U.S. patent application number 14/132461 was filed with the patent office on 2015-06-18 for submersible pumping system and method.
This patent application is currently assigned to General Electric Company. The applicant listed for this patent is General Electric Company. Invention is credited to Ameen Roshdy Aboel Hassan Muhammed, Stephen Michael Breit, Michael Franklin Hughes, Jeremy Daniel Van Dam, Joseph John Zierer, JR..
Application Number | 20150167652 14/132461 |
Document ID | / |
Family ID | 53367854 |
Filed Date | 2015-06-18 |
United States Patent
Application |
20150167652 |
Kind Code |
A1 |
Van Dam; Jeremy Daniel ; et
al. |
June 18, 2015 |
SUBMERSIBLE PUMPING SYSTEM AND METHOD
Abstract
A method of isolating a production fluid from a fluid-containing
reservoir is provided. The method includes disposing a first pump
within a horizontal section of a production well. The method also
includes disposing a second pump within a vertical section of the
production well. Further, the method includes pumping a reservoir
fluid via the first pump towards the second pump. The method also
includes capturing at least a portion of the reservoir fluid from
the first pump in a fluid-retaining section located around the
second pump. Furthermore, the method includes pumping the reservoir
fluid captured in the fluid-retaining section to a fluid
containment vessel via the second pump to provide an isolated
production fluid.
Inventors: |
Van Dam; Jeremy Daniel;
(West Coxsackie, NY) ; Aboel Hassan Muhammed; Ameen
Roshdy; (Schenectady, NY) ; Zierer, JR.; Joseph
John; (Niskayuna, NY) ; Breit; Stephen Michael;
(Edmond, OK) ; Hughes; Michael Franklin; (Oklahoma
City, OK) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
General Electric Company |
Schenectady |
NY |
US |
|
|
Assignee: |
General Electric Company
Schenectady
NY
|
Family ID: |
53367854 |
Appl. No.: |
14/132461 |
Filed: |
December 18, 2013 |
Current U.S.
Class: |
417/53 ; 417/203;
417/205; 417/244 |
Current CPC
Class: |
F04B 23/04 20130101;
E21B 43/126 20130101; F04B 47/02 20130101 |
International
Class: |
F04B 23/10 20060101
F04B023/10; F04B 15/02 20060101 F04B015/02 |
Claims
1. A method of isolating a production fluid from a fluid-containing
reservoir, the method comprising: (a) disposing a first pump within
a horizontal section of a production well; (b) disposing a second
pump within a vertical section of the production well; (c) pumping
a reservoir fluid via the first pump towards the second pump; (d)
capturing at least a portion of the reservoir fluid from the first
pump in a fluid-retaining section located around the second pump;
and (e) pumping the reservoir fluid captured in the fluid-retaining
section to a fluid containment vessel via the second pump to
provide an isolated production fluid.
2. The method of claim 1, further comprising controlling a flow of
fluids pumped from the first pump, the second pump and maintaining
an optimal level of fluids in the fluid retaining section by one or
more control systems.
3. The method of claim 1, wherein the one or more control systems
are located above or below ground and configured to control the
operating speed of the first pump and the second pump.
4. The method of claim 1, wherein the reservoir fluids comprises a
flow of multiphase fluids and solid matter.
5. The method of claim 4, wherein the multiphase fluids comprises a
mixture of gases, water, sand, crude oil, and the like.
6. The method of claim 1, wherein each of the first pump and the
second pump are controlled by a first power supply unit and a
second power supply unit respectively.
7. The method of claim 6, further comprising powering the first
pump and the second pump using the first power supply unit and the
second power supply unit via a first power delivery conduit and a
second power delivery conduit respectively that are disposed in the
production well.
8. The method of claim 7, wherein each of the first power supply
unit and the second power supply unit comprises an electrical
supply unit, a hydraulic supply unit, and a pneumatic unit.
9. The method of claim 1, wherein each of the first pump and the
second pump is a multistage pump comprising a turbo pump, a
progressive cavity pump, a reciprocating piston pump and a jet
pump.
10. The method of claim 9, wherein the turbo pump comprises a
centrifugal pump or an axial pump and combinations thereof.
11. The method of claim wherein the first pump comprises an
electric submersible pump having at least one or more helico-axial
configuration for pumping multiphase fluids having high gas volume
fractions.
