements determine a maximum possible diameter for a continuous portable wireline of any given length. 
         [0006]    Another requirement is that the wireline must be strong enough to support its own weight, in addition to the weight of the tools to be conveyed plus an allowance for over pull in the event that the tools become subjected to frictional sticking forces. This requirement works to increase the amount of steel armour and therefore to decrease the amount of space available for the internal electrical conductors and insulating materials. 
         [0007]    Another requirement is for high voltage ratings between the conductors and ground, as well as between the conductors themselves, if a plurality of conductors is desired. This requirement tends to increase the thickness of the insulating material that surrounds the conductors, further decreasing the amount of space available for the conducting material. Finally, the current carrying capacity of wireline increases with the diameter of the conducting material and electrical power is the product of voltage times current. 
         [0008]    When considered together, the aforementioned design requirements all work to place an upper limit on the amount of power that can be conveyed downhole via a portable wireline. Because power downhole is necessarily in limited supply, it is prudent to make the most efficient possible use of that power which is available, particularly in those instances where the wireline tool is expected to perform mechanical work. 
         [0009]    Conventional wirelines were first developed before the existence of WFT&#39;s and at a time when electronic technology was not in the advanced state it is today. The 7-conductor (heptacable) wireline which has become fairly standard for openhole wireline operations provided early tool designers with a plurality of signal pathways that enabled several measurements to be transmitted to the surface concurrently. Today, the need for multiple signal pathways is reduced or eliminated by the use of telemetry communications between the downhole tools and the surface equipment. 
         [0010]    First generation WFT&#39;s did not provide for direct continuous pumping of formation fluids or of borehole fluids. Pressure drawdown measurements were made indirectly using pressurized hydraulic fluid to drive pre-test pistons moving within chambers or test-volumes. Continuous pumping capacity was not a design consideration, so that standard heptacable wireline was adequate for the purpose and hydraulic fluid pumping efficiencies were not of great concern. 
         [0011]    While some second generation of WFT&#39;s tools do provide for direct continuous pumping of formation and of borehole fluids, the use of pressurized hydraulic fluid actuation continues. In these newer tools, the pressurized hydraulic fluid is often employed to actuate reciprocating downhole pumps, commonly referred to as mud-pumps, in addition to actuating pre-test pistons within pre-test volumes. 
         [0012]    Hydraulic systems are known to be inherently inefficient. The overall efficiency of a hydraulic system can be calculated as the product of the individual efficiencies of all of the system components. These components necessarily include a hydraulic fluid pump with both mechanical and volumetric losses, in addition to piping, valves and other sources of frictional loss that cause heat generation in the hydraulic fluid. These hydraulic losses further diminish an already limited amount of downhole power that can be delivered to the mud-pump. 
         [0013]    A second disadvantage of hydraulic actuation is the lack of ability to directly determine the position of the component being actuated. First generation WFT&#39;s employed pre-test designs with fixed volume chambers to address this limitation. Some second generation WFT&#39;s employing hydraulic actuation techniques require complex sensing apparatus to determine pre-test volumes or to control mud-pump through-put volumes. Frequently, this lack of ability to accurately control the volume of fluid being pumped has resulted in tool designs that continue to include pre-test volume capabilities, even though this is approach is functionally redundant in combination with a mud-pump. 
         [0014]    A third disadvantage of hydraulically actuated mud-pumps is that the best commercially available axial piston pumps to pressurize hydraulic fluid do not provide adequate output volumes in the small diameter sizes that would be required to manufacture a high mud-pump capacity WFT of a small enough diameter to be suitable for slim boreholes. In this case it is hydraulic fluid output capacity that may become the overall limiting design constraint. 
