U.S. patent application number 15/050689 was filed with the patent office on 2017-08-24 for multilateral junction with feed-through.
This patent application is currently assigned to Baker Hughes Incorporated. The applicant listed for this patent is Baker Hughes Incorporated. Invention is credited to Mark Knebel, Bryan P. Pendleton, Joseph Sheehan.
Application Number | 20170241241 15/050689 |
Document ID | / |
Family ID | 59630988 |
Filed Date | 2017-08-24 |
United States Patent
Application |
20170241241 |
Kind Code |
A1 |
Pendleton; Bryan P. ; et
al. |
August 24, 2017 |
Multilateral Junction with Feed-Through
Abstract
A hydrocarbon production assembly within a multilateral
wellbore, the multilateral wellbore having a main bore portion
which extends downwardly from surface and a lateral leg which
extends radially away from the main bore portion.
Inventors: |
Pendleton; Bryan P.;
(Cypress, TX) ; Sheehan; Joseph; (Cypress, TX)
; Knebel; Mark; (Tomball, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Baker Hughes Incorporated |
Houston |
TX |
US |
|
|
Assignee: |
Baker Hughes Incorporated
Houston
TX
|
Family ID: |
59630988 |
Appl. No.: |
15/050689 |
Filed: |
February 23, 2016 |
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 47/06 20130101;
E21B 41/0042 20130101; E21B 43/26 20130101; E21B 47/12 20130101;
E21B 47/07 20200501; E21B 43/14 20130101; E21B 47/10 20130101; E21B
2200/06 20200501; E21B 34/06 20130101; E21B 41/0035 20130101 |
International
Class: |
E21B 41/00 20060101
E21B041/00; E21B 43/14 20060101 E21B043/14; E21B 47/12 20060101
E21B047/12; E21B 34/06 20060101 E21B034/06; E21B 47/10 20060101
E21B047/10 |
Claims
1. A hydrocarbon production assembly within a multilateral
wellbore, the multilateral wellbore having a main bore portion
which extends downwardly from surface and a lateral leg which
extends radially away from the main bore portion, the completion
arrangement comprising: a lateral leg completion arrangement
located within the lateral leg and having a tubular conduit which
defines a flowbore along its length and at least one first flow
controller which can be opened and closed to selectively allow
fluid communication with the flowbore; a main bore completion
arrangement located within the main bore portion, the main bore
completion arrangement having a tubular conduit which defines a
flowbore along its length and at least one second flow controller
which can be opened and closed to selectively allow fluid
communication with the flowbore; a first isolation string which
resides within the lateral leg completion arrangement, the first
isolation string comprising a tool string having a valve actuator
which actuates the at least one first valve between open and closed
positions; and a second isolation string which resides within the
main bore completion arrangement, the second isolation string
comprising a tool string having a valve actuator which actuates the
at least one second valve between open and closed positions.
2. The hydrocarbon production assembly of claim 1 wherein: the at
least one first flow controller permits fluid flow outwardly from
the flowbore of the lateral leg completion assembly; and the at
least one second flow controller permits fluid flow outwardly from
the flowbore of the main bore completion assembly.
3. The hydrocarbon production assembly of claim 1 wherein: the at
least one first flow controller permits fluid flow inwardly to the
flowbore of the lateral leg completion assembly; and the at least
one second flow controller permits fluid flow inwardly to the
flowbore of the main bore completion assembly.
4. The hydrocarbon production assembly of claim 1 wherein at least
one of the first and second isolation strings further comprises a
monitoring gauge which is positioned proximate the valve of the
respective main bore or lateral leg completion arrangement when
seated within to measure at least one fluid flow related parameter
as fluid is flowed through the flowbore of the respective main bore
or lateral leg completion arrangement.
5. The hydrocarbon production assembly of claim 1 further
comprising a communication work string that is interconnected with
the first and second isolation strings to provide a communication
line between the first and second isolation strings and at least
one transmission/reception device at the surface.
