Patent Document

1. RELATED APPLICATIONS 
       [0001]    This application is a continuation in part of co-pending utility application Ser. No. 12/202,108 filed Aug. 29, 2008, entitled “SYSTEMS AND METHODS FOR DRIVING A SUBTERRANEAN PUMP.” 
     
    
     BACKGROUND OF THE INVENTION 
       [0002]    1. Field of the Invention The present invention relates to a low emission system for reciprocating a natural gas/oil well pumpjack associated with a subterranean well. In particular, the present invention relates to systems and methods for providing modular and combination units capable of driving a hydraulic pump or motor which in turn drives a pumpjack, as well as other components of the system, as required to produce the well. The present invention further relates to systems and methods for providing modular and combinations unit capable of driving a subterranean pump associated with a subterranean well. 
         [0003]    2. Background and Related Art 
         [0004]    Oil wells typically vary in depth from a few hundred feet, to several thousand feet. In many wells there is insufficient subterranean pressure to force the oil and water to the earth&#39;s surface. For this reason, some system must be used to pump the crude oil, hydrocarbon gas, produced water and/or hydrocarbon liquids of the producing formation to the earth&#39;s surface. The most common system for pumping an oil well is by the installation of a pumping unit at the earth&#39;s surface that vertically reciprocates a travelling valve of a subsurface pump. 
         [0005]    Traditionally, subsurface pumps have been reciprocated by a pumping device called a pumpjack which operates by the rotation of an eccentric crank driven by a prime mover which may be an engine or an electric motor. A mechanical mechanism such as this has been utilized extensively in the oil and natural gas production industry for decades and continues to be a primary method for extracting oil from a well. 
         [0006]    In addition to lifting gas and/or oil from the producing formation, traditional pumping systems further provide means for separating, compressing, cooling, and storing materials recovered from the associated well. The function of lifting the gas and/or oil, combined with the additional functions of separating, compressing, cooling and storing the lifted materials requires the use of multiple prime movers, motors, generators, power supplies and the like. The various prime movers or motors each require fuel and maintenance, as well as produce emissions. Thus, such mechanical systems suffer from a number of inherent disadvantages or inefficiencies which are undesirable. 
         [0007]    While techniques currently exist that relate to driving a pumpjack, challenges still exist. A need, therefore, exists for a dynamic pump driving system that overcomes the current challenges. Accordingly, it would be an improvement in the art to augment or even replace current techniques with other techniques. 
       SUMMARY OF THE INVENTION 
       [0008]    The present invention relates to reciprocating an oil or natural gas pumpjack associated with a subterranean well. In particular, the present invention relates to systems and methods for providing a dynamic, combination unit capable of driving a hydraulic portion of a pumpjack system, as well as other components of the system, as required. The present invention further relates to driving a subterranean pump associated with a subterranean well. 
         [0009]    Implementation of the present invention takes place in association with an artificial lift system for recovery of oil and/or gas from a subterranean well. In some implementations, the combination pump drive includes a prime mover, a hydraulic pump or motor, and a compressor. The combination unit further includes a drive train having a jack shaft interconnected to a plurality of pulleys and belts whereby the single prime mover drives the various components of the combination unit. The combined configuration of the prime mover and the drive train eliminates the need for multiple prime movers or motors to operate the various components of the unit. Thus, a single prime mover is used to simultaneously and efficiently drive the components of the unit, which in turn drives the pumpjack associated within a subterranean well. For example, in one embodiment a single prime mover is used to drive both the pumpjack and simultaneously perform other tasks, such as compressing and cooling the gas at the surface prior to storage. 
         [0010]    In at least some implementations of the present invention, the combination unit includes an oil-field separator, a filtration unit, a cooling unit, and a storage tank. The oil-field separator is interposed between the wellhead and the compressor to separate the various phases of materials lifted from the subterranean well. In some implementations the filtration unit is interposed between the separator and the compressor to remove undesirable debris and particulate matter prior to compression. In still further implementations, the cooling unit is interposed between the filtration unit and the storage tank to sufficiently cool the compressed and liquefied gas prior to storage. The storage tank is provided to receive and store the lifted gases and liquids, as required by the unit. 