         [0015]    A fourth disadvantage of hydraulically actuated mud-pumps is that inherent design difficulties exist in routing power and communication links through the electric motor and hydraulic pump sub-assembly. While hollow-shafted electric motors are commercially available, hollow bore hydraulic pumps are neither commercially available nor conceptually practical to design. For hydraulically actuated mud-pump designs, this restriction necessitates the routing of power and communication links around the outside of the electric motor and hydraulic pump sub-assembly. This in turn limits the maximum outer diameter of the motor and hydraulic pump sub-assembly, reducing its potential output power, as well as greatly complicating overall assembly and maintenance tasks. While this maximum outer diameter constraint may be mitigated by routing some of the power and communication lines through the motor stator windings rather than around the outside of the motor, such approach introduces additional difficulties due to line cross-talk and transient noise from motor switching, while it further increases assembly and maintenance complexity. 
         [0016]    Some of the other limitations of the currently available WFT&#39;s are described in the literature. WO97/08424 teaches a method of well testing and intervention that combines wireline with coiled tubing to overcome the fluid injection and discharge limitations of conventional WFT&#39;s. While the method in WO970848 might be an effective option, it is complex, costly and time consuming due to the need for large amounts of specialty surface equipment. 
         [0017]    A second example of a limitation of existing WFT mud-pumps can be found in U.S. Pat. No. 7,395,703, which teaches the use of a complex system of controls to overcome the limitations of pre-tests that are performed in variable test volumes. U.S. Pat. No. 7,395,703 does not indicate how such pre-testing might be done as part of a continuous, rather than a discrete process. 
         [0018]    A third example of a limitation of existing WFT mud-pumps can be found in U.S. Pat. No. 6,964,301, which teaches a method of formation sampling that uses two separate flow pathways. The first flow pathway is used to collect the sample while the second flow pathway, concentric around the first flow pathway at the inlet port, acts as a guard to limit the amount of drilling fluid filtrate entering into the first flow pathway. The intent of this arrangement is to minimize contamination of formation fluid samples. While this scheme might be partially effective, such a complex arrangement would not likely be necessary if a mud-pump of sufficient capacity were employed to ensure adequate cleanup of drilling fluid filtrate in the invaded zone prior to collecting the sample. 
         [0019]    A recent patent which discloses formation testing while connected to a pipe string, instead of a wireline, is U.S. Pat. No. 7,594,541 (Ciglenec et al) entitled “Pump Control for Formation Testing”. 
         [0020]    What is still needed, therefore, are simple downhole pumping techniques which make optimum use of the limited amount of power that can be supplied over wireline cables, while providing higher capacity output with pumping characteristics that are inherently useful for WFT&#39;s and that are designed in ways that make them amenable to deployment in smaller diameter formation test tools. 
       SUMMARY 
       [0021]    There is provided a high efficiency fluid pumping apparatus and methods having of an electronic motor controller controlling at least one electric motor that is directly coupled to the input of a hollow helical mechanism. The output of the hollow helical mechanism is directly coupled to the shaft of a reciprocating piston pump. Each moving component of the apparatus is designed with a hollow central bore, so that the apparatus assembly will accept a continuous, stationary, hollow conduit containing electrical through wiring and or fibre optics for power and communication to devices physically positioned below the apparatus. Check valves are provided to allow for pump intake and exhaust strokes and a 4-way valve is provided to permit the sources of the pump intake and exhaust to be reversed. 
         [0022]    In some embodiments the invention relates to a wireline formation test tool that includes a high efficiency downhole fluid pump. The wireline formation tester may be of a small diameter such as 3⅜″ outer diameter, or even smaller. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0023]    These and other features will become more apparent from the following description in which reference is made to the appended drawings. These drawings are for the purpose of illustration only and are not intended to be in any way limiting, wherein: 
           [0024]      FIG. 1  is a schematic cross-sectional view of one embodiment of a wireline formation test tool in which the present invention may be used. 
           [0025]      FIG. 2  is a schematic cross-sectional view of an alternative embodiment of a wireline formation test tool in which the present invention may be used. 
           [0026]      FIG. 3   a  is a is a schematic view of the electric motor section  300  of the embodiments of the wireline formation test tools of  FIG. 1  and  FIG. 2 . 
           [0027]      FIG. 3   b  is a schematic cross-sectional view of the electric motor section  300  of the embodiments of the wireline formation test tools of  FIG. 1  and  FIG. 2 . 
