U.S. patent application number 11/833049 was filed with the patent office on 2009-02-05 for apparatus and method for wirelessly communicating data between a well and the surface.
This patent application is currently assigned to BAKER HUGHES INCORPORATED. Invention is credited to Michael H. Johnson.
Application Number | 20090032303 11/833049 |
Document ID | / |
Family ID | 40305159 |
Filed Date | 2009-02-05 |
United States Patent
Application |
20090032303 |
Kind Code |
A1 |
Johnson; Michael H. |
February 5, 2009 |
APPARATUS AND METHOD FOR WIRELESSLY COMMUNICATING DATA BETWEEN A
WELL AND THE SURFACE
Abstract
In one aspect, wellbore apparatus is disclosed that includes: a
conduit in the wellbore that has a non-liquid medium therein; and a
transducer that is configured to transmit radio frequency signals
through the medium. In another aspect, a method is disclosed that
includes: placing a conduit in the wellbore that contains a
non-liquid medium therein; and transmitting information in the form
of radio frequency signals through the medium.
Inventors: |
Johnson; Michael H.; (Katy,
TX) |
Correspondence
Address: |
MADAN, MOSSMAN & SRIRAM, P.C.
2603 AUGUSTA DRIVE, SUITE 700
HOUSTON
TX
77057-5662
US
|
Assignee: |
BAKER HUGHES INCORPORATED
Houston
TX
|
Family ID: |
40305159 |
Appl. No.: |
11/833049 |
Filed: |
August 2, 2007 |
Current U.S.
Class: |
175/40 |
Current CPC
Class: |
E21B 47/13 20200501 |
Class at
Publication: |
175/40 |
International
Class: |
E21B 47/12 20060101
E21B047/12 |
Claims
1. A system for communicating information between a wellbore and
the surface, comprising: a conduit containing non-liquid medium
placed in the wellbore; a transducer that is configured to transmit
at a first location signals wirelessly through the medium in the
conduit for reception of the transmitted wireless signals at a
second location in the conduit.
2. The system of claim 1 further comprising a repeater receives the
signals transmitted by the transducer and transmits wirelessly
signals through the medium in the conduit that are representative
of the signals received by the repeater.
3. The system of claim 1 further comprising: a surface receiver
that receives the signals transmitted by the transducer and a
processor that process the signals received by the surface receiver
to determine the nature of the signals transmitted by the
transducer.
4. The system of claim 1, wherein the wireless signals transmitted
by the transducer relate to information receive from a sensor that
is selected from a group consisting of: (i) pressure sensor; (ii)
temperature sensor; (iii) an acoustic sensor; (iv) a flow rate
measuring sensor; (v) a water-cut measurement sensor; (vi) a
resistivity measurement sensor; (vii) a chemical detection sensor;
(viii) a fiber optic sensor; and (ix) a piezoelectric sensor.
5. The system of claim 1, wherein the wireless signals are radio
frequency signals.
6. The system of claim 1, wherein the conduit is one of: (i)
substantially filled with air; (ii) substantially filled with a
gas; and (iii) at least partially evacuated.
7. The system of claim 1, wherein the conduit extends from a first
location in the wellbore to a second location that is selected from
a group consisting of: (i) a location at the surface of the earth;
(ii) a location in the wellbore uphole of the data transmission
device: (iii) a location at a sea bed; (iv) a location on a land
rig; and (v) a location on an offshore platform.
8. The system of claim 1, wherein the transducer receives signals
to be transmitted via one of: (i) an electrical wire; (ii) an
optical fiber; and (iii) wirelessly.
9. The system of claim 1, wherein the transducer further comprises:
a circuit configured to receive the signals from at least one
sensor; and a signal conditioner configured to condition the
received signals; and a transmitter configured to transmit the
conditioned signals as radio frequency signals through the medium
in the conduit.
10. The system of claim 1 further comprising a power source that
provides electrical power to the transducer, wherein the power
source is selected from a group consisting of: (i) battery; (ii) a
power generation unit that generates electrical power in the
wellbore; and (iii) a power unit at the surface that supplies
electrical power via an electrical conductor disposed in or along
the conduit.
