US20110268586A1 - Systems and methods for artificially lifting a product from a well - Google Patents
Systems and methods for artificially lifting a product from a well Download PDFInfo
- Publication number
- US20110268586A1 US20110268586A1 US13/081,974 US201113081974A US2011268586A1 US 20110268586 A1 US20110268586 A1 US 20110268586A1 US 201113081974 A US201113081974 A US 201113081974A US 2011268586 A1 US2011268586 A1 US 2011268586A1
- Authority
- US
- United States
- Prior art keywords
- unit
- pump
- hydraulic
- compressor
- pumping unit
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
Images
Classifications
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04B—POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
- F04B47/00—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps
- F04B47/02—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps the driving mechanisms being situated at ground level
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04B—POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
- F04B47/00—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps
- F04B47/02—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps the driving mechanisms being situated at ground level
- F04B47/04—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps the driving mechanisms being situated at ground level the driving means incorporating fluid means
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04B—POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
- F04B47/00—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps
- F04B47/12—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having free plunger lifting the fluid to the surface
Definitions
- the present invention relates to a low emission system for reciprocating a natural gas/oil well pumpjack associated with a subterranean well.
- 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.
- 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.
- 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.
- the present invention relates to reciprocating an oil or natural gas pumpjack associated with a subterranean well.
- 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.
- 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.
- 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.
- 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.
- 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.
- the filtration unit is interposed between the separator and the compressor to remove undesirable debris and particulate matter prior to compression.
- the cooling unit is interposed between the filtration unit and the storage tank to sufficiently cool the compressed natural gas prior to storage.
- the storage tank is provided to receive and store the lifted gases and liquids, as required by the unit.
- 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.
- 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.
- FIG. 4 is a perspective side view of a representative embodiment of the present invention.
- FIG. 5 is a perspective side view of a representative embodiment of a modular pump driving system of the present invention.
- FIG. 6 is a perspective side view of a representative embodiment of a combination pump driving system of the present invention.
- FIG. 7 is a perspective side view of a representative embodiment of a combination pump driving system of the present invention.
- FIG. 8 is a perspective view of representative embodiment of a direct drive pump driving unit in accordance with a representative embodiment of the present invention.
- the present invention relates to reciprocating an oil or natural gas pumpjack associated with a subterranean well.
- 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.
- 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 .
- the prime mover 20 may include any device capable of driving the drive train 50 of the unit 10 .
- the prime mover 20 is a natural gas powered engine having an exhaust pipe 28 .
- the prime mover 20 is an electric motor, as shown in FIGS. 4-7 .
- 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.
- 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.
- the prime mover 20 may be powered by any electric source producing sufficient wattage and amperage, as required.
- the prime mover 20 is hardwired to an electrical line 76 .
- 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).
- 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.
- the hydraulic pump 30 is a hydrostatic pump.
- the hydraulic pump 30 is hydrodynamic.
- the displacement of the pump is fixed, such that the displacement through the pump 30 cannot be adjusted.
- 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.
- 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.
- 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 .
- 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 .
- 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 .
- 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 .
- 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.
- the outer tubing 82 has an inner diameter of approximately 38 mm while the inner tubing has an inner diameter of approximately 19 mm.
- 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 FIG. 5 , below.
- 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 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.
- 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 .
- 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 .
- the collection tank 110 may comprise any size and dimensions necessary to accommodate the oil and gas production of the unit 10 .
- the collection tank 110 is an underground storage tank in fluid communication with the compressor 40 via the second gas line 92 .
- 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 .
- 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.
- 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 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 .
- 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 .
- 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.
- 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 may be fastened to the jack shaft 52 as desired in order to drive additional components (not shown) of the unit 10 .
- 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 .
- 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 gas prior to storing the gas in the storage tank 110 .
- 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.
- 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).
- 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
- 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.
- 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 .
- the fan 102 of the cooling system 100 is powered by generator 104 .
- 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 .
- fan 108 is driven by a hydraulic motor.
- any cooling system known in the art may be successfully coupled with the compressor.
- 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.
- 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.
- 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 .
- 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.
- 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.
- 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 .
- 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 .
- 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 .
- the combination unit 10 of the present invention overcomes the deficiencies inherent in the prior art.
- 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 prime 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 .
- the hydraulic pump 30 is provided to drive a pump or pumping unit 210 associated with a subterranean well.
- 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 .
- 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 .
- the pumping unit 210 generally comprises machinery and apparatus configured to lift oil or gas from a subterranean well via a wellhead 12 .
- 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.
- 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 .
- the belt 226 rotates the pulley portion 240 of the counter weight 222 to rotate the counter weight 222 .
- 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 vertically within the wellhead 12 to produce the well.
- the hydraulic motor 230 is actuated by the hydraulic pump 30 via hydraulic lines 80 a and 80 b .
- 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 .
- hydraulic lines 80 a and 80 b are spliced and coupled to multiple pumping units 210 .
- one pump driving unit 200 is utilized to drive multiple pumping units 210 .
- hydraulic lines 80 a and 80 b are coupled to separate piece of equipment that is hydraulically driven but not a pumping unit 210 .
- hydraulic lines 80 a and 80 b are coupled to a subterranean pump.
- hydraulic lines 80 a and 80 b are coupled to a hydraulic drill.
- hydraulic lines 80 a and 80 b may be coupled to any hydraulic system both within and without the oil industry.
- the integrated unit 300 combines a pump driving unit 200 and a pumping unit 210 onto a single skid 72 .
- 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 .
- 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 .
- 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 .
- integrated pump driving unit 400 combines a pump driving unit 200 and a pumping unit 210 onto a single skid 72 .