           [0028]      FIG. 4   a  is a schematic cross-sectional view of the hollow helical mechanism section  400  of the embodiments of the wireline formation test tools of  FIG. 1  and  FIG. 2 , shown at the upper limit of the range of its travel. 
           [0029]      FIG. 4   b  is a schematic cross-sectional view of the hollow helical mechanism section  400  of the embodiments of the wireline formation test tools of  FIG. 1  and  FIG. 2 , shown at the lower limit of the range of its travel. 
           [0030]      FIG. 5   a  is a schematic cross-sectional view of the reciprocating piston pump section  500  of the embodiments of the wireline formation test tools of  FIG. 1  and  FIG. 2 , shown at the upper limit of the range of its travel. 
           [0031]      FIG. 5   b  is a schematic cross-sectional view of the reciprocating piston pump section  500  of the embodiments of the wireline formation test tools of  FIG. 1  and  FIG. 2 , shown at the lower limit of the range of its travel. 
           [0032]      FIG. 6  shows a method in accordance with one embodiment of the invention. 
           [0033]      FIG. 7   a  is a schematic cross-sectional view of an embodiment of a planetary roller screw with a hollow central bore. 
           [0034]      FIG. 7   b  is a schematic cross-sectional view of an embodiment of a recirculating roller screw with a hollow central bore. 
           [0035]      FIG. 7   c  is a schematic cross-sectional view of an embodiment of a lead screw with a hollow central bore. 
       
    
    
     DETAILED DESCRIPTION 
       [0036]    In one or more embodiments, the invention relates to a high efficiency fluid pump that may be used in a downhole tool for formation evaluation or for well stimulation purposes. In some embodiments, the invention relates to methods for using a high efficiency fluid pump. In one or more embodiments, the invention relates to a wireline formation evaluation tool that includes a high efficiency fluid pump. The invention will now be described with reference to  FIG. 1  through  FIG. 7   
       Structure and Relationship of Parts: 
       [0037]      FIG. 1  shows one embodiment of the invention that relates to a wireline formation evaluation tool  100  that includes a high efficiency fluid pump. A borehole  101  is shown to have penetrated two impermeable geological formations  102 , in addition to a permeable geological formation  103 . In order to evaluate the reservoir characteristics of the permeable formation  103 , the wireline formation evaluation tool  100  is conveyed into borehole  101 , via wireline  110 , so that an upper hydraulic isolation packer  160  is positioned above the permeable formation  103  and a lower hydraulic isolation packer  162  is positioned below the permeable formation  103 . The spacing between the upper and lower packers may vary. The packers are shown in their activated position, where their sealing elements have been brought into contact with the borehole wall, in order to provide fluid isolation of the interval of the borehole between the packers. 
         [0038]    The wireline formation evaluation tool  100  further comprises an electronics section that includes a motor controller  120 ; an electrical motor section  300  that is more fully described in  FIG. 3   a  and  FIG. 3   b ; a hollow helical mechanism section  400  that is more fully described in  FIG. 4   a  and  FIG. 4   b ; a pump section  500  that is more fully described in  FIG. 5   a  and  FIG. 5   b ; an optional fluid sampling section  130 ; a fluid property measurement section  140 ; and an optional well stimulation fluid carrier section  170 . 
         [0039]    A first internal fluid pathway is connected to a 4-way valve  503  and passes through internal components, devices and valves appropriate to the optional tool configurations being employed. The first internal fluid pathway may be connected to a first external fluid port  161 , placing it in fluid communication with the isolated interval of borehole between the isolation packers, or in the alternative it may be connected to an internal chamber in the optional fluid sampling section  130  or to an internal chamber in the optional well stimulation fluid carrier section  170 . By changing the 4-way valve setting, the first internal fluid pathway can either be connected to the high efficiency fluid pump intake  501  or it can be connected to the high efficiency fluid pump exhaust  502 . A second internal fluid pathway is connected to the 4-way valve  503  and passes through internal tool components, devices and valves appropriate to the optional tool configurations being employed. The second internal fluid pathway may be connected to a second external fluid port  141 , placing it in fluid communication with the borehole annulus above upper hydraulic isolation packer  160 , or in the alternative it may be connected to an internal chamber in the optional fluid sampling section  130  or to an internal chamber in the optional well stimulation fluid carrier section  170 . Construction of the 4-way valve  503  is such that the second internal fluid pathway is connected to either the high efficiency fluid pump intake  501  or to the high efficiency fluid pump exhaust  502 , but in a manner opposite to that of the first internal fluid pathway. 