6. The hydrocarbon production assembly of claim 1 further
comprising a feed-through device having: a mandrel to be seated
within the main bore portion; an opening disposed within the
mandrel through which the second isolation string is disposed into
the main bore completion arrangement; and a downhole mating
connector for connecting a communication line with the first
isolation string.
7. The hydrocarbon production assembly of claim 6 wherein the
mandrel of the feed-through device is seated upon a seal bore
diverter which is disposed upon the main bore completion
arrangement.
8. The hydrocarbon production assembly of claim 5 wherein the at
least one transmission/reception device is at least one of the
group consisting of: electrical power generator, hydraulic fluid
pump, optical time domain reflectometer and processor.
9. The hydrocarbon production assembly of claim 5 wherein the
communication line comprises at least one of the group consisting
of: electrical power conduit, hydraulic conduit, optical fiber, and
electrical data cable.
10. A hydrocarbon production assembly within a multilateral
wellbore, the multilateral wellbore having a main bore portion
which extends downwardly from surface and a lateral leg which
extends radially away from the main bore portion, the completion
arrangement comprising: a lateral leg completion arrangement
located within the lateral leg and having a tubular conduit which
defines a flowbore along its length and at least one first flow
controller which can be opened and closed to selectively allow
fluid communication with the flowbore; a main bore completion
arrangement located within the main bore portion, the main bore
completion arrangement having a tubular conduit which defines a
flowbore along its length and at least one monitoring gauge which
detects a parameter related to fluid flow proximate an at least one
second flow controller; a first isolation string which resides
within the lateral leg completion arrangement, the first isolation
string comprising a tool string having a valve actuator which
actuates the at least one first flow controller between open and
closed positions; and a second isolation string which resides
within the main bore completion arrangement.
11. The hydrocarbon production assembly of claim 10 further
comprising a communication work string that is interconnected with
the first and second isolation strings to provide a communication
line between the first and second isolation strings and at least
one transmission/reception device at the surface.
12. The hydrocarbon production assembly of claim 10 further
comprising a feed-through device having: a mandrel to be seated
within the main bore portion; an opening disposed within the
mandrel through which the second isolation string is disposed into
the main bore completion arrangement; and a downhole mating
connector for connecting a communication line with the first
isolation string.
13. The hydrocarbon production assembly of claim 12 further
comprising a whipstock and seal bore diverter which is disposed
atop the main bore completion arrangement.
14. The hydrocarbon production assembly of claim 13 wherein the
mandrel of the feed-through device is seated upon the seal bore
diverter.
15. The hydrocarbon production assembly of claim 11 wherein the at
least one transmission/reception device is at least one of the
group consisting of: electrical power generator, hydraulic fluid
pump, optical time domain reflectometer and processor.
16. The hydrocarbon production assembly of claim 11 wherein the
communication line comprises at least one of the group consisting
of: electrical power conduit, hydraulic conduit, optical fiber, and
electrical data cable.
17. The hydrocarbon production assembly of claim 10 wherein the
second isolation string comprising a tool string having a valve
actuator which actuates the at least one second flow controller
between open and closed positions.
18. A hydrocarbon production assembly within a multilateral
wellbore, the multilateral wellbore having a main bore portion
which extends downwardly from surface and a lateral leg which
extends radially away from the main bore portion, the completion
arrangement comprising: a lateral leg completion arrangement
located within the lateral leg and having a tubular conduit which
defines a flowbore along its length and at least one first flow
controller which can be opened and closed to selectively allow
fluid communication with the flowbore; a main bore completion
arrangement located within the main bore portion, the main bore
completion arrangement having a tubular conduit which defines a
flowbore along its length and at least one second flow controller
which can be opened and closed to selectively allow fluid
communication with the flowbore; a first isolation string which
resides within the lateral leg completion arrangement, the first
isolation string comprising a tool string having a valve actuator
which actuates the at least one first flow controller between open
and closed positions; a second isolation string which resides
within the main bore completion arrangement, the second isolation
string comprising a tool string having a valve actuator which
actuates the at least one second flow controller between open and
closed positions; and a communication work string that is
interconnected with the first and second isolation strings to
provide a communication line between the first and second isolation
strings and at least one transmission/reception device at the
surface.
