WO2023158811A2 - Downhole pump multiphase fluid conditioner - Google Patents

Downhole pump multiphase fluid conditioner Download PDF

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Publication number
WO2023158811A2
WO2023158811A2 PCT/US2023/013326 US2023013326W WO2023158811A2 WO 2023158811 A2 WO2023158811 A2 WO 2023158811A2 US 2023013326 W US2023013326 W US 2023013326W WO 2023158811 A2 WO2023158811 A2 WO 2023158811A2
Authority
WO
WIPO (PCT)
Prior art keywords
multiphase fluid
downhole
fluid conditioner
gas separator
pump stages
Prior art date
Application number
PCT/US2023/013326
Other languages
French (fr)
Other versions
WO2023158811A3 (en
Inventor
Terry Wayne Shafer
James Owen Rhys-Davies
Original Assignee
Extract Management Company, Llc
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Extract Management Company, Llc filed Critical Extract Management Company, Llc
Publication of WO2023158811A2 publication Critical patent/WO2023158811A2/en
Publication of WO2023158811A3 publication Critical patent/WO2023158811A3/en

Links

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
    • 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
    • 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
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/38—Arrangements for separating materials produced by the well in the well

Definitions

  • the present disclosure relates to, for example, a downhole pump multiphase fluid conditioner.
  • Figure 1 shows a representative multiphase fluid device.
  • FIG. 1 shows a representative device.
  • a head 10 is connected to a number of pump stages which stages may comprise a plurality of contrahelical, centrifugal, or gas handler centrifugal pump stages, e.g., up to 4, or up to 6, or up to 8, or up to 10, or up to 15, or up to 20, or up to 25, or up to 30, or even up to 35 or more contrahelical pump stages 20.
  • the contrahelical pump stages 20 are connected to at least one gas separator 30 having a plurality of gas exits 31. If desired for certain applications two, or three, or more gas separators may be used in series.
  • the one or more gas separator 30 is connected to either a second set of a plurality of pump stages, e.g., contrahelical pump stages, e.g., up to 4, or up to 6, or up to 8, or up to 10, or up to 15, or up to 20, or up to 25, or up to 30, or even up to 35 or more contrahelical pump stages or alternatively the second set of contrahelical pump stages may be a gas handler centrifugal stage.
  • the alternatives are shown as reference numeral 40 in Figure 1 and are connected to a base 50 of the device.
  • the gas separator 30 is not particularly limited as to type and in some embodiments a vortex gas separator may be useful.
  • the flow starts at the base of the device and travels to the head where it exits.
  • using the described configuration may result in compression being added before the primary pump. That is, adding the contrahelical, centrifugal, or gas handler centrifugal pump stages, e g., up to 4, or up to 6, or up to 8, or up to 10 contrahelical pump stages 20 facilitate more gas expulsion than a conventional gas separator. While not wishing to be bound to any particular theory it is believed that the addition of the stages 20 generates low pressure areas in stator and thereby increases gas removal.
  • the use of the contrahelical, centrifugal, or gas handler centrifugal pump stages may increase the pressure change and thereby condition the fluid exiting the gas separator for primary pump.
  • the stages at 20 may act as a charge pump to increase fluid pressure and condition the fluid by, for example, mixing and homogenizing multiphase fluid prior to entering the next stage.
  • the length of the device may vary depending upon the desired application. In some embodiments the length may be maximized while optimizing horsepower for gas bubble recirculation. In some embodiments the device may be from about 17 to about 24 feet in length with the device length being from about 10 to about 14 feet above the base 50.
  • the horsepower employed may vary depending upon the application and could be less than 80, or less than 60 horsepower. Of course, one may optimize the device in relation to horsepower, pressure differential, and cost.
  • a downhole multiphase fluid conditioner comprising: a head; a base; a gas separator having a plurality of gas exits and an uphole end and a downhole end; a plurality of contrahelical pump stages operably connected to the head and the uphole end of the gas separator; and a plurality of contrahelical pump stages operably connected to the base and the downhole end of the gas separator.
  • the downhole multiphase fluid conditioner of embodiment I wherein the length is from about 17 to about 24 feet. 5. The downhole multiphase fluid conditioner of embodiment 1, wherein the length of the downhole multiphase fluid conditioner excluding the base is from about 10 to about 14 feet.
  • a downhole multiphase fluid conditioner comprising: a head; a base; a gas separator having a plurality of gas exits and an uphole end and a downhole end; two or more pump stages operably connected to the head and the uphole end of the gas separator wherein each of the two or more pump stages are a contrahelical stage, a centrifugal stage, a gas handler centrifugal stage, or any combination thereof; and
  • each of the two or more pump stages are a contrahelical stage, a centrifugal stage, a gas handler centrifugal stage, or any combination thereof;
  • the downhole multiphase fluid conditioner comprises (1) two or more pump stages operably connected to the base and the dow nhole end of the gas separator wherein each of the two or more pump stages are a contrahelical stage, a centrifugal stage, a gas handler centrifugal stage, or any combination thereof .
  • the device may comprise hard materials such as tungsten carbide to protect against sand erosion and abrasion.
  • HS bearings may also be employed if desired.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (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)