         [0040]      FIG. 2  shows an alternative embodiment of the invention that relates to a wireline formation evaluation tool  200  that includes a high efficiency fluid pump. A borehole  101  is shown to have penetrated two impermeable geological formations  102 , in addition to a permeable geological formation  103 . In order to evaluate the reservoir characteristics of the permeable formation  103 , a wireline formation evaluation tool  200  is conveyed into borehole  101 , via wireline  110 , so that a probe  250  is positioned at a point within the interval of the permeable formation  103 . 
         [0041]    The probe is shown in its extended position, where the sealing element has been brought into contact with the borehole wall, in order to provide fluid isolation of a small, essentially circular area of the borehole. The probe  250  is held firmly against the wall of the borehole by a backup arm or similar device  252 , also shown in the extended position. 
         [0042]    The wireline formation evaluation tool  200  further comprises an electronics section that includes a motor controller  120 ; an electrical motor section  300  that is more fully described in  FIG. 3   a  and  FIG. 3   b ; a hollow helical mechanism section  400  that is more fully described in  FIG. 4   a  and  FIG. 4   b ; a pump section  500  that is more fully described in  FIG. 5   a  and  FIG. 5   b ; an optional fluid sampling section  130 ; a fluid property measurement section  140 ; and an optional well stimulation fluid carrier section  170 . 
         [0043]    A first internal fluid pathway is connected to a 4-way valve  503  and passes through internal components, devices and valves appropriate to the optional tool configurations being employed. The first internal fluid pathway may be connected to a first external fluid port  251 , placing it in fluid communication with the isolated interval of borehole at the tip of the probe  250 , or in the alternative it may be connected to an internal chamber in the optional fluid sampling section  130  or to an internal chamber in the optional well stimulation fluid carrier section  170 . By changing the 4-way valve setting, the first internal fluid pathway can either be connected to the high efficiency fluid pump intake  501  or it can be connected to the high efficiency fluid pump exhaust  502 . A second internal fluid pathway is connected to the 4-way valve  503  and passes through internal tool components, devices and valves appropriate to the optional tool configurations being employed. The second internal fluid pathway may be connected to a second external fluid port  141 , placing it in fluid communication with the borehole annulus, or in the alternative it may be connected to an internal chamber in the optional fluid sampling section  130  or to an internal chamber in the optional well stimulation fluid carrier section  170 . Construction of the 4-way valve  503  is such that the second internal fluid pathway is connected to either the high efficiency fluid pump intake  501  or to the high efficiency fluid pump exhaust  502 , but in a manner opposite to that of the first internal fluid pathway. 
         [0044]      FIG. 3   a  is a schematic view of one embodiment of an electrical motor section  300 .  FIG. 3   b  is a corresponding schematic cross-sectional view of the same embodiment of an electrical motor section  300 . Other embodiments comprising at least one electrical motor are possible. Referring to  FIG. 3   b , an upper electrical motor  310  is comprised of a hollow motor shaft  312 , a permanent magnet rotor  313  and an electrically wound stator  314 . Similarly, a lower electrical motor  320  is comprised of a hollow motor shaft  322 , a permanent magnet rotor  323  and an electrically wound stator  324 . The upper hollow motor shaft  312  is mechanically coupled to the lower hollow motor shaft  322  by a hollow shaft coupler  315 . The mechanical output of the electrical motor section  300  is coupled to a hollow helical mechanism section  400  that is more fully described in  FIG. 4   a  and  FIG. 4   b , via a hollow shaft spider-coupler  330  and a hollow détente-ball torque limiter  340 . A hollow tubular conduit  350  is provided for electrical wiring and fibre optic connections of any devices positioned below the electrical motor section  300 . Construction of electrical motor section  300  is such that a single rotational position resolver  311  is able to provide rotational position feedback for both the upper electrical motor  310  and the lower electrical motor  320 . It will be recognized by those skilled in the art that this control arrangement can be easily extended to control a plurality of motors. 