12. The method of claim 1, wherein the second pump comprises an
electric submersible pump having at least one or more pump stages
in radial or mixed flow configuration for generating desired head
pressure for lifting the fluids from the fluid retaining section to
the wellhead located aboveground.
13. The method of claim 1, further comprising isolating a first
zone having the first pump from a second zone having the second
pump in the production well by disposing a production packer.
14. The method of claim 13, wherein the second zone is the
fluid-retaining section.
15. The method of claim 13, wherein the first zone in the
horizontal section comprises one or more pumps along with the first
pump.
16. The method of claim 1, wherein the fluid-retaining section
comprises a cylindrical shroud section arranged around the second
pump comprising a basin for holding fluids that are pumped from the
first pump.
17. A pumping system for isolating a production fluid from a
fluid-containing reservoir comprising: a first pump configured to
be deployed in a horizontal section of a production well for
pumping a reservoir fluid; a second pump configured to be deployed
in a vertical section of the production well; and a fluid-retaining
section disposed around the second pump, wherein the first pump and
the second pump are in fluid communication via a first fluid
conduit.
18. The system of claim 17, wherein each of the first pump and the
second pump are controlled by a first power supply unit and a
second power supply unit respectively.
19. The system of claim 17, further comprising a first power
delivery conduit and a second power delivery conduit that are
disposed in the production well configured for powering the first
pump and the second pump respectively using the first power supply
unit and the second power supply.
20. The system of claim 19, wherein each of the first power supply
unit and the second power supply unit comprises an electrical
supply unit, a hydraulic supply unit, and a pneumatic unit.
21. The system of claim 17, wherein each of the first pump and the
second pump is a multistage pump comprises a turbo pump, a
progressive cavity pump, a reciprocating piston pump and a jet
pump.
22. The system of claim 21, wherein the turbo pump comprises a
centrifugal pump or an axial pump and combinations thereof.
23. The system of claim 17, wherein the first pump comprises an
electric submersible pump configured for pumping multiphase fluids
having high gas volume fractions and comprising at least one or
more helico-axial configuration.
24. The system of claim 17, wherein the second pump comprises an
electric submersible pump having at least one or more pump stages
in radial or mixed flow configuration configured to generate
desired head pressure for lifting the fluids from the fluid
retaining section to the wellhead located aboveground.
25. The system of claim 17, further comprises a production packer
disposed in the production well configured to separate a first zone
and a second zone, wherein the second zone is the fluid retaining
section.
26. The system of claim 17, wherein the fluid-retaining section
comprises a cylindrical shroud section arranged around the second
pump comprising a basin for holding fluids that are pumped from the
first pump.
27. A subterranean pumping system comprising: a first pump
configured to be deployed in a horizontal section of a production
well for pumping a reservoir fluid; a second pump configured to be
deployed in a vertical section of the production well; a
fluid-retaining section disposed around the second pump for holding
fluids that are pumped from the first pump; and a control system
configured for controlling flow of fluids pumped from the first
pump, the second pump and maintaining an optimal level of fluids in
the fluid-retaining section.
28. The system of claim 27, further comprises a production packer
disposed in the production well configured to separate a first zone
and a second zone, wherein the second zone is the fluid retaining
section.
29. The system of claim 27, wherein the fluid-retaining section
comprises a cylindrical shroud section arranged around the second
pump comprising a basin for holding fluids that are pumped from the
first pump.
Description
BACKGROUND
[0001] The present technology relates generally to fluid pumps and,
more specifically, to submersible fluid pumps of the type used in
wells such as oil wells for handling multiphase fluids.
[0002] Generally, pumping systems are used in a wide variety of
environments, including wellbore applications for pumping
production fluids, such as water or petroleum. The pumping systems
typically include, among other components, a submersible pump that
provides for the pumping of high volumes of fluid, such as for use
in oil wells which produce large quantities of water, or high
volume water wells and a submersible motor for operating the
electric submersible pump. A typical submersible pump utilizes
numerous pump stages for pumping fluid to the surface from the
well. Recovery of hydrocarbon resources has led to the development
of advanced drilling and completion strategies for wells in gas and
oil reserves. Many of these wells deviate from a straight path in
order to enter production zones and follow geological formations
that are often within a narrow band. Further, these directionally
drilled wells for production of natural gas or shale oil often
extend vertically down to reach the depth of the production
formation and then extend horizontally along the formation. The
flow of fluids produced in the horizontal section can be very
non-uniform depending on the rates at which fluids including water,
oil, and gas enter the flow. The fluids may flow in slugs or
streams depending on the inclination of the wellbore. Furthermore,
the proppants such as sand used in hydraulic fracturing procedures
may remain in the wellbore after well completion and additional
solids may be produced throughout the life of the well. This causes
inferior production rates by the traditional pumping systems due to
difficulty in maintaining required head pressure and handling
multiphase fluids. The life of the pumps is also degraded by the
solids.
