WO2001065066A1 - Tubage de revetement de puits utilisant la communication sans fil - Google Patents

Tubage de revetement de puits utilisant la communication sans fil Download PDF

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Publication number
WO2001065066A1
WO2001065066A1 PCT/US2001/006907 US0106907W WO0165066A1 WO 2001065066 A1 WO2001065066 A1 WO 2001065066A1 US 0106907 W US0106907 W US 0106907W WO 0165066 A1 WO0165066 A1 WO 0165066A1
Authority
WO
WIPO (PCT)
Prior art keywords
formation
piping structure
well
casing
downhole
Prior art date
Application number
PCT/US2001/006907
Other languages
English (en)
Inventor
Harold J. Vinegar
Robert Rex Burnett
William Mountjoy Savage
Frederick Gordon Carl, Jr.
Ilya Emil Berchenko
Original Assignee
Shell Internationale Research Maatschappij B.V.
Shell Canada Limited
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Shell Internationale Research Maatschappij B.V., Shell Canada Limited filed Critical Shell Internationale Research Maatschappij B.V.
Priority to CA002401723A priority Critical patent/CA2401723C/fr
Priority to GB0220347A priority patent/GB2376968B/en
Priority to US10/220,195 priority patent/US7114561B2/en
Priority to NZ521121A priority patent/NZ521121A/en
Priority to AU2001243405A priority patent/AU2001243405A1/en
Publication of WO2001065066A1 publication Critical patent/WO2001065066A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/003—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings with electrically conducting or insulating means
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/066—Valve arrangements for boreholes or wells in wells electrically actuated
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/16—Control means therefor being outside the borehole
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/14—Obtaining from a multiple-zone well
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/13—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency

Definitions

  • the present invention relates in general to petroleum wells, and in particular to a petroleum well having a casing which is used as a conductive path to transmit wireless spread spectrum communications between surface equipment and a downhole module used to measure physical characteristics of a petroleum formation or condition of well structures.
  • U. S. Patent No. 4,839,644 describes a method and system for wireless two-way communications in a cased borehole having a tubing string.
  • this system describes a communication scheme for coupling electromagnetic energy in a TEM mode using the annulus between the casing and the tubing.
  • This inductive coupling requires a substantially nonconductive fluid such as crude oil in the annulus between the casing and the tubing. Therefore, the invention described in U. S. Patent No. 4,839,644 has not been widely adopted as a practical scheme for downhole two-way communication.
  • Another system for downhole communication using mud pulse telemetry is described in U. S. Patent Nos. 4,648,471 and 5,887,657.
  • the problems associated with cornmunicating in the borehole of a petroleum well are solved by the present invention.
  • the metal well casing is used as a power and communications path between the surface and downhole modules, with a formation ground used as the return path to complete the electrical circuit.
  • Communications are implemented using spread-spectrum transceivers at the wellhead and at the downhole modules.
  • the communications enable transmission of measurements from downhole sensors to the surface and control of downhole devices.
  • a petroleum well includes a downhole module and a communications system.
  • the downhole module is positioned on an exterior surface of a piping structure, the piping structure being positioned within a borehole of the petroleum well that extends into a formation.
  • the downhole module collects formation data from the formation and communicates the data by using the communication system.
  • the signals transmitted by the communication system are passed along the piping structure.
  • a method for assessing a formation according to the present invention is applied to a petroleum well having a borehole that extends into the formation.
  • the petroleum well also includes a piping structure that is positioned within the borehole.
  • the method includes the step of sensing a formation characteristic within the formation and then communicating information about the formation characteristic along the piping structure of the well.
  • a downhole module is adapted for coupling to a piping structure of a petroleum well.
  • the module includes a sensor that is used to sense a physical characteristic of a formation surrounding the piping structure.
  • a downhole modem is used to transmit data representing the physical characteristic along the piping structure of the well.
  • FIG. 1 A is a schematic of a petroleum well having a downhole module attached to a casing, the downhole module being configured to measure formation characteristics according to the present invention. DESCRIPTION OF THE PREFERRED EMBODIMENTS
  • a "piping structure" can be one single pipe, a tubing string, a well casing, a pumping rod, a series of interconnected pipes, rods, rails, trusses, lattices, supports, a branch or lateral extension of a well, a network of interconnected pipes, or other structures known to one of ordinary skill in the art.
  • the preferred embodiment makes use of the invention in the context of an oil well where the piping structure comprises tubular, metallic, electrically-conductive pipe or tubing strings, but the invention is not so limited.
  • an electrically conductive piping structure is one that provides an electrical conducting path from one location where a power source is electrically connected to another location where a device and/or electrical return is electrically connected.
  • the piping structure will typically be conventional round metal tubing, but the cross- sectional geometry of the piping structure, or any portion thereof, can vary in shape (e.g., round, rectangular, square, oval) and size (e.g., length, diameter, wall thickness) along any portion of the piping structure.
  • valve is any device that functions to regulate the flow of a fluid.
  • valves include, but are not limited to, sub-surface safety valves used to control fluid flow in well tubulars, and bellows-type gas-lift valves and controllable gas-lift valves each of which may be used to regulate the flow of lift gas into a tubing string of a well.
  • the internal workings of valves can vary greatly, and in the present application, it is not intended to limit the valves described to any particular configuration, so long as the valve functions to regulate flow.
  • Some of the various types of flow regulating mechanisms include, but are not limited to, ball valve configurations, needle valve configurations, gate valve configurations, and cage valve configurations.
  • Valves can be mounted downhole in a well in many different ways, some of which include tubing conveyed mounting configurations, side-pocket mandrel configurations, or permanent mounting configurations such as mounting the valve in an enlarged tubing pod.
  • modem is used generically herein to refer to any communications device for transmitting and/or receiving electrical communication signals via an electrical conductor (e.g., metal).
  • the term is not limited to the acronym for a modulator (device that converts a voice or data signal into a form that can be transmitted)/demodulator (a device that recovers an original signal after it has modulated a high frequency carrier).
  • modem as used herein is not limited to conventional computer modems that convert digital signals to analog signals and vice versa (e.g., to send digital data signals over the analog Public Switched
  • a sensor outputs measurements in an analog format, then such measurements may only need to be modulated (e.g., spread spectrum modulation) and transmitted — hence no analog-to-digital conversion is needed.
  • a relay/slave modem or communication device may only need to identify, filter, amplify, and/or retransmit a signal received.
  • processor is used in the present application to denote any device that is capable of performing arithmetic and/or logic operations.
  • the processor may optionally include a control unit, a memory unit, and an arithmetic and logic unit.
  • sensor as used in the present application refers to any device that detects, determines, monitors, records, or otherwise senses the absolute value of or a change in a physical quantity. Sensors as described in the present application can be used to measure temperature, pressure (both absolute and differential), flow rate, seismic data, acoustic data, pH level, salinity levels, valve positions, or almost any other physical data.
  • wireless means the absence of a conventional, insulated wire conductor e.g. extending from a downhole device to the surface. Using the tubing and/or casing as a conductor is considered “wireless.”
  • Electronics module in the present application refers to a control device. Electronics modules can exist in many configurations and can be mounted downhole in many different ways. In one mounting configuration, the electronics module is actually located within a valve and provides control for the operation of a motor within the valve. Electronics modules can also be mounted external to any particular valve. Some electronics modules will be mounted within side pocket mandrels or enlarged tubing pockets, while others may be permanently attached to the tubing string. Electronics modules often are electrically connected to sensors and assist in relaying sensor information to the surface of the well. It is conceivable that the sensors associated with a particular electronics module may even be packaged within the electronics module.
  • the electronics module is often closely associated with, and may actually contain, a modem for receiving, sending, and relaying communications from and to the surface of the well. Signals that are received from the surface by the electronics module are often used to effect changes within downhole controllable devices, such as valves. Signals sent or relayed to the surface by the electronics module generally contain information about downhole physical conditions supplied by the sensors. In accordance with conventional terminology of oilfield practice, the descriptors "upper,”
  • lower,” “uphole,” and “downhole” as used herein are relative and refer to distance along hole depth from the surface, which in deviated or horizontal wells may or may not accord with vertical elevation measured with respect to a survey datum.
  • formation refers to a bed or deposit composed throughout of substantially the same kinds of rock.