Abstract

A downhole multiphase fluid conditioner is described that includes a head, a base, and a gas separator having a plurality of gas exits and an uphole end and a downhole end. Two or more pump stages are operably connected to the head and the uphole end of the gas separator. Each of the two or more pump stages are a contrahelical stage, a centrifugal stage, a gas handler centrifugal stage, or any combination thereof. The downhole multiphase fluid conditioner further may include either (1) two or more pump stages operably connected to the base and the downhole end of the gas separator wherein each of the two or more pump stages are a contrahelical stage, a centrifugal stage, a gas handler centrifugal stage, or any combination thereof; or (2) a gas handler centrifugal stage operably connected to the base and the downhole end of the gas separator.

Description

DOWNHOLE PUMP MULTIPHASE FLUID CONDITIONER
Inventors: Terry Wayne Shafer; James Owen Rhys-Davies
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] The present application claims priority to U.S. Application No. 63/311,127 filed February 17, 2022 which is incorporated by reference. It is also related to U.S. Patent No. 10,519,756 which is incorporated by reference.
FIELD OF THE DISCLOSURE
[0002] The present disclosure relates to, for example, a downhole pump multiphase fluid conditioner.
BRIEF DESCRIPTION OF THE DRAWINGS
[0003] Figure 1 shows a representative multiphase fluid device.
DETAILED DESCRIPTION
[0004] The following description of embodiments provides non-limiting representative examples to particularly describe features and teachings of different aspects of the invention. The embodiments described should be recognized as capable of implementation separately, or in combination, with other embodiments from the description of the embodiments. A person of ordinary skill in the art reviewing the description of embodiments should be able to leam and understand the different described aspects of the invention. The description of embodiments should facilitate understanding of the invention to such an extent that other implementations, not specifically covered but within the knowledge of a person of skill in the art having read the description of embodiments, would be understood to be consistent with an application of the invention.
[0005] Figure 1 shows a representative device. A head 10 is connected to a number of pump stages which stages may comprise a plurality of contrahelical, centrifugal, or gas handler centrifugal pump stages, e.g., up to 4, or up to 6, or up to 8, or up to 10, or up to 15, or up to 20, or up to 25, or up to 30, or even up to 35 or more contrahelical pump stages 20. The contrahelical pump stages 20 are connected to at least one gas separator 30 having a plurality of gas exits 31. If desired for certain applications two, or three, or more gas separators may be used in series. The one or more gas separator 30 is connected to either a second set of a plurality of pump stages, e.g., contrahelical pump stages, e.g., up to 4, or up to 6, or up to 8, or up to 10, or up to 15, or up to 20, or up to 25, or up to 30, or even up to 35 or more contrahelical pump stages or alternatively the second set of contrahelical pump stages may be a gas handler centrifugal stage. The alternatives are shown as reference numeral 40 in Figure 1 and are connected to a base 50 of the device. The gas separator 30 is not particularly limited as to type and in some embodiments a vortex gas separator may be useful. As one of ordinary skill in the art will appreciate, the flow starts at the base of the device and travels to the head where it exits. [0006] Advantageously, using the described configuration may result in compression being added before the primary pump. That is, adding the contrahelical, centrifugal, or gas handler centrifugal pump stages, e g., up to 4, or up to 6, or up to 8, or up to 10 contrahelical pump stages 20 facilitate more gas expulsion than a conventional gas separator. While not wishing to be bound to any particular theory it is believed that the addition of the stages 20 generates low pressure areas in stator and thereby increases gas removal. That is, the use of the contrahelical, centrifugal, or gas handler centrifugal pump stages, e.g., up to 4, or up to 6, or up to 8, or up to 10 contrahelical pump stages 20 may increase the pressure change and thereby condition the fluid exiting the gas separator for primary pump. The stages at 20 may act as a charge pump to increase fluid pressure and condition the fluid by, for example, mixing and homogenizing multiphase fluid prior to entering the next stage. [0007] The length of the device may vary depending upon the desired application. In some embodiments the length may be maximized while optimizing horsepower for gas bubble recirculation. In some embodiments the device may be from about 17 to about 24 feet in length with the device length being from about 10 to about 14 feet above the base 50. The horsepower employed may vary depending upon the application and could be less than 80, or less than 60 horsepower. Of course, one may optimize the device in relation to horsepower, pressure differential, and cost.