19. The hydrocarbon production assembly of claim 18 further: the at
least one first flow controller permits fluid flow outwardly from
the flowbore of the lateral leg completion assembly; and the at
least one second flow controller permits fluid flow outwardly from
the flowbore of the main bore completion assembly.
20. The hydrocarbon production assembly of claim 18 further: the at
least one first flow controller permits fluid flow inwardly to the
flowbore of the lateral leg completion assembly; and the at least
one second flow controller permits fluid flow inwardly to the
flowbore of the main bore completion assembly.
Description
[0001] FIG. 2 is a side, cross-sectional view of the wellbore shown
in FIG. 1, now with a lateral leg having been drilled.
[0002] FIG. 3 is a side, cross-sectional view of the wellbore shown
in FIGS. 1, 1A and 2 now with a lateral leg completion arrangement
run into the lateral leg.
[0003] FIG. 4 is a side, cross-sectional view of the wellbore shown
in FIGS. 1, 1A, 2-3 now with a feed-through assembly run into the
wellbore and a first isolation string run into the lateral leg
completion arrangement.
[0004] FIG. 4A is an enlarged, cross-sectional view of portions of
FIG. 4.
[0005] FIG. 5 is a side, cross-sectional view of the wellbore shown
in the previous figures, now with a pass-through device having been
landed within the wellbore.
[0006] FIG. 5A is an enlarged, cross-sectional view of portions of
FIG. 5.
[0007] FIG. 6 is a side, cross-sectional view of the wellbore shown
in the previous figures, how with a second isolation string having
been run into the main bore portion of the wellbore.
[0008] FIG. 7 is a side, cross-sectional view of an exemplary
feed-through device used within the wellbore, apart from the other
components.
[0009] FIG. 8 is an axial cross-section taken along lines 8-8 in
FIG. 7.
[0010] FIG. 9 is a schematic diagram which illustrates such
communication for a completed wellbore assembly.
DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS
[0011] The term "multilateral," as used herein, will refer to
wellbores having a main bore, or leg, and at least one lateral leg
which branches off from the main bore and extends radially away
from the main bore. The term "communication line," as used herein,
refers broadly to conduits used in a wellbore for transmission of
power, fluids and/or data. Communication lines can include
electrical power cables, electrical data cables, optic fibers,
and/or hydraulic lines.
[0012] FIGS. 1 and 1A illustrate a portion of an exemplary wellbore
10 which has been drilled through the earth 12. The wellbore 10 has
an upper portion which has been lined with casing 14 and a lower
main bore portion 16 which is unlined. A main bore completion
arrangement, generally indicated at 18, has been run into the lower
unlined portion 16, which shall also be referred to as the main
bore portion of the wellbore 10. The exemplary main bore completion
arrangement 18 is a tubular conduit which includes packers 20 and
22 which can be set to secure the main bore completion arrangement
18 within the main bore portion 16 of the wellbore 10. The main
bore completion arrangement 18 also includes a lateral valve 24 and
screen 26. A flowbore 28 is defined along the length of the main
bore completion assembly 18. Fluid communication with the flowbore
28 is permitted through the use of flow controllers in the form of
lateral valve 24 and screen 26. The lateral valve 24 is preferably
a frac sleeve of a type known in the art which can be selectively
moved between open and closed positions. In the open position, the
lateral valve 24 permits fluid communication between the flowbore
28 and the radial exterior of the main bore completion arrangement
18.
[0013] A combination whipstock and seal bore diverter 30 is located
within the wellbore 10 above the main bore completion arrangement
18. Preferably, the whipstock and seal bore diverter 30 is secured
within the casing 14 of the wellbore 10 by anchor 32.
