EP0816632A1 - Vorrichtung und Verfahren zur Übertragung von Nachrichten mittels elektromagnetischer Wellen - Google Patents

Vorrichtung und Verfahren zur Übertragung von Nachrichten mittels elektromagnetischer Wellen Download PDF

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Publication number
EP0816632A1
EP0816632A1 EP97401341A EP97401341A EP0816632A1 EP 0816632 A1 EP0816632 A1 EP 0816632A1 EP 97401341 A EP97401341 A EP 97401341A EP 97401341 A EP97401341 A EP 97401341A EP 0816632 A1 EP0816632 A1 EP 0816632A1
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EP
European Patent Office
Prior art keywords
tubes
well
assembly
information
contact
Prior art date
Legal status (The legal status 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 status listed.)
Granted
Application number
EP97401341A
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English (en)
French (fr)
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EP0816632B1 (de
Inventor
Louis Soulier
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Geoservices SA
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Geoservices SA
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Publication of EP0816632A1 publication Critical patent/EP0816632A1/de
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Publication of EP0816632B1 publication Critical patent/EP0816632B1/de
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/26—Storing data down-hole, e.g. in a memory or on a record carrier
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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 is in the field of well production tests drilled in a geological formation, generally for the purpose of qualitatively and quantitatively the effluents contained in the geological formation crossed by the drilling.
  • This type of test called “DST” for "Drill Stem Test” is generally performed in course of drilling an exploration well. We will not, however, depart from the framework of the present invention, if these tests are carried out in production wells, at the start or in during the production phase.
  • the present invention relates to a device for transmitting, in particular by real time, information on both sides of a test valve placed in a packing of tubes, commonly called test packing, the packing being introduced into a well drilled in the ground, according to conventional procedures.
  • Some systems use a hydraulic channel located in the wall of the train test, which connects the pressurized volume located under the test valve up to pressure measurement gauges located above the valve. Measures these gauges are then transmitted to the surface via an electric cable connected to a fitting with special electronic means. The connection is made by coupling by means of a mutual induction transformer or by a current.
  • the first systems have the main disadvantage of requiring a train test, and more specifically a test valve including the integration of a passage hydraulic. This type of construction is very complex and very expensive to manufacture and maintenance. Furthermore in these systems, the connection, electrical or mutual induction, of the electric cable connecting to the surface the measurement means located above of the test valve, is very sensitive to the nature of the fluid located inside the tube production. In particular, transmission is very difficult when the fluids are conductors.
  • the transmission distance is practically limited to a length of tubes, about ten meters. Therefore the connector attached to the lower end of the electrical cable must be positioned approximately ten meters above the test valve. In the event that the well produces a effluent containing sand, it sediments after the flow corresponding to closing the test valve, thereby forming a plug that can reach several tens of meters high, which can prevent the proper functioning of the connector, its anchoring or undocking.
  • the present invention relates to an information transmission device between the bottom of a well and the ground surface, said well comprising a set of tubes separated into a lower part and an upper part by means for closing off the interior space of said tubes, annular sealing means between said tubes and said well.
  • said lower part comprises a first set comprising means of acquiring information and means of transmitting and reception of electromagnetic signals
  • a second set of transmission and reception of electromagnetic signals is placed in the interior space of the party upper tubes by maneuvering means comprising at least one line of electrical or optical communication going up to the surface and said second set comprises means of electrical contact with said tubes.
  • the first and second sets may include means for injecting a low frequency electric current along the tubes.
  • the first set may include a toroidal transformer substantially concentric with the axis of the tubes.
  • the second part of the transformer can be a single turn constituted by the tubes looping through the casing or the ground.
  • the operating means may consist of at least one length of cable with coaxial conductors and metallic outer armor.