- integrated unit 400 comprises a hydraulic pump 30 that is coupled to the jack shaft 52 via a belt or chain 62 .
- 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 .
- the hydraulic driven unit 402 may include any hydraulically driven motor, pump, or device capable of driving a jackpump 212 .
- the hydraulic driven unit 402 comprises a hydraulic motor, similar to those discussed in connection with FIG. 5 above.
- the hydraulic driven unit 402 comprises a second hydraulic pump.
- the hydraulic driven unit 402 comprises a hydraulic gear reducer.
- the hydraulic driven unit 402 may be used to accomplish tasks in addition to driving the pumpjack unit 212 .
- the hydraulic driven unit 402 is utilized to drive both the pumpjack unit 212 and a compressor.
- the hydraulic driven unit 402 is utilized to drive both the pumpjack unit 212 and a subterranean pump.
- unit 500 comprises a prime mover 20 having an extended shaft or rotor 23 that is rotatably driven by the prime mover 20 .
- Prime mover 20 may comprise any electric or petrol powered motor or engine, as previously discussed.
- a portion of rotor 23 extends outwardly from prime mover 20 to operably intersect a first hydraulic pump 30 .
- first hydraulic pump 30 is directly driven by rotor 23 or prime mover 20 .
- hydraulic pump 30 is hydraulically coupled to a hydraulic motor 230 of a separate pumping unit 210 via hydraulic lines 80 a and 80 b , in accordance with previously discussed embodiments.
- pumping unit 210 is driven by hydraulic motor 230 which is hydraulically driven by hydraulic pump 30 , wherein hydraulic pump 30 is directly driven by prime mover 20 via rotor 23 . Accordingly, some embodiments of the present invention enable production of a pumping unit via a single prime mover 20 , without requiring a system of belts and pulleys, as taught in some of the previous embodiments.
- pumping unit 210 comprises any form of hydraulically-driven artificial lift. Further, in some embodiments pumping unit 210 comprises at least one of an above-ground pump, a subterranean pump, and/or combinations thereof.
- direct drive pump unit 500 further comprises a second hydraulic pump 31 which is further driven by prime mover 20 via rotor 23 .
- hydraulic pump 31 is hydraulically coupled to a hydraulic motor 231 of a remotely located processing unit 550 via hydraulic lines 81 a and 81 b.
- Hydraulic motor 231 is directly coupled to a compressor 40 .
- Compressor 40 may include any type of compressor or device capable of compressing a product artificially lifted from well 12 .
- compressor 40 comprises a rotary screw compressor.
- compressor 40 comprises a vain compressor.
- compressor 40 comprises a reciprocating compressor.
- processing unit 550 further comprises in input scrubber or filtering unit 552 in fluid communication with well 12 and compressor 40 via gas line 90 .
- processing unit 550 further comprises in input scrubber or filtering unit 552 in fluid communication with well 12 and compressor 40 via gas line 90 .
- processing unit 550 further comprises an inline cooling unit 100 whereby the compressed product is cooled prior to storing the product or sending the product to a pipeline 111 via gas line 92 .
- processing unit 550 further comprises an outlet scrubber or filtering unit 554 which further filters and/or processes the compressed and cooled product prior to storage.
- Direct drive pump unit 500 may further include additional hydraulic units 33 or other devices that are further driven by prime mover 20 via extended rotor 23 .
- direct drive pump unit 500 further comprises a plurality of additional units 33 for driving additional pumping units and/or cooling units (not shown), in accordance with the present invention.
- additional unit 33 further comprises a device for executing a function related to artificially lifting a product from well 12 , as described above.
- additional unit 33 comprises greater than five additional units, each unit being operated by prime mover 20 via extended rotor 23 .
- Some embodiments of the present system further include an enclosure, wherein each component 500 , 550 and 210 is independently enclosed, in accordance with an enclosure as described above.
- the direct drive pump unit 500 of the present invention enables a user to utilize a single prime mover 20 to artificially lift a product from a well 12 remotely located from the direct drive pump unit 500 . Further, the direct drive pump unit 500 enables a user to utilize a single prime mover 20 to process an artificially lifted product at a processing unit 550 located remotely from the direct drive pump unit 500 .
- the direct drive pump unit 500 may be safely used in combination with a pumping unit 210 and a processing unit 550 in accordance with safety rules and regulations within the oil and gas industries.
- the present invention utilizes a direct drive system that is compliant with class I, division II regulations, as known in the art.
Abstract
Systems and methods for providing a pump driving unit for driving an above ground pump. The pump driving unit utilizes a single prime mover and a drive train for actuating multiple components required to drive the above ground 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
- This application is a continuation in part of co-pending utility application Ser. No. 12/495,926 filed Jul. 1, 2010, entitled “SYSTEM AND METHODS FOR DRIVING A PUMPJACK” which 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”, both of which are incorporated herein by reference, in their entireties.
- 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.
- 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 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.
- 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.
- 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.
- 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.
- 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.
- 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 natural 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.
- 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 ofclaim 1; -
FIG. 3 is a cross-sectional view of a representative hydraulic line of an embodiment of the present invention; -
FIG. 4 is a perspective side view of a representative embodiment of the present invention; -
FIG. 5 is a perspective side view of a representative embodiment of a modular pump driving system of the present invention; -
FIG. 6 is a perspective side view of a representative embodiment of a combination pump driving system of the present invention; -
FIG. 7 is a perspective side view of a representative embodiment of a combination pump driving system of the present invention; and -
FIG. 8 is a perspective view of representative embodiment of a direct drive pump driving unit in accordance with a representative embodiment of the present invention. - 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.
