U.S. patent application number 11/860576 was filed with the patent office on 2009-03-26 for downhole gauge telemetry system and method for a multilateral well.
Invention is credited to Clark Bergeron, Andy Cantrelle, Scott Kruegel, Peter Sauermilch, Paulo S. Tubel.
Application Number | 20090080291 11/860576 |
Document ID | / |
Family ID | 40471428 |
Filed Date | 2009-03-26 |
United States Patent
Application |
20090080291 |
Kind Code |
A1 |
Tubel; Paulo S. ; et
al. |
March 26, 2009 |
DOWNHOLE GAUGE TELEMETRY SYSTEM AND METHOD FOR A MULTILATERAL
WELL
Abstract
A downhole gauge telemetry system for a multilateral well
includes a first wireless transceiver located in a primary borehole
of the multilateral well, a second wireless transceiver located in
a lateral borehole of the multilateral well, a wireless connection
between the first wireless transceiver and the second wireless
transceiver through which the first and second wireless
transceivers exchange data, and a surface transceiver
communicatively coupled to the first wireless transceiver.
Inventors: |
Tubel; Paulo S.; (Spring,
TX) ; Sauermilch; Peter; (Sugar Land, TX) ;
Bergeron; Clark; (The Woodlands, TX) ; Cantrelle;
Andy; (The Woodlands, TX) ; Kruegel; Scott;
(The Woodlands, TX) |
Correspondence
Address: |
RICHARD A. FAGIN
P.O. BOX 1247
RICHMOND
TX
77406-1247
US
|
Family ID: |
40471428 |
Appl. No.: |
11/860576 |
Filed: |
September 25, 2007 |
Current U.S.
Class: |
367/81 ;
166/65.1; 73/152.01 |
Current CPC
Class: |
E21B 47/13 20200501;
E21B 41/0035 20130101 |
Class at
Publication: |
367/81 ;
166/65.1; 73/152.01 |
International
Class: |
E21B 47/12 20060101
E21B047/12 |
Claims
1. A downhole gauge telemetry system for a multilateral well,
comprising: a first wireless transceiver located in a primary
borehole of the multilateral well; a second wireless transceiver
located in a lateral borehole of the multilateral well; a wireless
connection between the first wireless transceiver and the second
wireless transceiver through which the first and second wireless
transceivers exchange data; and a surface transceiver
communicatively coupled to the first wireless transceiver.
2. The downhole gauge telemetry system of claim 1, wherein the
first and second wireless transceivers are acoustic wireless
transceivers.
3. The downhole gauge telemetry system of claim 1, further
comprising a data acquisition module communicatively coupled to the
second wireless transceiver.
4. The downhole gauge telemetry system of claim 3, further
comprising at least one sensor located in the lateral borehole and
communicatively coupled to the data acquisition module.
5. The downhole gauge telemetry system of claim 4, wherein the
sensor is selected from the group consisting of pressure sensor,
temperature sensor, fluid flow sensor, fluid identification sensor,
resistivity sensor, cross-well acoustic sensor, cross-well seismic
sensor, perforation depth sensor, fluid characteristics sensor,
logging data sensor, strain gauge, and vibration sensor.
6. The downhole gauge telemetry system of claim 1, further
comprising a power generator located in the lateral borehole.
7. The downhole gauge telemetry system of claim 4, wherein the
power generator is a piezoelectric power generator.
8. The downhole gauge telemetry system of claim 1, wherein the
first wireless transceiver communicates with the surface
transceiver over a wired connection.
9. A method of transmitting data in a multilateral well extending
from a surface, comprising: deploying a first wireless transceiver
in a primary borehole of the multilateral well; deploying a second
wireless transceiver in a lateral borehole of the multilateral
well; establishing a wireless connection between the first wireless
transceiver and the second wireless transceiver; wirelessly
transmitting data between the first wireless transceiver and the
second wireless transceiver over the wireless connection;
establishing data communications between the first wireless
transceiver and a surface transceiver; and transmitting data
between the first wireless transceiver and the surface transceiver.
Description
BACKGROUND OF THE INVENTION
[0001] The invention relates generally to multilateral well
operations. More particularly, the invention relates to a system
and method for monitoring reservoir/borehole conditions in a
multilateral well.
[0002] Multilateral wells, also known as multi-branch wells, have
lateral boreholes that tie back to a primary wellbore. Production
through the primary wellbore can be significantly increased by
bringing the lateral boreholes into close proximity with several
target reservoirs. To maximize production, sensors/gauges can be
installed in the lateral boreholes and used to monitor
reservoir/borehole conditions, such as pressure, temperature, and
flow rate in the tubing and annulus. The output of the
sensors/gauges can be monitored in real-time and used to control
inflow from the lateral boreholes such that production is
optimized. To enable monitoring of reservoir/borehole conditions,
powering of the sensors/gauges and communication between the
sensors/gauges and the surface must be reliable. Making wire
connections between the surface and lateral boreholes can be
cumbersome or impossible. For example, it would be difficult to run
the long wires needed to make signal transmission links between the
surface and each of the sensors/gauges in the lateral boreholes.