         [0011]    In at least some implementations, the combination unit further includes an enclosure and a platform to contain the various components of the system. Additional features may include a battery and/or an alternative energy source to power the prime mover during operation of the unit. 
         [0012]    While the methods, modifications and components of the present invention have proven to be particularly useful in the area oil and/or gas production, those skilled in the art will appreciate that the methods, modifications and components can be used in a variety of different artificial lift applications. 
         [0013]    These and other features and advantages of the present invention will be set forth or will become more fully apparent in the description that follows and in the appended claims. The features and advantages may be realized and obtained by means of the instruments and combinations particularly pointed out in the appended claims. Furthermore, the features and advantages of the invention may be learned by the practice of the invention or will be obvious from the description, as set forth hereinafter. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0014]    In order that the manner in which the above recited and other features and advantages of the present invention are obtained, a more particular description of the invention will be rendered by reference to specific embodiments thereof, which are illustrated in the appended drawings. Understanding that the drawings depict only typical embodiments of the present invention and are not, therefore, to be considered as limiting the scope of the invention, the present invention will be described and explained with additional specificity and detail through the use of the accompanying drawings in which: 
           [0015]      FIG. 1  is a perspective side view of a representative embodiment of the present invention; 
           [0016]      FIG. 2  is a perspective top view of the combination unit of claim  1 ; 
           [0017]      FIG. 3  is a cross-sectional view of a representative hydraulic line of an embodiment of the present invention; 
           [0018]      FIG. 4  is a perspective side view of a representative embodiment of the present invention; 
           [0019]      FIG. 5  is a perspective side view of a representative embodiment of a modular pump driving system of the present invention; 
           [0020]      FIG. 6  is a perspective side view of a representative embodiment of a combination pump driving system of the present invention; and 
           [0021]      FIG. 7  is a perspective side view of a representative embodiment of a combination pump driving system of the present invention. 
       
    
    
     DETAILED DESCRIPTION OF THE INVENTION 
       [0022]    The present invention relates to reciprocating an oil or natural gas pumpjack associated with a subterranean well. In particular, the present invention relates to systems and methods for providing a dynamic, combination unit capable of driving a hydraulic portion of a pumpjack system, as well as other components of the system, as required. The present invention further relates to driving a subterranean pump associated with a subterranean well. 
         [0023]    It is emphasized that the present invention, as illustrated in the figures and description herein, may be embodied in other forms. Thus, neither the drawings nor the following more detailed description of the various embodiments of the system and method of the present invention limit the scope of the invention. The drawings and detailed description are merely representative of examples of embodiments of the invention; the substantive scope of the present invention is limited only by the appended claims recited to describe the many embodiments. The various embodiments of the invention will best be understood by reference to the drawings, wherein like elements are designated by like alphanumeric character throughout. 
         [0024]    Referring now to  FIG. 1 , an implementation of a combination pump driving unit  10  is shown. The combination unit  10  generally comprises a prime mover  20 , a hydraulic pump  30 , and a compressor  40 , as shown. Additionally, the combination unit  10  comprises a drive train  50  whereby the prime mover  20  actuates the various components  30  and  40  of the unit  10 . 
         [0025]    Referring now to  FIGS. 1 and 2 , the prime mover  20  may include any device capable of driving the drive train  50  of the unit  10 . For example, in one embodiment the prime mover  20  is a natural gas powered engine having an exhaust pipe  28 . In another embodiment, the prime mover  20  is an electric motor, as shown in  FIGS. 4-6 . In some embodiments, the prime mover  20  comprises at least one of a gas turbine, a steam turbine, a water turbine, a diesel engine, and a petrol engine. In each embodiment, the prime mover  20  further comprises a rotor  22  extending outwardly from the body of the prime mover  20 . The rotor  22  is positioned and configured so as to compatibly receive a pulley  24 , discussed in detail below. 
