WO2011041248A2 - Diagraphie électromagnétique entre un trou de forage gainé et la surface - Google Patents

Diagraphie électromagnétique entre un trou de forage gainé et la surface Download PDF

Info

Publication number
WO2011041248A2
WO2011041248A2 PCT/US2010/050338 US2010050338W WO2011041248A2 WO 2011041248 A2 WO2011041248 A2 WO 2011041248A2 US 2010050338 W US2010050338 W US 2010050338W WO 2011041248 A2 WO2011041248 A2 WO 2011041248A2
Authority
WO
WIPO (PCT)
Prior art keywords
receivers
wellbore
transmitter
formation
array
Prior art date
Application number
PCT/US2010/050338
Other languages
English (en)
Other versions
WO2011041248A3 (fr
Inventor
Hong Zhang
Richard A. Rosthal
Original Assignee
Schlumberger Canada Limited
Schlumberger Technology B.V.
Prad Research And Development Limited
Services Petroliers Schlumberger
Schlumberger Holdings 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
Priority claimed from US12/705,816 external-priority patent/US8155980B2/en
Application filed by Schlumberger Canada Limited, Schlumberger Technology B.V., Prad Research And Development Limited, Services Petroliers Schlumberger, Schlumberger Holdings Limited filed Critical Schlumberger Canada Limited
Priority to EP10821075.8A priority Critical patent/EP2483715A4/fr
Priority to CN201080053535.5A priority patent/CN102667530B/zh
Publication of WO2011041248A2 publication Critical patent/WO2011041248A2/fr
Publication of WO2011041248A3 publication Critical patent/WO2011041248A3/fr

Links

Classifications

    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V3/00—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation
    • G01V3/18—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging
    • G01V3/30—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging operating with electromagnetic waves
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01R—MEASURING ELECTRIC VARIABLES; MEASURING MAGNETIC VARIABLES
    • G01R33/00—Arrangements or instruments for measuring magnetic variables
    • G01R33/02—Measuring direction or magnitude of magnetic fields or magnetic flux
    • G01R33/035—Measuring direction or magnitude of magnetic fields or magnetic flux using superconductive devices
    • G01R33/0354—SQUIDS
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01R—MEASURING ELECTRIC VARIABLES; MEASURING MAGNETIC VARIABLES
    • G01R33/00—Arrangements or instruments for measuring magnetic variables
    • G01R33/02—Measuring direction or magnitude of magnetic fields or magnetic flux
    • G01R33/04—Measuring direction or magnitude of magnetic fields or magnetic flux using the flux-gate principle