[0014] The whipstock and seal bore diverter 30 may be used to
sidetrack a mill and subsequently a drill to create a lateral leg,
as is known in the art. FIG. 2 illustrates the wellbore 10 after a
lateral leg 34 has been created.
[0015] FIG. 3 illustrates the wellbore 10 at a subsequent time when
a lateral leg completion arrangement 36 has been emplaced within
the lateral leg 34. The lateral leg completion arrangement 36 can
be run in by wireline or coiled tubing based running string or by
other conventional methods and released within the lateral leg 34.
The running string is then removed. The exemplary lateral leg
completion arrangement 36 is a tubular string which includes
packers 38, 40 as well as a lateral valve 42 and sleeve 44. A
flowbore 46 is defined along the length of the lateral leg
completion arrangement 36. The lateral valve 42 can be selectively
moved between open and closed positions in order to control fluid
communication between the flowbore 46 and the area radially
surrounding the lateral leg completion arrangement 36. The
completion 36 presents a closed distal end 48 and an open proximal
end 50. The sleeve 44 is preferably a sliding sleeve device that
can be opened and closed to allow fluid communication with the
flowbore 46 of the lateral leg completion arrangement 36.
[0016] FIGS. 4 and 4A depict the wellbore 10 now with a first
isolation string 52 having been run in and landed within the
lateral leg completion arrangement 36. The first isolation string
52 is inserted into the open end 50 and preferably extends along
the entire length of the lateral leg completion arrangement 36 and
bottoms out at the closed distal end 48. The first isolation string
52 is preferably run in using a wireline or coiled tubing based
running string and is then released within the lateral leg
completion arrangement 36. The first isolation string 52 contains
one or more communication lines and one or more devices that either
utilize power from surface or that communicate with the surface. In
the depicted embodiment, the first isolation string 52 includes a
monitoring gauge 54. The monitoring gauge 54 typically includes one
or more sensors that are capable of detecting at least one
operational parameter, such as temperature, pressure or flow rate.
In preferred embodiments, the monitoring gauge 54 detects
operational parameters of fracturing fluid that is pumped through
the lateral leg completion assembly 36 during fracturing
operations. The operational parameters detected by the monitoring
gauge 54 are transmitted to surface via communication line. When
the first isolation string 52 is seated within the lateral leg
completion 36, the monitoring gauge 54 is preferably located
slightly upstream of the sleeve 44, as best seen in FIG. 4A, in
order to measure temperature, pressure or other parameters relating
to fracturing fluid proximate the sleeve 44 where the fluid would
exit the flowbore 46.
[0017] The first isolation string 52 also includes a valve actuator
56. The valve actuator 56 is operable to actuate the lateral valve
42 of the lateral leg completion arrangement 36 between open and
closed positions. A suitable valve actuator for use as the valve
actuator 56 is an IWS (Intelligent Wellbore System) valve actuator
which is available commercially from Baker Hughes Incorporated of
Houston, Tex. It is noted that both the monitoring gauge 54 and the
valve actuator 56 of the first isolation string 52 require, or
preferably utilize, communication from surface to operate in their
intended manner. The monitoring gauge 54, for example, preferably
transmits data relating to detected operational parameters uphole
to surface via one or more communication lines (electrical/fiber
optic). The valve actuator 56 preferably utilizes power from
surface (electrical/hydraulic) to operate.
[0018] The first isolation string 52 also features a mating
connector 58 at its uphole end which will permit connection of
communication lines within the first isolation string in end-to-end
fashion with other communication lines. Preferably, the mating
connector 58 is a wet mate connector which allows connection of
electrical and other communication lines even in the presence of
fluids. An example of a suitable wet mate connector is the annular
electrical wet connect CA2669750 A1 which is available commercially
from Baker Hughes Incorporated of Houston, Tex. Wet connect devices
are also described in U.S. Pat. No. 6,439,932 ("Multiple Protected
Live Circuit Wet Connect System") issued to Ripolone.
