Pumping System

Abstract

Methods and systems for pumping a production fluid from a production zone to a collection point are described herein. The methods generally include disposing a tubing in the production zone of a wellbore; pumping the production fluid from the production zone through a first stage of a pumping system to achieve an inter-stage pressure sufficient for entry into a second stage; and pumping the production fluid at the inter-stage pressure through a second stage of the pumping system to achieve a lifting pressure sufficient to lift the production fluid to a collection point, wherein the second stage includes a jet pump.

Description

CROSS-REFERENCE TO RELATED APPLICATIONS

[0001] Not applicable.

STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT

[0002] Not applicable.

BACKGROUND

[0003] 1. Field of the Invention

[0004] The present invention generally relates to pumping systems. In particular, embodiments of the present invention relate to pumping systems for use within artificial lift systems.

[0005] 2. Related Art

[0006] This section introduces information from the art that may be related to or provide context for some aspects of the techniques described herein and/or claimed below. This information is background facilitating a better understanding of that which is disclosed herein. This is a discussion of "related" art. That such art is related in no way implies that it is also "prior" art. The related art may or may not be prior art. The discussion is to be read in this light, and not as admissions of prior art.

[0007] A variety of systems are known for producing fluids from subterranean geological formations. In formations providing sufficient pressure to force the fluids to the earth's surface, the fluids may be collected and processed without the use of artificial lifting systems. Where, however, well pressures are insufficient to raise fluids to the collection point, artificial means are often employed, which include pumping systems.

[0008] The particular configurations of an artificial lift pumping system may vary widely depending upon the well conditions, the geological formations present, and the desired completion approach. In general, however, such systems often include an electric motor driven by power supplied from the earth's surface. The motor is coupled to a pump (often referred to as a down-hole pump), which draws production fluids from a production zone and imparts sufficient head to force the fluids to the collection point. Such systems may include additional components especially adapted for the particular production fluids or mix of fluids, including gas/oil separators, oil/water separators, sand control devices and so forth.

[0009] One such artificial lift pumping system includes a centrifugal pump, such as an electrical submersible pumps (ESP), often disposed below the level of fluids. Centrifugal pumps generally include a motor section, a pump section and a motor protector to seal the clean motor oil from production fluids, and are deployed in a wellbore where they receive power via an electrical cable. Centrifugal pumps are generally capable of generating a large pressure boost sufficient to lift production fluids, even in ultra-deep water, low pressure subsea formations. However, centrifugal pumps are susceptible to free gas impact (interference when gas bubbles/free gas is present at the intake of the pump).

[0010] Furthermore, centrifugal pumps are sensitive to sands and other abrasive solids that may be present in the production fluid. The amount of sand which is produced from a well depends on characteristics of the formation and various methods are used to control sand production. However, it is common for some amount of sand or abrasive solids to be present in the production fluid. ESPs are particular sensitive to sand presence due to the nature of their internal components.

[0011] In addition, problems can arise when the pump is shut down after a period of pumping fluid up production tubing to the collection point. On pump shutdown, flow ceases very quickly as the fluid levels in the wellbore and the annulus equalize. Gravity acting on the sand particles present in the column of fluid above the pump causes the sand and any other solids to fall back towards the pump. Due to the complex configuration of the interior features of the pump, there is no direct path for the sand to pass through the pump and therefore it tends to settle on the internal working components of the pump. This can cause the pump to become plugged or cause damage, leading to premature failure of the pump.

[0012] The present invention is directed to resolving, or at least reducing, one or all of the problems mentioned above.

SUMMARY

[0013] Various embodiments of the present invention include methods of pumping a production fluid from a production zone to a collection point. One specific, non-limiting embodiment of the methods include disposing a tubing in the production zone of a wellbore; pumping the production fluid from the production zone through a first stage of a pumping system to achieve an inter-stage pressure sufficient for entry into a second stage; and pumping the production fluid at the inter-stage pressure through a second stage of the pumping system to achieve a lifting pressure sufficient to lift the production fluid to a collection point, the second stage comprises a jet pump and wherein the first stage pump is selected and operated so that a first stage dynamic head is at least 110% of the total dynamic head of the first stage pump absent the second stage.

[0014] One or more embodiments include the method of the preceding paragraph, wherein the jet pump is selected and operated so that the first stage pump is choked and operating in its recommended operating range.

[0015] One or more embodiments include the method of any preceding paragraph, wherein the first stage includes a first stage pump that varies from the jet pump.