         [0026]    In embodiments where the prime mover  20  is an electric motor, as shown in  FIG. 4-7 , the prime mover  20  may be powered by any electric source producing sufficient wattage and amperage, as required. For example, in one embodiment the prime mover  20  is hardwired to an electrical line  76 . In another embodiment, the prime mover  20  is powered by a battery  96  via a power cord  98 . The battery  96  may include any battery commonly known in the art including galvanic cells, electrolytic cells, fuel cells, and voltaic piles. Additionally, the battery  96  may comprise primary batteries or secondary batteries, as required by the unit  10 . Where the battery  96  comprises secondary batteries, the battery  96  may be recharged by applying electrical current to the battery  96  via a charging source  94 . The charging source may include any alternate source of electricity such as a wind-powered generator, a solar-powered generator, a hydro-powered generator, a geothermal-powered generator, or a generator powered by a second prime mover (not shown). In one embodiment, the battery  96  is charged via a generator or alternator (not shown) that is driven by the drive train  50  of the unit. 
         [0027]    Additional components of the unit may include a hydraulic pump  30  and a compressor  40 . The hydraulic pump  30  is well known in the art and in some embodiments may be modified to enhance the pump&#39;s operation or efficiency. For example, in one embodiment the hydraulic pump  30  is a hydrostatic pump. In another embodiment the hydraulic pump  30  is hydrodynamic. In one embodiment where the hydraulic pump  30  is hydrostatic, the displacement of the pump is fixed, such that the displacement through the pump  30  cannot be adjusted. In another embodiment where the hydraulic pump  30  is hydrostatic, the displacement of the pump is variable, such that the displacement through the pump  30  is adjustable. Additional embodiments of the hydraulic pump  30  include a gear pump, a gerotor pump, a rotary vane pump, a screw pump, a bent axis pump, an axial piston pump, a radial piston pump, and a peristaltic pump. In some embodiments, a jet pump (not shown) is substituted for the hydraulic pump  30 . 
         [0028]    The hydraulic pump  30  is provided to drive a hydraulic cylinder portion (not shown) of a down hole oil pump, or subterranean pump as commonly used in the oil industry. As such, the hydraulic pump  30  typically requires approximately 0-5000 psig to sufficiently drive the subterranean pump. Various forms and combinations of subterranean pumps are available and commonly used, as will be appreciated by one of ordinary skill in the art. For example, in one embodiment the subterranean pump includes a hydraulic cylinder portion that is located or enclosed within the wellhead  12  and is accessible via the hydraulic port  14 . In another embodiment, the subterranean pump includes a hydraulic cylinder portion that is located at the bottom of the well and is accessible via hydraulic lines connecting the hydraulic pump and the hydraulic cylinder. The hydraulic pump  30  is fluidly coupled to the hydraulic port  14  via a hydraulic line  80 . The hydraulic line  80  is provided to circulate hydraulic fluid from the hydraulic pump  30  to the subterranean pump via the hydraulic port  14  and wellhead  12 . 
         [0029]    Referring now to  FIG. 3 , a cross-sectional view of an implementation of the hydraulic line  80  is shown. The hydraulic line  80  comprises an outer tubing  82  and an inner tubing  84 , the inner tubing  84  being entirely encased within the outer tubing  82 . The inner tubing  84  comprises a lumen  88  of sufficient diameter to permit flow of hydraulic fluid to the subterranean pump. As such, the inner tubing  84  acts as an egress line from the hydraulic pump  30 . Similarly, the outer tubing  82  comprises an inner lumen  86  of sufficient diameter to both house the inner tubing  84  and permit flow of hydraulic fluid from the subterranean pump to the hydraulic pump  30 . As such, the outer tubing  82  acts as an ingress line into the hydraulic pump  30 . The diameters of the outer tubing  82  and the inner tubing  84  may be configured as needed to provide sufficient supply of hydraulic fluid to the hydraulic components of the subterranean pump. For example, in one embodiment the outer tubing  82  as an inner diameter of approximately 38 mm while the inner tubing has an inner diameter of approximately 19 mm. One of skill in the art will appreciate that the wellhead  12 , the hydraulic cylinder, and the hydraulic pump  30  may be modified to accommodate multiple hydraulic lines in place of the combination hydraulic line  80 , as disclosed and shown in connection with  FIGS. 5 and 6 , below. 