  • the upper part of the tubes may include an electrical insulation means placed between two tube elements.
  • at least one of the means of contact between the second set and the tubes is located between the insulation means and the means shutter.
  • the information acquisition means may include at least one sensor pressure and a temperature sensor.
  • the operating means of the second set may include means of contact with the tubes on which the electromagnetic current flows, said contacts advantageously being spaced several meters apart.
  • the well can be cased by metal casing, and the portion of tubes included between said assemblies can be partially electrically isolated from said casing by centering means.
  • the tubes may include at least two means of electrical contact with the metal casing, the contacts being located on either side of said portion of tubes centered.
  • One of the means of contact with the metal casing can be constituted by said annular sealing means.
  • the information acquisition means can be remotely controlled from the surface through the line channel and electromagnetic transmission between said two together.
  • the invention also relates to a method of transmitting information between the bottom of a well and the ground surface, said well comprising a set of separate tubes in a lower part and an upper part by means of sealing the space inside said tubes, annular sealing means between said tubes and said well, means of acquiring information.
  • Information acquisition can be remotely controlled from the surface by the channel of said line and of the second and first sets.
  • Said second assembly can be maneuvered above the shutter means by by means of a coaxial cable of the "logging" type.
  • the device which is the subject of the present invention comprises a first communication set 1 equipped with transmitter / receiver means and various means measurement, including pressure and temperature sensors.
  • the device includes also a second communication set 2 called shuttle, and equipped with additional transmitter / receiver means of the first set 1 and means of bidirectional digital telemetry with the surface via a cable 3 (type logging) comprising electrical conductors or optical fibers.
  • Cable 3 is operated in tubes 4 using a surface installation known to technicians concerned, i.e. a winch and a control, recording and processing of signals passing through the communication lines integrated into the cable 3.
  • the tubes 4 are lowered into a well 5 drilled through a geological layer whose effluents that may be contained in the pores of the layer.
  • a so-called test lining is assembled. comprising the assemblies 1 and 2, a sealing means of the “packer” type 6 for performing an annular seal around the tubes, a strainer 7 placed below the packer and intended to allow access of the effluent to the interior space of the tubes 4, a sliding joint 8 and / or a threshing slide ("jar") to allow installation and facilitate removal of the packer, a test valve 9 which can be opened or closed several times in order to open or to close the communication between the geological layer and the interior space of the tubes 4 in communication with the surface.
  • Other conventional equipment, not shown here, can complete the test train: circulation fitting, safety seal, etc.
  • the well 5 is cased by a tube in steel 16, usually cemented in the drilled hole.
  • the link between the producing layer and the hole is made either by perforations through the casing tube, or by a borehole 17 extending to the beyond the shoe of column 16.
  • the test lining includes preferably contacts 10 and 11, for example in the form of blade centralizers metallic, packer or natural contacts provided by a set of tubes offset in a well.
  • the contact points 10 and 11 to be the most spaced possible along the lining, on either side of the valve 9 and at least separated more than one tube segment, i.e. at least 10 meters.
  • assembly 1 is of the insulating junction type and not of the transformer type, there will be a electrical interruption substantially to the right of the transmission / reception dipole of the assembly 2 and of assembly 1, according to the very principle of the transmission of the insulating junction type.
  • Sets 1 and 2 communicate with each other by means of currents electromagnetic guided by the casing 16 and / or the test train.
  • PSK phase jump
  • the sets 1 and 2 being most often located inside a casing 16, it is very advantageous to constitute the widest possible injection dipole in order to create behind casing as large a propagation signal as possible.
  • Such a dipole is described in the document US-A-5394141 cited here for reference.
  • the operation of this transmission device is always possible. But in this case, the transmission distance between set 1 and assembly 2 and / or the information rate can be reduced in order to reduce the energy of the noise according to well-known principles for improving the signal-to-noise ratio.
  • Standard tube protectors can be used in rubber or any other insulating ring 13 and 14 mounted on a tube element and inserted in the test train at adequate distances. Note that whatever the nature of the fluid in the annular test lining / well, including brines, difference in conductivity between the fluid and the packing tubes constitutes a dipole apparent more than 10 meters, which is generally sufficient for this transmission.