[0016] One or more embodiments include the method of any preceding paragraph, wherein the first stage pump is selected from centrifugal pumps, rotary pumps and combinations thereof.

[0017] One or more specific non-limiting embodiments of the invention include staged pumping systems for producing a fluid from a subterranean geological formation. The pumping system is disposed within a well via tubing and, in one embodiment, includes a centrifugal pump assembly comprising a motor section and a centrifugal pump section, wherein the centrifugal pump, in operation, transfers the production fluid from the subterranean geological formation; and a jet pump assembly including a nozzle, suction chamber and check valve disposed below the nozzle, wherein the jet pump assembly, in operation, receives the production fluid from the centrifugal pump assembly and lifts the production fluid to a collection point; and a single seat, wherein the seat, in operation secures the jet pump assembly thereon.

[0018] One or more embodiments include the system of the preceding paragraph, wherein the subterranean geological formation is a subsea formation.

[0019] One or more embodiments include the system of any preceding paragraph, wherein the centrifugal pump assembly, in operation, provides a total dynamic head of at least 110% of the total dynamic head of the centrifugal pump assembly absent the second stage.

[0020] One or more embodiments include the system of any preceding paragraph, wherein the pumping system is part of a lift system.

[0021] One or more embodiments include the lift system of the preceding paragraph and further including a production packer disposed within an annulus above the jet pump assembly.

[0022] One or more embodiments include the lift system of any preceding paragraph, wherein the production fluid includes gas and liquid and the lift system further includes a production packer disposed within an annulus below the jet pump assembly.

[0023] One or more embodiments include the pumping system of any preceding paragraph and further include a gas separator, a gas handling device or combinations thereof.

[0024] One or more embodiments include the system of the preceding paragraph, wherein the gas separator includes a tandem gas separator.

[0025] One or more embodiments include the system of any preceding paragraph and further include a fallback preventer disposed above the jet pump assembly.

[0026] One or more embodiments include the system of the preceding paragraph, wherein the fallback preventer includes an automatic shutoff valve.

[0027] In one or more specific, non-limiting embodiments, the staged pumping system includes a centrifugal pump assembly including a motor section and a centrifugal pump section, wherein the centrifugal pump, in operation, transfers the production fluid from the subterranean geological formation; and a jet pump assembly including a nozzle, suction chamber and check valve disposed below the nozzle, wherein the jet pump assembly, in operation, receives the production fluid from the centrifugal pump assembly and lifts the production fluid to a collection point; and wherein the centrifugal pump assembly is, in operation, controlled by a variable speed drive operated in current mode.

[0028] In other specific, non-limiting embodiments, the staged pumping system a first stage pump assembly, wherein the first stage pump assembly, in operation, transfers the production fluid from the subterranean geological formation; and a jet pump assembly including a nozzle, suction chamber and check valve disposed below the nozzle, wherein the jet pump assembly, in operation, receives the production fluid from the centrifugal pump assembly and lifts the production fluid to a collection point; and a fallback preventer disposed above the jet pump assembly.

[0029] One or more embodiments included the system of the preceding claim, wherein the first stage pump assembly is selected from rotary pumps, centrifugal pumps and combinations thereof.

[0030] One or more embodiments include the system of any preceding claim, wherein the fallback preventer includes an automatic diverter valve.

[0031] One or more embodiments include the system of any preceding claim, wherein the pumping system is part of an artificial lift system and wherein the lift system further includes a production packer disposed within an annulus above the jet pump assembly.

[0032] The above paragraphs present a simplified summary of the presently disclosed subject matter in order to provide a basic understanding of some aspects thereof. The summary is not an exhaustive overview, nor is it intended to identify key or critical elements to delineate the scope of the subject matter claimed below. Its sole purpose is to present some concepts in a simplified form as a prelude to the more detailed description set forth below.

BRIEF DESCRIPTION OF THE DRAWINGS

[0033] The claimed subject matter may be understood by reference to the following description taken in conjunction with the accompanying drawings, in which like reference numerals identify like elements, and in which:

[0034] FIG. 1 illustrates a non-limiting embodiment of a pumping system.

[0035] FIG. 2 illustrates a non-limiting embodiment of a jet pump assembly.

[0036] FIG. 3 illustrates a non-limiting embodiment of an artificial lift system.

[0037] While the claimed subject matter is susceptible to various modifications and alternative forms, the drawings illustrate specific embodiments herein described in detail by way of example. It should be understood, however, that the description herein of specific embodiments is not intended to limit the claimed subject matter to the particular forms disclosed, but on the contrary, the intention is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the invention as defined by the appended claims.