Definitions

  • the present application relates generally to the field of electromagnetic logging, and particularly to electromagnetic (EM) logging using one or more transmitters disposed in a cased borehole and one or more receivers located on the surface.
  • EM electromagnetic
  • One technique to measure formation resistivity involves the use of electromagnetic induction via transmitters of low frequency magnetic fields that induce electrical currents in the formation. These induced electrical currents in turn produce secondary magnetic fields that can be measured by a magnetic field receiver.
  • crosswell measurements Resistivity measurements of the earth's subsurface between proximately located wellbores are known as "crosswell measurements”.
  • Various tools and methods to perform crosswell logging, and thereby obtain crosswell measurement data sets, are known in the art.
  • a crosswell data set is typically collected by moving a transmitter in one well and a receiver array in another well. Measurements of the electric and magnetic fields corresponding to various positions of the transmitter and receiver array are made. A sophisticated inversion process is necessary to interpret this data set and obtain a resistivity image of the region between the wells.
  • a typical crosswell logging system uses a transmitter that produces a large vertical magnetic moment and very sensitive receivers that are particularly sensitive to the vertical moment of the magnetic field.
  • a wireline tool designed to measure formation resistivity in cased wells
  • a logging-while-drilling (LWD) tool that sends a current across an insulated gap in the tool and into the formation
  • a production logging tool that provides for wireless telemetry between a downhole component and the surface
  • an EM telemetry tool used as an alternative to mud pulse telemetry that applies a voltage across an insulated gap in the tool to create an E-dipole source
  • E-Pulse is described in commonly owned/assigned U.S. Patent 7,477,162).
  • the present disclosure relates to borehole-to- surface (including seafloor) electromagnetic induction logging in open-hole or metallic cased wells.
  • Figures 1 and 2 are schematic views of embodiments of geometries used to make borehole-to-surface resistivity measurements, in accordance with the present disclosure.
  • Figure 3 shows a flowchart describing the steps in one embodiment of the disclosed method.
  • Figure 4 shows a block diagram of a computer system used in accordance with an embodiment.
  • Complementary measurements to crosswell logging are surface-to-borehole or borehole-to-surface measurements.
  • a source is placed at the surface and receivers downhole, or vice versa.
  • Surface-to-borehole experiments have been performed in which the source was an electric dipole (e.g., a large generator connected to two stakes driven into the earth) and the receiver was a conventional crosswell magnetic field receiver that sensed the vertical component of the resulting magnetic field.
  • Borehole-to-surface using downhole E- dipole source has been proposed in U.S. Patent Application Serial Number 12/603,053. It should be noted that measuring the vertical electric field in a cased well is fairly impractical.
  • a configuration including a single downhole transmitter source with multiple receiver stations placed either in the borehole, on the surface, or at the sea floor is more time and cost efficient for deployment during EM surveys.
  • the limitation on the downhole transmitter moment mainly arises from the design of the logging cable, the number of turns of the transmitter coil, and the magnetic permeability and size of the transmitter core. Recent advances in logging cable technology allows delivery of high power to downhole transmitters that provide downhole transmitters with large moments previously hereto not achieved.
  • the transmitter in the presently employed system has a long magnetic core that is not optimized for operating in steel cased wells.
  • the effective magnetic moment of a transmitter coil inside steel casing can be measured using receivers placed outside of and relatively close to the steel casing, as long as there are no casing collars and casing centralizers that are overlap with the transmitter coil.
  • An array of receivers placed for a magnetotelluric (MT) or Controlled Source Electro- Magnetic (CSEM) survey could also be employed for a Borehole-to-surface survey with a downhole magnetic and/or electrical dipole source.
  • MT magnetotelluric
  • CSEM Controlled Source Electro- Magnetic
  • U.S. Patent Application Serial Number 12/603,053 there are commercial tools that transmit from downhole locations to receivers at the surface.
  • the above- mentioned LWD tool transmits data collected by the tool to the surface by creating a voltage difference across an insulated section on the surface of the drill collar. This voltage is modulated in the frequency range of 0.1875 - 12 Hz to transmit data to the surface.
  • electrodes measure the voltage (generally between the wellhead and a distant electrode) and the data is demodulated.
  • the tool has downhole memory and is capable of recording the voltage and current across the gap, or otherwise makes measurements from which the voltage and current can be obtained.
  • the above-mentioned production logging tool operates on the same principal, but also has the ability to receive transmissions from the surface. It operates in the frequency range of 0.25 - 3 Hz. Both tools are designed to transmit signals from a downhole antenna having a vertical electric dipole moment.
  • the above-mentioned wireline tool used to measure formation resistivity in cased wells, operates at approximately 1 Hz.
  • vertical means substantially parallel to the longitudinal axis of the wellbore in which the transmitter is deployed.
  • Electrode sensors may include, for example, stakes driven into the ground, or alternatively, non-polarizing electrodes (for lower frequency measurements), with the voltage measured between them. That would allow the production of a map of the voltage on the surface.