Wireless technology may alleviate some of the concerns with wired
transmission links.
[0003] U.S. Pat. No. 6,899,178 issued to Tubel describes a wireless
tool that can be deployed in one or more branches of a multilateral
well. The wireless tool transmits acoustic data to a data
acquisition transceiver at the surface via production tubing. The
data acquisition transceiver is connected to a data processor,
which may be equipped with Supervisory Control and Data Acquisition
(SCADA) software. The wireless tool includes a wireless tool
transceiver for wireless transmission of data to the surface
transceiver. The wireless tool transceiver includes transformer,
piezoelectric crystal or other acoustic generator, and acoustic
transmitter. The wireless tool includes a data acquisition module,
which is connected to the wireless tool transceiver. The data
acquisition module obtains data from sensors/gauges at
predetermined locations in the well. The wireless tool includes a
replaceable power source, such as batteries. The replaceable power
source may be augmented or replaced by downhole power
generation.
SUMMARY OF THE INVENTION
[0004] In one aspect, the invention relates to a downhole gauge
telemetry system for a multilateral well which comprises a first
wireless transceiver located in a primary borehole of the
multilateral well, a second wireless transceiver located in a
lateral borehole of the multilateral well, a wireless connection
between the first wireless transceiver and the second wireless
transceiver through which the first and second wireless
transceivers exchange data, and a surface transceiver
communicatively coupled to the first wireless transceiver.
[0005] In another aspect, the invention relates to a method of
transmitting data in a multilateral well extending from a surface
comprises deploying a first wireless transceiver in a primary
borehole of the multilateral well, deploying a second wireless
transceiver in a lateral borehole of the multilateral well,
establishing a wireless connection between the first wireless
transceiver and the second wireless transceiver, wirelessly
transmitting data between the first wireless transceiver and the
second wireless transceiver over the wireless connection,
establishing data communications between the first wireless
transceiver and a surface transceiver, and transmitting data
between the first wireless transceiver and the surface
transceiver.
[0006] Other features and advantages of the invention will be
apparent from the following description and the appended
claims.
BRIEF DESCRIPTION OF THE DRAWINGS
[0007] The accompanying drawings, described below, illustrate
typical embodiments of the invention and are not to be considered
limiting of the scope of the invention, for the invention may admit
to other equally effective embodiments. The figures are not
necessarily to scale, and certain features and certain view of the
figures may be shown exaggerated in scale or in schematic in the
interest of clarity and conciseness.
[0008] FIG. 1 is a block diagram of a downhole gauge telemetry
system for a multilateral well.
[0009] FIG. 2 shows an implementation of the downhole gauge
telemetry system of FIG. 1 in a multilateral well.
DETAILED DESCRIPTION OF THE INVENTION
[0010] The invention will now be described in detail with reference
to a few preferred embodiments, as illustrated in the accompanying
drawings. In describing the preferred embodiments, numerous
specific details are set forth in order to provide a thorough
understanding of the invention. However, it will be apparent to one
skilled in the art that the invention may be practiced without some
or all of these specific details. In other instances, well-known
features and/or process steps have not been described in detail so
as not to unnecessarily obscure the invention. In addition, like or
identical reference numerals are used to identify common or similar
elements.
[0011] FIG. 1 is a block diagram of a downhole gauge telemetry
system 100 for a multilateral well. The telemetry system 100
includes surface transceiver (or receiver/transmitter) 102
connected to a data processing system 103, wherein the data
processing system 103 retrieves data from the surface transceiver
102 and processes the data. The surface transceiver 102
communicates with and receives data from a first wireless
transceiver (or receiver/transmitter) 104 in a primary wellbore of
the multilateral well. Communication between the surface
transceiver 102 and the first wireless transceiver 104 may be over
a wired or wireless connection. The first wireless transceiver 104
in turn communicates with and receives data from a second wireless
transceiver (or receiver/transmitter) 106 in a lateral borehole of
the multilateral well over a wireless connection 107. The first and
second wireless transceivers 104, 106 may be acoustic devices,
including for example, transformer, acoustic generator, and
acoustic transmitter. Acoustic signals may be generated, for
example, by piezoelectric material or magneto-restrictive material.
The acoustic generator typically transmits at frequencies
unaffected by pump noise. The wireless connection 107 may be
provided by tubing or fluid between the first and second wireless
transceivers 104, 106. Communication between the first and second
wireless transceivers 104, 106 may be one-way or
bi-directional.
