EP1936113B1 - 2D-Bohrlochprüfung mit Smart-Plug-Sensoren - Google Patents

2D-Bohrlochprüfung mit Smart-Plug-Sensoren Download PDF

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Publication number
EP1936113B1
EP1936113B1 EP06126833A EP06126833A EP1936113B1 EP 1936113 B1 EP1936113 B1 EP 1936113B1 EP 06126833 A EP06126833 A EP 06126833A EP 06126833 A EP06126833 A EP 06126833A EP 1936113 B1 EP1936113 B1 EP 1936113B1
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EP
European Patent Office
Prior art keywords
formation
tool
wellbore
sensors
pressure
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.)
Not-in-force
Application number
EP06126833A
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English (en)
French (fr)
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EP1936113A1 (de
Inventor
Yves c/o Etudes et Prod. Schlumberger SA MANIN
Christian c/o Schlumberger SA CHOUZENOUX
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Services Petroliers Schlumberger SA
Prad Research and Development NV
Schlumberger Technology BV
Schlumberger Holdings Ltd
Original Assignee
Services Petroliers Schlumberger SA
Prad Research and Development NV
Schlumberger Technology BV
Schlumberger Holdings Ltd
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 Services Petroliers Schlumberger SA, Prad Research and Development NV, Schlumberger Technology BV, Schlumberger Holdings Ltd filed Critical Services Petroliers Schlumberger SA
Priority to DE602006010226T priority Critical patent/DE602006010226D1/de
Priority to EP06126833A priority patent/EP1936113B1/de
Priority to AT06126833T priority patent/ATE447661T1/de
Priority to CA2612357A priority patent/CA2612357C/en
Priority to US11/957,585 priority patent/US20090020283A1/en
Priority to RU2007147655/03A priority patent/RU2450123C2/ru
Publication of EP1936113A1 publication Critical patent/EP1936113A1/de
Application granted granted Critical
Publication of EP1936113B1 publication Critical patent/EP1936113B1/de
Not-in-force legal-status Critical Current
Anticipated expiration legal-status Critical

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Classifications

    • 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
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • E21B49/008—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor
    • 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
    • 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
    • E21B47/14—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 using acoustic waves

