SYSTEMS AND METHODS FOR DRIVING A SUBTERRANEAN PUMP

Abstract

Systems and methods for providing a pump driving unit for driving a subterranean pump. The pump driving unit utilizes a single prime mover and a drive train for actuating multiple components required to drive the subterranean pump. Some implementations of the pump driving unit include phase separation devices, filtering units, and cooling units that may also be actuated by the drive train of the unit. Some implementations of the pump driving unit further include an enclosure and a platform for containing the unit and simplifying on-site installation.

Description

BACKGROUND OF THE INVENTION

1. Field of the Invention

The present invention relates to reciprocating an natural gas/oil well down hole pump associated with a subterranean well. In particular, the present invention relates to systems and methods for providing a combination unit capable of driving a hydraulic portion of a subterranean pump system, as well as other components of the system, as required to produce the well.

2. Background and Related Art

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'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's surface. The most common system for pumping an oil well is by the installation of a pumping unit at the earth's surface that vertically reciprocates a travelling valve of a subsurface pump.

Traditionally, subsurface pumps have been reciprocated by a pumping device called a jack pump 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. However, such mechanical systems suffer from a number of inherent disadvantages or inefficiencies. For example, the substantial size and weight of the systems make them expensive to produce, difficult to transport, cumbersome to repair, expensive to install, and unsightly. Additional disadvantages include the substantial expense and environmental toll associated with their operation. For example, the substantial size and weight of current pumping devices requires a prime mover having excessive horsepower and torque. Furthermore, additional components of current well pumping systems, such as compressors and hydraulic pumps, require separate power sources, each power source requiring it's own energy source and producing its own emission.

Thus, while techniques currently exist that relate to driving subterranean pumps, challenges still exist. A need, therefore, exists for a 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

The present invention relates to reciprocating an oil or natural gas well pump associated with a subterranean well. In particular, the present invention relates to systems and methods for providing a combination unit capable of driving a hydraulic portion of a subterranean pump system, as well as other components of the system, as required.

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, 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 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 subterranean pump located within a subterranean well. For example, in one embodiment a single prime mover is used to drive both the subterranean pump and simultaneously perform other tasks, such as compressing the gas at the surface to move the lifted natural gas.

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 by the subterranean pump. 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.

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.

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.

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

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:

FIG. 1 is a perspective side view of a representative embodiment of the present invention;

FIG. 2 is a perspective top view of the combination unit of claim 1;

FIG. 3 is a cross-sectional view of a representative hydraulic line of an embodiment of the present invention; and

FIG. 4 is a perspective side view of a representative embodiment of the present invention.

DETAILED DESCRIPTION OF THE INVENTION

The present invention relates to reciprocating an oil well pump associated with a subterranean well. In particular, the present invention relates to systems and methods for providing a combination unit capable of driving a hydraulic portion of a subterranean pump system, as well as other components of the system, as required.

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.

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.

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 FIG. 4. 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.

In embodiments where the prime mover 20 is an electric motor, as shown in FIG. 4, 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, 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.

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'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 gerator 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.

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.

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.

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.

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.

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.

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 puller 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.

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.

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.

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.

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.

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.

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.

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.

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.

Claims

1. A combination pump driving unit, comprising:

a drive train having a jack shaft;

a master pulley coupled to the jack shaft;

a prime mover having a first pulley supported by a rotor;

a first belt interconnecting the first pulley and the master pulley;

a first slave pulley coupled to a first portion of the jack shaft;

a second slave pulley coupled to a second portion of the jack shaft;

a hydraulic pump having a second pulley supported by a rotor;

a compressor having a third pulley supported by a rotor;

a second belt interconnecting the second pulley and the first slave pulley;

a third belt interconnecting the third pulley and the second slave pulley, wherein the combination pump driving unit is coupled to a subterranean pump to drive the subterranean pump.

2. The combination unit of claim 1, further comprising a hydraulic line in fluid communication with the hydraulic pump and a hydraulic component of a subterranean pump.

3. The combination unit of claim 1, further comprising a gas line in fluid communication with the compressor and a wellhead.