[0012] A data acquisition module 108 is located in the lateral
borehole and coupled to the second wireless transceiver 106 via
communications link 110. The data acquisition module 108 includes
the circuitry needed to collect data and may include memory for
storing data. The data acquisition module 108 may also be equipped
with a rechargeable or replaceable power source. One or more
sensors/gauges 112 are coupled to the data acquisition module 108
via communications link 114, which may be a wired link. The
sensors/gauges 112 may monitor/measure one or more
reservoir/borehole conditions or parameters. In one example, the
sensors/gauges 112 are selected from pressure sensor, temperature
sensor, fluid flow sensor, fluid identification sensor, resistivity
sensor, cross-well acoustic sensor, cross-well seismic sensor,
perforation depth sensor, fluid characteristics sensor, logging
data sensor, strain gauge, and vibration sensor. In operation, the
data acquisition module 108 obtains data from the sensors/gauges
112 through the communication link 114. The second wireless
transceiver 106 transmits the data from the data acquisition module
108 to the first wireless transceiver 104 over the wireless
connection 107. The first wireless transceiver 104 in turn
transmits the data received from the second wireless transceiver
106 to the surface transceiver 102. Data may be transmitted from
downhole to the surface in real-time, in a predetermined sequence,
or in response to a command from the surface transceiver 102.
[0013] The telemetry system 100 includes a power generator 116
which can supply power to the sensors/gauges 112, the second
wireless transceiver 106, and the data acquisition module 108. The
power generator 116 can be a piezoelectric power generator, i.e.,
one that uses a piezoelectric stack to convert motion or vibration
into electrical energy. The piezoelectric stack may convert motion
of borehole fluids or vibrations within piping in the lateral
borehole into electrical energy. Other power generators besides one
based on piezoelectric may be used. For example, turbines or
magneto-restrictive power generation may be used. The telemetry
system 100 also includes a power generator 118 at the surface. The
power generator 118 supplies power to the surface transceiver 102.
The first wireless transceiver 104 may also be connected to the
power generator 118 in order to receive power. Alternately, the
first wireless transceiver 104 may be provided with a downhole
power source or generator.
[0014] The physical implementation of the telemetry system 100 in a
multilateral well may take various forms. FIG. 2 shows an example
wherein a multilateral well 200 extends below a surface 202. The
multilateral well 200 includes a primary wellbore 204 and a lateral
borehole 206. The multilateral well 200 can have more than one
lateral borehole, but only one is shown for the sake of simplicity.
The primary wellbore 204 is shown as vertical, but it may also be
deviated or horizontal. Casing 208 extends from a wellhead 210 near
the surface 202 into the primary wellbore 204. The lateral borehole
206 is accessible through a window in the casing 208. Although not
shown, a liner or other tubular may be installed in the lateral
borehole 206, for example, to prevent the lateral borehole from
collapsing. A production tubing 212 extends from the wellhead 210
down through the casing 208 and into the lateral borehole 206. The
first wireless transceiver 104 and the power generator 118 can be
mounted on the portion of the production tubing 212 in the primary
wellbore 204, with a cable 214 running between them. The power
generator 118 is linked to the surface transceiver 102.
Sensors/gauges 222 may be mounted on the portion of the production
tubing 212 in the primary wellbore 204 and used to monitor
reservoir/borehole conditions in the primary wellbore 204. The
sensors/gauges 222 may also be powered by the power generator
118.
[0015] The second wireless transceiver 104 is mounted on the
portion of the production tubing 212 in the lateral borehole 206.
The data acquisition module 108, power generator 116, and
sensors/gauges 112 are also mounted on the portion of the
production tubing 212 in the lateral borehole 206. In the
arrangement shown in FIG. 2, the data acquisition module 108 is
mounted adjacent to the second wireless transceiver 104 and the
power generator 116 adjacent to the data acquisition module 108.
These components can be contained within a single housing or
multiple housings made of material suitable for use in a downhole
environment. The sensors/gauges 112 are mounted further down, with
cable links 216 between them and the power generator 116 and data
acquisition module 108. As an example, the sensors/gauges 112 may
be electromagnetic or resistivity sensors, gravity sensors, and
geophones, or hydrophones. Flow controllers with drivers 218 are
also mounted on the production tubing 212 to monitor inflow in the
lateral borehole 206. The flow controllers 218 may also be powered
by the power generator 116. Packers 220, which may be swellable
elastomer packers, are also mounted on the production tubing 212 to
isolate a portion of the lateral borehole 206. In this example, the
production tubing 212 and/or fluid in the production tubing 212 can
provide the wireless connection between the first and second
wireless transceivers 104, 106. Acoustics waves may travel between
the first and second wireless transceivers 104, 106 through the
production tubing 212 and the fluid in the production tubing
212.
[0016] While the invention has been described with respect to a
limited number of embodiments, those skilled in the art, having
benefit of this disclosure, will appreciate that other embodiments
can be devised which do not depart from the scope of the invention
as disclosed herein. Accordingly, the scope of the invention should
be limited only by the attached claims.
* * * * *