         [0030]    Referring again to  FIGS. 1 and 2 , the unit  10  further comprises a compressor  40 . The compressor  40  is a well known component in the art of oil production, and is provided to compress hydrocarbon gases into hydrocarbon liquids following extraction from the well. The compressor  40  may include any device capable of increasing the pressure of gas removed from the well by reducing the volume of the gas. For example, in one embodiment the compressor  40  includes at least one of a reciprocating compressor, a diaphragm compressor, a diagonal compressor, a mixed-flow compressor, an axial-flow compressor, a centrifugal compressor, a rotary screw compressor, a rotary vane compressor, and a scroll compressor. 
         [0031]    The compressor  40  is provided to draw gas from the wellhead  12  via a gas line  90  and then compress the gas to optimize natural gas production and increase flow from the well. The gas line  90  is generally configured to be in fluid communication with the wellhead such that any gas brought to the wellhead via suction provided by the compressor  40  is directed into the gas line  90  and subsequently drawn into the compressor  40 . Following compression, the compressed gas exits the compressor  40  through a second gas line  92  and is deposited into a pipeline or a storage container or collection tank  110 . One of skill in the art will appreciate that the collection tank  110  may comprise any size and dimensions necessary to accommodate the oil production of the unit  10 . For example, in one embodiment the collection tank  110  is an underground storage tank in fluid communication with the compressor  40  via the second gas line  92 . 
         [0032]    With continued reference to  FIGS. 1 and 2 , the various components  30  and  40  of the unit  10  are actuated by the prime mover  20  via the drive train  50 . The drive train  50  generally comprises a system of interconnected pulleys and belts to link the prime mover  20  to the remaining components  30  and  40  of the unit  10 . However, in some implementations of the present invention, the drive train  50  is directly coupled to the driving components  30  and  40  of the unit  10  without the use of a jack shaft or pulleys. As illustrated, the central feature of the drive train  50  is a jack shaft  52 , as best shown in  FIG. 2 . The jack shaft  52  is generally located at a central position between the various components of the unit  10 . The jack shaft  52  generally comprises a steel or otherwise metallic material rod having a length sufficient to accommodate the various positions of the components of the unit  10 . The jack shaft  52  is rotatably secured to the enclosure  70  or the skid  72  by means of a stator  74 . A set of bearings (not shown) is interposed between the stator  74  and the jack shaft  52  so as to permit rotation of the jack shaft  52  relative to the stator  74 . 
         [0033]    The jack shaft  52  further comprises a master pulley  54  fixedly attached to the jack shaft  52  at a position approximately in the same plane as a rotor  22  and pulley  24  of the prime mover  20 . The master pulley  54  and the pulley  24  of the prime mover  20  are interconnected via a belt or chain  26 , thereby forming a primary section  60  of the drive train  50 . As configured, the torque of the prime mover  20  is transferred to the master pulley  54  via the pulley  24  and belt  26  thereby causing the jack shaft  52  to rotate relative to the stators  74 . One of ordinary skill in the art will appreciate that by varying the sizes of the master pulley  54  and the prime mover  20  pulley  24 , the relative rotations per minute of the jack shaft  52  may be adjusted to accommodate the needs of the unit  10 . Additionally or alternatively, the relative rotations per minute of the jack shaft  52  may be altered by varying the rotations per minute of the prime mover  20 , as commonly understood in the art. 
         [0034]    In addition to the master pulley  54 , the jack shaft  52  further comprises a plurality of slave pulleys  56  and  58 . The slave pulleys  56  and  58  are fixedly attached to the jack shaft  52  at a position generally in the same plane as an adjacent component  30  and  40 . The slave pulley  56  is interconnected to the adjacent pulley  32  of the hydraulic pump  30  via the belt or chain  34  thereby forming a secondary section  62  of the drive train  50 . The slave pulley  58  is interconnected to the adjacent pulley  42  of the compressor  40  via the belt or chain  44  thereby forming a tertiary section  64  of the drive train  50 . Additional slave pulleys (not shown) may be fastened to the jack shaft  52  as desired in order to drive additional components (not shown) of the unit  10 . As configured, the prime mover  20  drives both the hydraulic pump  30  and the compressor  40  via the jack shaft  52  and the various belts and pulleys of the drive train  50 . 
