U.S. patent application number 10/709755 was filed with the patent office on 2005-12-01 for flow control in conduits from multiple zones of a well.
This patent application is currently assigned to SCHLUMBERGER TECHNOLOGY CORPORATION. Invention is credited to Achee, Timothy T. JR., Hines, Christopher B..
Application Number | 20050263287 10/709755 |
Document ID | / |
Family ID | 35423942 |
Filed Date | 2005-12-01 |
United States Patent
Application |
20050263287 |
Kind Code |
A1 |
Achee, Timothy T. JR. ; et
al. |
December 1, 2005 |
Flow Control in Conduits from Multiple Zones of a Well
Abstract
An apparatus and method for use in a well having at least three
zones includes at least three sand control assemblies for
positioning proximal respective zones. A flow assembly defines at
least three flow conduits to respectively communicate with the at
least three zones, where each of at least two of the flow conduits
includes an annular path. At least three flow control devices
respectively control flow of the at least three flow conduits.
Inventors: |
Achee, Timothy T. JR.;
(Slidell, LA) ; Hines, Christopher B.; (Covington,
LA) |
Correspondence
Address: |
SCHLUMBERGER RESERVOIR COMPLETIONS
14910 AIRLINE ROAD
ROSHARON
TX
77583
US
|
Assignee: |
SCHLUMBERGER TECHNOLOGY
CORPORATION
300 Schlumberger Drive
Sugar Land
TX
|
Family ID: |
35423942 |
Appl. No.: |
10/709755 |
Filed: |
May 26, 2004 |
Current U.S.
Class: |
166/313 ;
166/54.1 |
Current CPC
Class: |
E21B 43/12 20130101;
E21B 43/14 20130101 |
Class at
Publication: |
166/313 ;
166/054.1 |
International
Class: |
E21B 043/32 |
Claims
1. An apparatus for use in a well having at least three zones,
comprising: at least three sand control assemblies for positioning
proximal respective zones; a flow assembly defining at least three
flow conduits to respectively communicate with the at least three
zones, wherein each of at least two of the flow conduits includes
an annular path; and at least three flow control devices to
respectively control flow of the at least three flow conduits.
2. The apparatus of claim 1, wherein the flow assembly includes a
first tube having an inner bore, a first one of the flow conduits
including the inner bore of the first tube.
3. The apparatus of claim 2, wherein the flow assembly further
includes a second tube having a diameter larger than that of the
first tube, wherein a first annular path is defined between the
first and second tubes, a second one of the flow conduits including
the first annular path.
4. The apparatus of claim 3, wherein the flow assembly further
includes a third tube having a diameter larger than that of the
second tube, wherein a second annular path is defined between the
second and third tubes, a third one of the flow conduits including
the third annular path.
5. The apparatus of claim 4, wherein a first one of the flow
control devices includes a ball valve, the ball valve to control
fluid communication between the first flow conduit and a flow
path.
6. The apparatus of claim 5, wherein a second one of the flow
control device includes a first sleeve valve, the first sleeve
valve to control fluid communication between the second flow
conduit and the flow path.
7. The apparatus of claim 6, wherein a third one of the flow
control devices includes a second sleeve valve, the second sleeve
valve to control fluid communication between the third flow conduit
and the flow path.
8. The apparatus of claim 1, wherein the sand control assembly each
includes at least one sand screen.
9. A system for use in a well having at least three zones,
comprising: a production tubing; and at least three sand control
assemblies for positioning proximal respective zones; a flow
assembly having at least three flow conduits to respectively
communicate with the at least three zones, the flow assembly having
a first tube, wherein a first one of the flow conduits includes an
inner bore of the first tube, a second one of the flow conduits
includes an annular path around the first tube, and a third one of
the flow conduits includes a second annular path around the first
annular path; and at least three flow control devices to
respectively control flow between the at least three flow conduits
and the production tubing.
10. The system of claim 9, wherein the flow assembly includes a
second tube, the first and second tubes defining the first annular
path.
11. The system of claim 10, wherein the flow assembly further
includes a third tube, the second and third tubes defining the
second annular path.
12. The system of claim 11, wherein the first tube has a first
diameter, the second tube has a second diameter greater than the
first diameter, and the third tube has a third diameter greater
than the second diameter.
13. The system of claim 12, wherein at least portions of the first,
second, and third tubes have a common axis.