DETAILED DESCRIPTION

[0038] Illustrative embodiments of the subject matter claimed below will now be disclosed. In the interest of clarity, not all features of an actual implementation are described in this specification. It will be appreciated that in the development of any such actual embodiment, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which will vary from one implementation to another. Moreover, it will be appreciated that such a development effort, even if complex and time-consuming, would be a routine undertaking for those of ordinary skill in the art having the benefit of this disclosure.

[0039] In the description below, various ranges and/or numerical limitations may be expressly stated below. It should be recognized that unless stated otherwise, it is intended that endpoints are to be interchangeable. Further, any ranges include iterative ranges of like magnitude falling within the expressly stated ranges or limitations.

[0040] In the specification and appended claims, the terms "connect", "connection", "connected", "in connection with" and "connecting" are used to mean "in direct connection with" or "in connection with via another element", and the term "set" is used to mean "one element" or "more than one element". As used herein, the terms "up" and "down", "upper" and "lower", "upwardly" and "downwardly", "upstream" and "downstream", "above" and "below" and other like terms indicating relative positions above or below a given point or element are used in this description to more clearly describe some embodiments of the invention. However, when applied to equipment and methods for use in wells that are deviated or horizontal, such terms may refer to a left to right, right to left or other relationship as appropriate.

[0041] Furthermore, various modifications may be made within the scope of the invention as herein intended, and embodiments of the invention may include combinations of features other than those expressly claimed. In particular, flow arrangements other than those expressly described herein are within the scope of the invention.

[0042] A completed well generally includes a main wellbore that is lined and supported by one or more casing strings and production tubing. It is noted that the wellbore may be uncased in accordance with other embodiments of the invention. The space between the production tubing and casing is called the annulus. A production packer sometimes seals the annulus above the production zone. As used herein, the term "above" refers to a location between the production zone and the collection point. The casing, when present, may be perforated adjacent to the production zone to allow entrance of fluid into the wellbore and/or the production tubing may extend into the open hole. The production fluid may flow into a valve, such as a circulation valve of the production tubing and be communicated to the surface of the well via the production tubing's central passageway (e.g., the wellbore).

[0043] In one or more embodiments, a pumping system is provided for lifting production fluid (e.g., oil, gas, water, helium or other fluid, or a combination thereof) from a well. The pumping system may be included within an artificial lift system, for example.

[0044] The pumping system generally includes staged pumping of the production fluids. For example, the production fluid is pumped through a first stage to achieve an inter-stage pressure sufficient for entry into a second stage to achieve a lifting pressure sufficient to lift the fluid to the collection point. Accordingly, the pumping system generally includes a first stage pump and a second stage pump. The first stage pump includes any pump capable of lifting the fluid as required. For example, the first stage pump may include a rotary pump, such as a positive displacement pump (including progressing cavity pumps), a centrifugal pump, such as an ESP or combinations thereof. The second stage pump generally includes one or more jet pumps.

[0045] Jet pumps generally operate by forcing a pressurized fluid through a nozzle, where it is converted into a high velocity stream. This high velocity stream decreases the pressure in a suction chamber, creating a partial vacuum that draws the suction material into the chamber where it is entrained. Once the suction stream is drawn in, shear causes intermixing and pumping the fluid out of a discharge dispelled at a pressure greater than that of the suction stream. Jet pumps are able to tolerate a wide range of operating conditions, including sand laden or abrasive fluids.

[0046] In one or more embodiments, the jet pump is selected so that the first stage pump is choked and operating in its recommended operating range. Such selection/operation reduces the load on the first stage pump, thereby extending its operating life.

[0047] In one or more embodiments, the tubing includes a seat for securing components of the pumping system therein. For example, the seat may secure the jet pump assembly. In one or more embodiments, the seat is disposed above a first stage total dynamic head. In another embodiment, the seat is disposed, during operation, below a first stage total dynamic head. As used herein, the "first stage dynamic head" refers to the total equivalent height that a fluid is to be pumped in the first stage, taking into account friction losses in the pipe. It is to be noted that first stage dynamic head can be referred to interchangeably herein and is approximately equal to the discharge pressure of the first stage pump. In one or more embodiments, the system is absent a second seat. The jet pump may be run in and out of the well with the help of wire line tools (i.e., the jet pump is "wireline retrievable").