         [0035]    Referring now to  FIG. 4 , various additional features may be included to enhance the functionality of the unit  10 . For example, as compression of the gas naturally increases the temperature of the gas, in one embodiment the compressor  40  is used in combination with an inline cooling unit  100 . The inline cooling unit  100  is located on the second gas line  92  between the compressor  40  and the storage tank  110  so as to cool the liquefied gas prior to storing the gas in the storage tank  110 . In one embodiment, the cooling unit  100  comprises a plurality of coils (not shown) and a fan  102 , whereby the compressed gas is circulated through the plurality of coils and the fan  102  draws air through the coils thereby cooling the compressed gas. In another embodiment, the cooling unit  100  comprises a first set of coils (not shown), a second set of coils (not shown), a fan  102 , and a coolant (not shown). As such, the first set of coils is submerged in the coolant, the compressed gas is circulated through the first set of coils, the coolant is circulated through the second set of coils, and the fan  102  forces or draws air through the second set of coils to remove excess heat from the second set of coils and the coolant. In another embodiment, the compressor  40  is further modified to include an electric generator  104  that is driven by the tertiary section  64  of the drive train  50 . As such, the fan  102  of the cooling system  100  is powered by generator  104 . In an alternate embodiment, an additional pulley (not shown) is attached to the jack shaft  52  at a position adjacent the fan  108 , whereby the jack shaft  52  and the fan  108  are interconnected via a belt or chain  112  which drives the fan  108  in accordance with the cooling system  100 . One of skill in the art will appreciate that any cooling system known in the art may be successfully coupled with the compressor. For example, in one embodiment the compressor  40  and the cooling unit  100  are combined into a single unit and are commercially available as such. 
         [0036]    Additional features may also include an oil-field separator  120  and a filtering unit  122 . The oil-field separator  120  is commonly used in the oil industry and may include any device capable of reducing wellhead  12  pressure so that dissolved gas associated with hydrocarbon liquids is flashed off or separated as a separate phase for compression, cooling and storage. The oil-field separator  120  generally comprises a stock tank  124  or series of tanks interposed between the wellhead  12  the compressor  40 . The stock tank  124  may further comprise a plurality of vents or valves  126  for diverting different phase materials into separate storage tanks or treatment processes. 
         [0037]    A filtering unit  122  may further be interposed between the oil-field separator  120  and the compressor  40 , as shown. The filtering unit  122  is provided to further homogenize the gaseous material entering the compressor  40  by removing debris or other unwanted materials. In some implementations of the current invention, the filtering unit  122  comprises a plurality of filtering units, the filtering units comprising varying sizes of porosity or filtering mediums to further homogenize the gas. One of skill in the art will appreciate that oil and gas filters are common in the gas and oil industry and therefore the present invention may be configured to utilize any filtering unit  122  suitable to achieve the purpose of the combination unit  10 . 
         [0038]    Referring now to  FIGS. 1 ,  2  and  4 , some embodiments of the combination unit  10  further comprises an enclosure  70 , shown in phantom. The enclosure  70  may include any portion of the unit  10  and may also be configured to enclosure the wellhead  12 , as shown in  FIG. 4 . The enclosure  70  is generally provided to prevent interference with the components and drive train  50  of the unit  10 . Therefore, in one embodiment the enclosure  70  substantially and individually covers the drive train  50  and each component  20 ,  30 ,  40 ,  96 ,  100 ,  110 ,  120  of the unit  10 . In another embodiment, the enclosure  70  substantially covers the unit  10  as a whole. In yet another embodiment, the enclosure  70  comprises a steel mesh thereby allowing ventilation for the various components of the unit  10 , yet preventing tampering therewith. Finally, in one embodiment a portion of the enclosure  70  is substantially solid to protect the unit  10  from the elements. 
         [0039]    The combination unit  10  may also include a platform or skid  72  upon which the various components of the unit  10  are situated and supported. As such, the unit  10  is portable and may initially be built off site and then installed at the wellhead  12  location. The skid  72  generally comprises a material, such as steel, and structure sufficient to withstand the weight of the individual components  20 ,  30 ,  40 ,  96 ,  100 ,  110 ,  120  as well as to provide a sturdy foundation upon which to support the components. In some embodiments, the skid  72  is configured to compatibly receive and support the enclosure  70 . 
