U.S. patent application number 14/260731 was filed with the patent office on 2015-10-29 for pumping system.
The applicant listed for this patent is PUMPTEK ASIA LTD., DBA PUMPTEK, LLC. Invention is credited to Mitchell Crane, Anton Shakirov.
Application Number | 20150308434 14/260731 |
Document ID | / |
Family ID | 54334331 |
Filed Date | 2015-10-29 |
United States Patent
Application |
20150308434 |
Kind Code |
A1 |
Crane; Mitchell ; et
al. |
October 29, 2015 |
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.
Inventors: |
Crane; Mitchell;
(Samutprakarn, TH) ; Shakirov; Anton; (Moscow,
RU) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
PUMPTEK ASIA LTD., DBA PUMPTEK, LLC |
Hong Kong |
|
CN |
|
|
Family ID: |
54334331 |
Appl. No.: |
14/260731 |
Filed: |
April 24, 2014 |
Current U.S.
Class: |
417/54 ;
417/84 |
Current CPC
Class: |
F04F 5/10 20130101; F04D
13/12 20130101; F04D 13/10 20130101; F04D 1/06 20130101; F04D
29/708 20130101 |
International
Class: |
F04D 13/12 20060101
F04D013/12; F04F 5/10 20060101 F04F005/10; F04D 29/70 20060101
F04D029/70; F04D 1/06 20060101 F04D001/06; F04D 13/06 20060101
F04D013/06 |
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.
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.
* * * * *