11. The system of claim 1, wherein the conduit is placed in the
well in a manner that is one of: (i) along a production tubing that
carries fluid from the well to the surface; (ii) along a casing in
the wellbore; and (iii) between a casing and formation surrounding
the well.
12. The system of claim 1, wherein the transducer performs at least
one function that is selected from a group of functions consisting
of: (i) receives analog signals from at least one sensor and
transmits analog signals that are representative of the received
signals over a radio frequency; (ii) receives analog signals from
at least one sensor and transmits digital signals that are
representative of the received signals over a radio frequency; and
(iii) receives digital signals from at least one sensor and
transmits digital signals that are representative of the received
signals over a radio frequency.
13. A method for communicating information between a downhole
location in a well and an uphole location, the method comprising:
placing a conduit in the well, which conduit contains a non-liquid
medium; transmitting wireless signals trough the medium in the
conduit at a first location that are representative of selected
information; and receiving the signals transmitted through the
medium at a second location in the conduit; processing the received
signals to obtain a parameter of interest; and recording the
parameter of interest in a suitable medium.
14. The method of claim 13 further comprising receiving the
wireless signals at a repeater between the first and second
locations and retransmitting such received signals wirelessly
through the medium.
15. The method of claim 13, wherein the parameter of interest is
selected from a group consisting of: (i) pressure; (ii)
temperature; (iii) resistivity; (iv) fluid flow rate; (v)
capacitance; (v) viscosity; (vi) density; (vii) presence of a
chemical in the wellbore; (viii) paraffin; (ix) scale; (x) hydrate;
(xi) hydrogen sulfide; (xii) asphaltene; (xiii) corrosion; (xiv)
water content; and (xv) presence of gas.
16. The method of claim 13, wherein the conduit is placed in a
manner that is one of: (i) inside a casing in the well; (ii)
between a casing in the well and the formation surrounding the
well; (iii) inside a production tubing that carries the well
fluid.
17. A method for communicating data between a well and a surface
location, comprising: placing a conduit in the well that contains a
non-liquid medium therein; and transmitting wireless signals
representative of a desired information as wireless signals through
the non-liquid medium in the conduit.
18. The method of claim 17 further comprising detecting the
wireless signals in the conduit and processing the detected signals
to ascertain the desired information.
19. The method of claim 18 further comprising recording the desired
information in a suitable medium.
20. The method of claim 18 further comprising controlling an
operation of a well system in response to processed signals.
21. An apparatus for use in a well, comprising: a conduit
containing a non-liquid therein and configured for deployment in
the well; and a transmitter configured to transmit information
wirelessly through the non-liquid medium in the conduit at a
selected location in the conduit.
22. The apparatus of claim 21 further comprising receiving the
wireless signals at second location spaced from the selected
location and retransmitting the received signals wirelessly through
the non-liquid medium in the conduit.
Description
BACKGROUND OF THE DISCLOSURE
[0001] 1. Field of the Disclosure
[0002] This disclosure relates to apparatus and methods for
wirelessly communicating data between a well and the surface.
[0003] 2. Background Information
[0004] Wells (also referred to as "wellbores" or "boreholes") are
drilled and completed to produce hydrocarbons (oil and gas) from
one or more production zones penetrated by a wellbore. A typical
completed well may include a metallic casing that lines the well.
Cement is generally placed between the casing and the well to
provide a seal between the formation surrounding the well and the
casing. Perforations made in the formation through the casing at
selected locations across from the producing formations (also
referred to as the "production zones" or "reservoirs") allow the
formation fluid containing the hydrocarbons to flow into the cased
well. The formation fluid flows to the surface via a production
tubing placed inside the casing because the pressure in the
production zone is generally higher than the pressure caused by the
weight of the fluid column in the well. An artificial lift
mechanism, such as an electrical submersible pump ("ESP") or a
gas-lift mechanism is often employed when the formation pressure is
not adequate to push the fluid in the well to the surface.