- 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 combinationpump driving unit 10 is shown. Thecombination unit 10 generally comprises aprime mover 20, ahydraulic pump 30, and acompressor 40, as shown. Additionally, thecombination unit 10 comprises adrive train 50 whereby theprime mover 20 actuates thevarious components unit 10. - Referring now to
FIGS. 1 and 2 , theprime mover 20 may include any device capable of driving thedrive train 50 of theunit 10. For example, in one embodiment theprime mover 20 is a natural gas powered engine having anexhaust pipe 28. In another embodiment, theprime mover 20 is an electric motor, as shown inFIGS. 4-7 . In some embodiments, theprime 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, theprime mover 20 further comprises arotor 22 extending outwardly from the body of theprime mover 20. Therotor 22 is positioned and configured so as to compatibly receive apulley 24, discussed in detail below. - In embodiments where the
prime mover 20 is an electric motor, as shown inFIG. 4-7 , theprime mover 20 may be powered by any electric source producing sufficient wattage and amperage, as required. For example, in one embodiment theprime mover 20 is hardwired to anelectrical line 76. In another embodiment, theprime mover 20 is powered by abattery 96 via apower cord 98. Thebattery 96 may include any battery commonly known in the art including galvanic cells, electrolytic cells, fuel cells, and voltaic piles. Additionally, thebattery 96 may comprise primary batteries or secondary batteries, as required by theunit 10. Where thebattery 96 comprises secondary batteries, thebattery 96 may be recharged by applying electrical current to thebattery 96 via a chargingsource 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, thebattery 96 is charged via a generator or alternator (not shown) that is driven by thedrive train 50 of the unit. - Additional components of the unit may include a
hydraulic pump 30 and acompressor 40. Thehydraulic 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 thehydraulic pump 30 is a hydrostatic pump. In another embodiment thehydraulic pump 30 is hydrodynamic. In one embodiment where thehydraulic pump 30 is hydrostatic, the displacement of the pump is fixed, such that the displacement through thepump 30 cannot be adjusted. In another embodiment where thehydraulic pump 30 is hydrostatic, the displacement of the pump is variable, such that the displacement through thepump 30 is adjustable. Additional embodiments of thehydraulic 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 thehydraulic 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, thehydraulic 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 thewellhead 12 and is accessible via thehydraulic 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. Thehydraulic pump 30 is fluidly coupled to thehydraulic port 14 via ahydraulic line 80. Thehydraulic line 80 is provided to circulate hydraulic fluid from thehydraulic pump 30 to the subterranean pump via thehydraulic port 14 andwellhead 12. - Referring now to
FIG. 3 , a cross-sectional view of an implementation of thehydraulic line 80 is shown. Thehydraulic line 80 comprises anouter tubing 82 and aninner tubing 84, theinner tubing 84 being entirely encased within theouter tubing 82. Theinner tubing 84 comprises alumen 88 of sufficient diameter to permit flow of hydraulic fluid to the subterranean pump. As such, theinner tubing 84 acts as an egress line from thehydraulic pump 30. Similarly, theouter tubing 82 comprises aninner lumen 86 of sufficient diameter to both house theinner tubing 84 and permit flow of hydraulic fluid from the subterranean pump to thehydraulic pump 30. As such, theouter tubing 82 acts as an ingress line into thehydraulic pump 30. The diameters of theouter tubing 82 and theinner 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 theouter tubing 82 has 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 thewellhead 12, the hydraulic cylinder, and thehydraulic pump 30 may be modified to accommodate multiple hydraulic lines in place of the combinationhydraulic line 80, as disclosed and shown in connection withFIG. 5 , below. - Referring again to
FIGS. 1 and 2 , theunit 10 further comprises acompressor 40. Thecompressor 40 is a well known component in the art of oil production, and is provided to compress hydrocarbon gases following extraction from the well. Thecompressor 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 thecompressor 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 thewellhead 12 via agas line 90 and then compress the gas to optimize natural gas production and increase flow from the well. Thegas 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 thecompressor 40 is directed into thegas line 90 and subsequently drawn into thecompressor 40. Following compression, the compressed gas exits thecompressor 40 through asecond gas line 92 and is deposited into a pipeline or a storage container orcollection tank 110. One of skill in the art will appreciate that thecollection tank 110 may comprise any size and dimensions necessary to accommodate the oil and gas production of theunit 10. For example, in one embodiment thecollection tank 110 is an underground storage tank in fluid communication with thecompressor 40 via thesecond gas line 92. - With continued reference to
FIGS. 1 and 2 , thevarious components unit 10 are actuated by theprime mover 20 via thedrive train 50. Thedrive train 50 generally comprises a system of interconnected pulleys and belts to link theprime mover 20 to the remainingcomponents unit 10. However, in some implementations of the present invention, thedrive train 50 is directly coupled to the drivingcomponents unit 10 without the use of a jack shaft or pulleys. As illustrated, the central feature of thedrive train 50 is ajack shaft 52, as best shown inFIG. 2 . Thejack shaft 52 is generally located at a central position between the various components of theunit 10. Thejack shaft 52 generally comprises a steel or otherwise metallic material rod having a length sufficient to accommodate the various positions of the components of theunit 10. Thejack shaft 52 is rotatably secured to theenclosure 70 or theskid 72 by means of astator 74. A set of bearings (not shown) is interposed between thestator 74 and thejack shaft 52 so as to permit rotation of thejack shaft 52 relative to thestator 74. - The