[0048] In one or more embodiments, the first stage pump is selected and operated so that the first stage dynamic head within the pumping system is at least 110%, or greater than 110%, or at least 120%, or at least 150%, or at least 175% or at least 200% of the total dynamic head of the first stage pump absent the second stage (i.e., when run in a standalone configuration), for example.

[0049] In one or more embodiments, the first stage pump is controlled by a variable speed drive (VSD) having i-mode (i.e., current mode) adapted to automatically increase frequency for a short period of time, resulting in a higher ejection coefficient of the jet pump, thereby preventing first stage pump gas lock. For example, when operating in current mode, when gas enters the first stage pump, the drive senses the lower amperage, speeds up to maintain amperage and compress the gas to move it through the first stage pump. When passed, the drive will slow back down to maintain a desired amperage, thereby improving efficiency and reducing shut downs.

[0050] Often, the production fluid has a liquid component and a gas component (e.g., the production fluid may include any amount of gas, such as at least 50 scf/bbl, or at least 100 scf/bbl). In such cases, the first stage flow pump may include a mixed flow pump. The mixed flow pump boosts the pressure of the input production fluid to a particular level to compress or move a sufficient volume of the liberated gas component into solution such that the production fluid may be pumped by the subsequently disposed jet pump. The acceptable gas to liquid ratio may vary depending on the characteristics of the jet pump. Once the production fluid is pressurized to a sufficient level, the production fluid is fed into the jet pump. The jet pump will further boost the pressure of the production fluid to a sufficient level to facilitate artificial lift of the fluid to the surface or to another collection point.

[0051] The pumping system may further utilize a gas separator. In one or more embodiments, the gas separator is disposed within the first stage pump assembly prior to the pump section. In operation, the production fluid including mixtures of gas and liquid (oil/gas or water/oil/gas) enters the gas separator. Free gas is then separated in the gas separator from the liquid and discharged into the annulus, while the first stage pump pumps the liquid to the nozzle of the jet pump apparatus. It should be noted that the liquid may contain some gas, but the reduction of gas allows the fluid to be better produced with the first stage pump. In alternative embodiments, the gas separator may be disposed elsewhere within the pumping system and/or the artificial lift system.

[0052] The gas separator may have a variety of designs depending on the specific application, environment, and types of fluids to be produced. When the gas content of a production fluid is sufficiently high to cause risk of "gas lock" in the first stage pump, at least some of the gas is removed to create a liquid component with lower gas content. Gas content in the production fluid also can reduce the hydraulic efficiency of the first stage pump. Accordingly, the gas separator may have a variety of designs to remove this excess gas. By way of non-limiting example, the gas separator may be a natural separator, a vortex separator, a reverse flow gas separator, a centrifugal gas separator, a tandem rotary gas separator or combinations thereof, for example.

[0053] The pumping system may alternatively, or in combination with the gas separator, include a gas handling device capable of conditioning the production fluid prior to passing through the first stage pump.

[0054] In accordance with one or more embodiments, the fluid that is received from the production zone may be produced from various perforated production zones of a horizontal or deviated wellbore. Depending on the particular embodiment of the invention, each production zone may be established between packers that form annular seals.

[0055] In one or more embodiments, the artificial lift system includes one or more fallback preventers. The fallback preventer is generally disposed above the jet pump assembly (herein referring to a location between the jet pump assembly and the collection point).

[0056] The fallback preventer may include any apparatus capable of preventing debris fallback within the wellbore. However, it is to be noted that the fallback preventer is typically capable of allowing debris to pass there through towards the surface of the well but prevents debris from falling back downward through the wellbore, such as upon pump shut-down. For example, the fallback preventer may include a valve. The valve functions to divert flow in the production tubing and is operable to be moved between an open position and a closed position.

[0057] In one or more embodiments, the valve is a check valve. In other specific embodiments, the valve is an auto shutoff valve (i.e., the valve closes automatically upon fluid flow interruption). On pump start-up, the auto shutoff valve automatically operates to close ports to the annulus and pumped production commences to collection point. Upon pump shut-down, fluid within the production tubing exhaust into the annulus. Communication to the pumping system is blocked preventing solids from falling back towards the pumping system. When the pumping system is restarted, the auto shutoff valve automatically operates to close ports to annulus and normal production resumes. As with the jet pump, the fallback preventer may be run in and out of the well with the help of wire line tools (i.e., the fallback preventer is "wireline retrievable").