  • the magnetic field could be measured with sensors similar to those used for crosswell logging or with other sorts of conventional magnetic field sensors such as fluxgate magnetometers, or SQUIDs (Superconducting Quantum Interference Devices). Since such devices do not need to withstand downhole conditions, they can be far less expensive to make and easier to procure, setup, and operate than downhole tools.
  • the above-mentioned LWD tool makes two types of measurements.
  • the signal i.e., voltage
  • the signal strength decreases. The rate of decrease is a function of the geometry of the well and also the resistivity of the formation. The more conductive the formation, the more rapidly the signal strength decreases. By monitoring the signal strength, low resolution, deep measurements of the formation resistivity are obtained.
  • the measurements can be made while the tool is being used in its normal role as an LWD telemetry tool, without additional rig time.
  • an open-hole log may be produced.
  • the downhole transmitter can be moved, either for the specific purpose of enhancing the determination of the earth formation properties, or because of the nature of the wellbore operation. It may be possible to increase the efficiency of the wellbore operation by performing some of the measurements while the transmitter is stationary and some of the measurements while the transmitter is moving.
  • Fig. 1 illustrates system 100 with a transmitter tool 102 that has been lowered into a wellbore 104 by a carrier structure 106.
  • the carrier structure 106 can be a wireline, coiled tubing, or any other carrier structure that extends from a wellhead of the wellbore 104.
  • the carrier structure 106 includes a communications medium (e.g., electrical communications medium, optical communications medium, etc.) to allow for communication between the transmitter tool 102 and surface equipment 108, as well as to deliver power to the transmitter tool 102.
  • the carrier structure 106 is preferably a high power cable, such as Nu PowerTM, as described in commonly owned U.S. Patent No. 7,586,313 and U.S. Patent No. 7,259,689, each of which is incorporated in its entirety by reference.
  • the surface equipment 108 generally includes a computer that has a processor and storage media.
  • Software is executable on the processor to perform predefined tasks.
  • the software can process measurement data received from the tool to determine formation characteristics.
  • the surface equipment 108 may be transportable, such as located in a wireline truck, or may also be located at a location remote from the wellsite.
  • data may be transferred from the wellsite to the surface equipment 108 via any of many well-known methods, including but not limited to, via satellite or wireless connection, to as simple a method as recording the data to a storage medium, and physically moving the storage medium to an off-site surface equipment computer for processing.
  • the wellbore 104 can be lined with casing 109 comprising steel having a high chromium content, or any other casing is non-magnetic and has a lower conductivity than standard casing. Casing 109 is put in place to stabilize the wellbore 104, protect fresh water formations, isolate a zone of lost returns and/or isolate formations with significantly different pressure gradients. Also disposed along the length of the wellbore 104, various collars or centralizers 110 may be deployed to, respectively, couple lengths of casing together and keep the casing 109 from contacting the wall of the wellbore 104 prior to cementing the casing 109 in place. In a typical well, wells are completed with casing segments that are approximately 30 to 40 feet long, jointed together by casing collars, and each casing segment has one or maximum two casing centralizers.
  • An array of electromagnetic sensors 112 (either electric field sensors or magnetic field sensors or a combination of the two) is deployed at a location outside of the well, at the seafloor surface 114 or at locations 116 on land or towed in shallow water.
  • twelve receivers with certain orientations are shown in Fig. 1, it is noted that in alternative implementations, any different number of receivers can be employed, from one to more than one, and at various orientations.
  • a portion of the wellbore 104 is open, that is, not yet cased.
  • the transmitter tool 102 is deployed to the desired depth of investigation, activated, and drawn back up towards the surface, as measurements are taken by the array(s) of electromagnetic sensors 112.
  • a single pass of the transmitter tool 102 through a range of depths about the depth of investigation produces a plurality of measurements from which formation characteristics can be determined.
  • FIG. 2 the system 100 of Fig. 1 with a transmitter tool 102 that has been lowered into a wellbore 104 by a carrier structure 106, with casing 109 (along with occasional casing collars and centralizers 110) extending throughout the desired depth of investigation.
  • an additional sensor is added on the seafloor as a local reference receiver station 118.
  • the location of the local reference receiver station 118 is outside, but close to, the well on the seafloor or surface, and is thus located apart from where the targeted geology in the formation.
  • the local reference receiver station 118 measures the effective transmitter moment of the transmitter tool 102 just outside the casing 109. With the known effective moment of the transmitter in casing measured this way outside the casing 109, the far field measured in the relatively remote receiver stations of the array of receivers can be normalized directly to remove the transmitter casing effect.
  • Fig. 3 a flowchart of a general method of conducting a borehole to surface electromagnetic survey is shown.
  • the method begins at 300 with deploying an array of receivers outside of a wellbore penetrating a formation. Arranging the array of receivers on the seafloor or surface is time and cost efficient comparing to towing a transmitter for downhole receivers.
  • a transmitter is moveably deployed in the wellbore penetrating the formation.
