Classifications

• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
  • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
  • E21B43/121—Lifting well fluids
  • E21B43/128—Adaptation of pump systems with down-hole electric drives
• • 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
  • F04B23/00—Pumping installations or systems
  • F04B23/04—Combinations of two or more pumps
  • F04B23/08—Combinations of two or more pumps the pumps being of different types
  • F04B23/10—Combinations of two or more pumps the pumps being of different types at least one pump being of the reciprocating positive-displacement type
  • F04B23/106—Combinations of two or more pumps the pumps being of different types at least one pump being of the reciprocating positive-displacement type being an axial piston pump
• • 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
  • F04B23/00—Pumping installations or systems
  • F04B23/04—Combinations of two or more pumps
  • F04B23/08—Combinations of two or more pumps the pumps being of different types
  • F04B23/14—Combinations of two or more pumps the pumps being of different types at least one pump being of the non-positive-displacement type
• • 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
• • 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
  • F04B47/06—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
  • F04C—ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT PUMPS
  • F04C11/00—Combinations of two or more machines or pumps, each being of rotary-piston or oscillating-piston type; Pumping installations
  • F04C11/005—Combinations of two or more machines or pumps, each being of rotary-piston or oscillating-piston type; Pumping installations of dissimilar working principle
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
  • F04C—ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT PUMPS
  • F04C13/00—Adaptations of machines or pumps for special use, e.g. for extremely high pressures
  • F04C13/008—Pumps for submersible use, i.e. down-hole pumping
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
  • F04C—ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT PUMPS
  • F04C2/00—Rotary-piston machines or pumps
  • F04C2/08—Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing
  • F04C2/10—Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
  • F04D—NON-POSITIVE-DISPLACEMENT PUMPS
  • F04D13/00—Pumping installations or systems
  • F04D13/02—Units comprising pumps and their driving means
  • F04D13/06—Units comprising pumps and their driving means the pump being electrically driven
  • F04D13/08—Units comprising pumps and their driving means the pump being electrically driven for submerged use
  • F04D13/10—Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
  • F04D—NON-POSITIVE-DISPLACEMENT PUMPS
  • F04D13/00—Pumping installations or systems
  • F04D13/12—Combinations of two or more pumps
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
  • F04D—NON-POSITIVE-DISPLACEMENT PUMPS
  • F04D9/00—Priming; Preventing vapour lock
  • F04D9/04—Priming; Preventing vapour lock using priming pumps; using booster pumps to prevent vapour-lock

Definitions

• the present disclosure is directed to a system for artificially lifting fluid from a wellbore. More specifically, the present disclosure concerns pumping fluid from the wellbore with an electrical submersible pump (“ESP”), and pressurizing the fluid upstream of the ESP with a positive displacement pump.
• ESP electrical submersible pump
• ESP systems are deployed in some hydrocarbon producing wellbores to provide artificial lift to deliver fluids to the surface.
• ESP systems are also sometimes used to transfer fluids from a wellsite to other equipment or facility for further processing.
• the fluids are usually made up of hydrocarbon and water.
• a typical ESP system is suspended in the wellbore at the bottom of a string of production tubing.
• ESP systems are inserted directly into the production tubing.
• ESP systems usually include an electrically powered motor for driving the pump, and a seal section for equalizing pressure in the motor to ambient.
• Centrifugal pumps usually have a stack of alternating impellers and diffusers coaxially arranged in a housing along a length of the pump.
• the impellers each attach to a shaft that couples to the motor; rotating the shaft and impellers forces fluid through passages that helically wind through the stack of impellers and diffusers.
• the produced fluid is pressurized as it is forced through the helical path in the pump.
• the pressurized fluid is discharged from the pump and into the production tubing, where the fluid is then conveyed to surface for distribution downstream for processing.
• the fluid being pressurized by ESP systems has some percentage of gas or vapor entrained therein.
• ESP systems generally produce less head and become less efficient. Lowering pump head results in reduced pump discharge pressure and a drop in fluid being pumped by the ESP system.
• a high amount of gas or liquid in the produced fluid increases fluid pressure drop when flowing through the tubing, which further contributes to a reduction in the produced fluid flow rate.
• ESP systems are operationally limited by how much gas or vapor can be present in the downhole fluid being pressurized; and can experience vapor lock when the percentage of gas or vapor exceeds a threshold value. Occasionally, the upper limit of gas or vapor percentage in the produced fluid can approach around 30% by weight.
• Some of the conventional methods of tackling ESP gas problems include the use of gas separators, gas handlers, and helico-axial multiphase pumps.