[0003] There is therefore a desire for a system and method that
allow increased production rates and life of the pumping systems
used in deviated wellbores.
BRIEF DESCRIPTION
[0004] In accordance with an example of the technology, a method of
isolating a production fluid from a fluid-containing reservoir is
provided. The method includes disposing a first pump within a
horizontal section of a production well. The method also includes
disposing a second pump within a vertical section of the production
well. Further, the method includes pumping a reservoir fluid via
the first pump towards the second pump. The method also includes
capturing at least a portion of the reservoir fluid from the first
pump in a fluid-retaining section located around the second pump.
Furthermore, the method includes pumping the reservoir fluid
captured in the fluid-retaining section to a fluid containment
vessel via the second pump to provide an isolated production
fluid.
[0005] In accordance with an example of the technology, a pumping
system for isolating a production fluid from a fluid-containing
reservoir is provided. The pumping system includes a first pump
configured to be deployed in a horizontal section of a production
well for pumping a reservoir fluid. The pumping system also
includes a second pump configured to be deployed in a vertical
section of the production well. The pumping system further includes
a second pump configured to be deployed in a vertical section of
the production well. The first pump and the second pump are in
fluid communication via a production tubing string.
[0006] In accordance with an example of the technology, a
subterranean pumping system is provided. The subterranean pumping
system includes a first pump configured to be deployed in a
horizontal section of a production well for pumping a reservoir
fluid. The subterranean pumping system also includes a second pump
configured to be deployed in a vertical section of the production
well. Further, the subterranean pumping system includes a
fluid-retaining section disposed around the second pump for holding
fluids that are pumped from the first pump. Further, the
subterranean pumping system includes a control system configured
for controlling flow of fluids pumped from the first pump, the
second pump and maintaining pan optimal level of fluids in the
fluid-retaining section.
DRAWINGS
[0007] These and other features, aspects, and advantages of the
present technology will become better understood when the following
detailed description is read with reference to the accompanying
drawings in which like characters represent like parts throughout
the drawings, wherein:
[0008] FIG. 1 is a schematic view of a pumping system for pumping a
multiphase fluid in accordance with an embodiment of the present
invention;
[0009] FIG. 2 is a schematic view of a pumping system for pumping a
multiphase fluid in accordance with another embodiment of the
present invention;
[0010] FIG. 3 is a schematic view of a pumping system for pumping a
multiphase fluid in accordance with another embodiment of the
present invention;
[0011] FIG. 4 is a schematic view of a pumping system for pumping a
multiphase fluid in accordance with yet another embodiment of the
present invention;
[0012] FIG. 5 of isolating a production fluid from a
fluid-containing reservoir in accordance with an embodiment of the
present invention.
DETAILED DESCRIPTION
[0013] When introducing elements of various embodiments of the
present technology, the articles "a," "an," "the," and "said" are
intended to mean that there are one or more of the elements. The
terms "comprising," "including," and "having" are intended to be
inclusive and mean that there may be additional elements other than
the listed elements. Any examples of operating parameters are not
exclusive of other parameters of the disclosed examples.
[0014] FIG. 1 is a schematic view of a pumping system 10 for
pumping a multiphase fluid in accordance with an embodiment of the
present invention. In the exemplary embodiment, the pumping system
10 includes a first pump 12 that is located in a horizontal section
14 of a production well 16 at an upstream side 18. The pumping
system 10 also includes a second pump 22 located in a vertical
section 24 of the production well 16 at a downstream side 26. Both
the first pump 12 and the second pump 22 are in fluid communication
via a first fluid conduit 20. The second pump 22 is in fluid
connection with a wellhead 28 located aboveground via a second
fluid conduit 23 located in the vertical section 24. The pumping
system 10 may be operated in any location that permits the pumping
system 10 to operate as described herein, e.g., aboveground to
transfer a multiphase fluid from one storage location to another.