Definitions

  • This invention relates to an apparatus for characterising the permeability of a formation surrounding a borehole well.
  • permeability is determined by measuring the formation and borehole pressure in oil, gas or similar wells.
  • a well test is usually performed to characterise the formation surrounding the borehole. Properties such as skin, permeability, porosity of a reservoir, and production capacity are some the properties used to characterise the formations. Knowing how fluids flow through a reservoir is important for managing hydrocarbons reserves. Fluid flow is governed by the permeability of the formations.
  • a conventional well test can determine formation properties from pressure measurements obtained by a drillstem test (DST) tool as shown in Figure 1 .
  • DST drillstem test
  • transient well test conditions are applied to the well and the pressure below a tester valve is measured. The valve is shut off causing a pressure build up which is recorded. This build up is interpreted and can lead to the determination of a series of well/formation parameters such as: skin, permeability, reservoir pressure and distances to boundaries.
  • formations are not homogenous in quality and will have layering features.
  • the results obtained in terms of reservoir properties from testing the whole thickness, h is representative of some average of the individual layer permeability which is not really useful to a reservoir engineer for assessing the potential of the well or the field under evaluation.
  • US6693553 describes deploying sensors into the formations as the wellbore is being drilled. An antenna that can communicate with the sensor is located on the downhole tool.
  • US6070662 describes deploying sensors into the formations and placing an antenna in the casing to communicate with the sensor.
  • WO2006/026311 discloses the preamble of claim 1, and describes a method of estimating permeability of a formation using a single probe having a flow rate and pressure sensors to make measurements to determine the vertical and horizontal permeabilities of the formation.
  • US4890487 also described using a single probe inserted into the formation for making pressure and flow measurements to determine the permeability of the formation.
  • US5265015 discloses determining vertical and horizontal permeabilities using a single probe. Measurements are made with two orientations of the probe, one with the axis of elongation parallel vertical and with the axis of elongation horizontal.
  • WO2006008172 describes a method for estimating the permeability distribution of a formation surrounding a borehole.
  • An acoustic emitter located either on the surface in the borehole excites a portion of the formation with an acoustic signal.
  • An acoustic receiver located within the borehole measures the acoustic response. This acoustic response can be used to assess a formation pressure from which the permeability of the formation can be estimated. Conventional well test pressure measurements can also be taken to estimate the permeability of the formation.
  • the object of the invention to provide an apparatus to characterise the permeability of the formation around a borehole.
  • the invention proposes an apparatus and method for characterising the permeability of the formation in two dimensions, horizontally and vertically, by directly measuring both the borehole pressure and formation pressure.
  • a first aspect of the invention comprises an apparatus for characterising the permeability of a formation surrounding a wellbore, comprising; a drillstem test (DST) tool comprising, a pressure gauge for detecting the pressure in the well bore, a valve for controlling fluid into and out of the zone via the drill string of the tool and a packer for isolating a zone of the wellbore; wherein the apparatus further comprises an array of at least two antennas arranged on the tool above the packer such that when in use each antenna of the array aligns with a corresponding pressure sensor placed in the formation to obtain pressure measurements and therefore allow horizontal and vertical permeability to be determined.
  • DST drillstem test
  • the distance between each individual antenna of the array is determined by the placement of the sensors in the formation. Differing lengths of pipes making up the drill string can be used to alter the distance between the individual antennas.
  • the apparatus can further comprise an interrogating tool.
  • the tool scans the array of antennas so that data obtained from each antenna is transmitted to the interrogating tool which conveys the information up to the surface.
  • the array of antenna is mounted on the outside of the DST tool.
  • the antennas can transmit and receive information from the sensors by wireless communication.
  • the interrogating tool can also be used to transfer power to the sensors via the antennas.
  • the wireless communication and the transfer of power can be based on electromagnetic coupling or acoustic transmission.
  • a second aspect of the invention is a sensor system for characterising the permeability of a formation surrounding a wellbore in two dimensions, comprising: at least two sensors installed in the formation surrounding the wellbore; and an apparatus comprising, a drillstem test (DST) tool comprising, a packer for isolating a zone of the wellbore, a pressure gauge for detecting the pressure in the wellbore, a valve for controlling fluid into and out of the zone via the drill string of the tool, and an array of at least two antennas arranged on the DST tool above the packer such that each antenna of the array aligns with a corresponding pressure sensor in the formation.
  • DST drillstem test
  • a third aspect of the invention comprises a method for characterising the permeability of a formation surrounding a wellbore, comprising:
  • the spacing between the sensors is recorded as the sensors are inserted into the formation.
  • Preferably method further comprises positioning the antennas along the DST tool so that the spacing between the antennas is equal to the spacing between the sensors in the formation, before inserting the tool body down the wellbore.
  • the method can further comprise scanning the array of antennas with an interrogating tool to transfer the information from the antenna to the tool and to power the sensors.
  • the information from the interrogating tool is sent up-hole for surface recording and further analysis.
  • Preferably transmitting the data between the sensors and antenna is done by wireless mode. This can be electro-magnetic coupling or acoustic transmission.
  • the method is preformed using the system described above.
  • Figure 1 shows a conventional drillstem test tool arrangement.