• Some gas separators remove gas from the gas-liquid mixture into the tubing-casing annulus by centrifugal means, thereby reducing the amount of gas or vapor that actually enters the ESP system.
• Devices known as advanced gas handlers use centrifugal action to compress the gas before feeding the entire fluid into the ESP system.
• Helico-axial multiphase pumps have specially designed rotating impellers and diffusers that homogenize the gas and liquid phases prior to directing the coalesced gas- liquid mixture to the ESP system for pressurization.
• a limitation of conventional gas-handling systems is a high incremental cost to the total cost of the ESP string; and some systems have many internal components with moving parts, resulting in a complex system.
• an electrical submersible pumping (“ESP") system disposable in a wellbore that includes a gerotor pump with an inlet in communication with fluid in the wellbore, and an exit through which fluid pressurized in the gerotor pump is directed away from the gerotor pump.
• ESP electrical submersible pumping
• a centrifugal pump having an inlet in fluid communication with the exit of the gerotor pump, and a discharge in which fluid pressurized in the centrifugal pump is directed away from the centrifugal pump.
• the gerotor pump includes a body, an idler in the body having an axis, planar upper and lower surfaces, a curved outer side surface, and a chamber having profiled sidewalls that lobes at designated locations along a circumference of the chamber, and a rotor disposed in the chamber and having an axis, an outer circumference profiled to define gears that project radially outward, so that when the rotor is rotated about its axis, the gears contact the sidewall of the chamber at various locations to define sealing interfaces and define high and low pressure sides in the chamber.
• the rotor has n gears and the idler has n+1 lobes.
• the centrifugal pump is equipped with a series of diffusers, impellers disposed between adjacent diffusers, and a flow path extending through the diffusers and impellers, so that when the impellers are rotated, fluid is urged through the flow path and is pressurized with distance through the flow path.
• an end of the production tubing distal from the centrifugal pump couples with a wellhead assembly disposed at an opening of the wellbore.
• the fluid being pressurized by the gerotor pump can include a fluid having phases of liquid and gas or vapor.
• the ESP system optionally includes a motor section mechanically coupled with the gerotor pump and the centrifugal pump, a seal section in pressure communication with the motor so that a pressure in the motor section remains at substantially ambient pressure, and a monitoring sub coupled with the motor section.
• the centrifugal pump operates at an increased efficiency when pressurizing fluid from the discharge of the gerotor pump than when pressurizing fluid received from the wellbore.
• an electrical submersible pumping (“ESP") system disposable in a wellbore that is made up of a positive displacement pump with a suction port in communication with fluid in the wellbore, a pressurization chamber in communication with the inlet, and a discharge port in communication with the pressurization chamber and that is at a pressure that is greater than a pressure of the suction port of the positive displacement pump; and a centrifugal pump having a suction port in communication with the discharge of the positive displacement pump and a discharge port that is at a pressure greater than a pressure of the suction port of the centrifugal pump.
• ESP electrical submersible pumping
• the ESP system can further have production tubing with an end in communication with the discharge port of the centrifugal pump, and a distal end coupled to a wellhead assembly disposed at an opening of the wellbore.
• the positive displacement pump is a gerotor pump.
• the ESP system can include a motor mechanically coupled to the positive displacement pump and to the centrifugal pump, and a seal section in pressure communication with the motor, so that pressure in the motor is maintained substantially at ambient pressure when the motor is in the wellbore.
• a ratio of vapor or gas volume to liquid volume of the fluid is greater at the suction port of the positive displacement pump than at the suction port of the centrifugal pump, thereby increasing the operating efficiency of the centrifugal pump.
• Also disclosed herein is a method of pumping fluid produced from within a wellbore, where the method includes pressurizing an amount of the fluid having phases of liquid and gas or vapor, so that the gas or vapor in the fluid is compressed to thereby reduce a ratio of gas or vapor volume to liquid volume, directing the pressurized amount of the fluid to a centrifugal pump, and further pressurizing the pressurized amount of the fluid with the centrifugal pump.
• the step of pressurizing the amount of fluid having phases of liquid and gas or vapor can be performed using a positive displacement pump.
• the positive displacement pump is a gerotor pump.
• the fluid further pressurized by the centrifugal pump can be directed to a wellhead assembly disposed at an opening of the wellbore. Both the positive displacement pump and the centrifugal pump can be powered with a single motor.
• FIG. 1 is a partial sectional view of an example of an ESP system disposed in a wellbore.
• FIGS. 2A and 2B are sectional views of an example of a portion of the ESP system of Figure 1 having a positive displacement pump in combination with an centrifugal pump.