jack shaft 52 further comprises amaster pulley 54 fixedly attached to thejack shaft 52 at a position approximately in the same plane as arotor 22 andpulley 24 of theprime mover 20. Themaster pulley 54 and thepulley 24 of theprime mover 20 are interconnected via a belt orchain 26, thereby forming aprimary section 60 of thedrive train 50. As configured, the torque of theprime mover 20 is transferred to themaster pulley 54 via thepulley 24 andbelt 26 thereby causing thejack shaft 52 to rotate relative to thestators 74. One of ordinary skill in the art will appreciate that by varying the sizes of themaster pulley 54 and theprime mover 20pulley 24, the relative rotations per minute of thejack shaft 52 may be adjusted to accommodate the needs of theunit 10. Additionally or alternatively, the relative rotations per minute of thejack shaft 52 may be altered by varying the rotations per minute of theprime mover 20, as commonly understood in the art. - In addition to the
master pulley 54, thejack shaft 52 further comprises a plurality of slave pulleys 56 and 58. The slave pulleys 56 and 58 are fixedly attached to thejack shaft 52 at a position generally in the same plane as anadjacent component slave pulley 56 is interconnected to theadjacent pulley 32 of thehydraulic pump 30 via the belt orchain 34 thereby forming asecondary section 62 of thedrive train 50. Theslave pulley 58 is interconnected to theadjacent pulley 42 of thecompressor 40 via the belt orchain 44 thereby forming atertiary section 64 of thedrive train 50. Additional slave pulleys (not shown) may be fastened to thejack shaft 52 as desired in order to drive additional components (not shown) of theunit 10. As configured, theprime mover 20 drives both thehydraulic pump 30 and thecompressor 40 via thejack shaft 52 and the various belts and pulleys of thedrive train 50. - Referring now to
FIG. 4 , various additional features may be included to enhance the functionality of theunit 10. For example, as compression of the gas naturally increases the temperature of the gas, in one embodiment thecompressor 40 is used in combination with aninline cooling unit 100. Theinline cooling unit 100 is located on thesecond gas line 92 between thecompressor 40 and thestorage tank 110 so as to cool the gas prior to storing the gas in thestorage tank 110. In one embodiment, thecooling unit 100 comprises a plurality of coils (not shown) and afan 102, whereby the compressed gas is circulated through the plurality of coils and thefan 102 draws air through the coils thereby cooling the compressed gas. In another embodiment, thecooling unit 100 comprises a first set of coils (not shown), a second set of coils (not shown), afan 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 thefan 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, thecompressor 40 is further modified to include anelectric generator 104 that is driven by thetertiary section 64 of thedrive train 50. As such, thefan 102 of thecooling system 100 is powered bygenerator 104. In an alternate embodiment, an additional pulley (not shown) is attached to thejack shaft 52 at a position adjacent thefan 108, whereby thejack shaft 52 and thefan 108 are interconnected via a belt orchain 112 which drives thefan 108 in accordance with thecooling system 100. Further, in someembodiments fan 108 is driven by a hydraulic motor. 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 thecompressor 40 and thecooling 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 afiltering unit 122. The oil-field separator 120 is commonly used in the oil industry and may include any device capable of reducingwellhead 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 astock tank 124 or series of tanks interposed between thewellhead 12 thecompressor 40. Thestock tank 124 may further comprise a plurality of vents orvalves 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 thecompressor 40, as shown. Thefiltering unit 122 is provided to further homogenize the gaseous material entering thecompressor 40 by removing debris or other unwanted materials. In some implementations of the current invention, thefiltering 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 anyfiltering unit 122 suitable to achieve the purpose of thecombination unit 10. - Referring now to
FIGS. 1 , 2 and 4, some embodiments of thecombination unit 10 further comprises anenclosure 70, shown in phantom. Theenclosure 70 may include any portion of theunit 10 and may also be configured to enclosure thewellhead 12, as shown inFIG. 4 . Theenclosure 70 is generally provided to prevent interference with the components and drivetrain 50 of theunit 10. Therefore, in one embodiment theenclosure 70 substantially and individually covers thedrive train 50 and eachcomponent unit 10. In another embodiment, theenclosure 70 substantially covers theunit 10 as a whole. In yet another embodiment, theenclosure 70 comprises a steel mesh thereby allowing ventilation for the various components of theunit 10, yet preventing tampering therewith. Finally, in one embodiment a portion of theenclosure 70 is substantially solid to protect theunit 10 from the elements. - The
combination unit 10 may also include a platform orskid 72 upon which the various components of theunit 10 are situated and supported. As such, theunit 10 is portable and may initially be built off site and then installed at thewellhead 12 location. Theskid 72 generally comprises a material, such as steel, and structure sufficient to withstand the weight of theindividual components skid 72 is configured to compatibly receive and support theenclosure 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. Theunit 10 is solely driven by theprime mover 20, which may be powered by any source deemed necessary, as described above. Theprime mover 20 is interconnected with thedrive train 50 of the unit via apulley 24 and abelt 26. Thedrive train 50 comprises ajack shaft 52 having amaster pulley 54 coupled to thebelt 26, and a plurality of slave pulleys 56 and 58 each being coupled tovarious components belts jack shaft 52 and thepulleys prime mover 20. As such, the slave pulleys 56 and 58 drive theirrespective components components hydraulic pump 30 is driven thereby providing a circulation of hydraulic fluid to the hydraulic components of the subterranean pump, as described above. Thecompressor 40 is driven thereby providing sufficient compression to the gaseous material from thewellhead 12, effecting a phase change prior to storage in thestorage tank 110. As configured, the singleprime mover 20 is sufficient to drive all of the components of theunit 10, which in turn drives the subterranean pump associated with thewellhead 12. Thus, thecombination unit 10 of the present invention overcomes the deficiencies inherent in the prior art. - Referring now to