  • each set 1 and 2 of this device used to inject, or receive the carrier frequency propagating along the test train may be realized using one of the well known techniques, namely either an insulating junction such as described in document US-A-5163714, either an extended dipole, or else a transformer whose toroidal magnetic circuit surrounds the assembly 1.
  • the second transmitter / receiver assembly 2 called shuttle, includes a link insulator 21 and a lower electrical contact means 18 with the inside of the tube 4, said means that can be achieved, either by dogs anchored in a corresponding gorge machined in a screw connection on the tubes 4 or by extractable pads remotely controlled from the surface via the electrical connection used for data transfer measured.
  • the second pole, or upper pole, of the receive / transmit dipole is constituted by the metallic reinforcement of the coaxial cable 3 (for example, of the logging type).
  • This cable being sufficiently centered in the tubes up to a height where there is a point of contact 15, it can only be in contact with the wall of the tubes at a sufficient distance large thus making it possible to produce a very long transmitter / receiver dipole.
  • the contact 11 is located below the point of contact 15, or in the vicinity.
  • FIG. 2 represents the configuration where the well 20 is not cased by a steel casing.
  • the test lining comprises at least one strainer 7, one packer 6, one test valve 9 assembled to tubes 4.
  • the first assembly 1 comprises means for measures, electronic and electromagnetic means to ensure communication by electromagnetic waves with shuttle 2.
  • Shuttle 2 descended into space inside the tubes, above the test valve 9, by means of a cable 3 comprising at least one electrical or optical communication line.
  • Set 2 or shuttle comprises electrical contact means 18, preferably in the form of fingers remotely controlled or wipers.
  • the shuttle has an insulating connection 21 so as to constitute a first lower pole thanks to contact 18 and a second pole with the cable frame 3.
  • the pressure and temperature measurement is ensured by three standard 30 gauges, say by memory, powered by three independent energy sources.
  • the measurements are stored in non-volatile memory with a programmed sampling frequency on the surface by an operator.
  • Each gauge measures, as desired, the internal pressure in the channel 31 via conduit 32 or the pressure in the ring finger, that is to say outside of the assembly 1.
  • the gauges 30 are connected to an electronic cartridge 33 by via an electrical connection 34.
  • the electronic cartridge 33 collects the data measured by one of the three gauges and injects a signal in the preferential form a representative low frequency phase modulated electromagnetic current (PSK) of this data to the torus 35.
  • PSK phase modulated electromagnetic current
  • a cover 36 integral with the assembly 1 is electrically insulated at least on one of its ends 37 while protecting the torus 35 and the electronic cartridge 33.
  • the operation control signal emitted from the surface, also allows choose the gauge that will be read by the electronic cartridge.
  • each gauge 30 can also be read on the surface at the end of the test.
  • the second set 2 or shuttle ( Figure 1 and Figure 2) is connected to the surface by a coaxial cable 3.
  • the cable provides power to the electronic compartment included in the shuttle and the bidirectional dialogue between the shuttle and the surface.
  • the electronic compartment mainly consists of: a electromagnetic transmitter / receiver and a two-way electrical transmitter allowing dialogue with the surface via the cable conductors.
  • the shuttle's electromagnetic transmitter generates a low frequency signal modulated in phase between the armouring of the cable and the contact means 18, these two points being electrically isolated by insulating junction 21.
  • the shuttle generates this signal on reception of an order signal from the surface via the coaxial cable.
  • the signal generated by the shuttle is received and then decoded by set 1 to allow it to modify its operating mode.
  • the shuttle can inject or receive an electromagnetic current using means comprising a transformer.
  • the shuttle's electromagnetic receiver receives, then decodes, the low signal frequency emitted by the assembly 1. This signal is measured between the armouring of the cable 3 and the contact 18. It is generally representative of the data measured by the gauges of the set 1.
  • the contact means 18 can, in addition to ensuring electrical contact between the shuttle and the test train, ensure mechanical anchoring of the shuttle in the test train. This anchoring may be necessary if, as in the case of using an insulation fitting 12 in the test set, a specific position of the shuttle is required, or if the flow of the effluent risks creating untimely displacements, or vibrations which can be troublesome for the proper functioning of the transmission.