• FIG. 3 is a sectional view of an alternate example of positive displacement pump of Figure 2.
• FIG. 1 One example of an electrical submersible pump (“ESP") system 10 is shown in a partial side sectional view in Figure 1.
• the ESP system 10 is illustrated disposed in a wellbore 12 which intersects a subterranean formation 14.
• Tubular casing 16 lines the wellbore 12 and tubing 18 is inserted coaxially within the casing 16.
• the ESP system 10 includes a motor 20, a seal system 22 mounted on an upper end of motor 20, wherein seal system 22 equalizes pressure within motor 20 to ambient.
• a positive displacement pump 24 mounted on an end of seal system 22 distal from motor 20.
• a centrifugal pump 26 is shown mounted on an end of positive displacement pump 24 distal from seal system 22.
• monitoring sub 28 is included with ESP system 10, where monitoring sub may include sensors for sensing one or more of temperature, pressure, and vibration within wellbore 12.
• monitoring sub 28 may include a controller for sending and receiving control signals for controlling operations of ESP system 10.
• Perforations 30 are shown projecting radially outward from wellbore 12 through casing 16, and into formation 14. Perforations 30 provide a flow path for fluid entrained in the formation to make its way into the wellbore 12. Further in this example, openings 32 are formed through sidewalls of tubing 18 to allow wellbore fluid F produced from formation 14 to flow into tubing 18. After being directed into the tubing 18, the fluid F can be pressurized by artificial lift by ESP system 10. Optionally, a packer 34 is shown formed in the annulus 36 between tubing 18 and casing 16, and is used for directing the flow of fluid F into tubing 18. Fluid F enters into ESP system 10 via an inlet 38 formed on positive displacement pump 24.
• fluid F can then be directed to a centrifugal pump 26.
• a string of production tubing 40 is shown coupled to a discharge end of centrifugal pump 26.
• a packer 42 is disposed and which forms a flow barrier in the annular space 44 between ESP system 10 and the inner surface of tubing 18. Packer 42 thus forces fluid F flowing upwards within tubing 18 to make its way into inlet 38.
• an upper end of production tubing 40 terminates within a wellhead assembly 46 depicted positioned at an opening of wellbore 12 on surface 47.
• Piping within wellhead assembly 46 defines a production circuit 48 for selectively directing the fluid F within production tubing 40 to designated destinations.
• fluid F within production circuit 48 is directed to a transfer line 50 shown having a distal end terminating at a processing facility 52.
• processing facilities 52 include refineries, olefins plants, and other facilities that process the fluid F for transport. Examples of processing for transport includes removing constituents from the fluid F such as water, sulfur, and other undesirable elements.
• valves 54 are provided within production circuit 40 and transfer line 50 for selectively directing the flow of fluid F therethrough.
• FIG. 2A and 2B shown in a side sectional view is one example of an embodiment of the positive displacement pump 24A coupled with centrifugal pump 26A.
• a housing 56 which defines a cavity 58 therein.
• a piston 60 is disposed within cavity 58, and as shown by the double-headed arrow reciprocates axially in the cavity 58.
• a piston rod 62 connects to an end of piston 60, and selectively provides a motive force to reciprocate piston 60 within cavity 58.
• a compression chamber 64 is defined within cavity 58 on a side of piston 60 opposite from piston rod 62.
• fluid F from within wellbore 12 Figure 1 is within compression chamber 64.
• Fluid F of Figures 2A and 2B includes a two-phase mixture of liquid L and vapor V, where vapor V can include gas, vapor, or a mixture of both.
• fluid F is directed into compression chamber 64 via an inlet line 66, which has a distal end connecting to inlet 38 illustrated disposed on an outer surface of positive displacement pump 24A.
• inlet line 66 can be equipped with a check valve 68, so that during a compression cycle, fluid F cannot escape from cavity 58 back into inlet line 66.
• fluid F can have up to around 75% gas by volume or by mass, and examples exist wherein fluid F is around 100% vapor.
• centrifugal pump 26A includes a main body 72 through which a fluid flow path P helically courses from an inlet space 74 to an outlet space 76.
• Impellers 80 are shown disposed within pump body 72 and are intersected by path P.
• Diffusers 82 are sequentially spaced between impellers 80 and are also intersected by path P.
• a shaft 84 is shown that connects to the impellers 80, rotating shaft 84 correspondingly rotates impellers 80, that in turn exert a force on the fluid F that urges fluid F through the path P and pressurizes fluid F.