  • the transmitter comprises either an electric dipole or magnetic dipole transmitter source depending on the degree of sensitivity necessitated by the particular survey being performed.
  • the magnetic dipole transmitter inherently has a magnetic moment, which depends primarily on the design of the logging cable, the number of turns of the transmitter coil, and the magnetic permeability of the transmitter core.
  • NuPowerTM cabling technology it is possible to achieve delivery of high power to the transmitter in order to, in turn, achieve a large magnetic moment.
  • a transmitter having a core length of not more than eight (8) feet is desirable, such that the effective magnetic moment is not reduced, but the amount of usable data is increased in steel cased wells since fewer data points are affected by casing collars and casing centralizers, and will be thrown away.
  • measurements of the formation response are recorded by the array of receivers for each of the plurality of locations, in accordance with methods already described and claimed in commonly owned/assigned U.S. Patent Application Serial Number 12/603,053, herein incorporated by reference in its entirety.
  • the receiver array may be moved to another location to completely cover all of the survey area and log the transmitter again, as shown in optional step 311.
  • inversion is performed on the measurements of the formation response, allowing a determination of a formation characteristic in the area around the depth of investigation.
  • an additional sensor that of a local reference receiver station, is deployed outside the well.
  • the local reference receiver station is positioned outside the well casing on the seafloor.
  • the transmitter is activated.
  • we measure the effective magnetic moment of the transmitter at the local receiver station outside the well casing such that we know how the casing affects the magnetic moment of the transmitter in the near- field in an area where there is little to no geological formation to affect the field, so we can then later use the effective magnetic moment of the transmitter to eliminate some of the effects of casing on the formation response (measured at the array of receivers).
  • a cased-hole transmitter sonde will be used, such as a shorter version of the sonde used in Schlumberger's Deep Look EM system.
  • the cased hole transmitter is moved in the wellbore to a plurality of locations. More specifically, the transmitter is moved through the wellbore by drawing the tool upwards on the carrier structure 106 described above.
  • measurements of the formation response are recorded by the array of receivers for each of the plurality of locations, in accordance with methods already described and claimed in commonly owned/assigned U.S. Patent Application Serial Number 12/603,053, herein incorporated by reference in its entirety.
  • inversion is performed on the measurements of the formation response, allowing a determination of a formation characteristic in the area around the depth of investigation with reduced or eliminated effects due to casing, casing collars, and centralizers.
  • Fig. 4 illustrates a computer system 400 that can be used to perform tasks according to an embodiment.
  • the computer system 400 includes inversion processing software 402 that is executable on a processor 404.
  • the processor 404 is connected to storage media 406, which stores survey measurement data 408 that had been received from the various receivers.
  • the storage media 406 can be implemented with one or more disk-based storage devices or integrated circuit (IC) storage devices.
  • the computer system further includes a graphical user interface (GUI) 410 on which a graphical representation of the survey inversion can be output and represented in 2D, 3D, and even 4D.
  • GUI graphical user interface
  • processors such as processor 400 in Fig. 4
  • the processor includes microprocessors, microcontrollers, processor modules or subsystems (including one or more microprocessors or microcontrollers), or other control or computing devices.
  • a "processor” can refer to a single component or to plural components (e.g. , one or multiple central processing units in one or more computers).
  • Data and instructions (of the software) are stored in respective storage devices, which are implemented as one or more computer-readable or computer-usable storage media.
  • the storage media include different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable readonly memories (EEPROMs) and flash memories; magnetic disks such as fixed, floppy and removable disks; other magnetic media including tape; and optical media such as compact disks (CDs) or digital video disks (DVDs).
  • the source is on the surface and the receiver sensors are moved through a length of the borehole. After each transit of the downhole sensor, the source is typically moved to a new location and the process is repeated. This is very time consuming. If multiple sensor arrays are instead placed on the surface in the scale of kilometers, the transmitter only needs to be run through the well once to obtain measurements at a plurality of locations. This saves considerable valuable rig time. In addition, a more complete set of sensor positions can be obtained since the rig time does not depend upon the number of measurements. The setup time to deploy surface receivers is generally much shorter than the setup time for surface transmitters.
  • the contact resistance downhole is generally very low, large currents can be used without needing high power (i.e., low voltage may be used). If high voltage is used, it would be applied in the borehole instead of at surface transmitter locations. There is also no need to attempt or arrange to lower the contact resistance of the downhole transmitter as is often done for surface transmitter electrodes.
  • the transmitter waveform can be modified to shape the frequency or time domain content to enhance the ability to increase the signal-to-noise ratio at desired frequencies or transient times, or to otherwise optimize the transmitted energy for the desired formation imaging.