         [0045]      FIG. 4   a  is a schematic cross-sectional view of an embodiment of a hollow helical mechanism section  400 , shown at the upper limit of the range of its travel.  FIG. 4   b  shows the same embodiment of a hollow helical mechanism section  400  at the lower limit of the range of its travel. A hollow helical screw  410  is held in position by roller bearings  411  and by roller thrust bearings  412 . A helical nut assembly  413  is prevented from rotating by guide sleeve  414  but is free to travel along the length of the hollow helical screw  410 . The internal central bore of the hollow helical mechanism  400  is designed to accept a hollow tubular conduit containing electrical wiring and fibre optic connections for any devices positioned below the hollow helical mechanism section. A hollow sleeve  415  and a hollow coupler  416  move with the helical nut assembly  413 , providing a means for connection to the reciprocating piston pump section that is more fully described in  FIG. 5   a  and  FIG. 5   b.    
         [0046]      FIG. 5   a  is a schematic cross-sectional view of an embodiment of a reciprocating piston pump section  500 , shown at the upper limit of the range of its travel.  FIG. 5   b  shows the same embodiment of a reciprocating piston pump section  500 , at the lower limit of the range of its travel. Pump body  501  forms a core upon which two intake check valves  523  and two exhaust check valves  513  are mounted. Each intake check valve  523  comprises an intake piston  520 , an intake piston seal  521 , and an intake return spring  522 . Fluid intake is provided via an intake fluid tube  524  and low profile intake elbow  525 . Each exhaust check valve  513  comprises an exhaust piston  510 , an exhaust piston seal  511 , and an exhaust return spring  512 . Fluid exhaust is provided via an exhaust fluid tube  514  and low profile exhaust elbow  515 . A reciprocating piston shaft  551  is disposed within the bore of a pressure tube  550  and provides a means of mounting for a piston assembly  540  and two opposing piston seals  541 . Both ends of the reciprocating piston shaft  551  are constrained to run through seal assemblies  530  and opposing rod seals  531 . A hollow tubular conduit  552  is provided for electrical wiring and fibre optic connections of any devices positioned below the reciprocating piston pump section  500 . 
         [0047]      FIG. 6  shows a method for operating a fluid pumping system  600  in accordance with one embodiment of the invention. The method first includes providing a downhole motor controller  601  with a desired motor torque reference value  602  or alternatively with a range of motor torque reference values. Similarly, the method includes providing the downhole motor controller  601  with a desired motor speed reference  603  or alternatively with a range of motor speed reference values. Utilizing the desired values for motor torque and motor speed, in conjunction with motor rotational position data supplied by the rotational position resolver  311 , the motor controller adjusts the characteristics of the power supplied to the electric motor section  300 . After taking into consideration the individual efficiencies of the electric motor section  300 , the hollow helical mechanism section  400 , and the reciprocating piston pump section  500 , precise control of desired pumping characteristics can be achieved. This arrangement eliminates any need of additional feed-back control loops such as those based on pump output pressure measurement or based on pump piston displacement measurement. In one embodiment, motor torque is held constant by the motor controller  601 , while motor speed is controlled within an acceptable range of values. After including calculated allowances for the efficiencies of all components of the high efficiency assembly  610 , this method of fluid pump control has the effect of providing control over pump output pressure within the range of the capacity of the pump, and without the need to measure pump output pressure directly. In a second embodiment, motor speed is held constant by the motor controller  601 , while motor torque is controlled within an acceptable range of valves. After including calculated allowances for the efficiencies of all components of the high efficiency assembly  610 , this method of fluid pump control has the effect of providing control over pump output rate, within the range of the capacity of the pump, and without the need to measure pump output rate directly. In a third embodiment, the electric motor section  300  is first started and then stopped after a desired time interval has elapsed or alternatively after a desired number of motor shaft revolutions has occurred, while both motor torque and motor speed are controlled within desired ranges of values. This method of pump control has the effect of providing control of discrete pump output volumes, at desired output pressures and at desired pump output rates, within the range of the capacity of the pump. 