FIG. 5 , thecombination unit 10 may be bisected to provide a modular pump-drivingsystem 200 and aseparate pumping unit 210. The pump-drivingsystem 200 generally comprises aprime mover 20 configured to drive adrive train 50, as previously disclosed. Thedrive train 50 comprises a plurality of pulleys and belts that are positioned to transfer torque from theprime mover 20 to the individual components of the pump-drivingsystem 200. The components of the pump-drivingsystem 200 include, but are not limited to, acompressor 40 and ahydraulic pump 30. As previously discussed, thehydraulic pump 30 is provided to drive a pump orpumping unit 210 associated with a subterranean well. In some embodiments,hydraulic lines hydraulic pump 30 to facilitate ingress and egress of hydraulic fluid between thehydraulic pump 30 and hydraulic components of thepumping unit 210. In some embodiments,hydraulic lines end couplings 180 that are adapted to permanently or temporarily couple thehydraulic lines pumping unit 210. - The
pumping unit 210 generally comprises machinery and apparatus configured to lift oil or gas from a subterranean well via awellhead 12. Referring toFIG. 5 , some implementations of the present invention include apumping unit 210 having apumpjack 212. Apumpjack 212, also known as a walking beam pump or a nodding donkey pump, generally includes ascaffold 214 pivotally coupled to abeam 216. Thebeam 216 comprises a first end that is pivotally coupled to apitman arm 220 which in turn is pivotally coupled to acounter weight 222. Thebeam 216 further comprises a second end that is fixedly coupled to ahead 218, also known as a horse head. Thehead 218 is further coupled to asucker line 224 which accesses the subterranean well via thewellhead 12. Specifics regarding the operation and mechanics of pumpjack are well known in the art. - In some embodiments of the present invention, the
counter weight 222 of thepumpjack 212 is coupled to ahydraulic motor 230 via a chain orbelt 226. Thehydraulic motor 230 is configured to drive apulley 232 which in turn drives or rotates apulley portion 240 of thecounter weight 222. Thepulley portion 240 of thecounter weight 222 is rotationally secured to astator 250 via arotor 252. As thepulley 232 of thehydraulic motor 230 rotates, thebelt 226 rotates thepulley portion 240 of thecounter weight 222 to rotate thecounter weight 222. As thecounter weight 222 rotates, thepitman arm 220 pivots thebeam 216 relative to thescaffold 214. The pivoting action of thebeam 216 causes thesucker line 224 to move vertically within thewellhead 12 to produce the well. - The
hydraulic motor 230 is actuated by thehydraulic pump 30 viahydraulic lines hydraulic lines pumping unit 210 relative to the position of thepump driving system 200. In other embodiments,hydraulic lines multiple pumping units 210. As such, onepump driving unit 200 is utilized to drive multiple pumpingunits 210. Alternatively, in some embodimentshydraulic lines pumping unit 210. For example, in some embodimentshydraulic lines hydraulic lines hydraulic lines - Referring now to
FIG. 6 , an integrated pump driving unit andpumping unit 300 is shown. Theintegrated unit 300 combines apump driving unit 200 and apumping unit 210 onto asingle skid 72. As such,hydraulic lines chain 62. The belt orchain 62 directly links the torque of thejack shaft 52 to thepulley 232 of agear reducer 310. Thegear reducer 310 further comprises acrank arm 312 having a first end that is directly coupled to a system of gears within thegear reducer 310. The crank arm further includes a second end that is directly coupled to thecounter weight 222 of thepumpjack 212. Thus, as thejack shaft 52 rotates under the power of theprime mover 20, thepulley 232 of thegear reducer 310 is rotated at a determined speed. Gears (not shown) within thegear reducer 310 are configured to reduce the rotational speed of thepulley 232 to achieve a desired rotational speed for thecrank arm 312. As thecrank arm 312 rotates, thecounterweight 222 rotates which moves thepitman arm 220 thereby transferring the rotation of thecrank arm 312 and thecounterweight 222 into a linear motion that drives thepumpjack 212. - Referring now to
FIG. 7 , an integratedpump driving unit 400 is shown. Theintegrated unit 400 combines apump driving unit 200 and apumping unit 210 onto asingle skid 72. However, unlikeintegrated unit 300,integrated unit 400 comprises ahydraulic pump 30 that is coupled to thejack shaft 52 via a belt orchain 62. Additionally,integrated unit 400 includeshydraulic lines hydraulic pump 30 to a hydraulic drivenunit 402. Hydraulic drivenunit 402 is provided to convert the hydraulic pressure fromhydraulic lines counterweight 222 of thepumpjack 212. One of skill in the art will appreciate that the hydraulic drivenunit 402 may include any hydraulically driven motor, pump, or device capable of driving ajackpump 212. For example, in some embodiments the hydraulic drivenunit 402 comprises a hydraulic motor, similar to those discussed in connection withFIG. 5 above. In other embodiments, the hydraulic drivenunit 402 comprises a second hydraulic pump. Finally, in some embodiments the hydraulic drivenunit 402 comprises a hydraulic gear reducer. - One of skill in the art will appreciate that the hydraulic driven
unit 402 may be used to accomplish tasks in addition to driving thepumpjack unit 212. For example, in some embodiments the hydraulic drivenunit 402 is utilized to drive both thepumpjack unit 212 and a compressor. In other embodiments, the hydraulic drivenunit 402 is utilized to drive both thepumpjack unit 212 and a subterranean pump. - Referring now to