Landscapes

  • Physics & Mathematics (AREA)
  • General Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Condensed Matter Physics & Semiconductors (AREA)
  • Electromagnetism (AREA)
  • Engineering & Computer Science (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geology (AREA)
  • Remote Sensing (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geophysics (AREA)
  • Geophysics And Detection Of Objects (AREA)

Abstract

La présente invention concerne des systèmes et procédés pour mener un relevé électromagnétique trou de forage à surface d'une formation entourant un trou de sondage. De tels procédés consistent à déployer un émetteur dipôle dans le trou de forage à une profondeur de recherche, à déployer un réseau de récepteurs électromagnétiques en dehors du puits de forage, et mesurer une réponse de la formation au niveau du réseau de récepteurs électromagnétiques déployés en dehors du puits de forage, par exemple à la surface. A partir de la réponse de la formation, il est possible de déterminer une propriété de la formation sur la base de la réponse de la formation mesurée au niveau du réseau de récepteurs électromagnétiques. Pour le scénario d'un puits gainé, un récepteur de référence local peut être ajouté à un emplacement à proximité du trou de forage pour mesurer le couple magnétique efficace de l'émetteur à l'intérieur du gainage et normaliser la réponse de la formation afin d'obtenir une détermination plus précise d'une caractéristique de la formation, telle que la résistivité. On peut également utiliser ces récepteurs pour d'autres types de relevés.
PCT/US2010/050338 2009-10-02 2010-09-27 Diagraphie électromagnétique entre un trou de forage gainé et la surface WO2011041248A2 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
EP10821075.8A EP2483715A4 (fr) 2009-10-02 2010-09-27 Diagraphie électromagnétique entre un trou de forage gainé et la surface
CN201080053535.5A CN102667530B (zh) 2009-10-02 2010-09-27 加套管井眼和表面之间的电磁测井

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US24816209P 2009-10-02 2009-10-02
US61/248,162 2009-10-02
US12/705,816 2010-02-15
US12/705,816 US8155980B2 (en) 2006-02-14 2010-02-15 Systems and methods for managing medical data

Publications (2)

Publication Number Publication Date
WO2011041248A2 true WO2011041248A2 (fr) 2011-04-07
WO2011041248A3 WO2011041248A3 (fr) 2011-08-18

Family

ID=43826843

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2010/050338 WO2011041248A2 (fr) 2009-10-02 2010-09-27 Diagraphie électromagnétique entre un trou de forage gainé et la surface

Country Status (3)

Country Link
EP (1) EP2483715A4 (fr)
CN (1) CN102667530B (fr)
WO (1) WO2011041248A2 (fr)

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
RU2475644C1 (ru) * 2011-07-15 2013-02-20 Государственное образовательное учреждение высшего профессионального образования "Омский государственный университет им. Ф.М. Достоевского" Способ передачи и приема информации с забоя скважины на поверхность по электромагнитному каналу связи по породе с использованием сквид-магнитометра
WO2018071658A1 (fr) * 2016-10-13 2018-04-19 Groundmetrics, Inc. Cartographie d'intégrité de puits de forage à l'aide d'électrodes de tubage de puits et de champs électromagnétiques de surface
WO2018164884A1 (fr) * 2017-03-06 2018-09-13 Saudi Arabian Oil Company Traitement informatique de données de relevé avec un émetteur électromagnétique entre le trou de forage et la surface
US10145975B2 (en) 2011-04-20 2018-12-04 Saudi Arabian Oil Company Computer processing of borehole to surface electromagnetic transmitter survey data

Families Citing this family (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN104453847B (zh) * 2013-09-13 2023-09-19 中国石油集团长城钻探工程有限公司 三维阵列感应仪器的刻度器系统
CN107725025B (zh) * 2016-08-10 2023-10-20 中国石油化工股份有限公司 多功能井筒检测装置及检测方法
US10705240B2 (en) 2017-05-11 2020-07-07 Saudi Arabian Oil Company Capacitive electromagnetic formation surveillance using passive source
US11035972B2 (en) 2019-05-13 2021-06-15 Saudi Arabian Oil Company Systems and methods for electromagnetic waterfront surveillance in a vicinity of an oil well
US11346177B2 (en) 2019-12-04 2022-05-31 Saudi Arabian Oil Company Repairable seal assemblies for oil and gas applications