         [0048]      FIG. 7   a  is a schematic cross-sectional view of an embodiment of a planetary roller screw  700  with a hollow central bore. Planetary roller screws with solid central cores are commercially available. A plurality of roller screws with helical splines on the outer surfaces thereof  704  are disposed between a nut  701  and a lead screw  705  comprising a helical spline on the outer surface thereof. Gear teeth are provided on each end of the roller screws to mate with two ring gears  702  while circumferential spacing of the plurality of roller screws is maintained by two spacer inserts  703 . 
         [0049]      FIG. 7   b  is a schematic cross-sectional view of an embodiment of a recirculating roller screw  710  with a hollow central bore. Recirculating roller screws with solid central cores are commercially available. A plurality of roller screws with circumferential grooves on the outer surfaces thereof  712  are disposed between a nut  711  and a lead screw  715  comprising a helical spline on the outer surface thereof. Engagement between the roller screw circumferential grooves and the lead screw helical spline is made possible through the use of even multiples of multi-start threading for the helical spline. Circumferential spacing of the plurality of roller screws is maintained by a roller cage  713  which is held in position by two retainers  714 . 
         [0050]      FIG. 7   c  is a schematic cross-sectional view of an embodiment of a lead screw  720  with a hollow central bore. Lead screws with solid central cores are commercially available. A nut  721  comprising a helical spline on the inner surface thereof is directly engaged with a lead screw  722  comprising a helical spline on the outer surface thereof. 
       Operation: 
       [0051]    Referring now to  FIG. 1  and to  FIG. 2 , in a first embodiment the high efficiency fluid pump intake  501  is brought into fluid communication with a hydraulically isolated area of the geological formation  103  via external fluid port  161 , while the high efficiency fluid pump exhaust  502  is brought into fluid communication with the borehole annulus via external fluid port  141 . This first embodiment permits fluid to be extracted from the formation  103  and expelled into the borehole annulus while pressure measurements are recorded. In a second embodiment the high efficiency fluid pump intake  501  is brought into fluid communication with the borehole annulus via external fluid port  141 , while the high efficiency fluid pump exhaust  502  is brought into fluid communication with a hydraulically isolated area of a geological formation  103  via external fluid port  161 . This second embodiment permits borehole fluid to be injected into the formation  103  while pressure measurements are recorded. In a third embodiment the high efficiency fluid pump intake  501  is brought into fluid communication with a hydraulically isolated area of a geological formation  103  via external fluid port  161 , while the high efficiency fluid pump exhaust  502  is brought into fluid communication with a sample chamber disposed in the optional fluid sampling section  130 . This third embodiment permits fluid to be extracted from the formation  103  and expelled into the sample chamber while pressure measurements are recorded. In a fourth embodiment the high efficiency fluid pump intake  501  is brought into fluid communication with a cushioning fluid contained in a first isolated volume in a fluid sample chamber disposed in the optional fluid sampling section  130 , while the high efficiency fluid pump exhaust  502  is brought into fluid communication with the borehole annulus via external fluid port  141 . This fourth embodiment permits the cushioning fluid to be extracted from the first isolated volume in the fluid sample chamber while formation fluid is simultaneously drawn into a second isolated volume in the sample chamber that is separated from the first isolated volume by means of a moveable piston. This arrangement permits the collection of formation fluid samples without the risk such formation fluid samples becoming contaminated through direct contact with internal pump components. In a fifth embodiment the high efficiency fluid pump intake  501  is brought into fluid communication with a stimulation fluid contained in a chamber disposed within the optional well stimulation fluid carrier section  170 , while the high efficiency fluid pump exhaust  502  is brought into fluid communication with a hydraulically isolated area of a geological formation  103  via external fluid port  161 . This fifth embodiment permits stimulation fluid to be injected into the formation  103  while pressure measurements are recorded. In a sixth embodiment the high efficiency fluid pump intake  501  is brought into fluid communication with the borehole annulus via external fluid port  141 , while the high efficiency fluid pump exhaust  502  is brought into fluid communication with a first isolated fluid chamber disposed within the optional well stimulation fluid carrier section  170 . This sixth embodiment permits borehole fluid to be expelled into the first isolated fluid chamber, while stimulation fluid contained within a second isolated fluid chamber that is separated from the first isolated volume by means of a moveable piston is simultaneously injected into the hydraulically isolated area of a geological formation  103 . This arrangement permits the handling of corrosive stimulation fluids such as acids without such corrosive fluids coming into direct contact with internal pump components. 