Such multiphase fluids may contain high volumes of gas and solids
21 including various mixture of gases, water, sand, crude oil and
the like. In the exemplary embodiment, the production well 16 is a
deviated wellbore used for oil production, where a petroleum fluid
includes a gaseous and liquid multiphase fluid. As used herein, the
term "petroleum fluid" refers broadly to mineral hydrocarbons, such
as crude oil, natural gas, and combinations of oil and gas.
[0015] Further, the pumping system 10 includes a fluid-retaining
section 25 disposed around the second pump 22. The production well
16 is divided between two sections forming a first zone that
encloses the first pump 12 and a second zone that encloses the
second pump 22 by disposing a production packer 27. The second zone
enclosing the second pump 22 forms the fluid-retaining section 25
configured to capture the reservoir fluid pumped from the first
pump 12. The captured reservoir fluid in the fluid-retaining
section 25 is pumped by the second pump 22 to the wellhead 28 above
ground and further to a fluid containment vessel 30.
[0016] Furthermore, each of the first pump 12 and the second pump
22 are controlled by a first power supply unit 32 and a second
power supply unit 34 respectively located above ground. It is to be
noted that each of the first power supply unit 32 and the second
power supply unit 34 includes an electrical supply unit, a
hydraulic supply unit, and a pneumatic unit. Non-limiting examples
of each of the first pump 12 and the second pump 22 includes a
turbo pump, a progressive cavity pump, a reciprocating piston pump
and a jet pump. The turbo pump may include a centrifugal pump or an
axial pump and combinations thereof. Further, in one example each
of the first pump 12 and the second pump 22 is a multistage pump.
In one embodiment, the first pump 12 includes an electric
submersible pump having one or more helico-axial configuration for
pumping multiphase fluids having, high gas volume fractions. The
second pump 22 includes an electric submersible pump having one or
more pump stages in radial or mixed flow configuration for
generating desired head pressure for lifting the fluids from the
fluid-retaining section 25 to the wellhead 16 located aboveground.
As shown, the pumping system 10 includes a first power delivery
conduit 36 and a second power delivery conduit 38 that are disposed
in the production well 16 for delivering power from the first power
supply unit 32 and the second power supply unit 34 to the first
pump 12 and the second pump 22 respectively.
[0017] FIG. 2 is a schematic view of a pumping system 11 for
pumping a multiphase fluid in accordance with another embodiment of
the present invention. As shown in this embodiment, the first zone
in the horizontal section 14 includes the first pump 12 along with
one or more pumps 13, 15. The first pump 12 and the one or more
pumps 13, 15 may be jet pumps and configured to pump reservoir
fluids from the first zone in the horizontal section 14 to the
fluid-retaining section 25. The second pump 22 located in the
second zone within the fluid-retaining section 25 may be an
electric submersible pump configured to pump the reservoir fluid
contained in the fluid retaining section 25 to the wellhead 28
above ground.
[0018] FIG. 3 is a schematic view of a pumping system 40 for
pumping a multiphase fluid in accordance with another embodiment of
the present invention. In this embodiment, the pumping system 40
includes a first pump 12 that is an electric submersible pump
connected with a first variable frequency drive 42 and the first
power supply unit 32 via the first power conduit 36. Similarly, the
pumping system 40 includes a second pump 22 that is also an
electric submersible pump connected with a second variable
frequency drive 44 and the second power supply unit 34 via the
second power conduit 38.
[0019] Further, the pumping system 40 may be operated by a control
system 46 located aboveground and configured for controlling flow
rate of fluids pumped from the first pump 12 and the second pump
22. In one embodiment, the pumping system 40 includes one or more
control systems located above or below ground and configured to
control the operating speed of the first pump 12 and the second
pump 22. Alternatively, the pumping system 40 may be operated to
pump any gaseous and liquid multiphase fluid that permits pumping
system 40 to operate as described herein. The control system 46 may
also be configured to maintain an optimal level of fluids in the
fluid retaining section 25.