  • Figure 2 shows a schematic of a two dimensional well test tool arrangement.
  • Figure 3 shows a schematic of a sensor plug used to detect the pressure in the formation.
  • Figure 4 shows an arrangement for data transmission between the sensor and array of antennas.
  • Figure 5 shows a schematic of the test well arrangement used to carry out the example.
  • Figure 6 shows the results of the wellbore and layers pressure responses of the test well.
  • a conventional drill stem test tool 1 for measuring the wellbore pressure comprises a pressure gauge 2, a packer 3 and a tester valve 4.
  • the DST tool 1 is lowered down into a wellbore 5.
  • the packer 3 is inflated to isolate the zone of interest, h, of the wellbore.
  • the valve 4 is initially open and fluid can flow into the drillstring of the DST tool.
  • the valve 4 is then closed to stop the fluid flow through the wellbore.
  • a build up occurs below the valve 4, and the pressure is monitored as a function of time.
  • the permeability of the reservoir is then estimated from the well test measurement.
  • the whole thickness, h, of the formation zone tested is often not homogenous in quality but instead comprises layering features, with separate layers of medium quality sands 6 and layers very good quality sands 7, surrounding the wellbore the result obtained merely indicates an average of the zone and does not characterise each individual layer component that may be present in the reservoir.
  • This conventional test only provides a one dimensional horizontal characterisation of the permeability of the formation.
  • the DST tool 26 comprises an array of antennas 21 located on the outside of the drill string of the tool, a pressure gauge 23, a valve 27 and packer 28.
  • Each of the antennas 21 comprising the array are spaced apart to line up with a pressure sensor 24 in the formation 25 to receive data from the sensor.
  • the pressure gauge 23 measures the pressure in the wellbore 22 in the perforated interval, h1, as for a conventional DST well test.
  • the spacing between the pressure sensors 24 is recorded as the sensors are inserted into the formation at predetermined depths such that the spacing between each of the sensors 24 relative to each other is known.
  • the distance between the sensors is recorded by differential measurements between the depths at which each sensor is inserted into the formation. This information is used to ensure that the antennas in the array are correctly spaced apart when preparing the tool for inserting down the wellbore so that the spacing between antennas on the array will be equal to the spacing between the sensors.
  • These sensors 24, located at different depths of the formation record the pressure within the formation at each of their locations. The data obtained from these measurements at different depths allows for the permeability of the formation to be characterised along the wellbore axis.
  • an example of a sensor plug 31, that can be inserted in the formation comprises a sensing element 32, an electronics platform 33 inside a protective housing and a communication element 34.
  • the sensing element 32 senses the pressure in the formation and the communication element 34, such as an antenna, enables data to be received and transmitted from the sensor.
  • the antenna transmits the pressure data recorded by the sensing element 32 to an antenna outside the formation located on tool placed down the wellbore.
  • the power supply for electronics platform 33 is provided by embedded batteries or directly by antenna 34. To supply power via the antenna 34, the power is transferred from the tool antenna towards antenna 34 by electro-magnetic coupling between the two antennae. Rechargeable batteries can be used and recharged from the tool antenna.
  • Energy harvesting techniques can also be used to collect energy available at the reservoir level. Vibrations induced by the downhole flow can be collected by electro-acoustic sensors and converted to electrical energy to supply the sensor electronics or recharge the battery cells. Further details of suitable sensors can be found in WO2006/005555 .
  • each sensor 41 aligns with an antenna 42 of the array.
  • the sensors 41 are inserted into the formation 44 through the casing 45 of the wellbore 46.
  • the spacing of the sensors 41 is recorded during their insertion into the formation 44.
  • the sensors 41 are installed in a hole through the casing so that the sensor extends between the inside and outside of the casing 45, with the sensing elements in the formation 44 surrounding the well and the communication antenna of the sensor able to communicate with the antennas in the well.
  • An array of antennas 42 and its associated interrogating tool 47 are mounted on the outside of the drillstring 48 of the DST tool.
  • the antennas 42 are positioned along the drillstring 48 so that their spacing is equal to the spacing between each sensor 41.
  • the distance between each antenna 42 can be adjusted with pipes of various lengths.
  • the drillstring 48 is inserted down into the wellbore 46 until the array of antennas 42 is proximate to the sensor 41.
  • antenna coupling 49 occurs between the antenna 42 of the array located on the drillstring 48 and the antenna of the sensor 41.
  • the sensors 41 may comprise a radioactive marker, such as a gamma ray pip-tag that allows their location in the wellbore to be sensed by the DST tool.
  • Data is transmitted from the antenna in the sensor 41 to its corresponding antenna 42 mounted on the outside of the drillstring 48 of the DST tool by wireless communication such as by electro-magnetic coupling or acoustic transmission.
  • the interrogating tool 47 scans the array of antennas 42 and all the data acquired by each antenna 42 is transferred to the interrogating tool 47. This allows the data to be sent up-hole for surface recording and further analysis.
  • a vertical test well penetrating a three layer formation as shown in Figure 5 is constructed and pressure measurements are taken using the apparatus and method of the invention.
  • the welltest consists of flowing layer 3 at 318m 3 /day (2000 bl/d) for 24 hours followed by 48 hours of build up.
  • the pressure response is recorded at the wellbore by gauge 53 and within the formation layers 1 and 2 by monitoring gauges 51 and 52 respectively.
  • Table 1 An analytic model is built to have the characteristics shown in Table 1.
  • Table 1 Forward model values of test well Layer # Thickness (m) k h (mD) k z (mD) Skin 1 10.6 (35ft) 70 10 - 2 6.1 (20ft) 35 4 - 3 15.2 (50ft) 150 20 0.5
  • the model is first run in a forward mode to simulate the pressure responses in the well bore and at the two monitoring gauges. The results are shown in Figure 6 .