FIG. 8 , a direct drive pump driving unit 500 is shown. In some embodiments, unit 500 comprises aprime mover 20 having an extended shaft orrotor 23 that is rotatably driven by theprime mover 20.Prime mover 20 may comprise any electric or petrol powered motor or engine, as previously discussed. In some embodiments, a portion ofrotor 23 extends outwardly fromprime mover 20 to operably intersect a firsthydraulic pump 30. Thus, firsthydraulic pump 30 is directly driven byrotor 23 orprime mover 20. - In some embodiments,
hydraulic pump 30 is hydraulically coupled to ahydraulic motor 230 of aseparate pumping unit 210 viahydraulic lines embodiments pumping unit 210 is driven byhydraulic motor 230 which is hydraulically driven byhydraulic pump 30, whereinhydraulic pump 30 is directly driven byprime mover 20 viarotor 23. Accordingly, some embodiments of the present invention enable production of a pumping unit via a singleprime mover 20, without requiring a system of belts and pulleys, as taught in some of the previous embodiments. - In some embodiments, pumping
unit 210 comprises any form of hydraulically-driven artificial lift. Further, in someembodiments pumping unit 210 comprises at least one of an above-ground pump, a subterranean pump, and/or combinations thereof. - In some embodiments, direct drive pump unit 500 further comprises a second
hydraulic pump 31 which is further driven byprime mover 20 viarotor 23. In some embodiments,hydraulic pump 31 is hydraulically coupled to ahydraulic motor 231 of a remotely located processingunit 550 viahydraulic lines 81 a and 81 b. -
Hydraulic motor 231 is directly coupled to acompressor 40.Compressor 40 may include any type of compressor or device capable of compressing a product artificially lifted from well 12. In some embodiments,compressor 40 comprises a rotary screw compressor. In other embodiments,compressor 40 comprises a vain compressor. Further, in someembodiments compressor 40 comprises a reciprocating compressor. - In some embodiments, processing
unit 550 further comprises in input scrubber orfiltering unit 552 in fluid communication with well 12 andcompressor 40 viagas line 90. Thus, a product lifted from the well 12 by thepumping unit 210 first passed throughfiltering unit 552 and then delivered to thecompressor 40, whereincompressor 40 compresses the product prior to cooling the lifted the product. - In some embodiments, processing
unit 550 further comprises aninline cooling unit 100 whereby the compressed product is cooled prior to storing the product or sending the product to a pipeline 111 viagas line 92. In some embodiments, processingunit 550 further comprises an outlet scrubber orfiltering unit 554 which further filters and/or processes the compressed and cooled product prior to storage. - Direct drive pump unit 500 may further include additional
hydraulic units 33 or other devices that are further driven byprime mover 20 viaextended rotor 23. For example, in some embodiments direct drive pump unit 500 further comprises a plurality ofadditional units 33 for driving additional pumping units and/or cooling units (not shown), in accordance with the present invention. In other embodiments,additional unit 33 further comprises a device for executing a function related to artificially lifting a product from well 12, as described above. Still further, in some embodimentsadditional unit 33 comprises greater than five additional units, each unit being operated byprime mover 20 viaextended rotor 23. Some embodiments of the present system further include an enclosure, wherein eachcomponent - The direct drive pump unit 500 of the present invention enables a user to utilize a single
prime mover 20 to artificially lift a product from a well 12 remotely located from the direct drive pump unit 500. Further, the direct drive pump unit 500 enables a user to utilize a singleprime mover 20 to process an artificially lifted product at aprocessing unit 550 located remotely from the direct drive pump unit 500. Thus, the direct drive pump unit 500 may be safely used in combination with apumping unit 210 and aprocessing unit 550 in accordance with safety rules and regulations within the oil and gas industries. For example, in some embodiments the present invention utilizes a direct drive system that is compliant with class I, division II regulations, as known in the 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 (23)
1. A pump driving system, comprising:
a direct drive pump driving unit comprising a prime mover having a rotating shaft operably coupled to a first hydraulic pump and a second hydraulic pump;
a pumping unit remotely located from the direct drive remote pump driving unit, a hydraulic motor of the pumping unit being hydraulically coupled to the first hydraulic pump, the hydraulic motor of the pumping unit further being operably coupled to an artificial lift whereby the hydraulic motor of the pumping unit drives the artificial lift;
a processing unit remotely located from the direct drive remote pump driving unit and from the pumping unit, a hydraulic motor of the cooling unit further being operably coupled to a compressor of the cooling unit, wherein a lifted material from the pumping unit is process through the cooling unit prior to being stored.
2. The system of claim 1 , further comprising a hydraulic line hydraulically coupling the first hydraulic pump and the second hydraulic pump to the hydraulic motor of the pumping unit and the hydraulic motor of the processing unit, respectively.
3. The system of claim 1 , further comprising a gas line in fluid communication with the compressor and a wellhead.
4. The system of claim 3 , further comprising an oil-field separator in fluid communication with the gas line.
5. The system of claim 3 , further comprising an inlet scrubber in fluid communication with the gas line.
6. The system 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 system of claim 3 , further comprising a cooling unit in fluid communication with the gas line.
8. The system of claim 1 , further comprising an enclosure surrounding at least one of the direct drive pump driving unit, the pumping unit, and the processing unit.
9. The system of claim 1 , further comprising a pipeline in fluid communication with the gas line.
10. The system of claim 6 , wherein the electric motor is powered by a battery.
11. The system 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, a geothermal powered generator, and an electrical power line.