         [0040]    The combination unit  10  of the present invention is provided to replace and/or augment current artificial lift systems, such as the jack pump. The unit  10  is solely driven by the prime mover  20 , which may be powered by any source deemed necessary, as described above. The prime mover  20  is interconnected with the drive train  50  of the unit via a pulley  24  and a belt  26 . The drive train  50  comprises a jack shaft  52  having a master pulley  54  coupled to the belt  26 , and a plurality of slave pulleys  56  and  58  each being coupled to various components  30  and  40  of the unit via belts  34  and  44 . The jack shaft  52  and the pulleys  54 ,  56 , and  58  coupled thereto are rotated by the prime mover  20 . As such, the slave pulleys  56  and  58  drive their respective components  30  and  40 , thereby providing the actuation necessary for the components  30  and  40  to perform their function. The hydraulic pump  30  is driven thereby providing a circulation of hydraulic fluid to the hydraulic components of the subterranean pump, as described above. The compressor  40  is driven thereby providing sufficient compression to the gaseous material from the wellhead  12 , effecting a phase change prior to storage in the storage tank  110 . As configured, the single prime mover  20  is sufficient to drive all of the components of the unit  10 , which in turn drives the subterranean pump associated with the wellhead  12 . Thus, the combination unit  10  of the present invention overcomes the deficiencies inherent in the prior art. 
         [0041]    Referring now to  FIG. 5 , the combination unit  10  may be bisected to provide a modular pump-driving system  200  and a separate pumping unit  210 . The pump-driving system  200  generally comprises a prime mover  20  configured to drive a drive train  50 , as previously disclosed. The drive train  50  comprises a plurality of pulleys and belts that are positioned to transfer torque from the prim e mover  20  to the individual components of the pump-driving system  200 . The components of the pump-driving system  200  include, but are not limited to, a compressor  40  and a hydraulic pump  30 . As previously discussed, the hydraulic pump  30  is provided to drive a pump or pumping unit  210  associated with a subterranean well. In some embodiments, hydraulic lines  80   a  and  80   b  are coupled to the hydraulic pump  30  to facilitate ingress and egress of hydraulic fluid between the hydraulic pump  30  and hydraulic components of the pumping unit  210 . In some embodiments, hydraulic lines  80   a  and  80   b  further include end couplings  180  that are adapted to permanently or temporarily couple the hydraulic lines  80   a  and  80   b  to a hydraulic portion of the pumping unit  210 . 
         [0042]    The pumping unit  210  generally comprises machinery and apparatus configured to lift oil or gas from a subterranean well via a wellhead  12 . Referring to  FIG. 5 , some implementations of the present invention include a pumping unit  210  having a pumpjack  212 . A pumpjack  212 , also known as a walking beam pump or a nodding donkey pump, generally includes a scaffold  214  pivotally coupled to a beam  216 . The beam  216  comprises a first end that is pivotally coupled to a pitman arm  220  which in turn is pivotally coupled to a counter weight  222 . The beam  216  further comprises a second end that is fixedly coupled to a head  218 , also known as a horse head. The head  218  is further coupled to a sucker line  224  which accesses the subterranean well via the wellhead  12 . Specifics regarding the operation and mechanics of pumpjack are well known in the art. 
         [0043]    In some embodiments of the present invention, the counter weight  222  of the pumpjack  212  is coupled to a hydraulic motor  230  via a chain or belt  226 . The hydraulic motor  230  is configured to drive a pulley  232  which in turn drives or rotates a pulley portion  240  of the counter weight  222 . The pulley portion  240  of the counter weight  222  is rotationally secured to a stator  250  via a rotor  252 . As the pulley  232  of the hydraulic motor  230  rotates, the belt  226  rotates the pulley portion  240  of the counter weight  222  to rotate the counter weight  222 . As the counter weight  222  rotates, the pitman arm  220  pivots the beam  216  relative to the scaffold  214 . The pivoting action of the beam  216  causes the sucker line  224  to move laterally within the wellhead  12  to produce the well. 