• FIG. 3 shows in a plan sectional view one example of the positive displacement pump 24B, wherein the pump 24B is the same as or similar to what is commonly referred to as a gerotor pump.
• pump 24B has an outer housing 56B and in which an idler 86 is disposed.
• Idler 86 of Figure 3 has generally planar upper and lower surfaces, and a curved outer circumference. Idler 86 is selectively rotated about an axis A X i with respect to housing 56B and as illustrated by arrow Ai.
• a rotor 88 shown rotatable about axis ⁇ 2, and in a direction illustrated by arrow A 2 .
• Discharge line 70 intersects a side of housing 56B distal from inlet 66.
• an idler chamber 90 Formed axially through a middle portion of idler 86 is an idler chamber 90 which has an undulating curved profile and which forms lobes 92i_5 at spaced apart angular locations around axis ⁇ . Although five lobes 92i_5 are shown in Figure 3, the number of lobes 92i_5 is not limited to five, but instead can be any other number.
• the outer circumference of rotor 88 is also profiled but semi-complementary to the idler chamber 90.
• the curved undulating circumference of the rotor 88 defines gears 94i_ 4 that selectively fit into the lobes 92i_5. As shown, the number of gears 94i_ 4 is one less than the number of lobes 92i_5.
• An inner surface of chamber 90 forms a chamber wall 96.
• gear 94 2 is in sealing contact with a location on the wall 96 proximate lobe 92 2
• gear 94 3 is in sealing contact with a location on the wall 96 proximate lobe 92 3
• gear 94 4 is in sealing contact with a location on the wall 96 proximate lobe 92 4 .
• the sealing contact between gears 94 2 , 94 3 and wall 96 forms an enclosed space in idler chamber 90 to define a lower pressure side 98.
• the sealing contact between gears 94 4 , 94 3 and wall 96 forms another enclosed space in idler chamber 90 to define a higher pressure side 100.
• Lower pressure side 98 is in fluid communication with inlet line 66 and higher pressure side 100 is in fluid communication with discharge line 70.
• Continuous rotation of both the idler 86 and rotor 88 causes the fluid initially trapped within the lower pressure side 98 to be compressed between the gears 94i_ 4 and sidewall 96 thereby pressurizing the fluid F prior to being discharged through the discharge line 70.
• One advantage of the gerotor pump illustrated in Figure 3 is that multiple phased fluids, i.e., those having a mixture of liquid and vapor and/or gas, can be efficiently pressurized irrespective of how compressible is the fluid F. As is known, the presence of gas, vapor, or both in the fluid F can increase compressibility of the fluid F. Accordingly, significant advantages are realized by incorporating the gerotor pump assembly with a centrifugal pump to increase the efficiency of the centrifugal pump. In one example, during gerotor rotation, due to the difference between the gears 94i_ 4 and lobes 92i_5, enlarging and decreasing cavities are created, such as illustrated by the higher pressure and lower pressure sides 98, 100.
• Inlet line 66 as shown is a single conduit to pumps 24A, 24B ( Figures 2A, 2B, and 3); in an example, multiple lines are provided to the pumps 24A, 24B, and the pumps 24A, 24B have multiple ports.
• the high pressure side of the pumps 24A, 24B communicates directly into a discharge chamber (not shown), which directly feeds into the suction of centrifugal pump 26A, 26B; in this alternate embodiment discharge line 70 is not included.
• a progressive cavity pump can be used as a pre-conditioning device, in lieu of a gerotor pump, and for conditioning fluid upstream of a centrifugal pump.

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• Engineering & Computer Science (AREA)
• Mechanical Engineering (AREA)
• General Engineering & Computer Science (AREA)
• Mining & Mineral Resources (AREA)
• Life Sciences & Earth Sciences (AREA)
• Geology (AREA)
• Physics & Mathematics (AREA)
• Environmental & Geological Engineering (AREA)
• Fluid Mechanics (AREA)
• General Life Sciences & Earth Sciences (AREA)
• Geochemistry & Mineralogy (AREA)
• Structures Of Non-Positive Displacement Pumps (AREA)

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• 2015
  • 2015-12-28 US US14/980,535 patent/US20170183948A1/en not_active Abandoned
• 2016
  • 2016-12-15 WO PCT/US2016/066843 patent/WO2017116732A1/en active Application Filing
  • 2016-12-15 CA CA3009492A patent/CA3009492A1/en not_active Abandoned
  • 2016-12-15 EP EP16823412.8A patent/EP3397834A1/de not_active Withdrawn
  • 2016-12-15 CN CN201680076897.3A patent/CN108474246B/zh not_active Expired - Fee Related

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