12. A method for driving an above ground pump, the method comprising:
providing a direct drive pump driving unit comprising a prime mover having a rotating shaft operably coupled to a first hydraulic pump and a second hydraulic pump;
operably coupling the first hydraulic pump to a hydraulic motor of a remotely located pumping unit, wherein the prime mover drives the hydraulic motor of the remotely located pumping unit via the first hydraulic pump to artificially lift a product from a well;
operably coupling the second hydraulic pump to a hydraulic motor of a remotely located processing unit, wherein the prime mover drives the hydraulic motor of the remotely located processing unit via the second hydraulic pump, and wherein the hydraulic motor of the remotely located processing unit drives a compressor of the processing unit to compress the lifted product from the well;
providing fluid communication between the well and the compressor via a gas line, wherein the pumping unit is actuated by the prime mover via the first hydraulic pump to artificially lift the product from the well and into the gas line, whereafter the product is compressed by compressor, the compressor being actuated by the prime mover via the second hydraulic pump and the hydraulic motor of the remotely located processing unit.
13. The method of claim 12 , further comprising the steps of:
hydraulically coupling the first hydraulic pump to the hydraulic motor of the remotely located pumping unit via a first hydraulic line; and
hydraulically coupling the second hydraulic pump to the hydraulic motor of the remotely located processing unit via a second hydraulic line.
14. The method of claim 13 , further comprising the step of interposing an inlet scrubber between the well and the compressor via the gas line.
15. The method of claim 13 , further comprising the step of interposing an outlet scrubber between the compressor and the pipeline via the gas line.
16. The method of claim 13 , further comprising the step of collecting the compressed product in at least one of a storage tank and a pipeline in fluid communication with the compressor.
17. The method of claim 16 , further comprising the step of cooling the compressed product prior to collecting the compressed product in at least one of the storage tank and the pipeline.
18. The method of claim 17 , wherein the compressor is at least one of a rotary screw compressor, a vain compressor, and a reciprocating compressor.
19. The method of claim 12 , wherein the pumping unit is at least one of an above-ground pumping unit and a subterranean pumping unit.
20. A modular pumping unit, comprising:
a direct drive pump driving unit comprising a prime mover having an extended rotating shaft operably coupled to a first hydraulic pump and a second hydraulic pump;
a pumping unit remotely located from the direct drive pump driving unit, a hydraulic motor of the pumping unit being hydraulically coupled to the first hydraulic pump, the hydraulic motor of the pumping unit being hydraulically coupled to the first hydraulic pump, the hydraulic motor of the pumping unit further being operably coupled to an artificial lift whereby the hydraulic motor of the pumping unit drives the artificial lift to lift a product from a well.
21. The modular pumping unit of claim 20 , further comprising a processing unit remotely located from the direct drive pump driving unit and further remotely located from the pumping unit, wherein the processing unit comprises a hydraulic motor that is operably coupled to the second hydraulic pump, wherein the hydraulic motor of the processing unit drives at least one component selected from the group consisting of a compressor, an oil-field separator, an inlet scrubber, an outlet scrubber, a filtering unit, a cooling unit, a generator, a battery, and an alternative power source.
22. The modular pumping unit of claim 20 , wherein the artificial lift is at least one of an above ground pump and a subterranean pump.
23. The modular pumping unit of claim 21 , further comprising a gas line fluidly interconnecting the well and the compressor, wherein the first hydraulic pump drives the hydraulic motor of the artificial lift to artificially lift the product from the well, through the gas line, and to the compressor fluidly coupled thereto.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/081,974 US20110268586A1 (en) | 2008-08-29 | 2011-04-07 | Systems and methods for artificially lifting a product from a well |
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/202,108 US20100054966A1 (en) | 2008-08-29 | 2008-08-29 | Systems and methods for driving a subterranean pump |
US12/495,926 US20100054959A1 (en) | 2008-08-29 | 2009-07-01 | Systems and methods for driving a pumpjack |
US13/081,974 US20110268586A1 (en) | 2008-08-29 | 2011-04-07 | Systems and methods for artificially lifting a product from a well |
Related Parent Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/495,926 Continuation-In-Part US20100054959A1 (en) | 2008-08-29 | 2009-07-01 | Systems and methods for driving a pumpjack |
Publications (1)
Publication Number | Publication Date |
---|---|
US20110268586A1 true US20110268586A1 (en) | 2011-11-03 |
Family
ID=44858393
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US13/081,974 Abandoned US20110268586A1 (en) | 2008-08-29 | 2011-04-07 | Systems and methods for artificially lifting a product from a well |
Country Status (1)
Country | Link |
---|---|
US (1) | US20110268586A1 (en) |
Cited By (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20120048543A1 (en) * | 2010-08-27 | 2012-03-01 | Joseph Fink | Method and Apparatus for Removing Liquid from a Gas Producing Well |