4. The combination unit of claim 3, further comprising an oil-field separator in fluid communication with the gas line.

5. The combination unit of claim 3, further comprising a filtering unit in fluid communication with the gas line.

6. The combination unit of claim 1, wherein the prime mover is selected from the group consisting of a natural gas engine, a diesel engine, a petrol engine, a gas turbine, a water turbine, and an electric motor.

7. The combination unit of claim 3, further comprising a cooling unit in fluid communication with the gas line.

8. The combination unit of claim 1, further comprising an enclosure.

9. The combination unit of claim 1, further comprising a storage tank in fluid communication with the gas line.

10. The combination unit of claim 6, wherein the electric motor is powered by a battery.

11. The combination unit of claim 6, wherein the electric motor is powered by an alternate power source selected from the group consisting of a hydro-powered generator, a solar-powered generator, a wind-powered generator, and an electrical power line.

12. A method for driving a subterranean pump, the method comprising:

providing a pump driving unit having a drive train coupled to a prime mover;

coupling a hydraulic pump to a first portion of the drive train;

coupling a compressor to a second portion of the drive train;

providing fluid communication between the hydraulic pump and the subterranean pump via a hydraulic line;

providing fluid communication between a wellhead and the compressor via a gas line, wherein the subterranean pump is actuated by the hydraulic pump to artificially lift a substance through the wellhead and into the gas line, whereafter the substance is, separated and deposited into a holding tank; and

routing gas to the compressor, wherein the compressor is actuated by the prime mover via the drive train.

13. The method of claim 12, wherein the drive train comprises a jack shaft having a plurality of slave pulleys and wherein the hydraulic pump is coupled to the jack shaft via a first slave pulley and the compressor is coupled to the jack shaft via a second slave pulley.

14. The method of claim 13, further comprising the step of interposing an oil-field separator between the wellhead and the compressor via the gas line.

15. The method of claim 13, further comprising the step of interposing a filtering unit between the well head and the compressor via the gas line.

16. The method of claim 13, further comprising the step of collecting the compressed substrate in a storage tank in fluid communication with the compressor.

17. The method of claim 16, further comprising the step of interposing a cooling unit between the compressor and the storage tank via the gas line

18. The method of claim 17, further comprising the step of cooling the compressed substrate prior to collecting the compressed substrate in the storage tank.

19. The method of claim 18, further comprising the step of coupling the cooling unit to the drive train.

20. A pump driving unit, comprising:

a drive train having a jack shaft;

a master pulley coupled to the jack shaft;

a prime mover having a first pulley supported by a rotor;

a first belt interconnecting the first pulley and the master pulley;

a first slave pulley coupled to a first portion of the jack shaft;

a second slave pulley coupled to a second portion of the jack shaft;

a hydraulic pump having a second pulley supported by a rotor;

a compressor having a third pulley supported by a rotor;

a second belt interconnecting the second pulley and the first slave pulley;

a third belt interconnecting the third pulley and the second slave pulley;

a hydraulic line fluidly interconnecting the hydraulic pump and the subterranean pump; and

a gas line fluidly interconnecting a wellhead and the compressor, wherein the hydraulic pump drives the subterranean pump to artificially lift a substance to the wellhead, the substance being separated and routed to at least on of (i) a holding tank and (ii) the compressor.

21. The pump driving unit of claim 20, further comprising components selected from the group consisting of an oil-field separator, a filtering unit, a cooling unit, a generator, a battery, and an alternative power source.

22. A combination pump driving unit, comprising:

a prime mover;

a drive train directly coupled to both the prime mover and a plurality of drive components, the plurality of drive components being selected from the group consisting of: (a) a hydraulic pump; (b) a compressor; (c) a cooling unit; (d) a generator; (e) an alternator; (f) an alternate energy source; (g) an oil-field separator; and (h) a second prime mover

wherein the drive train actuates the plurality of drive components to simultaneously drive the down hole pump, recover a lifted substance, and store the lifted substance from a well associated with the down hole pump.

23. The combination unit of claim 22, wherein the compressor is a rotary screw compressor.