14. The system of claim 9, wherein the flow control device to
control flow between the first flow conduit and the production
tubing comprises a ball valve.
15. The system of claim 14, wherein the flow control device to
control flow between the second flow conduit and the production
tubing comprises a first sleeve valve.
16. The system of claim 15, wherein the flow control device to
control flow between the third flow conduit and the production
tubing comprises a second sleeve valve.
17. The system of claim 16, wherein the third flow conduit further
comprises a well annular region, the second sleeve valve to control
fluid communication between the well annular region and the
production tubing.
18. The system of claim 9, wherein the flow control devices are
remotely actuatable.
19. The system of claim 18, wherein the flow control devices are
actuatable by at least one of electrical signals, fiber optic
signals, and hydraulic pressure.
20. A method of controlling fluid flow in a well having at least
three zones, comprising: providing a flow assembly having at least
three conduits to communicate with the at least three zones,
wherein a second one of the conduits comprises a first annular path
around a first one of the conduits, and a third one of the conduits
comprises a second annular path around the first annular path;
positioning sand control equipment proximal the at least three
zones; and remotely controlling flow control devices to control
fluid flow through the at least three flow conduits.
21. The method of claim 20, wherein providing the flow assembly
comprises providing first, second, and third tubes, the first
conduit comprising an inner bore of the first tube, the first
annular path defined between the first tube and the second tube,
and the second annular path defined between the second tube and the
third tube.
22. The method of claim 20, wherein remotely controlling the flow
control devices comprises remotely controlling with at least one of
electrical signals, fiber optic signals, and hydraulic pressure.
Description
BACKGROUND OF INVENTION
[0001] It is common for wells to include multiple zones. A
completion string positioned in a well to produce fluids from one
or more zones may include casing, production tubing, packers,
valves, pumps, and other components. One or more well sections may
be perforated using a perforating gun string to create openings in
the casing and to extend perforations into corresponding zones.
Fluid flows from the zones through the perforations and casing
openings into the wellbore and up the production tubing to the
surface.
[0002] In many wells, sand control has to be performed to prevent
the production of sand along with hydrocarbons through the
production string. Sand control is typically accomplished by use of
sand face completion hardware, which typically includes a sand
screen. In a well having multiple zones, the presence of certain
completion hardware, such as sand face completion hardware, may
complicate the placement of flow control conduits and flow control
valves. The complexity of completion hardware associated with
completing a well with multiple zones can lead to increased
expenses associated with operating the well. Also, in some cases,
the presence of completion hardware for multiple zones may prevent
convenient intervention operations.
SUMMARY OF INVENTION
[0003] In general, enhanced methods and apparatus are provided to
complete a well having multiple zones. For example, an apparatus
for use in a well having at least three zones includes at least
three sand control assemblies for positioning proximal respective
zones. The apparatus further includes a flow assembly defining at
least three flow conduits to respectively communicate with the at
least three zones, where each of at least two of the flow conduits
includes an annular path. At least three flow control devices
respectively control flow in the at least three flow conduits.
[0004] Other or alternative features will become apparent from the
following description, from the drawings, and from the claims.
BRIEF DESCRIPTION OF DRAWINGS
[0005] FIG. 1 illustrates a completion string incorporating an
embodiment of the invention.
[0006] FIGS. 2A-2C are cross-sectional views of the completion
string of FIG. 1.
DETAILED DESCRIPTION
[0007] In the following description, numerous details are set forth
to provide an understanding of the present invention. However, it
will be understood by those skilled in the art that the present
invention may be practiced without these details and that numerous
variations or modifications from the described embodiments are
possible.
[0008] As used here, 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 described 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.
[0009] FIG. 1 is a general view of a completion string positioned
in a well 100. Although the well 100 depicted in FIG. 1 has one
wellbore, it is contemplated that a well can have multiple bores,
such as multilateral or branch bores. The well 100 has at least
three zones 102, 104, and 106. In other implementations, the well
100 may have additional zones (such as four or more). The zones
102, 104, and 106 are stacked one above another generally along an
axial direction of the wellbore 100. In this stacked arrangement,
particularly when sand control equipment is used, it is sometimes
difficult to provide flow conduits through the completion string in
an efficient manner.