Embodiments
[0008]
1. A downhole multiphase fluid conditioner comprising: a head; a base; a gas separator having a plurality of gas exits and an uphole end and a downhole end; a plurality of contrahelical pump stages operably connected to the head and the uphole end of the gas separator; and a plurality of contrahelical pump stages operably connected to the base and the downhole end of the gas separator.
2. The downhole multiphase fluid conditioner of embodiment 1 , wherein the gas separator comprises a vortex gas separator.
3. The downhole multiphase fluid conditioner of embodiment 1, wherein the gas separator comprises two or more gas separator units connected in series.
4. The downhole multiphase fluid conditioner of embodiment I, wherein the length is from about 17 to about 24 feet. 5. The downhole multiphase fluid conditioner of embodiment 1, wherein the length of the downhole multiphase fluid conditioner excluding the base is from about 10 to about 14 feet.
6. The downhole multiphase fluid conditioner of embodiment 1, wherein the downhole multiphase fluid conditioner is configured to employ a horsepower of less than 80 horsepower.
7. The downhole multiphase fluid conditioner of embodiment 1, wherein the downhole multiphase fluid conditioner is configured to employ a horsepower of less than 60 horsepower.
8. A downhole multiphase fluid conditioner comprising: a head; a base; a gas separator having a plurality of gas exits and an uphole end and a downhole end; two or more pump stages operably connected to the head and the uphole end of the gas separator wherein each of the two or more pump stages are a contrahelical stage, a centrifugal stage, a gas handler centrifugal stage, or any combination thereof; and
(1) two or more pump stages operably connected to the base and the downhole end of the gas separator wherein each of the two or more pump stages are a contrahelical stage, a centrifugal stage, a gas handler centrifugal stage, or any combination thereof; or
(2) a gas handler centrifugal stage operably connected to the base and the downhole end of the gas separator.
9. The downhole multiphase fluid conditioner of embodiment 8, wherein the two or more pump stages operably connected to the head and the uphole end of the gas separator comprise contrahelical pump stages.
10. The downhole multiphase fluid conditioner of embodiment 8, wherein the two or more pump stages operably connected to the head and the uphole end of the gas separator comprise up to 10 contrahelical pump stages. 11. The downhole multiphase fluid conditioner of embodiment 8, wherein the downhole multiphase fluid conditioner comprises (1) two or more pump stages operably connected to the base and the dow nhole end of the gas separator wherein each of the two or more pump stages are a contrahelical stage, a centrifugal stage, a gas handler centrifugal stage, or any combination thereof .
12. The downhole multiphase fluid conditioner of embodiment 11, wherein the downhole multiphase fluid conditioner comprises up to 6 contrahelical pump stages operably connected to the base and the downhole end of the gas separator.
13. The downhole multiphase fluid conditioner of embodiment 8, wherein the downhole multiphase fluid conditioner comprises (2) a gas handler centrifugal stage operably connected to the base and the downhole end of the gas separator.
14. The downhole multiphase fluid conditioner of embodiment 8, wherein the gas separator comprises a vortex gas separator.
15. The downhole multiphase fluid conditioner of embodiment 8, wherein the gas separator comprises two or more gas separator units connected in series.
16. The downhole multiphase fluid conditioner of embodiment 8, wherein the length is from about 17 to about 24 feet.
17. The downhole multiphase fluid conditioner of embodiment 8, wherein the length of the downhole multiphase fluid conditioner excluding the base is from about 10 to about 14 feet.
18. The downhole multiphase fluid conditioner of embodiment 8, wherein the downhole multiphase fluid conditioner is configured to employ a horsepower of less than 80 horsepower.
19. The downhole multiphase fluid conditioner of embodiment 8, wherein the downhole multiphase fluid conditioner is configured to employ a horsepower of less than 60 horsepower. 20. The downhole multiphase fluid conditioner of embodiment 8, wherein the two or more pump stages operably connected to the head and the uphole end of the gas separator are configured to homogenize a multiphase fluid.
[0009] In some applications the device may comprise hard materials such as tungsten carbide to protect against sand erosion and abrasion. HS bearings may also be employed if desired.
[0010] In the preceding specification, various embodiments have been described with references to the accompanying drawings. It will, however, be evident that various modifications and changes may be made thereto, and additional embodiments may be implemented, without departing from the broader scope of the invention as set forth in the claims that follow. The specification and drawings are accordingly to be regarded as an illustrative rather than restrictive sense.