  • a formation may or may not contain petroleum products.
  • Petroleum well 10 having a wireless smart well casing 12 is illustrated.
  • Petroleum well 10 includes a borehole 14 extending into a formation from a surface 16 to a production zone 18 that is located downhole.
  • the casing 12 is disposed in borehole 14 and includes a structure of the type conventionally employed in the oil and gas industry.
  • the casing 12 is typically installed in sections and is secured in borehole 14 during well completion with cement 34.
  • a tubing string, or production tubing, 26 is generally conventional comprising a plurality of elongated tubular pipe sections joined by threaded couplings at each end of the pipe sections. Oil or gas produced by petroleum well 10 is typically delivered to surface 16 by tubing string 26.
  • a production platform 27 is located at surface 16 and includes a tubing hanger 28.
  • Tubing hanger 28 supports tubing string 26 such that the tubing string 26 is concentrically positioned within casing 12.
  • production platform 27 also includes a gas input throttle 30 to permit the input of compressed gas into an annular space 31 between casing 12 and tubing string 26.
  • an output valve 32 permits the expulsion of oil and gas bubbles from an interior of tubing string 26 during oil production. While FIG. 1 illustrates a gas lift well, the present invention is not so limited, and the gas input throttle valve 30 and its associated input tubing is therefore optional.
  • Well 10 includes a communication system 44 for providing power and two-way communication signals downhole in well 10.
  • Casing 12 acts as an electrical conductor for communication system 44.
  • an induction choke 42 is positioned concentrically around casing 12 prior to securing the casing 12 within cement 34.
  • Induction choke 42 serves as a series impedance to electric current flow along the casing 12.
  • the size and material of lower induction choke 42 can be altered to vary the series impedance value; however, the lower induction choke 42 is made of a ferromagnetic material.
  • Induction choke 42 is mounted concentric and external to casing 12, and is typically hardened with epoxy to withstand rqugh handling.
  • a means is provided to electrically insulate casing 12 and tubing string 26 from ground connection through surface ancillary tubing connected to valves 30 and 32.
  • Insulators 40 provide this function as shown in FIG. 1, but alternative methods exist and will be clear to those of average skill in the art, such as the use of an insulated tubing hanger (not shown) in combination with an electrical isolation tubing joint (not shown).
  • another induction choke (not shown) can be placed about the casing above the electrical point of connection 49 of the surface power and communication equipment 44, or two such chokes may be placed individually about the production fluids tubing and the lift gas supply pipe.
  • inductive chokes such as 42 external to the casing act to impede current flow on both casing and tubing at the points where these pass through such inductive chokes.
  • the cement 20 can be of low electrical conductivity and provides a degree of electrical isolation between casing 12 and the formation surrounding the well.
  • Induction choke 42 further impedes current flow along casing 12 and tubing 26, thereby allowing the signals to be passed between induction choke 42 and the surface of the well. It is important to note that electrical contact between casing 12 and tubing string 26 does not short circuit the signals travelling along casing 12. Since tubing string 26 is also located within the annulus of induction choke 42, the choke 42 has the same electrical impedance effect on tubing string 26 as on casing 12.
  • a computer and power source 44 including a power supply 46 and a spread spectrum communications device (e.g. modem) 48 is disposed outside of borehole 14 at surface 16.
  • the computer and power source 44 is electrically connected to casing 12 at a current supply point 49 for supplying time varying current to the casing 12.
  • Computer and power source 44 is grounded to surface 16.
  • downhole electronics module 50 is positioned proximate to an exterior surface of the casing 12 prior to completion of the well.
  • Downhole module 50 includes a plurality of sensors 70, 72, 74, for assessing formation characteristics (i.e. physical characteristics) about the formation that surrounds the well.
  • sensors 70, 72, 74 could include resistivity sensors, pressure sensors, temperature sensors, flow rate sensors, corrosion sensors, or geophones. Each of these sensors can be used to obtain information about the characteristics of the formation. Additionally, hydrophones could be used to measure acoustic waves in well fluids within casing 12.
  • sensors 70 - 74 would be able to measure formation characteristics such as pressure or resistivity, since they are embedded within cement 34 and not in direct connection with formation 18.
  • formation characteristics such as pressure or resistivity
  • the pressure of fluids in the pore spaces of the cement 34 equilibrates with the pressure in the formation. Rapid changes in formation pressure cannot be measured, but slow changes can be measured, and it is data from slow changes as the reservoir is depleted that are valuable as an indication of reservoir condition.
  • resistivity logs reveal the spatial variation of resistivity over the logged section of the formation, measured at essentially a single instant of time.
  • the resistivity log acquired by the methods of the present invention is derived from a locationally static single sensor, but over an extended period of time.
  • changes in the resistivity are the features which reveal the condition of the formation: in the open-hole log, these are spatial changes, in the present invention, the changes are a function of time rather than spatial variations.
  • Downhole module 50 is configured to be mechanically connected to the casing 12 either above or below induction choke 42. Electrical connections to the downhole module 50 are provided by jumpers. Power is received at the downhole module 50 by a jumper connected to casing 12 above the induction choke 42. A ground return jumper is provided that connects downhole module 50 to casing 12 below induction choke 42.
  • Downhole module 50 also includes a spread spectrum transceiver (not shown) for communicating with modem 48 at the surface of the well 10.
  • the transceiver enables sensor data representing the formation characteristics to be transmitted to the surface of the well 10 for use in optimizing production of the well 10. If multiple downhole modules 50 are positioned on the casing 12, the transceiver in each downhole module is able to communicate with transceivers in the other downhole modules, thereby allowing transceivers to relay signals and providing redundancy in the event of a failure of one of the downhole modules 50. After positioning induction choke 42 and downhole module 50 on casing 12, the casing
  • cement 34 is injected into the annulus between the borehole and casing 12 to secure the casing within the borehole 14. The cement 34 also further secures the * positioning of the induction choke 42 and the downhole module 50 relative to casing 12
  • the present invention can be applied in many areas where there is a need to provide a communication system within a borehole, well, or any other area that is difficult to access. Also, one skilled in the art will see that the present invention can be applied in many areas where there is an already existing conductive piping structure and a need to route power and communications to a location on the piping structure.
  • a water sprinkler system or network in a building for extinguishing fires is an example of a piping structure that may be already existing and may have a same or similar path as that desired for routing power and communications. In such case another piping structure or another portion of the same piping structure may be used as the electrical return.
  • the steel structure of a building may also be used as a piping structure and/or electrical return for transmitting power and communications in accordance with the present invention.
  • the steel rebar in a concrete dam or a street may be used as a piping structure and/or electrical return for transmitting power and communications in accordance with the present invention.
  • the transmission lines and network of piping between wells or across large stretches of land may be used as a piping structure and/or electrical return for transmitting power and communications in accordance with the present invention.
  • Surface refinery production pipe networks may be used as a piping structure and/or electrical return for transmitting power and communications in accordance with the present invention.