[0010] In accordance with some embodiments of the invention, three
flow conduits 108, 110, and 112 are provided by a flow assembly in
the completion string. In the implementation of FIG. 1, the first
flow conduit 108 communicates with the zone 102 through a first
sand control assembly 114. The second flow conduit 110 communicates
with the second zone 104 through a second sand control assembly
116. The third flow conduit 112 communicates with the third zone
106 through a third sand control assembly 118. Note that in the
depiction of FIG. 1, the zone 102 is the most distal zone of the
well from the well earth surface, whereas the zone 106 is the most
proximal zone to the well earth surface.
[0011] The first flow conduit 108 extends through the inner bore of
a tube or pipe. As used here, the term "tube" or "pipe" refers to
an elongated structure that defines an inner bore. The elongated
structure can be formed of one segment or of plural segments that
are attached or coupled to each other. Although some embodiments of
a "tube" or "pipe" are generally cylindrical in shape, other
embodiments of a "tube" or "pipe" do not have to be cylindrically
shaped. The terms "tube" and "pipe" are used interchangeably.
[0012] The second flow conduit 110 is an annular path that is
defined outside of the tube that defines the first flow conduit
108. In some embodiments, the second flow conduit 110 is the
annular path between a first tube containing the first flow conduit
108 and a second tube having a larger diameter than the first
tube.
[0013] Similarly, the third flow conduit 112 is an annular path
that is defined outside of the second tube. The third flow conduit
112, in some embodiments, is defined between the second tube and a
third tube having a larger diameter than the second tube. A portion
of the third flow conduit 112 includes a wellbore annulus region
120, according to one embodiment.
[0014] Also shown in FIG. 1 are several packers 122, 124, 126, 128,
130, and 132. In other implementations, the number of packers can
vary. The packers are provided to provide isolation between zones.
Thus, any number of packers that provide adequate isolation between
zones can be employed.
[0015] Flow control devices are also part of the completion string
to control fluid flow in the flow conduits 108, 110, and 112. A
first flow control device 134 controls fluid flow through the first
flow conduit 108. In one implementation, the first flow control
device 134 is a ball valve that is actuatable between an open
position and a closed position.
[0016] In other embodiments, other types of valves can be used in
the flow control device 134. Examples of other valves include
flapper valves, sleeve valves, barrel valves, and so forth.
[0017] A second flow control device 136 controls fluid flow in the
second flow conduit 110. In one implementation, the second flow
control device 136 includes a sleeve valve, although other types of
valves can be used in other embodiments.
[0018] A third flow control device 138 controls fluid flow in the
third flow conduit 112. Again, the third flow control device 138 is
implemented as a sleeve valve in one embodiment. In other
embodiments, the flow control device 138 can be implemented with
other types of valves.
[0019] Each of the flow control devices 134, 136, and 138 is
remotely actuatable by use of signals transmitted from the well
surface to the flow control devices 134, 136, and 138. For example,
the flow control devices 134, 136, and 138 can be electrically
activated between open and closed positions. Electrical activation
can be accomplished by using electrical lines run from the well
surface to the flow control devices. Alternatively, hydraulic
pressure can be used to control the flow control devices 134, 136,
and 138. The hydraulic pressure can be communicated through control
lines that are run from the well surface. Pressure pulses can also
be transmitted through fluids in the wellbore to perform actuation
of the flow control devices. Also, fiber optic lines can be run
from the well surface, with optical signals transmitted through the
fiber optic lines to control the flow control devices. Remote
mechanical actuation can also be performed by use of mechanical
signals (such as by lifting and dropping a portion of the
completion screen in a predetermined sequence to control activation
of the flow control devices 134, 136, and 138). Wireless
techniques, such as electromagnetic, seismic, and acoustic
telemetry, may also be used to communicated with the flow control
devices.
[0020] In other embodiments, the flow control devices 134, 136, and
138 are multi-position flow control device having at least one
additional position between on and off.
[0021] Once activated, each of the flow control devices 134, 136,
and 138 controls fluid communication between the flow conduits 108,
110, and 112, respectively, and a flow path 140 that extends
upwardly, such as to the well surface through a production
tubing.
[0022] Although not shown, sensors (e.g., flow rate sensors,
pressure sensors, temperature sensors, etc.) can also be provided
in the flow conduits 108, 110, and 112. The sensors are provided to
measure characteristics associated with fluid flow from the zones
102, 104, and 106.