[0058] FIG. 1 illustrates a specific, non-limiting embodiment of the pumping system (100) disposed within a well. The pumping system (100) includes a centrifugal pump assembly (102) adapted to receive a production fluid disposed within a production zone of a geological formation (112). The centrifugal pump assembly (102) is in turn operably connected to a jet pump assembly (104) via production tubing (106).

[0059] The centrifugal pump assembly (102) generally includes a pump section (103) and a motor (105) with a seal section (not shown). The centrifugal pump assembly (102) optionally includes a gas separator (107).

[0060] The pumping system (100) further includes a seat (108) adapted to receive the jet pump assembly (104). The seat includes bypass channel (109) to communicate fluid between the jet pump assembly (104) and the annulus (110).

[0061] FIG. 2 further illustrates a specific, non-limiting embodiment of the jet pump assembly (200). The jet pump assembly (200) is fitted with a check valve (202) disposed below the jet nozzle (204). A system of bypass channels (203, 205, 109--see, FIG. 1) connects the space (207) under the check valve (202) and the suction chamber (206) of the jet pump assembly (200) and the space (209) under the jet nozzle (204) with the production tubing (106) connected to the centrifugal pump assembly (102)--see, FIG. 1.

[0062] The jet pump assembly (200) further includes a mixing chamber (208), a diffuser (210), a discharge head (212), sealing elements (211, 213) and is fitted with a retaining clamp (215) and shear ring (217) for securing in the seat (108--see, FIG. 1). The jet pump assembly 200 may optionally be fitted with a screen (214) to protect the nozzle (204) from plugging with solids.

[0063] FIG. 3 further illustrates an embodiment of an artificial lift system (300) including a fallback preventer (304) disposed within the tubing above the jet pump assembly (104). The fallback preventer (304) is further disposed below a production packer (302). It is to be noted that in FIG. 3, the fallback preventer (300) as well as the jet pump assembly (104) is disposed below the production packer (302). However, in wells with having gas present within the production fluid, production can be limited by gas interference in the pumping system, and particularly in the jet pump assembly (104). Accordingly, it is within the scope of the embodiments described herein to have an artificial lift system wherein the jet pump assembly (and possibly the fallback preventer) is disposed above the production packer.

[0064] It is noted that the wells that depicted in the figures are exemplary in nature, in that the pumping system and associated control techniques that are disclosed herein, may likewise be applied in other wells. Thus many variations are contemplated and are within the scope of the appended claims.

[0065] Further, while the centrifugal pump assembly (102) and the jet pump assembly (104) are illustrated as single pumps, it is contemplated that any number of pumps may be employed with or without standby, backup, or reserve pumps.

[0066] With reference again to the Figures, a specific, non-limiting embodiment of the present invention includes an operation for providing a pumping system in a subsea environment. The pumping system is formed by connecting at least one first stage pump assembly with at least one jet pump assembly. The pumping system may be formed at the surface and deployed subsea, or deployed as disconnected components and assembled subsea. Once deployed and connected to an inflow of production fluid, the pumping system imparts flow energy to the production fluid to generate an energized outlet hydrocarbon flow via an export line to a target destination. In some embodiments, a power hub is electrically connected to the pump system to route electrical energy to the pumps via jumpers or cables. A power umbilical may be provided (e.g., by remote operated vehicle or other remote mechanism) to electrically connect the power hub to an electrical energy source located on the surface, the seabed, subsea or down-hole, for example.

[0067] Embodiments of the invention described herein improve the reliability of the pumping system. For example, the embodiments described herein are capable of reliable operation in high gas environments, sandy well environments and combinations thereof.

CLOSING OF THE DETAILED DESCRIPTION

[0068] Therefore, the present invention is well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. Note, however, that not all embodiments will necessarily attain all the ends noted or manifest all the advantages mentioned. Furthermore, different embodiments will do so to different degrees to the extent they do at all. The particular embodiments disclosed above are illustrative only, as the present invention may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular illustrative embodiments disclosed above may be altered, combined, or modified and all such variations are considered within the scope and spirit of the present invention.

[0069] The invention illustratively disclosed herein suitably may be practiced in the absence of any element that is not specifically disclosed herein and/or any optional element disclosed herein. While compositions and methods are described in terms of "comprising," "containing," or "including" various components or steps, the compositions and methods can also "consist essentially of" or "consist of" the various components and steps. All numbers and ranges disclosed above may vary by some amount. Whenever a numerical range with a lower limit and an upper limit is disclosed, any number and any included range falling within the range are specifically disclosed. In particular, every range of values (of the form, "from about a to about b," or, equivalently, "from approximately a to b," or, equivalently, "from approximately a-b") disclosed herein is to be understood to set forth every number and range encompassed within the broader range of values.