Abstract

La présente invention concerne un puits de pétrole dont le trou de forage est situé dans une formation. On positionne une structure de tubage dans ce trou de forage et on positionne une duse d'induction au fond du trou autour de cette structure. Un système de communication est prévu le long de cette structure entre une surface du puits et cette duse d'induction. On positionne un module de fond sur une surface extérieure de la structure de tubage et on l'agence de façon à mesurer des caractéristiques de la formation. Ces caractéristiques de formation, telles que la pression et la résistivité, sont communiquées à la surface du puits le long de cette structure de tubage.
PCT/US2001/006907 2000-01-24 2001-03-02 Tubage de revetement de puits utilisant la communication sans fil WO2001065066A1 (fr)

Priority Applications (5)

Application Number Priority Date Filing Date Title
CA002401723A CA2401723C (fr) 2000-03-02 2001-03-02 Tubage de revetement de puits utilisant la communication sans fil
GB0220347A GB2376968B (en) 2000-03-02 2001-03-02 Wireless communication in a petroleum well
US10/220,195 US7114561B2 (en) 2000-01-24 2001-03-02 Wireless communication using well casing
NZ521121A NZ521121A (en) 2000-03-02 2001-03-02 Wireless communication using well casing
AU2001243405A AU2001243405A1 (en) 2000-03-02 2001-03-02 Wireless communication using well casing

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US18650300P 2000-03-02 2000-03-02
US60/186,503 2000-03-02

Publications (1)

Publication Number Publication Date
WO2001065066A1 true WO2001065066A1 (fr) 2001-09-07

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Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2001/006907 WO2001065066A1 (fr) 2000-01-24 2001-03-02 Tubage de revetement de puits utilisant la communication sans fil

Country Status (5)

Country Link
AU (1) AU2001243405A1 (fr)
CA (1) CA2401723C (fr)
GB (1) GB2376968B (fr)
NZ (1) NZ521121A (fr)
WO (1) WO2001065066A1 (fr)