[0019] FIGS. 5 and 5A illustrate the wellbore 10 now with a feed
through device having been landed within the wellbore and a mating
connection made with the mating connector 58 of the first isolation
string 52. Feed through device 60 is shown seated upon the seal
bore assembly 30, the whipstock having been removed previously. A
packer 62 is preferably used to secure the feed through device 60
within the cased portion 14 of the wellbore 10.
[0020] A suitable device for use as the feed-through device 60
would be a Hydrasplit.TM. multilateral junction which is available
commercially from Baker Hughes Incorporated of Houston, Tex. FIGS.
7 and 8 illustrate an exemplary feed-through device 60 which
features a central mandrel 64 which defines an interior bore 66.
The mandrel 64 splits into two legs 68, 70 at its lower end. First
leg 68 has an outer surface portion 72 which is shaped and sized to
be seated within the upper end of the seal bore diverter 30. When
the first leg 68 is so seated, the second leg 70 will have entered
the lateral leg 34 of the wellbore 10. The first leg 68 also
defines an interior bore 74 through which tools, objects and fluids
can be passed through the feed through device 60 into or out of the
main bore completion assembly 18 below. The second leg 70 features
one or more bores 76 through which objects and fluids can be passed
through the feed through device 60 into or out of the lateral leg
completion assembly 36. In the depicted embodiment, the bores 76
are used to contain communication lines, although some bores 76 may
be used purely for production and be isolated from the interior
bore 66. In the embodiment depicted in FIGS. 7-8, there are three
bores 76. However, there may be more or fewer than three, as
desired to create the desired number and types of communication
lines to surface.
[0021] The feed-through device 60 is provided with suitable
communication lines 78 (best shown in FIG. 5A) which extend through
the feed-through device 60 and will permit communication of power
and/or data between the surface and the first isolation string 52.
As best seen in FIG. 5A, communication lines 78 include a mating
connector 80 which is complementary to the uphole mating connector
58 of the first isolation string 52. The communication lines 78
terminate at an uphole mating connector 82. When the feed through
device 60 is set down and landed upon the seal bore diverter 30 and
set down weight applied, the connector 80 is interconnected with
the uphole mating connector 58.
[0022] FIG. 6 illustrates the wellbore 10 at a time after the
feed-through device 60 has been landed and communication line
interconnection is made with the first isolation string 52. A
communication work string 84 has now been lowered into the wellbore
10. The communication work string 84 includes tubing 86 for
production to surface. The production tubing 86 also includes
communication lines which extend to surface. A communications
mating assembly 88 is located at the lower end of the production
tubing 86. The communications mating assembly 88 will interconnect
with the uphole mating connector 82 and will thereby provide a
communication path between the first isolation string 52 and the
surface of the wellbore 10.
[0023] A second isolation string 90 forms a part of the
communication work string 84 and extends downwardly from the
communications mating assembly 88. As the communications mating
assembly 88 is interconnected with the uphole mating connector 82,
the second isolation string 90 will be fed through the bore 74 of
the feed through device 60 and landed within the flowbore 28 of the
main bore completion assembly 18. The exemplary second isolation
string 90 of FIG. 6 includes a monitoring gauge 92. The monitoring
gauge 92 will preferably be positioned slightly uphole from the
screen 26 in order to measure temperature, pressure or other
parameters relating to fracturing fluid proximate the screen 26
where the fluid would exit the flowbore 28. The exemplary second
isolation string 90 also includes a valve actuator 94. The frac
sleeve 24 is used for fracturing the surrounding formation prior to
installation of the second isolation string 90. Production fluid
will later enter via the screen 26. The valve actuator 94 allows an
operator to flow from the particular zone in which the screen 26 is
located. The valve actuator 94 is located proximate the lateral
valve 24 so that it can move the lateral valve 24 between open and
closed positions. The valve actuator 94 preferably utilizes power
from surface (electrical/hydraulic) to operate.