         [0044]    The hydraulic motor  230  is actuated by the hydraulic pump  30  via hydraulic lines  80   a  and  80   b . In some embodiments, hydraulic lines  80   a  and  80   b  span extensive lengths to permit remote placement of the pumping unit  210  relative to the position of the pump driving system  200 . In other embodiments, hydraulic lines  80   a  and  80   b  are spliced and coupled to multiple pumping units  210 . As such, one pump driving unit  200  is utilized to drive multiple pumping units  210 . Alternatively, in some embodiments hydraulic lines  80   a  and  80   b  are coupled to separate piece of equipment that is hydraulically driven but not a pumping unit  210 . For example, in some embodiments hydraulic lines  80   a  and  80   b  are coupled to a subterranean pump. In other embodiments, hydraulic lines  80   a  and  80   b  are coupled to a hydraulic drill. Finally, one of skill in the art will appreciate that hydraulic lines  80   a  and  80   b  may be coupled to any hydraulic system both within and without the oil industry. 
         [0045]    Referring now to  FIG. 6 , an integrated pump driving unit and pumping unit  300  is shown. The integrated unit  300  combines a pump driving unit  200  and a pumping unit  210  onto a single skid  72 . As such, hydraulic lines  80   a  and  80   b  are excluded from the design and replaced by a belt or chain  62 . The belt or chain  62  directly links the torque of the jack shaft  52  to the pulley  232  of a gear reducer  310 . The gear reducer  310  further comprises a crank arm  312  having a first end that is directly coupled to a system of gears within the gear reducer  310 . The crank arm further includes a second end that is directly coupled to the counter weight  222  of the pumpjack  212 . Thus, as the jack shaft  52  rotates under the power of the prime mover  20 , the pulley  232  of the gear reducer  310  is rotated at a determined speed. Gears (not shown) within the gear reducer  310  are configured to reduce the rotational speed of the pulley  232  to achieve a desired rotational speed for the crank arm  312 . As the crank arm  312  rotates, the counterweight  222  rotates which moves the pitman arm  220  thereby transferring the rotation of the crank arm  312  and the counterweight  222  into a linear motion that drives the pumpjack  212 . 
         [0046]    Referring now to  FIG. 7 , an integrated pump driving unit  400  is shown. The integrated unit  400  combines a pump driving unit  200  and a pumping unit  210  onto a single skid  72 . However, unlike integrated unit  300 , integrated unit  400  comprises a hydraulic pump  30  that is coupled to the jack shaft  52  via a belt or chain  62 . Additionally, integrated unit  400  includes hydraulic lines  80   a  and  80   b  coupling the hydraulic pump  30  to a hydraulic driven unit  402 . Hydraulic driven unit  402  is provided to convert the hydraulic pressure from hydraulic lines  80   a  and  80   b  into rotational movement which rotates the counterweight  222  of the pumpjack  212 . One of skill in the art will appreciate that the hydraulic driven unit  402  may include any hydraulically driven motor, pump, or device capable of driving a jackpump  212 . For example, in some embodiments the hydraulic driven unit  402  comprises a hydraulic motor, similar to those discussed in connection with  FIG. 5  above. In other embodiments, the hydraulic driven unit  402  comprises a second hydraulic pump. Finally, in some embodiments the hydraulic driven unit  402  comprises a hydraulic gear reducer. 
         [0047]    One of skill in the art will appreciate that the hydraulic driven unit  402  may be used to accomplish tasks in addition to driving the pumpjack unit  212 . For example, in some embodiments the hydraulic driven unit  402  is utilized to drive both the pumpjack unit  212  and a compressor. In other embodiments, the hydraulic driven unit  402  is utilized to drive both the pumpjack unit  212  and a subterranean pump. 
         [0048]    The present invention may be embodied in other specific forms without departing from its spirit or essential characteristics. The described embodiments are to be considered in all respects only as illustrative and not restrictive. The scope of the invention is, therefore, indicated by the appended claims rather than by the foregoing description. All changes that come within the meaning and range of equivalency of the claims are to be embraced within their scope.

Technology Category: 2