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  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Remote Sensing (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Geophysics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Electromagnetism (AREA)
  • Arrangements For Transmission Of Measured Signals (AREA)
  • Geophysics And Detection Of Objects (AREA)
EP97401341A 1996-07-01 1997-06-13 Vorrichtung und Verfahren zur Übertragung von Nachrichten mittels elektromagnetischer Wellen Expired - Lifetime EP0816632B1 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
FR9608256 1996-07-01
FR9608256A FR2750450B1 (fr) 1996-07-01 1996-07-01 Dispositif et methode de transmission d'informations par onde electromagnetique

Publications (2)

Publication Number Publication Date
EP0816632A1 true EP0816632A1 (de) 1998-01-07
EP0816632B1 EP0816632B1 (de) 2003-09-03

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US (1) US5945923A (de)
EP (1) EP0816632B1 (de)
AU (1) AU726088B2 (de)
CA (1) CA2209423C (de)
FR (1) FR2750450B1 (de)
NO (1) NO317444B1 (de)

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2337546A (en) * 1998-05-18 1999-11-24 Baker Hughes Inc Drillpipe structures to accomodate downhole testing
EP0995877A1 (de) * 1998-10-23 2000-04-26 Geoservices S.A Vorrichtung und Verfahren zur Übertragung von Nachrichten mittels elektromagnetischer Wellen
US6710600B1 (en) 1994-08-01 2004-03-23 Baker Hughes Incorporated Drillpipe structures to accommodate downhole testing
US7071837B2 (en) 1999-07-07 2006-07-04 Expro North Sea Limited Data transmission in pipeline systems

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US6684952B2 (en) 1998-11-19 2004-02-03 Schlumberger Technology Corp. Inductively coupled method and apparatus of communicating with wellbore equipment
US7407006B2 (en) * 1999-01-04 2008-08-05 Weatherford/Lamb, Inc. System for logging formations surrounding a wellbore
US7513305B2 (en) * 1999-01-04 2009-04-07 Weatherford/Lamb, Inc. Apparatus and methods for operating a tool in a wellbore
US6736210B2 (en) 2001-02-06 2004-05-18 Weatherford/Lamb, Inc. Apparatus and methods for placing downhole tools in a wellbore
US6798338B1 (en) 1999-02-08 2004-09-28 Baker Hughes Incorporated RF communication with downhole equipment
US6343649B1 (en) * 1999-09-07 2002-02-05 Halliburton Energy Services, Inc. Methods and associated apparatus for downhole data retrieval, monitoring and tool actuation
US7385523B2 (en) * 2000-03-28 2008-06-10 Schlumberger Technology Corporation Apparatus and method for downhole well equipment and process management, identification, and operation
US6989764B2 (en) * 2000-03-28 2006-01-24 Schlumberger Technology Corporation Apparatus and method for downhole well equipment and process management, identification, and actuation
US6516663B2 (en) 2001-02-06 2003-02-11 Weatherford/Lamb, Inc. Downhole electromagnetic logging into place tool
GB0124451D0 (en) * 2001-10-11 2001-12-05 Flight Refueling Ltd Magnetic signalling in pipelines
AU2002347006A1 (en) * 2001-10-12 2003-06-10 Shell Internationale Research Maatschappij B.V. B.V. Method and device for transferring data between an object moving in a well tubular and a remote station
US6915848B2 (en) 2002-07-30 2005-07-12 Schlumberger Technology Corporation Universal downhole tool control apparatus and methods
US6776240B2 (en) 2002-07-30 2004-08-17 Schlumberger Technology Corporation Downhole valve
US7163065B2 (en) * 2002-12-06 2007-01-16 Shell Oil Company Combined telemetry system and method
US7170423B2 (en) * 2003-08-27 2007-01-30 Weatherford Canada Partnership Electromagnetic MWD telemetry system incorporating a current sensing transformer
US7145473B2 (en) * 2003-08-27 2006-12-05 Precision Drilling Technology Services Group Inc. Electromagnetic borehole telemetry system incorporating a conductive borehole tubular
US7080699B2 (en) * 2004-01-29 2006-07-25 Schlumberger Technology Corporation Wellbore communication system
US7249636B2 (en) 2004-12-09 2007-07-31 Schlumberger Technology Corporation System and method for communicating along a wellbore
CA2596349C (en) * 2005-01-31 2010-04-20 Baker Hughes Incorporated Telemetry system with an insulating connector
US7518528B2 (en) * 2005-02-28 2009-04-14 Scientific Drilling International, Inc. Electric field communication for short range data transmission in a borehole
US8056619B2 (en) 2006-03-30 2011-11-15 Schlumberger Technology Corporation Aligning inductive couplers in a well
US7735555B2 (en) * 2006-03-30 2010-06-15 Schlumberger Technology Corporation Completion system having a sand control assembly, an inductive coupler, and a sensor proximate to the sand control assembly
US7712524B2 (en) * 2006-03-30 2010-05-11 Schlumberger Technology Corporation Measuring a characteristic of a well proximate a region to be gravel packed
US7793718B2 (en) 2006-03-30 2010-09-14 Schlumberger Technology Corporation Communicating electrical energy with an electrical device in a well
CA2544457C (en) 2006-04-21 2009-07-07 Mostar Directional Technologies Inc. System and method for downhole telemetry
US8839850B2 (en) * 2009-10-07 2014-09-23 Schlumberger Technology Corporation Active integrated completion installation system and method
US20110192596A1 (en) * 2010-02-07 2011-08-11 Schlumberger Technology Corporation Through tubing intelligent completion system and method with connection
RU2475642C1 (ru) * 2011-08-09 2013-02-20 Открытое акционерное общество "Научно-производственная фирма "Геофизика" (ОАО НПФ "Геофизика") Способ и оборудование для проведения гидродинамических исследований пластов на трубах
US9249559B2 (en) 2011-10-04 2016-02-02 Schlumberger Technology Corporation Providing equipment in lateral branches of a well
US9644476B2 (en) 2012-01-23 2017-05-09 Schlumberger Technology Corporation Structures having cavities containing coupler portions
US9175560B2 (en) 2012-01-26 2015-11-03 Schlumberger Technology Corporation Providing coupler portions along a structure
US9938823B2 (en) 2012-02-15 2018-04-10 Schlumberger Technology Corporation Communicating power and data to a component in a well
US10036234B2 (en) 2012-06-08 2018-07-31 Schlumberger Technology Corporation Lateral wellbore completion apparatus and method
GB2506123C (en) 2012-09-19 2024-02-21 Expro North Sea Ltd Downhole communication
MX2015008634A (es) 2013-01-04 2016-02-05 Carbo Ceramics Inc Agente de sosten electricamente conductivo y metodos de deteccion, localizacion y caracterizacion del agente de sosten electricamente conductivo.
US9434875B1 (en) 2014-12-16 2016-09-06 Carbo Ceramics Inc. Electrically-conductive proppant and methods for making and using same
US11008505B2 (en) 2013-01-04 2021-05-18 Carbo Ceramics Inc. Electrically conductive proppant
US9551210B2 (en) 2014-08-15 2017-01-24 Carbo Ceramics Inc. Systems and methods for removal of electromagnetic dispersion and attenuation for imaging of proppant in an induced fracture