[0024] Once the communication work string 84 has been landed within
the wellbore 10, complete communication lines are now provided
between devices at the surface and components in the first and
second isolation strings 52, 90. FIG. 9 is a schematic diagram
illustrating communication lines between the surface 96 and certain
components within the first and isolation strings 52, 90 in the
wellbore 10. At surface 96 are several exemplary
transmission/reception devices which can be used to transmit power
or commands downhole or which receive data or information from the
wellbore 10. Some or all of these transmission/reception devices
might be used in any particular instance. These devices include an
electrical power generator 98 and hydraulic fluid pump 100. An
optical time-domain reflectometer ("OTDR") 102 is also located at
surface 96 and is used to transmit and receive data along an
optical fiber. Additionally, a processor 104 is located at surface
96 which is programmed to receive, store and/or display data
detected by a downhole sensor. The processor 104 may be in the form
of a computer with suitable software and programming.
[0025] Communication lines extend from the surface 96 to components
within the wellbore 10. FIG. 9 is a schematic diagram which
illustrates such communication for a completed wellbore assembly.
Communication lines include an electrical power conduit 106 which
extends from the power generator 98 into the wellbore 10. The
electrical power conduit 106 can supply electrical power to valve
actuators 56, 94 (if electrically operated) and/or to monitoring
gauges 54, 92. A hydraulic conduit 108 leads from the fluid pump
100 and can be used to supply hydraulic power to operate valve
actuators 56, 94 (if hydraulically actuated). An optical fiber 110
and an electrical data cable 112 extend into the wellbore 10 from
the OTDR 102 and processor 104, respectively. Each of these
communication lines (110, 112) is useful to transmit data,
information, or commands between the surface 96 and components
within the wellbore 10, such as the monitoring gauges 54, 92 or
possibly the valve actuators 56, 94.
[0026] The invention provides a communication junction arrangement
for a multilateral wellbore having a main bore portion 16 and at
least one lateral leg 34. In other aspects, the invention provides
a method for constructing a hydrocarbon production assembly within
a multilateral wellbore which provides communication lines for
completion arrangements 18, 36 in both the main bore portion 16 and
the lateral leg 34. In accordance with these methods, a main bore
completion arrangement 18 is disposed within a main bore portion 16
of a wellbore 10. A whipstock and seal bore diverter 30 is then
landed upon the main bore completion arrangement 18. A lateral leg
34 is then formed which extends radially away from the main bore
portion 16. Next, a lateral leg completion arrangement 36 is then
disposed within the lateral leg 34. A first isolation string 52 is
inserted into the lateral leg completion arrangement 36. A second
isolation string 90 is then inserted into the main bore completion
arrangement below the seal bore diverter 30. Communication is then
established between each of the first and second isolation strings
52, 90 and at least one transmission/reception device at surface
96. The transmission/reception devices include electrical power
generator 98, hydraulic fluid pump 100, OTDR 102 and processor 104.
Communication is established by lines 106, 108, 110 and/or 112.
[0027] In operation, fluid flow parameters are measured as fluid
(i.e., fracturing fluid) is flowed out of the flowbores 28, 46 of
the main bore and lateral leg completion arrangements 18, 36
through valves 56, 94 and screen 26. Fluid that is flowed can
include fracturing fluid or other formation treatment fluid which'
is flowed out of the flowbores 28, 46 and into the surrounding
formation. Fluid that is flowed can also include hydrocarbon
production fluid that is drawn into the flowbores 28, 46 of the
main bore and lateral leg completion arrangements 18, 36. Thus, the
valves 56, 94, screen 26, and valve 42 can be thought of as flow
controllers which can be opened and closed by the first and second
isolation strings 52, 90 to permit fluid communication either
outwardly into the surrounding formation (i.e., for fracturing
fluids) or inwardly from the formation (i.e., production
fluid).
[0028] Those of skill in the art will recognize that numerous
modifications and changes may be made to the exemplary designs and
embodiments described herein and that the invention is limited only
by the claims that follow and any equivalents thereof.
* * * * *