Cited By (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2830272A1 (fr) * 2001-10-01 2003-04-04 Schlumberger Services Petrol Dispositif de surveillance ou d'etude d'un reservoir traverse par un puits
US6727827B1 (en) 1999-08-30 2004-04-27 Schlumberger Technology Corporation Measurement while drilling electromagnetic telemetry system using a fixed downhole receiver
US6987386B1 (en) 1986-11-04 2006-01-17 Western Atlas International, Inc. Determining resistivity of a geological formation using circuitry located within a borehole casing
GB2404681B (en) * 2002-02-06 2006-08-23 Weatherford Lamb Automated wellbore apparatus and method based on a centralised bus network
US7278480B2 (en) 2005-03-31 2007-10-09 Schlumberger Technology Corporation Apparatus and method for sensing downhole parameters
US20100223988A1 (en) * 2009-03-06 2010-09-09 Bp Corporation North America Inc. Apparatus And Method For A Wireless Sensor To Monitor Barrier System Integrity
US8056623B2 (en) 2007-08-09 2011-11-15 Schlumberger Technology Corporation Surface formation monitoring system and method
WO2019018706A1 (fr) * 2017-07-21 2019-01-24 The Charles Stark Draper Laboratory, Inc. Système de capteur de fond de trou utilisant une source résonante
GB2548031B (en) * 2014-12-31 2021-02-10 Halliburton Energy Services Inc Electromagnetic telemetry for sensor systems deployed in a borehole environment
US11976550B1 (en) 2022-11-10 2024-05-07 Halliburton Energy Services, Inc. Calorimetric control of downhole tools

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EP0964134A2 (fr) * 1998-06-12 1999-12-15 Schlumberger Technology B.V. Transmission de puissance et de signal au moyen d'un conduit isolé pour des ins-tallations permanentes de fond de puits

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WO1980000727A1 (fr) * 1978-09-29 1980-04-17 Secretary Energy Brit Ameliorations se rapportant a la transmission d'energie electrique dans des puits de fluide
US4468665A (en) 1981-01-30 1984-08-28 Tele-Drill, Inc. Downhole digital power amplifier for a measurements-while-drilling telemetry system
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EP0295178A2 (fr) * 1987-06-10 1988-12-14 Schlumberger Limited Dispositif et procédé pour communiquer des signaux dans un puits armé muni de tubes
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EP0339825A1 (fr) * 1988-04-29 1989-11-02 Utilx Corporation Dispositif de transmission d'informations dans un puits de forage
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US5576703A (en) 1993-06-04 1996-11-19 Gas Research Institute Method and apparatus for communicating signals from within an encased borehole
US5467083A (en) 1993-08-26 1995-11-14 Electric Power Research Institute Wireless downhole electromagnetic data transmission system and method
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US5883516A (en) 1996-07-31 1999-03-16 Scientific Drilling International Apparatus and method for electric field telemetry employing component upper and lower housings in a well pipestring
WO1999037044A1 (fr) * 1998-01-16 1999-07-22 Flight Refuelling Ltd. Systeme de transmission dans un trou de sondage mettant en application une modulation d'impedance
EP0964134A2 (fr) * 1998-06-12 1999-12-15 Schlumberger Technology B.V. Transmission de puissance et de signal au moyen d'un conduit isolé pour des ins-tallations permanentes de fond de puits

Cited By (21)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6987386B1 (en) 1986-11-04 2006-01-17 Western Atlas International, Inc. Determining resistivity of a geological formation using circuitry located within a borehole casing
US6727827B1 (en) 1999-08-30 2004-04-27 Schlumberger Technology Corporation Measurement while drilling electromagnetic telemetry system using a fixed downhole receiver
FR2830272A1 (fr) * 2001-10-01 2003-04-04 Schlumberger Services Petrol Dispositif de surveillance ou d'etude d'un reservoir traverse par un puits
WO2003029615A1 (fr) * 2001-10-01 2003-04-10 Services Petroliers Schlumberger Dispositif de surveillance de formations souterraines
GB2397383A (en) * 2001-10-01 2004-07-21 Schlumberger Holdings Apparatus for monitoring undergound formations
GB2397383B (en) * 2001-10-01 2005-08-24 Schlumberger Holdings Apparatus for monitoring underground formations
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GB2404681B (en) * 2002-02-06 2006-08-23 Weatherford Lamb Automated wellbore apparatus and method based on a centralised bus network
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NZ521121A (en) 2005-03-24
GB2376968B (en) 2004-03-03
AU2001243405A1 (en) 2001-09-12
GB0220347D0 (en) 2002-10-09
CA2401723C (fr) 2009-06-09
GB2376968A (en) 2002-12-31
CA2401723A1 (fr) 2001-09-07

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