         [0052]    In all embodiments, the desired pumping parameters are determined and appropriate reference values or ranges of values for motor torque  602  and for motor speed  603  are calculated and transmitted by telemetry link to the downhole motor controller  601 . The downhole motor controller  601  may use a commercially available method of motor control such as “Field Oriented Control” or “Flux Vector Control” to regulate both motor torque and motor speed independently. After an acknowledgment that the reference values have been received by the motor controller  601  a command is sent to start the motor section  300 . On motor start up, the initial direction for motor rotation is determined by the position of the reciprocating piston assembly  540  in relation to the limits of its travel, and is selected to be the greater of the two available distances. Mechanical power from the output shaft of the motor assembly is transmitted via the spider coupler  330  and the détente ball torque limiter  340  to the lead screw  410  of the hollow helical mechanism  400 . The rotating lead screw  410  induces linear motion in the helical nut assembly  413  and consequently transmits this linear motion to the reciprocating piston shaft  551  which is connected to the helical nut assembly  413  by hollow coupler  416 . This linear movement of the reciprocating piston shaft  551  causes the piston assembly  540  to move within the bore of the pressure tube  550  resulting in the displacement of fluid. This fluid displacement causes an increase in fluid pressure on one side of the moving piston assembly  540 , defeating the exhaust return spring  512  of the exhaust valve  513  located on the higher pressure end of the pump to permit an exhaust of the pressurized fluid. Simultaneously, there is a drop in fluid pressure on the opposite side of the moving piston assembly  540 , defeating the intake return spring  522  of the intake valve  523  located on the lower pressure end of the pump to permit an intake of the unpressurized fluid. As a safety precaution against loss of communications, the motor controller  601  will only continue to operate the motor section  300  for a fixed period of time, unless it receives a further command to continue for another fixed period of time. This scheme has the effect of permitting semi-autonomous downhole motor control with a built in failsafe mechanism. Whenever the piston assembly  540  approaches the end of its permitted travel in either direction, the motor controller  601  applies a proprietary algorithm to decelerate motor speed to zero and then to reverse the direction of motor rotation and accelerate once again to the motor reference speed  603  or to the previous speed setting within the permissible range of values. Whenever the direction of travel of the piston assembly  540  changes, both intake check valves  523  and both exhaust check valves  513  change their state, opening or closing as required. As pumping progresses, pertinent data are transmitted from downhole to a surface display that can be viewed by the operator. Adjustments may be made to the motor torque  602  and motor speed  603  reference values by the operator and the new values may be sent downhole to the motor controller  601  in order to fine tune the characteristics of the pumping. At the conclusion of the pumping operation a stop command is sent to the downhole motor controller  601 . 
         [0053]    In this patent document, the word “comprising” is used in its non-limiting sense to mean that items following the word are included, but items not specifically mentioned are not excluded. A reference to an element by the indefinite article “a” does not exclude the possibility that more than one of the element is present, unless the context clearly requires that there be one and only one of the elements. 
         [0054]    The following claims are to be understood to include what is specifically illustrated and described above, what is conceptually equivalent, and what can be obviously substituted. Those skilled in the art will appreciate that various adaptations and modifications of the described embodiments can be configured without departing from the scope of the claims. The illustrated embodiments have been set forth only as examples and should not be taken as limiting the invention. It is to be understood that, within the scope of the following claims, the invention may be practiced other than as specifically illustrated and described.