[0020] In one embodiment, as shown in FIG. 4, a pumping system 50
includes a fluid-retaining section 52 that has a cylindrical shroud
section 54 arranged around the second pump 22 forming a basin for
holding reservoir fluids that are pumped from the first pump 12. In
this embodiment, an inlet 56 of the second pump 22 is located
within the cylindrical shroud section 54 for allowing intake of
reservoir fluids that are further pumped to the wellhead 28 above
ground and to the fluid containment vessel 30. The second pump 22
is controlled by the second power supply unit 34 such that a liquid
level 58 is maintained above the inlet 56 of the second pump 22.
This ensures there is sufficient flow of reservoir fluids into the
second pump 22 for further pumping to the wellhead 28.
[0021] FIG. 5 is a flow chart of a method 100 of isolating a
production fluid from a fluid-containing reservoir in accordance
with an embodiment of the present invention. At step 102, the
method includes disposing a first pump within a horizontal section
of a production well. At step 104, the method includes disposing a
second pump within a vertical section of the production well.
Further, at step 106, the method includes pumping a reservoir fluid
via the first pump towards the second pump. The reservoir fluids
include a flow of multiphase fluids and solid matter such as
mixture of gases, water, sand, crude oil, and the like. The method
also includes powering the first pump and the second pump using a
first power supply unit and a second power supply unit via a first
power delivery conduit and a second power delivery conduit
respectively that are disposed in the production well. Each of the
first power supply unit and the second power supply unit includes
an electrical supply unit, a hydraulic supply unit, and a pneumatic
unit. Moreover, each of the first pump and the second pump is a
multistage pump including a turbo pump, a progressive cavity pump,
a reciprocating piston pump and a jet pump. The turbo pump used as
the first pump or the second pump may include centrifugal pump or
an axial pump and combinations thereof. In one embodiment, the
first pump includes an electric submersible pump having at least
one or more helico-axial configuration for pumping multiphase
fluids having high gas volume fractions. The second pump includes
an electric submersible pump having at least one or more pump
stages in radial or mixed flow configuration for generating desired
head pressure for lifting the fluids from the fluid retaining
section to the wellhead located aboveground. In one embodiment, the
method further includes isolating a first zone having the first
pump from a second zone having the second pump in the production
well by disposing a production packer, where the second zone is the
fluid-retaining section. In another embodiment, the fluid-retaining
section comprises a cylindrical shroud section arranged around the
second pump comprising a basin for holding fluids that are pumped
from the first pump. At step 108, the method includes capturing at
least a portion of the reservoir fluid from the first pump in the
fluid-retaining section located around the second pump. Finally at
step 110, the method includes pumping the reservoir fluid captured
in the fluid-retaining section to a fluid containment vessel via
the second pump to provide an isolated production fluid. The method
also includes controlling a flow of fluids pumped from the first
pump, the second pump and maintaining an optimal level of reservoir
fluids in the fluid retaining section by one or more control
systems. In one embodiment, a reservoir fluid level is always
maintained above an inlet of the second pump for ensuring
sufficient flow of reservoir fluids into the second pump 22 for
further pumping to the wellhead 28. The one or more control systems
are located above or below ground and configured to control the
operating speed of the first pump and the second pump.
[0022] Advantageously, the present invention is directed towards
improving operability and durability of the pumping system used in
directionally drilled wells. The present pumping system and method
allows efficient pumping of multiphase fluids including solids,
liquids and gases in production of unconventional oil and gas
wells.
[0023] Furthermore, the skilled artisan will recognize the
interchangeability of various features from different examples.
Similarly, the various methods and features described, as well as
other known equivalents for each such methods and feature, can be
mixed and matched by one of ordinary skill in this art to construct
additional systems and techniques in accordance with principles of
this disclosure. Of course, it is to be understood that not
necessarily all such objects or advantages described above may be
achieved in accordance with any particular example. Thus, for
example, those skilled in the art will recognize that the systems
and techniques described herein may be embodied or carried out in a
manner that achieves or improves one advantage or group of
advantages as taught herein without necessarily achieving other
objects or advantages as may be taught or suggested herein.
[0024] While only certain features of the technology have been
illustrated and described herein, many modifications and changes
will occur to those skilled in the art. It is, therefore, to be
understood that the appended claims are intended to cover all such
modifications and changes as fall within the true spirit of the
claimed inventions.
* * * * *