Family Cites Families (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4009609A (en) * 1975-08-15 1977-03-01 Sayer Wayne L Method and apparatus for testing a subsurface formation for fluid retention potential
US6219619B1 (en) * 1999-03-08 2001-04-17 Baker Hughes Incorporated Inhomogeneous background-based software focusing method for array-type induction logging tools
US6294917B1 (en) * 1999-09-13 2001-09-25 Electromagnetic Instruments, Inc. Electromagnetic induction method and apparatus for the measurement of the electrical resistivity of geologic formations surrounding boreholes cased with a conductive liner
US7495446B2 (en) * 2005-08-23 2009-02-24 Schlumberger Technology Corporation Formation evaluation system and method
US7888940B2 (en) * 2007-02-19 2011-02-15 Schlumberger Technology Corporation Induction resistivity cover
US7991553B2 (en) * 2007-06-27 2011-08-02 Schlumberger Technology Corporation Method and system for removing effects of conductive casings and wellbore and surface heterogeneity in electromagnetic imaging surveys
US8744817B2 (en) * 2007-12-21 2014-06-03 Schlumberger Technology Corporation Method for upscaling a reservoir model using deep reading measurements

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10145975B2 (en) 2011-04-20 2018-12-04 Saudi Arabian Oil Company Computer processing of borehole to surface electromagnetic transmitter survey data
RU2475644C1 (ru) * 2011-07-15 2013-02-20 Государственное образовательное учреждение высшего профессионального образования "Омский государственный университет им. Ф.М. Достоевского" Способ передачи и приема информации с забоя скважины на поверхность по электромагнитному каналу связи по породе с использованием сквид-магнитометра
WO2018071658A1 (fr) * 2016-10-13 2018-04-19 Groundmetrics, Inc. Cartographie d'intégrité de puits de forage à l'aide d'électrodes de tubage de puits et de champs électromagnétiques de surface
WO2018164884A1 (fr) * 2017-03-06 2018-09-13 Saudi Arabian Oil Company Traitement informatique de données de relevé avec un émetteur électromagnétique entre le trou de forage et la surface

Also Published As

Publication number Publication date
EP2483715A4 (fr) 2017-11-08
CN102667530A (zh) 2012-09-12
EP2483715A2 (fr) 2012-08-08
WO2011041248A3 (fr) 2011-08-18
CN102667530B (zh) 2014-12-10

Similar Documents

Publication Publication Date Title
US9035657B2 (en) Electromagnetic logging between a cased borehole and surface
US8638103B2 (en) Electromagnetic logging between borehole and surface
WO2011041248A2 (fr) Diagraphie électromagnétique entre un trou de forage gainé et la surface
CA2959346C (fr) Telemetrie electromagnetique pour la mesure et la diagraphie en cours de forage et la telemetrie magnetique entre des puits de forage
US8188749B2 (en) Removing effects of near surface geology from surface-to-borehole electromagnetic data
US6670813B2 (en) Integrated borehole system for reservoir detection and monitoring
US6534986B2 (en) Permanently emplaced electromagnetic system and method for measuring formation resistivity adjacent to and between wells
US7663372B2 (en) Resistivity tools with collocated antennas
US20100271030A1 (en) Borehole Transient EM System for Reservoir Monitoring
US7228903B2 (en) Apparatus and method for wireline imaging in nonconductive muds
US20050001624A1 (en) Apparatus and method for resistivity measurements during rotational drilling
US10024995B2 (en) System and method for elevated source to borehole electromagnetic survey
US20120130641A1 (en) Marine Source To Borehole Electromagnetic Mapping Of Sub-Bottom Electrical Resistivity
US8901931B2 (en) Electromagnetic surface-to-borehole look around systems and methods of monitoring in horizontal wells
US9765614B2 (en) Wireless communication and telemetry for completions
US10227868B2 (en) Electromagnetic telemetry using capacitive surface electrodes
GB2382143A (en) A method for telemetering data between wellbores
US10459110B2 (en) Flexible conductive shield for downhole electromagnetic noise suppression

Legal Events

Date Code Title Description
WWE Wipo information: entry into national phase

Ref document number: 201080053535.5

Country of ref document: CN

121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 10821075

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase in:

Ref country code: DE

WWE Wipo information: entry into national phase

Ref document number: 2010821075

Country of ref document: EP