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  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Remote Sensing (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geophysics (AREA)
  • Chemical & Material Sciences (AREA)
  • Acoustics & Sound (AREA)
  • Analytical Chemistry (AREA)
  • Electromagnetism (AREA)
  • Measuring Fluid Pressure (AREA)
  • Geophysics And Detection Of Objects (AREA)
  • Measuring And Recording Apparatus For Diagnosis (AREA)
  • Coupling Device And Connection With Printed Circuit (AREA)
  • Arrangements For Transmission Of Measured Signals (AREA)

Claims (14)

  1. Vorrichtung zum Kennzeichnen der horizontalen und der vertikalen Permeabilität einer ein Bohrloch (22) umgebenden Formation (25), die umfasst:
    ein Bohrschafttest-Werkzeug (DST-Werkzeug) (26), das einen Einfachschieber (28) zum Isolieren einer Zone des Bohrlochs (22), ein Ventil (27) zum Steuern von Fluid in die und aus der Zone durch den Bohrstrang des Werkzeugs (26) und einen Druckmesser (23) zum Erfassen des Drucks in der Zone enthält;
    dadurch gekennzeichnet, dass die Vorrichtung ferner eine Anordnung aus wenigstens zwei Antennen (21) umfasst, die am Werkzeug (26) über dem Einfachschieber angeordnet ist, derart, dass sich im Gebrauch jede Antenne (21) der Anordnung auf einen entsprechenden Drucksensor (24) ausrichtet, der in der Formation (25) angeordnet ist, um Druckmessungen zu erhalten und um dadurch die Bestimmung der horizontalen und der vertikalen Permeabilität zu ermöglichen.
  2. Vorrichtung nach Anspruch 1, wobei der Abstand zwischen jeder einzelnen Antenne (21) der Anordnung durch die Positionierung der Sensoren (24) in der Formation bestimmt ist.
  3. Vorrichtung nach einem der Ansprüche 1 oder 2, die ferner ein Abfragewerkzeug (47) umfasst, das die Anordnung von Antennen (21) abtasten kann, um die Informationen zur Oberfläche zu übermitteln.
  4. Vorrichtung nach einem der Ansprüche 1, 2 oder 3, wobei die Antennenanordnung (21) an der Außenseite des DST-Werkzeugs (26) montiert ist.
  5. Vorrichtung nach einem der Ansprüche 1-4, wobei die Antennen (21) Informationen von den Sensoren durch drahtlose Kommunikation senden und empfangen können und Leistung an die Sensoren (24) übertragen können.
  6. Vorrichtung nach Anspruch 5, wobei die drahtlose Kommunikation und die Leistungsübertragung auf einer elektromagnetischen Kopplung oder auf einer Schallübertragung beruhen.
  7. Sensorsystem für die Kennzeichnung der Permeabilität einer ein Bohrloch (22) umgebenden Formation (25) in zwei Dimensionen, das umfasst:
    wenigstens zwei Sensoren (24) in der das Bohrloch (22) umgebenden Formation (25); und eine Vorrichtung nach einem der Ansprüche 1-6.
  8. Verfahren zum Kennzeichnen der horizontalen und der vertikalen Permeabilität einer ein Bohrloch (22) umgebenden Formation (25), das umfasst:
    Einsetzen von Sensoren (24) in die das Bohrloch (22) umgebende Formation (25) auf verschiedenen Tiefen;
    Einsetzen einer Vorrichtung nach einem der Ansprüche 1-6 in das Bohrloch (22);
    Isolieren einer Zone des Bohrlochs (22);
    Ändern des Drucks in der Zone durch Verändern der Strömung durch das Ventil (27);
    Messen des Drucks der Formation (25) am Ort jedes Sensors (24) und Senden der erhaltenen Daten zu der Antennenanordnung (21);
    Messen des Drucks in der Zone mit dem Druckmesser (23); und
    Bestimmen der horizontalen und der vertikalen Permeabilität der Formation (25) unter Verwendung der erhaltenen Druckmessungen.
  9. Verfahren nach Anspruch 8, das ein Aufzeichnen des Abstandes zwischen den Sensoren (24) umfasst, wenn die Sensoren in die Formation (25) eingesetzt werden.
  10. Verfahren nach einem der Ansprüche 8 oder 9, das ein Positionieren der Antennen (21) längs des DST-Werkzeugs (26) umfasst, derart, dass der Abstand zwischen den Antennen (21) gleich dem Abstand zwischen den Sensoren (24) in der Formation (25) ist, bevor das DST-Werkzeug (26) in das Bohrloch (22) eingesetzt wird.
  11. Verfahren nach einem der Ansprüche 8, 9 oder 10, das ein Abtasten der Antennenanordnung (21) mit einem Abfragewerkzeug (47) umfasst, um die Sensoren (24) mit Leistung zu versorgen und um die Informationen von den Antennen (21) an das Werkzeug (47) zu übertragen.
  12. Verfahren nach Anspruch 11, das ein Senden der Informationen von dem Abfragewerkzeug (47) im Bohrloch aufwärts für eine Aufzeichnung und eine weitere Analyse an der Oberfläche umfasst.
  13. Verfahren nach einem der Ansprüche 8-12, wenn das Senden der Daten zwischen den Sensoren (24) und der Antenne (21) in einer drahtlosen Betriebsart erfolgt.
  14. Verfahren nach einem der Ansprüche 8-13, wenn es unter Verwendung des Systems nach Anspruch 7 ausgeführt wird.
EP06126833A 2006-12-21 2006-12-21 2D-Bohrlochprüfung mit Smart-Plug-Sensoren Not-in-force EP1936113B1 (de)