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US5396232A (en) * 1992-10-16 1995-03-07 Schlumberger Technology Corporation Transmitter device with two insulating couplings for use in a borehole
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Title
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Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6710600B1 (en) 1994-08-01 2004-03-23 Baker Hughes Incorporated Drillpipe structures to accommodate downhole testing
GB2337546A (en) * 1998-05-18 1999-11-24 Baker Hughes Inc Drillpipe structures to accomodate downhole testing
GB2337546B (en) * 1998-05-18 2000-12-06 Baker Hughes Inc Drillpipe structures to accomodate downhole testing
EP0995877A1 (de) * 1998-10-23 2000-04-26 Geoservices S.A Vorrichtung und Verfahren zur Übertragung von Nachrichten mittels elektromagnetischer Wellen
FR2785017A1 (fr) * 1998-10-23 2000-04-28 Geoservices Methode et systeme de transmission d'informations par onde electromagnetique
US6628206B1 (en) 1998-10-23 2003-09-30 Geoservices S.A. Method and system for the transmission of informations by electromagnetic wave
US7071837B2 (en) 1999-07-07 2006-07-04 Expro North Sea Limited Data transmission in pipeline systems

Also Published As

Publication number Publication date
CA2209423C (fr) 2006-11-14
AU2834897A (en) 1998-01-15
US5945923A (en) 1999-08-31
NO973006L (no) 1998-01-02
AU726088B2 (en) 2000-11-02
NO973006D0 (no) 1997-06-27
FR2750450B1 (fr) 1998-08-07
NO317444B1 (no) 2004-11-01
FR2750450A1 (fr) 1998-01-02
EP0816632B1 (de) 2003-09-03
CA2209423A1 (fr) 1998-01-01

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