[0023] FIGS. 2A-2C provide cross-sectional views of a portion of
the completion string of FIG. 1. The bottom part of FIG. 2C shows
the lower-most packer 122 and sand control assembly 114. The sand
control assembly 114 includes two sand screens 200 and 202 stacked
one on top of the other. In other implementations, one sand screen
can be used in the sand control assembly 114. Fluid flows from
surrounding formation (of the first zone 102) through the sand
screens 200 and 202 into an inner bore 204 defined by a first tube
206. Note that the first tube 206 includes many segments as
depicted in FIGS. 2A Rather than label each of these segments with
a different reference number, the segments are referred to
collectively as a "tube" 206. The segments of the tube 206 include
all segments that define the inner bore 204, which is part of the
first flow conduit 108. An isolation sub 208 includes a ball valve
210. During run-in of the completion string, the ball valve 210 is
in a closed position. However, once the completion string is
installed, the ball valve 210 is opened and kept open during
production. The ball valve 210 has a bore through which
intervention equipment can pass.
[0024] The inner bore 204 (and first flow conduit 108) extend
through the packer 124 that is located above the isolation assembly
208. The flow conduit 108 also extends through another packer 126
located above the packer 124. The packer 126 is connected to the
second sand control assembly 116, which also includes a sand screen
212. As shown at the top part of FIG. 2C, flow from the surrounding
formation (in zone 104) passes through the sand screen 212 into an
annular path 214 that is defined outside the tube 206 defining the
first flow path 108. The annular path is defined between the first
tube 206 and a second tube 216 (FIG. 2B) that has a larger diameter
than the first tube 206. The second flow conduit 110 extends
through the annular path between the first tube 206 and the second
tube 216. As with the first tube 206, the second tube 216 also
includes multiple segments, which are collectively referred to as
"tube" 216.
[0025] The first and second flow conduits 108 and 110 extend
through the next upper packer 128. The packer 128 is connected to
the third sand control assembly 118, which includes a sand screen
218. Fluid flows through the sand screen 218 into an annular path
220 defined between the second tube 216 and a third tube 222. The
annular region 220 is part of the third flow conduit 112. The
first, second and third flow conduits extend through the next
packer 130.
[0026] In one embodiment, at least portions of the first, second,
and third tubes have a common axis. In other words, these portions
of the first, second, and third tubes are concentric.
[0027] The third flow conduit 112 extends into the well annulus 120
outside the second tube 216. The ball valve 134 is located in the
first flow conduit 108 (see the upper part of FIG. 2B) to control
fluid flow between the first flow conduit 108 and the flow path 140
in a production tubing. The ball valve 134 is remotely actuatable
to rotate between open and closed positions. A sleeve valve 136 is
provided slightly above the ball valve 134 to control fluid flow in
the second flow conduit 110. The sleeve valve 136 is slidable up
and down (by remote actuation) to enable opening and closing of a
port between the annular path 214 and the flow path 140.
[0028] As depicted in FIG. 2A, the third flow conduit 112 extends
through the well annulus 120 to the sleeve valve 138, which is
slidable up and down (by remote actuation) to open and close ports
between the well annulus 120 and the flow path 140.
[0029] In operation, depending on which of the zones 102, 104, and
106 are to be produced, one of the flow control devices 134, 136,
and 138 is actuated to the open position, while the remaining two
flow control devices are maintained in the closed position.
Alternatively, if multiple zones are to be produced, then two or
more of the flow control devices 134, 136, and 138 can be opened,
with fluids from the multiple zones commingled for production in
the flow path 140 to the well surface. In other implementations,
instead of producing fluids from zones 102, 104, and 106, injection
can be performed in which fluid is injected into one or more of the
zones 102, 104, and 106. In similar fashion, the flow control
devices 134, 136, and 138 control injection of fluids into
respective zones 102, 104, and 106.
[0030] Another valve can also be stacked in the lower completion
(such as below sand control assembly 114) to incorporate flow from
an additional zone, if desired. Such valve would provide selective
fluid communication between the additional zone and the flow
conduit 108.
[0031] By using the flow assembly according to some embodiments of
the invention, convenient placement of flow control devices in
conjunction with sand control equipment can be accomplished. Also,
by using the flow assembly according to some embodiments,
intervention operations are made more convenient.
[0032] While the present invention has been described with respect
to a limited number of embodiments, those skilled in the art,
having the benefit of this disclosure, will appreciate numerous
modifications and variations therefrom. For instance, the present
invention may be installed in a land as well as a subsea wellbore.
It is intended that the appended claims cover all such
modifications and variations as fall within the true spirit and
scope of this present invention.
* * * * *