[0070] This concludes the detailed description. The particular embodiments disclosed above are illustrative only, as the invention may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular embodiments disclosed above may be altered or modified and all such variations are considered within the scope and spirit of the invention. Accordingly, the protection sought herein is as set forth in the claims below.

Claims

1. A method of pumping a production fluid from a production zone to a collection point comprising: disposing a tubing in the production zone of a wellbore; pumping the production fluid from the production zone through a first stage of a pumping system to achieve an inter-stage pressure sufficient for entry into a second stage; and pumping the production fluid at the inter-stage pressure through a second stage of the pumping system to achieve a lifting pressure sufficient to lift the production fluid to a collection point, the second stage comprises a jet pump and wherein the first stage pump is selected and operated so that a first stage dynamic head is at least 110% of the total dynamic head of the first stage pump absent the second stage.

2. The method of claim 1, wherein the jet pump is selected and operated so that the first stage pump is choked and operating in its recommended operating range.

3. The method of claim 1, wherein the first stage comprises a first stage pump that varies from the jet pump.

4. The method of claim 1, wherein the first stage pump is selected from centrifugal pumps, rotary pumps and combinations thereof.

5. A staged pumping system for producing a fluid from a subterranean geological formation, wherein the pumping system is disposed within a well via tubing and wherein the pumping system comprises: a centrifugal pump assembly comprising a motor section and a centrifugal pump section, wherein the centrifugal pump, in operation, transfers the production fluid from the subterranean geological formation; and a jet pump assembly comprising a nozzle, suction chamber and check valve disposed below the nozzle, wherein the jet pump assembly, in operation, receives the production fluid from the centrifugal pump assembly and lifts the production fluid to a collection point; and a single seat, wherein the seat, in operation secures the jet pump assembly thereon.

6. The pumping system of claim 5, wherein the subterranean geological formation is a subsea formation.

7. The pumping system of claim 5, wherein the centrifugal pump assembly, in operation, provides a total dynamic head of at least 110% of the total dynamic head of the centrifugal pump assembly absent the second stage.

8. The pumping system of claim 5, wherein the pumping system is part of a lift system.

9. The lift system of claim 8 further comprising a production packer disposed within an annulus above the jet pump assembly.

10. The lift system of claim 8, wherein the production fluid comprises gas and liquid and the lift system further comprises a production packer disposed within an annulus below the jet pump assembly.

12. The pumping system of claim 5, wherein the pumping system further comprises a gas separator, a gas handling device or combinations thereof.

13. The pumping system of claim 5, wherein the pumping system further comprises a tandem gas separator.

14. The pumping system of claim 5 further comprising a fallback preventer disposed above the jet pump assembly.

15. The pumping system of claim 14, wherein the fallback preventer comprises an automatic shutoff valve.

16. A staged pumping system for producing a fluid from a subterranean geological formation, wherein the pumping system is disposed within a well via tubing and wherein the pumping system comprises: a centrifugal pump assembly comprising a motor section and a centrifugal pump section, wherein the centrifugal pump, in operation, transfers the production fluid from the subterranean geological formation; and a jet pump assembly comprising a nozzle, suction chamber and check valve disposed below the nozzle, wherein the jet pump assembly, in operation, receives the production fluid from the centrifugal pump assembly and lifts the production fluid to a collection point; and wherein the centrifugal pump assembly is, in operation, controlled by a variable speed drive operated in current mode.

17. A staged pumping system for producing a fluid from a subterranean geological formation, wherein the pumping system is disposed within a well via tubing and wherein the pumping system comprises: a first stage pump assembly, wherein the first stage pump assembly, in operation, transfers the production fluid from the subterranean geological formation; and a jet pump assembly comprising a nozzle, suction chamber and check valve disposed below the nozzle, wherein the jet pump assembly, in operation, receives the production fluid from the centrifugal pump assembly and lifts the production fluid to a collection point; and a fallback preventer disposed above the jet pump assembly.

18. The pumping system of claim 17, wherein the first stage pump assembly is selected from rotary pumps, centrifugal pumps and combinations thereof.

19. The pumping system of claim 17, wherein the fallback preventer comprises an automatic diverter valve.

20. The pumping system of claim 17, wherein the pumping system is part of an artificial lift system and wherein the lift system further comprises a production packer disposed within an annulus above the jet pump assembly.