[0005] A variety of devices are used in the well to control the
flow of the fluid from the production zones to optimize the oil and
gas production over the life of the well. Remotely-controlled flow
control valves and chokes are often used to control the flow of the
fluid. Chemicals are injected at certain locations in the well via
one or more tubes that run from the surface to the production zones
to inhibit the formation of harmful chemicals, such as corrosion,
hydrate, scale, hydrogen sulfide, methane, asphaltene, etc. A
number of sensors are typically placed in the well to provide
information about a variety of downhole parameters, including the
position of the valves and chokes, pressure, temperature, fluid
flow rate, acoustic signals responsive to water front and surface
or downhole induced signals in the subsurface formations,
resistivity, porosity, permeability, water-cut, etc. The
measurement data is typically transmitted to the surface via
conductors, such as electrical wires, that run from the surface to
selected locations in the well. Signals are also sent from the
surface to the downhole sensors and devices via such conductors to
control their operations. Such conductors (also referred to herein
as data communication "links") sometimes degrade over time. It is
therefore desirable to have a data communication system that may be
less prone to degradation.
[0006] The present disclosure provides improved apparatus, systems
and methods for communicating data between a well and the
surface.
SUMMARY
[0007] In one aspect, a well data communication system is disclosed
that includes a conduit placed in a well, the conduit having a
non-liquid medium therein, and a transducer that transmits wireless
signals through the medium in the conduit that are representative
of a selected information. The system may further include one or
more repeaters associated with the conduit that receive the
wireless signals transmitted by the transducer and retransmit the
received signals wirelessly through the medium in the conduit. The
system may further include a receiver that receives the signals
transmitted by the transducer or the repeaters and a processor that
processes the received signals to determine the selected
information or to estimate a property of interest. The wireless
signals may be radio frequency signals. The information may relate
to downhole sensor measurements, downhole devices, surface sensor
measurements, surface devices, stored in a suitable medium,
received from a remote unit, etc. The transducer and/or any of the
repeaters may be a transceiver and each may further be an
autonomous device. The system may further include a transducer at
the surface that transmits wireless signals, such as radio
frequency signals, to a location in the well (a "downhole
location") via the medium in the conduit or another conduit that
runs from the surface to the downhole location. Each of the
transducers and repeaters may transmit and/or receive signals at a
plurality of frequencies.
[0008] In another aspect, an apparatus is disclosed for use in a
well that includes a conduit that has a non-liquid medium therein
and which conduit is configured to be deployed in the well, and a
transmitter that is configured to transmit wireless signals, which
may be radio frequency signals, from one a downhole location and/or
a surface location via the medium in the conduit.
[0009] In another aspect, a method is disclosed that includes
transmitting wireless signals relating to selected information
through a non-liquid filled conduit deployed in a well.
[0010] Examples of the more important features of a well data
communication system and methods have been summarized rather
broadly in order that the detailed description thereof that follows
may be better understood, and in order that the contributions to
the art may be appreciated. There are, of course, additional
features that will be described hereinafter and which will form the
subject of the claims. The summary is provided to provide the
reader with broad information and is not intended to be used in any
way to limit the scope of the claims.
BRIEF DESCRIPTION
[0011] For a detailed understanding of the apparatus and methods
for communicating information between a well and the surface,
reference should be made to the following detailed description,
taken in conjunction with the accompanying drawings, in which like
elements generally have been given like numerals, wherein:
[0012] FIG. 1A shows a schematic diagram of an exemplary well that
is configured to provide data communication between devices in the
well and a surface controller according to one embodiment of the
disclosure;
[0013] FIG. 1B shows a schematic diagram of certain controllers and
devices at the surface that may be utilized to establish data
communication between the well and the surface according to one
embodiment of the disclosure; and
[0014] FIG. 2 shows a functional block diagram of a transducer that
may be utilized to transmit wireless signals in a well system, such
as shown in FIGS. 1A and 1B.
DETAILED DESCRIPTION OF EMBODIMENTS
[0015] FIGS. 1A and 1B (collectively referred to as "FIG. 1")
collectively show schematic diagrams of one embodiment of a well
system 100 that includes a data communication system between a
completed well 50 and the surface 112 according to one embodiment
of the disclosure. FIG. 1A shows the schematic diagram of the
equipment of the well system that is below the surface 112, while
FIG. 1B shows the functional block diagram of exemplary equipment
of the well system 100 that may be placed at the surface 112. The
system 100 shows the well 50 formed in a formation 55 that produces
formation fluids 56a and 56b (such as hydrocarbons) from two
exemplary production zones 52a (upper production zone) and 52b
(lower production zone) respectively. The well 50 is shown lined
with a casing 57 containing perforations 54a adjacent the upper
production zone 52a and perforations 54b adjacent the lower
production zone 52b. A packer 64, which may be a retrievable
packer, positioned above or uphole of the lower production zone
perforations 54a, isolates the lower production zone 52b from the
upper production zone 52a. A screen 59b adjacent to the
perforations 54b may be installed to prevent or inhibit solids,
such as sand, from entering into the wellbore from the lower
production zone 54b. Similarly, a screen 59a may be used adjacent
the upper production zone perforations 59a to prevent or inhibit
solids from entering into the well 50 from the upper production
zone 52a.
[0016] Formation fluid 56b from the lower production zone 52b
enters the annulus 51a of the well 50 through the perforations 54a
and into a tubing 53 via a flow control valve 67. The flow control
valve 67 may be a remotely controlled sliding sleeve valve or any
other suitable valve or choke that is configured to regulate the
flow of the fluid from the annulus 51a into the production tubing
53. An adjustable choke 40 in the tubing 53 may be used to regulate
the fluid flow from the lower production zone 52b to the surface
112. The formation fluid 56a from the upper production zone 52a
enters the annulus 51b (the annulus portion above the packer 64)
via perforations 54a. The formation fluid 56a enters production
tubing or line 45 via inlets 42. An adjustable valve or choke 44
regulates the fluid flow into the tubing 45. Each valve, choke and
other devices in the well may be operated electrically,
hydraulically, mechanically and/or pneumatically by a surface
controller, such as a control unit 150 and/or by a downhole
controller, such as a control unit 60. The fluid from the upper
production zone 52a and the lower production zone 52b enter the
line 46.
[0017] When the formation pressure is not sufficient to push the
fluid 56a and/or fluid 56b to the surface, an artificial lift
mechanism, such as an electrical submersible pump (ESP), gas lift
system or other desired systems may be utilized to lift the fluids
from the well 50 to the surface 112. In the system 10, an ESP 30 in
a manifold 31 is shown as the artificial lift mechanism, which
receives the formation fluids 56a and 56b and pumps such fluids via
tubing 47 to the surface 112. A cable 134 provides power to the ESP
30 from a surface power source 132 (FIG. 1B). The cable 134 also
may include two-way data communication links 134a and 134b (FIG.
1B), which may include one or more electrical conductors or fiber
optic links to provide two-way signal and data communication
between the ESP 30, ESP sensors S.sub.E and an ESP control unit
130.
[0018] Still referring to FIGS. 1A and 1B, in one aspect, a variety
of sensors are placed at suitable locations in the well 50 to
provide measurements or information relating to a number of
downhole parameters of interest. In one aspect, one or more gauge
or sensor carriers, such as a carrier 15, may be placed in the
production tubing to house any number of suitable sensors. The
carrier 15 may include one or more temperature sensors, pressure
sensors, flow measurement sensors, resistivity sensors, sensors
that may provide information about density, viscosity, water
content or water cut, etc., and chemical sensors that provide
information about scale, corrosion, hydrate, paraffin, hydrogen
sulfide, emulsion, asphaltene, etc. Density sensors may provide
fluid density measurements for fluid produced from each production
zone and that of the combined fluid from two or more production
zones. A resistivity sensor or another suitable sensor may provide
measurements relating to the water content or the water-cut of the
fluid mixture received from each production zones and/or for the
combined fluid. Other sensors may be used to estimate the oil/water
ratio and gas/oil ratio for each production zone and for the
combined fluid. The temperature, pressure and flow sensors provide
measurements for the pressure, temperature and flow rate of the
fluid. Additional gauge carriers may be used to obtain the
above-noted and other measurements relating to the upper production
zone 52a. Also, downhole sensors may be used at other desired
locations to provide measurements relating to the presence and
extent of chemicals downhole. Additionally, sensors S.sub.1-S.sub.m
may be permanently installed in the wellbore 50 to provide
measurements, such as acoustic, seismic or microseismic
measurements, formation pressure and temperature measurements,
resistivity measurements and measurements relating to the
properties of the casing 51 and formation 55. Such sensors may be
installed in the casing 57 or between the casing 57 and the
formation 55. Microseismic and other sensors may be used to detect
water fronts, which may imbalance the composition of the fluids
being produced, thereby providing early warning relating to the
formation of certain chemicals. Pressure and temperature changes or
expected changes may provide early warning of changes in the
chemical composition of the production fluid. Additionally, the
screen 59a and/or screen 59b may be coated with tracers that are
released due to the presence of water, which tracers may be
detected at the surface or downhole to determine or predict the
occurrence of water breakthrough. EPS sensors S.sub.E may provide
information relating to the ESP 30, such as power to the ESP,
frequency, flow rate, temperature, pressure, differential pressure
across ESP, presence of certain chemicals, such as corrosion,
scale, hydrate, hydrogen sulfide, asphaltene, etc. Sensors also may
be provided at the surface, such as a sensor for measuring the
water content in the received fluid, total flow rate for the
received fluid, fluid pressure at the wellhead, temperature, etc.
Other devices may be used to estimate the production of sand for
each zone.
[0019] In general, sufficient sensors may be suitably placed in the
well 50 and the surface 112 to obtain measurements relating to each
desired parameter of interest. Such sensors may include, but are
not limited to: sensors for measuring pressures corresponding to
each production zone, pressure along the wellbore, pressure inside
the tubings carrying the formation fluid, pressure in the annulus;
sensors for measuring temperatures at selected places along the
wellbore; sensors for measuring fluid flow rates corresponding to
each of the production zones, total flow rate, flow through the
ESP; sensors for measuring ESP temperature and pressure; chemical
sensors for providing signals relating to the presence and extent
of chemicals, such as scale, corrosion, hydrates, paraffin,
emulsion, hydrogen sulfide and asphaltene; acoustic or seismic
sensors that measure signals generated at the surface or in offset
wells and signals due to the fluid travel from injection wells or
due to a fracturing operation; optical sensors for measuring
chemical compositions and other parameters; sensors for measuring
various characteristics of the formations surrounding the well,
such as resistivity, porosity, permeability, fluid density, etc.
The sensors may be installed in the tubing in the well or in any
device or may be permanently installed in the well. For example,
sensors may be installed in the wellbore casing, in the wellbore
wall or between the casing and the wall. The sensors may be of any
suitable type, including electrical sensors, mechanical sensors,
piezoelectric sensors, fiber optic sensors, optical sensors, etc.
The signals from the downhole sensors may be partially or fully
processed downhole by a downhole controller, such as controller 60,
which may include a microprocessor and associated electronic
circuitry and programs and then communicated to the surface
controller 150 (FIG. 1A) via a signal/data link, such as link 101.
The signals from downhole sensors may also be sent directly to the
controller 150.
[0020] A variety of hydraulic, electrical and data communication
lines (collectively designated by numeral 20 (FIG. 1A) are run
inside the well 50 to operate the various devices in the well 50 to
obtain measurements and other data from the various sensors in the
well 50 and to provide power and data communication between the
surface and downhole equipment. As an example, a tube or tubing 21
may supply or inject a particular chemical from the surface into
the fluid 56b via a mandrel 36. Similarly, a tubing 22 may supply
or inject a particular chemical to the fluid 56a in the production
tubing via a mandrel 37. Separate lines may be used to supply the
additives at different locations in the well 50 or to supply
different types of additives. Lines 23 and 24 may operate the
chokes 40 and 44 and may be used to operate any other device, such
as the valve 67. Line 25 may provide electrical power to certain
devices downhole from a suitable surface power source. One or more
non-liquid filled conduits, such as conduits 101 and 102 may be
deployed in the well to establish two-way data communication
between sensors and devices in the system. A downhole control unit,
such as controller 60 and a surface controller, such as controller
150 may be used to process signals from these sensors and devices
and then transmit desired information wirelessly via the conduits
101 and/or 102. The sensors and the devices may communicate with
the controllers by any suitable links, including, but not limited
to, electrical conductors, optical fibers, acoustic signals,
electromagnetic signals, and wireless signals.
[0021] In one aspect, one or more conduits or tubing, such as
tubing 101 and 102 are placed or run between a suitable location in
the well 50 and the surface to establish wireless data
communication between a well 50 and the surface 112. These tubings
may be made from any suitable material, such as an alloy or a
composite material capable of withstanding the downhole environment
for an extended time period. In one aspect, the tubings 101, 102
may be filled with a suitable gas, such as air or an inert gas,
such as nitrogen or argon. In another aspect, the tubings 101, 102
may be partially, substantially or fully evacuated. In FIG. 1,
tubing 101 is shown in signal communication with a downhole
transducer 110, which may include an RF data transmitter an/or a
transceiver. The transducer 110 may include a receiver that
receives signals or data from one or more sensors, such a sensors
S.sub.1-S.sub.m in the well 50 and other devices. Such data or
signals may be provided to the transducer 110 by coupling the
sensors to the transducer via electrical, fiber optic or wireless
links. The transducer may be an active device and may include a
processor, memory and other circuitry that can process the signals
received from the sensors, process the received signals and
transmit the processed signals as wireless signals through the
medium in the tubing 101 at one or more selected frequencies. A
transducer 120 (FIG. 1B) spaced from the transducer 110 receives
the wireless signals and sends the received signals to a surface
controller or control unit 150. The surface controller 150 decodes
the signals received from the receiver 120 and uses the signals to
manage one or more operations of the well system 100. The surface
controller also may send data signals to the transducer 120, which
transmits the received signals via the non-liquid media in the
tubing 101 as wireless signals. Alternatively, a separate
transducer 122 and tubing 102 may be used to send the wireless
signals from the surface 112 to a downhole controller 60 via the
non-liquid medium in the tubing 102. Each of the transducers 110
and 120 may be configured to transmit the wireless signals at more
than one frequency. The signals may be coded signals and may use
any desired signals modulation technique, such as amplitude, phase
and frequency modulation.
[0022] Wells can be very long and can extend to several thousand
meters. In some such wells, the radio frequency signal transmitted
by a transducer, such transducer 110, may attenuate and may not be
detectable by the receiver 120. In other cases, it may be desirable
to transmit radio frequency signals between a branch wellbores or a
branch wellbore and a main wellbore or the surface via a conduit in
which the signals may attenuate to an undesirable extent. Also, the
transducer 110 over time may not be able to send signals that are
strong enough to reach a desired receiver in the system 100. In any
such cases, one or more repeaters, such as R.sub.1-R.sub.n,
(generally designated by numeral 114) may be deployed in the well
50 and configured in a manner so that they can detect signals from
the conduit medium and retransmit the detected signals to the
receiver 120. Similar transmitters may be deployed in conduit
102.
[0023] Each of the transducers, such as transducer 110, and the
repeaters R.sub.1-R.sub.n may be an autonomous device. FIG. 2 shows
a functional diagram of an autonomous transducer or repeater 200
according to one embodiment of the disclosure. The device 200 may
include: a processor 210, such as a micro-controller,
microprocessor or another suitable circuit combination; a data
storage device or memory device 212, such a solid state memory
device (Read-only-memory "ROM," random access memory ("RAM", flash
memory, etc.) that is suitable for downhole application; and one or
more computer programs or sets of instructions 214 that may be
stored in the memory 212 and which programs are accessible to the
processor 210. The processor 210 communicates with the memory 212
and the programs 214 via links 211 and 213 respectively. A power
source 220 provides power to the processor as shown by link 231 and
to the other components of the device 200 via link 223. In
operation, signals T.sub.1-T.sub.p from sensors and other devices
may be received by an interface 230 that is configured to receive
such signals. The interface 230 may be configured to condition such
signals, such as by amplifying and digitizing the signals. The
processor 210 processes receives the signals from the interface and
processes such signals, such as by sequencing the signals, putting
the signals in appropriate data packets, assigning addresses of the
sensors or the devices from which such signals are received, etc.
and sends such processed signals via link 241 to a transmitter 240
that transmits the signals wirelessly via the medium in the
conduit. The wireless signals, such as radio frequency signals,
sent from the surface via the conduits 101 and/or 102 are received
by a second interface or a receiver 245, which conditions the
received signals and provides them to the processor 210. The
processor 210 then may process these signals and may control one or
more downhole devices 260 in response to such signals. The
processor may store any information in the memory device 212 and
use any programs 214 to perform one or more of the functions
described herein. The processor 210 is shown to communicate with
the receiver radio frequency 245 via link 243, with downhole
devices 260 via link 261. Alternatively, the signals sent from the
surface may be received by a downhole controller 60 or received by
the transducer 110 and passed on to the controller 60. Thus, in one
aspect, the downhole transducer 110 receives signals from one or
more devices or sensors in the well or from a controller in the
well and transmits signals representative of the received signals
as wireless signals, such as RF signals, through a non-liquid
filled conduit placed in the well. A receiver spaced from the
downhole transducer detects the RF signals and transmits to a
surface controller for further use. The surface controller may send
RF signals to a downhole receiver via the same or a separate
non-liquid filled conduit. One or more repeaters placed between the
transducer and the surface receiver may be used to receive and
retransmit the signals sent by the transducer.
[0024] Referring back to FIG. 1B, in one aspect, the exemplary
equipment shown in FIG. 1B may be utilized to manage and control
the various operations of the well system 100 in response to the
signals received from the downhole transducer 110. In one aspect,
the controller 150 may manage injection of additives from a
chemical injection unit 120 into the well 50 to enhance production
from one or more zones in response to the signals received from a
chemical sensor that may provide information about the presence of
certain chemicals, such as scale, hydrate, corrosion, asphaltene,
hydrogen sulfide, etc. or in response to a water-cut sensor,
resistivity sensor, etc.
[0025] In another aspect, the central controller 150 may control
the operation of one or more downhole devices directly or via a
downhole control unit 160 and lines 21-25 by sending commands via a
link 161. The commands may be instructions to alter the position of
a choke or a sliding sleeve, etc and such commands may be in
response to signals received from one or more downhole sensors,
surface sensors, based on programmed instructions provided to the
controller and/or signals received from a remote controller, such
as controller 185 that may communicate with the controller 150 via
any suitable link 189, such as Ethernet, the Internet, etc. In
another aspect, the central controller 150 may control the
operation of the ESP 30 directly or via an ESP controller 130. The
ESP controller may control power to the ESP from a power source 132
in response to the signals received from the ESP sensors and/or
signals received from the central controller 150.
[0026] Still referring to FIGS. 1 and 2, a system is disclosed that
includes: a non-liquid filled-conduit ("conduit") in a well; at
least one sensor that provides signals relating to a parameter of
interest; and a transducer in the wellbore that transmits wireless
signals, such as radio-frequency signals, through the non-liquid
medium in the conduit that are representative of the signals
provided by the at least one sensor. The system may further include
a repeater in the well that receives the signals transmitted by the
transducer in the well and retransmits the received signals as
radio frequency signals through the medium in the conduit. The
system may further include a surface receiver that receives the
signals transmitted by the transducer and a processor that process
the signals received by the surface receiver to estimate the
property of interest. The sensor in the well may be a: (i) pressure
sensor; (ii) temperature sensor; (iii) an acoustic sensor; (iv) a
flow rate measuring sensor; (v) a water-cut measurement sensor;
(vi) a resistivity measurement sensor; (vii) a chemical detection
sensor; (viii) a fiber optic sensor; and (ix) a piezoelectric
sensor. The conduit may be: (i) substantially filled with air; (ii)
substantially filled with a gas; or (iii) at least partially
evacuated. The conduit may extend from a selected location in the
wellbore to an uphole location. The uphole location may be: (i) a
location at the surface of the earth; (ii) a location in the
wellbore uphole of the data transmission device: (iii) a location
at a sea bed; (iv) a location on a land rig; and (v) a location on
an offshore platform. The sensors may communicate with the
transducer in the well via: (i) an electrical wire; (ii) an optical
fiber; and (iii) wirelessly.
[0027] Each transducer and/or repeater include: a circuit that
receives the signals from the at least one sensor; and a signal
conditioner that conditions the received signals; and a transmitter
that transmits signals as radio frequency signals through the
medium in the conduit. The system may further include a power
source that provides electrical power to the transducer. The power
source may be: (i) a battery; (ii) a power generation unit that
generates electrical power in the wellbore; or (iii) a power unit
at the surface that supplies electrical power via an electrical
conductor disposed in or along the conduit. The conduit may be
placed along a production tubing that carries fluid from the
wellbore to the surface; along a casing in the well or between a
casing in the well and the formation surrounding the well.
Additionally, the transducer may: (i) receive analog signals from
the at least one sensor and transmit analog signals that are
representative of the received signals over a radio frequency; (ii)
receive analog signals from the at least one sensor and transmit
digital signals that are representative of the received signals
over a radio frequency and/or receive digital signals from the at
least one sensor and transmit digital signals that are
representative of the received signals over a radio frequency.
[0028] In another aspect, the system may include: a plurality of
sensors distributed in the wellbore, each sensor in the plurality
of sensors providing the at least one? signals relating to a
measurement made by such sensor; a conduit in the wellbore that is
gas-filled or at least partially evacuated; a plurality of
transceivers in the wellbore; and wherein each sensor in the
plurality of sensors provides signals to a corresponding
transceiver in the plurality of transducers, wherein each
transceiver transmits the signals received from its associated
sensor wirelessly through the conduit. Each transducer may comprise
a unique address. Each transducer may be a transceiver. Energy to
the transceivers may be provided by: (i) a battery; (ii) a
thermoelectric generator; and (iii) a combination of a battery and
a thermoelectric generator. Any transceiver also may include a
sensor for taking a measurement relating to a parameter of
interest, which may relate to health of the transceiver, formation
or the well.
[0029] Also, a method for communicating information between a
location in a wellbore and an uphole location is disclosed, which
method comprises: placing a non-liquid filled conduit in the
wellbore; placing at least one sensor in the wellbore that provides
signals relating to a parameter of interest; placing a first device
in the conduit downhole; receiving signals provided by the at least
one sensor at the first device; transmitting signals representative
of the received signals wirelessly by the first device through the
conduit; and receiving the signals transmitted by the first device
at a second device uphole of the first device; processing the
received signals to estimate the property of interest; and
recording the property of interest in a suitable medium. The method
may further comprise one or more repeaters that receive the signals
transmitted by the first device and transmits the received signals
to the second device. The parameter of interest may be: (i)
pressure; (ii) temperature; (iii) resistivity; (iv) fluid flow
rate; (v) capacitance; (v) viscosity; (vi) density; (vii) presence
of a chemical in the wellbore; (viii) paraffin; (ix) scale; (x)
hydrate; (xi) hydrogen sulfide; (xii) asphaltene; (xiii) corrosion;
(xiv) water content; and (xv) presence of gas.
[0030] While the foregoing disclosure is directed to certain
disclosed embodiments and methods, various modifications will be
apparent to those skilled in the art. It is intended that all
modifications that fall within the scopes of the claims relating to
this disclosure be deemed as part of the foregoing disclosure.
Also, an abstract is provided in this application with the
understanding that it will not be used to interpret or limit the
scope or meaning of the claims.
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