Claims

What is claimed is:
1. A downhole multiphase fluid conditioner comprising: a head; a base; a gas separator having a plurality of gas exits and an uphole end and a downhole end; a plurality of contrahelical pump stages operably connected to the head and the uphole end of the gas separator; and a plurality of contrahelical pump stages operably connected to the base and the downhole end of the gas separator.
2. The downhole multiphase fluid conditioner of claim 1, wherein the gas separator comprises a vortex gas separator.
3. The downhole multiphase fluid conditioner of claim 1, wherein the gas separator comprises two or more gas separator units connected in series.
4. The downhole multiphase fluid conditioner of claim 1 , wherein the length is from about 17 to about 24 feet
5. The downhole multiphase fluid conditioner of claim 1 , wherein the length of the downhole multiphase fluid conditioner excluding the base is from about 10 to about 14 feet.
6. The downhole multiphase fluid conditioner of claim 1, wherein the downhole multiphase fluid conditioner is configured to employ a horsepower of less than 80 horsepower.
7. The downhole multiphase fluid conditioner of claim 1, wherein the downhole multiphase fluid conditioner is configured to employ a horsepower of less than 60 horsepower.
8. A downhole multiphase fluid conditioner comprising: a head; a base; a gas separator having a plurality of gas exits and an uphole end and a downhole end; two or more pump stages operably connected to the head and the uphole end of the gas separator wherein each of the two or more pump stages are a contrahelical stage, a centrifugal stage, a gas handler centrifugal stage, or any combination thereof; and
(1) two or more pump stages operably connected to the base and the downhole end of the gas separator wherein each of the two or more pump stages are a contrahelical stage, a centrifugal stage, a gas handler centrifugal stage, or any combination thereof; or
(2) a gas handler centrifugal stage operably connected to the base and the downhole end of the gas separator.
9. The downhole multiphase fluid conditioner of claim 8, wherein the two or more pump stages operably connected to the head and the uphole end of the gas separator comprise contrahelical pump stages.
10. The downhole multiphase fluid conditioner of claim 8, wherein the two or more pump stages operably connected to the head and the uphole end of the gas separator comprise up to 10 contrahelical pump stages.
1 1 . The downhole multiphase fluid conditioner of claim 8, wherein the downhole multiphase fluid conditioner comprises (1) two or more pump stages operably connected to the base and the dow nhole end of the gas separator wherein each of the two or more pump stages are a contrahelical stage, a centrifugal stage, a gas handler centrifugal stage, or any combination thereof .
12. The downhole multiphase fluid conditioner of claim 11, wherein the downhole multiphase fluid conditioner comprises up to 6 contrahelical pump stages operably connected to the base and the downhole end of the gas separator.
13. The downhole multiphase fluid conditioner of claim 8, wherein the downhole multiphase fluid conditioner comprises (2) a gas handler centrifugal stage operably connected to the base and the downhole end of the gas separator.
14. The downhole multiphase fluid conditioner of claim 8, wherein the gas separator comprises a vortex gas separator.
15. The downhole multiphase fluid conditioner of claim 8, wherein the gas separator comprises two or more gas separator units connected in series.
16. The downhole multiphase fluid conditioner of claim 8, wherein the length is from about 17 to about 24 feet.
17. The downhole multiphase fluid conditioner of claim 8, wherein the length of the downhole multiphase fluid conditioner excluding the base is from about 10 to about 14 feet.
18. The downhole multiphase fluid conditioner of claim 8, wherein the downhole multiphase fluid conditioner is configured to employ a horsepower of less than 80 horsepower.
19. The downhole multiphase fluid conditioner of claim 8, wherein the downhole multiphase fluid conditioner is configured to employ a horsepower of less than 60 horsepower.
20. The downhole multiphase fluid conditioner of claim 8, wherein the two or more pump stages operably connected to the head and the uphole end of the gas separator are configured to homogenize a multiphase fluid.
PCT/US2023/013326 2022-02-17 2023-02-17 Downhole pump multiphase fluid conditioner WO2023158811A2 (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US202263311127P 2022-02-17 2022-02-17
US63/311,127 2022-02-17

Publications (2)

Publication Number Publication Date
WO2023158811A2 true WO2023158811A2 (en) 2023-08-24
WO2023158811A3 WO2023158811A3 (en) 2023-12-14

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Application Number Title Priority Date Filing Date
PCT/US2023/013326 WO2023158811A2 (en) 2022-02-17 2023-02-17 Downhole pump multiphase fluid conditioner

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US (1) US20230258067A1 (en)
WO (1) WO2023158811A2 (en)

Family Cites Families (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6413065B1 (en) * 1998-09-09 2002-07-02 Pradeep Dass Modular downhole multiphase pump
US7343967B1 (en) * 2005-06-03 2008-03-18 Wood Group Esp, Inc. Well fluid homogenization device
US20110073305A1 (en) * 2009-09-28 2011-03-31 Morrison Iii Guy Multisection Downhole Separator and Method
US9283497B2 (en) * 2013-02-01 2016-03-15 Ge Oil & Gas Esp, Inc. Abrasion resistant gas separator

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US20230258067A1 (en) 2023-08-17
WO2023158811A3 (en) 2023-12-14

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