Priority Applications (6)

Application Number Priority Date Filing Date Title
DE602006010226T DE602006010226D1 (de) 2006-12-21 2006-12-21 2D-Bohrlochprüfung mit Smart-Plug-Sensoren
EP06126833A EP1936113B1 (de) 2006-12-21 2006-12-21 2D-Bohrlochprüfung mit Smart-Plug-Sensoren
AT06126833T ATE447661T1 (de) 2006-12-21 2006-12-21 2d-bohrlochprüfung mit smart-plug-sensoren
CA2612357A CA2612357C (en) 2006-12-21 2007-11-26 2d well testing with smart plug sensors
US11/957,585 US20090020283A1 (en) 2006-12-21 2007-12-17 2D Well Testing with Smart Plug Sensor
RU2007147655/03A RU2450123C2 (ru) 2006-12-21 2007-12-20 Испытание скважин в двух измерениях интеллектуальным датчиком-вставкой

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP06126833A EP1936113B1 (de) 2006-12-21 2006-12-21 2D-Bohrlochprüfung mit Smart-Plug-Sensoren

Publications (2)

Publication Number Publication Date
EP1936113A1 EP1936113A1 (de) 2008-06-25
EP1936113B1 true EP1936113B1 (de) 2009-11-04

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EP06126833A Not-in-force EP1936113B1 (de) 2006-12-21 2006-12-21 2D-Bohrlochprüfung mit Smart-Plug-Sensoren

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Country Link
US (1) US20090020283A1 (de)
EP (1) EP1936113B1 (de)
AT (1) ATE447661T1 (de)
CA (1) CA2612357C (de)
DE (1) DE602006010226D1 (de)
RU (1) RU2450123C2 (de)

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AU2008329140B2 (en) * 2007-11-30 2015-11-12 Schlumberger Technology B.V. Downhole, single trip, multi-zone testing system and downhole testing method using such
WO2011163602A2 (en) * 2010-06-24 2011-12-29 Schlumberger Canada Limited Systems and methods for collecting one or more measurements in a borehole
CN101963056B (zh) * 2010-08-19 2014-04-09 中国石油大学(北京) 一种利用测井资料预测碳酸盐岩地层孔隙压力的方法
US20130319102A1 (en) * 2012-06-05 2013-12-05 Halliburton Energy Services, Inc. Downhole Tools and Oil Field Tubulars having Internal Sensors for Wireless External Communication
WO2015178883A1 (en) * 2014-05-19 2015-11-26 Halliburton Energy Services, Inc. Nuclear magnetic resonance sensors embedded in cement
GB2557752B (en) * 2015-09-09 2021-03-31 Halliburton Energy Services Inc Methods to image acoustic sources in wellbores
CN110824580B (zh) * 2019-11-27 2024-06-04 中国电建集团贵阳勘测设计研究院有限公司 一种斜孔孔间模型物探试验装置
CN111594158A (zh) * 2020-06-11 2020-08-28 中国石油集团渤海钻探工程有限公司 套管井分层排液测试工艺管柱及测试方法
CN116163720B (zh) * 2022-09-07 2025-10-17 中海石油(中国)有限公司 一种声波与电磁探头共置的套后储层在线监测方法和系统
EP4623184A1 (de) * 2022-11-22 2025-10-01 Shell Internationale Research Maatschappij B.V. Verfahren zur installation eines permanenten bohrlochsensors

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Publication number Publication date
CA2612357A1 (en) 2008-06-21
CA2612357C (en) 2015-08-04
EP1936113A1 (de) 2008-06-25
US20090020283A1 (en) 2009-01-22
ATE447661T1 (de) 2009-11-15
DE602006010226D1 (de) 2009-12-17
RU2007147655A (ru) 2009-06-27
RU2450123C2 (ru) 2012-05-10

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