US20130126155A1 (en) * | 2010-08-27 | 2013-05-23 | Cnx Gas Company Llc | Methods and Apparatus for Removing Liquid from a Gas Producing Well |
CN108691522A (en) * | 2018-07-30 | 2018-10-23 | 芜湖中淇节能科技有限公司 | A kind of energy-saving pumping unit |
US20190211663A1 (en) * | 2016-06-29 | 2019-07-11 | Thomas Kunkel | Slug Catcher Skid |
CN111927424A (en) * | 2020-09-25 | 2020-11-13 | 胜利油田高原石油装备有限责任公司 | Heavy hammer balanced type petroleum pumping unit |
US11415140B2 (en) * | 2017-05-19 | 2022-08-16 | Hoerbiger Service Inc. | Gas compressor unit for oil wells |
US20220260071A1 (en) * | 2016-09-02 | 2022-08-18 | Halliburton Energy Services, Inc. | Hybrid drive systems for well stimulation operations |
Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5199266A (en) * | 1991-02-21 | 1993-04-06 | Ugland Engineering A/S | Unprocessed petroleum gas transport |
US20110061873A1 (en) * | 2008-02-22 | 2011-03-17 | Conocophillips Company | Hydraulically Driven Downhole Pump Using Multi-Channel Coiled Tubing |
US7909585B2 (en) * | 2006-05-19 | 2011-03-22 | Lyle John Watts | Natural gas compressor and a system for operating the same |
-
2011
- 2011-04-07 US US13/081,974 patent/US20110268586A1/en not_active Abandoned
Patent Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5199266A (en) * | 1991-02-21 | 1993-04-06 | Ugland Engineering A/S | Unprocessed petroleum gas transport |
US7909585B2 (en) * | 2006-05-19 | 2011-03-22 | Lyle John Watts | Natural gas compressor and a system for operating the same |
US20110061873A1 (en) * | 2008-02-22 | 2011-03-17 | Conocophillips Company | Hydraulically Driven Downhole Pump Using Multi-Channel Coiled Tubing |
Cited By (15)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9856728B2 (en) * | 2010-08-27 | 2018-01-02 | Cnx Gas Company Llc | Method and apparatus for removing liquid from a gas producing well |
US20120048543A1 (en) * | 2010-08-27 | 2012-03-01 | Joseph Fink | Method and Apparatus for Removing Liquid from a Gas Producing Well |
US9359876B2 (en) * | 2010-08-27 | 2016-06-07 | Well Control Technologies, Inc. | Methods and apparatus for removing liquid from a gas producing well |
US9376895B2 (en) * | 2010-08-27 | 2016-06-28 | Well Control Technologies, Inc. | Method and apparatus for removing liquid from a gas producing well |
US20160281485A1 (en) * | 2010-08-27 | 2016-09-29 | Cnx Gas Company Llc | Methods and Apparatus for Removing Liquid from a Gas Producing Well |
US20170022794A1 (en) * | 2010-08-27 | 2017-01-26 | Well Control Technologies, Inc. | Method and Apparatus for Removing Liquid from a Gas Producing Well |
US20130126155A1 (en) * | 2010-08-27 | 2013-05-23 | Cnx Gas Company Llc | Methods and Apparatus for Removing Liquid from a Gas Producing Well |
US20190211663A1 (en) * | 2016-06-29 | 2019-07-11 | Thomas Kunkel | Slug Catcher Skid |
US10641076B2 (en) * | 2016-06-29 | 2020-05-05 | Thomas Kunkel | Slug catcher skid |
US11035215B2 (en) * | 2016-06-29 | 2021-06-15 | Tk Skids, Llc | Slug catcher skid |
US20220260071A1 (en) * | 2016-09-02 | 2022-08-18 | Halliburton Energy Services, Inc. | Hybrid drive systems for well stimulation operations |
US11808127B2 (en) * | 2016-09-02 | 2023-11-07 | Halliburton Energy Services, Inc. | Hybrid drive systems for well stimulation operations |
US11415140B2 (en) * | 2017-05-19 | 2022-08-16 | Hoerbiger Service Inc. | Gas compressor unit for oil wells |
CN108691522A (en) * | 2018-07-30 | 2018-10-23 | 芜湖中淇节能科技有限公司 | A kind of energy-saving pumping unit |
CN111927424A (en) * | 2020-09-25 | 2020-11-13 | 胜利油田高原石油装备有限责任公司 | Heavy hammer balanced type petroleum pumping unit |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US20110268586A1 (en) | Systems and methods for artificially lifting a product from a well | |
US11339769B2 (en) | Electric drive pump for well stimulation | |
US11635066B2 (en) | Electric drive pump for well stimulation | |
US20100054959A1 (en) | Systems and methods for driving a pumpjack | |
US6601651B2 (en) | Downhole gas compression | |
US20170051732A1 (en) | Pump system and method of starting pump | |
CN105408581A (en) | Integrated pump and compressor and method of producing multiphase well fluid downhole and at surface | |
CN106089617B (en) | A kind of drilling mud shaking pump | |
US10788029B2 (en) | Method and system for energy recovery from a rod pump | |
US5992517A (en) | Downhole reciprocating plunger well pump system | |
US6929064B1 (en) | Downhole pump | |
US20180334894A1 (en) | Gas pumping unit for oil wells | |
CN104564717B (en) | Direct driven high-speed turbine vacuum pump and operation method thereof | |
CN102536807B (en) | Raw oil lifting system and method for conveying fluid by utilizing sliding vane pump | |
US20100054966A1 (en) | Systems and methods for driving a subterranean pump | |
WO2020257350A1 (en) | Electrically-actuated linear pump system and method | |
JP7266589B2 (en) | Wind turbine generator with hydraulic pump | |
CN100390372C (en) | Underground reciprocating oil puming machine driven by rotary motor | |
US7717082B2 (en) | Prime mover with integral oil reservoir | |
CN202467779U (en) | Crude oil lifting system | |
CN2823597Y (en) | Linear motor double pumping oil pumping device for downhole | |
CN204041035U (en) | A kind of oil/gas well stimulation system | |
CN205243563U (en) | Exempt from electric power air cycle impeller | |
US11542799B2 (en) | Rod pump having a hydraulic cylinder and a variable speed reversible motor-generator | |
RU2426915C2 (en) | Booster pump station |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: SOONER B & B INC., NEW MEXICO Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:ROGERS, TRACY;MONTOYA, MATT;CROSBY, CURTIS;REEL/FRAME:026238/0259 Effective date: 20110413 |
|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |