US20090032303A1

US20090032303A1 - Apparatus and method for wirelessly communicating data between a well and the surface

Info

Publication number: US20090032303A1
Application number: US11/833,049
Authority: US
Inventors: Michael H. Johnson
Original assignee: Baker Hughes Inc
Current assignee: Baker Hughes Holdings LLC
Priority date: 2007-08-02
Filing date: 2007-08-02
Publication date: 2009-02-05
Also published as: WO2009017900A2; CA2693335A1; WO2009017900A3

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.

Description

BACKGROUND OF THE DISCLOSURE

1. Field of the Disclosure
This disclosure relates to apparatus and methods for wirelessly communicating data between a well and the surface.
2. Background Information
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.
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.
The present disclosure provides improved apparatus, systems and methods for communicating data between a well and the surface.

SUMMARY

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.
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.
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.
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

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:

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;

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

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

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 56 a and 56 b (such as hydrocarbons) from two exemplary production zones 52 a (upper production zone) and 52 b (lower production zone) respectively. The well 50 is shown lined with a casing 57 containing perforations 54 a adjacent the upper production zone 52 a and perforations 54 b adjacent the lower production zone 52 b. A packer 64, which may be a retrievable packer, positioned above or uphole of the lower production zone perforations 54 a, isolates the lower production zone 52 b from the upper production zone 52 a. A screen 59 b adjacent to the perforations 54 b may be installed to prevent or inhibit solids, such as sand, from entering into the wellbore from the lower production zone 54 b. Similarly, a screen 59 a may be used adjacent the upper production zone perforations 59 a to prevent or inhibit solids from entering into the well 50 from the upper production zone 52 a.
Formation fluid 56 b from the lower production zone 52 b enters the annulus 51 a of the well 50 through the perforations 54 a 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 51 a 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 52 b to the surface 112. The formation fluid 56 a from the upper production zone 52 a enters the annulus 51 b (the annulus portion above the packer 64) via perforations 54 a. The formation fluid 56 a 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 52 a and the lower production zone 52 b enter the line 46.
When the formation pressure is not sufficient to push the fluid 56 a and/or fluid 56 b 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 56 a and 56 b 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 134 a and 134 b (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_Eand an ESP control unit 130.
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 52 a. Also, downhole sensors may be used at other desired locations to provide measurements relating to the presence and extent of chemicals downhole. Additionally, sensors S₁-S_mmay 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 59 a and/or screen 59 b 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_Emay 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.
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.
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 56 b via a mandrel 36. Similarly, a tubing 22 may supply or inject a particular chemical to the fluid 56 a 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.
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 S₁-S_min 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.
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 R₁-R_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.
Each of the transducers, such as transducer 110, and the repeaters R₁-R_nmay 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 T₁-T_pfrom 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.
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.
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.
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.
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.
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.
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.
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.

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.