EP2985408A1 - Vorrichtung und Verfahren zur Bohrlochzementierung - Google Patents

Vorrichtung und Verfahren zur Bohrlochzementierung Download PDF

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Publication number
EP2985408A1
EP2985408A1 EP14290249.3A EP14290249A EP2985408A1 EP 2985408 A1 EP2985408 A1 EP 2985408A1 EP 14290249 A EP14290249 A EP 14290249A EP 2985408 A1 EP2985408 A1 EP 2985408A1
Authority
EP
European Patent Office
Prior art keywords
telemetry system
downhole
pressure
data
tubular body
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.)
Withdrawn
Application number
EP14290249.3A
Other languages
English (en)
French (fr)
Inventor
Simon Gareth James
Viktor Balogh
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
Schlumberger Technology BV
Schlumberger Holdings Ltd
Original Assignee
Services Petroliers Schlumberger SA
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, Schlumberger Technology BV, Schlumberger Holdings Ltd filed Critical Services Petroliers Schlumberger SA
Priority to EP14290249.3A priority Critical patent/EP2985408A1/de
Publication of EP2985408A1 publication Critical patent/EP2985408A1/de
Withdrawn legal-status Critical Current

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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
    • 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
    • E21B47/18—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 through the well fluid, e.g. mud pressure pulse telemetry
    • 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
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
    • 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
    • E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions

Definitions

  • the present disclosure broadly relates to systems and methods for controlling annular fluid pressures in a subterranean well during cementing operations.
  • Managed pressure drilling is a general oilfield term that refers to techniques for achieving improved control of annular fluid pressures.
  • BHP bottomhole pressure
  • MPD minimizes BHP fluctuations by intervening at different points, including varying the backpressure applied to the annulus, changing the hydrostatic pressure of the fluid column and adjusting the mud pump rate.
  • MPD techniques allow operators to drill through formations in which the pore-and fracture pressures are very close, or in deviated sections in which, to maintain wellbore stability, annular pressures may be very close to fracture pressures. Additionally, MPD may be used to drill underbalanced or "at balance.” Other benefits of the MPD technique may include increased rate of penetration (ROP) and earlier kick detection.
  • ROP rate of penetration
  • MPD is often complemented by a technique called pressure-while-drilling (PWD).
  • PWD comprises attaching a tool to the bottomhole assembly (BHA) that is capable of measuring annular fluid pressure and transmitting the data to the surface using available telemetry. This reduces uncertainties related to BHP values, which are normally estimated or simulated from surface-pressure data, pump rates, wellbore-fluid density and rheological properties.
  • the present disclosure reveals apparatuses and methods by which downhole pressures may be controlled during cementing operations.
  • embodiments relate to apparatuses.
  • One embodiment comprises at least one pressure sensor that is attached to a tubular body, a downhole telemetry system capable of transmitting data to a surface location and receiving data from the surface location, a surface telemetry system capable of receiving data from the downhole telemetry system and transmitting data to the downhole telemetry system, and a managed pressure drilling interface capable of receiving data from the surface telemetry system and transmitting data to the surface telemetry system.
  • embodiments relate to methods for cementing a subterranean well having a borehole.
  • At least one pressure sensor is attached to a tubular body, and the tubular body is lowered into the borehole.
  • a downhole telemetry system is installed in the wellbore that is capable of transmitting data to a surface location and receiving data from the surface location.
  • a surface telemetry system is installed that is capable of receiving data from the downhole telemetry system and transmitting data to the downhole telemetry system.
  • a managed pressure drilling system is installed that is capable of receiving data from the surface telemetry system and transmitting data to the surface telemetry system.
  • a pumpable and settable sealant is prepared and then placed into the well.
  • Figure 1 shows a diagram of the disclosed apparatus.
  • a range of from 1 to 10 is to be read as indicating each possible number along the continuum between about 1 and about 10.
  • a certain range is expressed, even if a few specific data points are explicitly identified or referred to within the range, or even when no data points are referred to within the range, it is to be understood that the Applicants appreciate and understand that any data points within the range are to be considered to have been specified, and that the Applicants have possession of the entire range points within the range.
  • the tubular body may be any string of tubulars that may be run into the wellbore and at least partially cemented in place. Examples include casing, liner, solid expandable tubular, production tubing, coiled tubing and drill pipe.
  • embodiments relate to apparatuses.
  • One embodiment comprises at least one pressure sensor that is attached to a tubular body, a downhole telemetry system capable of transmitting data to a surface location and receiving data from the surface location, a surface telemetry system capable of receiving data from the downhole telemetry system and transmitting data to the downhole telemetry system, and a managed pressure drilling interface capable of receiving data from the surface telemetry system and transmitting data to the surface telemetry system.
  • embodiments relate to methods for cementing a subterranean well having a borehole and a downhole pressure.
  • At least one pressure sensor is attached to a tubular body, and the tubular body is lowered into the borehole.
  • a downhole telemetry system is installed in the wellbore that is capable of transmitting data to a surface location and receiving data from the surface location.
  • a surface telemetry system is installed that is capable of receiving data from the downhole telemetry system and transmitting data to the downhole telemetry system.
  • a managed pressure drilling system is installed that is capable of receiving data from the surface telemetry system and transmitting data to the surface telemetry system.
  • a pumpable and settable sealant is prepared and then placed into the well.
  • the viscosity of the sealant during placement may be lower than 1000 cP at a shear rate of 100 s -1 .
  • the sealant composition may comprise inorganic materials including portland cement, calcium aluminate cement, fly ash, blast furnace slag, lime/silica blends, zeolites, magnesium oxychloride, geopolymers or chemically bonded phosphate ceramics or combinations thereof.
  • the sealant composition may comprise organic materials including epoxy resins, furan resins, polyester resins or vinyl ester resins or combinations thereof.
  • a first component of the apparatus is a pressure sensor 101 that is attached to the tubular body at a certain depth, prior to running in the borehole.
  • the sensor may measure the downhole pressure along the outside of the tubular body (i.e., in the annular region between the tubular body and the borehole wall). Pressure measurements may be performed anytime during the period that the sensor spends in the well, including the following operations: running the tubular body, pre-job circulation, cement placement, post-job circulation, tubular expansion, waiting-on-cement (WOC) time and static periods in between.
  • the pressure sensor may be attached to a memory device 105 that allows pressure measurements to be recorded even when data transmission is not possible (e.g., when mud pulse telemetry is the communication mechanism and the fluid is not being circulated).
  • the depth to which the sensor 101 is run may be selected according to adjacent geological parameters, tubular body properties, operational factors or other considerations. Multiple sensors may be placed along the tubular body string to allow measurements at several depths.
  • a second component of the apparatus is a downhole telemetry system 102 that transfers measured data to the surface.
  • Annular mud pulse telemetry may be employed to send the data.
  • the technique performs the required encoding and manages other aspects of communication with the surface. It is also capable of responding to commands from surface components, known as downlinking. Downlinked commands may be related to flow control and settings of the signal processing unit.
  • Annular mud pulse telemetry may be complemented or replaced, if environmental and operating conditions permit, by other forms of telemetry including tubular mud pulse, guided electromagnetic waves and wired pipe.
  • the downhole telemetry system may further comprise a signal processing unit that may perform functions including filtering, averaging and compressing data.
  • a memory device 105 may be integrated into the downhole telemetry system.
  • the device may be used for buffering, may serve as the operational memory for the signal processing unit and may perform continuous data recording.
  • the memory device may be deployed such that memory device itself, or the recorded content, may be retrieved-even after the rest of the downhole components are cemented in place. The retrieval may be performed by ordinary well intervention techniques.
  • multiple downhole telemetry operations may be run on the same string. If annular mud pulse telemetry is used and the sensor is exposed to the annulus, the telemetry unit may be placed at the bottom of the tubular body with transducers connected to the unit.
  • Sensors that measure parameters other than pressure are included in the present disclosure, for example temperature sensors, chemical sensors, acoustic sensors, strain gauges. electrical conductivity sensors and other devices known in the art. Such devices may allow operators to monitor the properties of downhole fluids.
  • a third component of the apparatus is a surface telemetry system 103.
  • the surface telemetry system receives data sent from the downhole telemetry system 102, decodes it and sends it to a managed pressure drilling (MPD) interface 104.
  • MPD managed pressure drilling
  • the equipment is installed in the well annulus.
  • MPD intervention points e.g., chokes, subsea pumps, etc.
  • the appropriate sensors may be installed according to normal practice provided they do not interfere with MPD operations.
  • the surface telemetry system may be able to send downlink commands to the downhole telemetry system and may communicate with more than one downhole telemetry sensor.
  • a fourth component of the apparatus is a managed pressure drilling (MPD) interface 104.
  • a first function of the MPD interface is to act as a physical connection between the surface telemetry system and the MPD system, supplying the measured downhole pressure to the MPD system.
  • a second function is to perform further data processing prior to forwarding it to the MPD system. Such data processing may include filtering, averaging, error correction, extrapolation and interpolation.
  • a delay may be introduced into a MPD control loop. If the dead-time compensation of the MPD system cannot be adjusted to match the dead time, a predictive compensation may be applied as part of the data processing. If well control and borehole stability information are provided to the MPD interface, the interface may be able to change the set point for the MPD system. Thus, compensations may be made for data transmission lags.
  • the downhole components of the apparatus may be run into the borehole together with the tubular body and cemented in place (with the possible exception of the memory unit). This deployment procedure may allow extending the application of the downhole components from the time the tubular body is run into the wellbore and throughout a period during which measured data can be retrieved.
  • downhole components of the apparatus may be battery powered.
  • the battery life may be sufficient to supply power to the components during the period between installation and cementing in place.
  • sensors may be placed on the outside of the tubular body, on the inside of the tubular body or both.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics (AREA)
  • Remote Sensing (AREA)
  • Acoustics & Sound (AREA)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)
EP14290249.3A 2014-08-11 2014-08-11 Vorrichtung und Verfahren zur Bohrlochzementierung Withdrawn EP2985408A1 (de)

Priority Applications (1)

Application Number Priority Date Filing Date Title
EP14290249.3A EP2985408A1 (de) 2014-08-11 2014-08-11 Vorrichtung und Verfahren zur Bohrlochzementierung

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP14290249.3A EP2985408A1 (de) 2014-08-11 2014-08-11 Vorrichtung und Verfahren zur Bohrlochzementierung

Publications (1)

Publication Number Publication Date
EP2985408A1 true EP2985408A1 (de) 2016-02-17

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Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN110446826A (zh) * 2017-03-21 2019-11-12 韦尔泰克油田解决方案股份公司 井下传感器系统
CN110593856A (zh) * 2019-10-21 2019-12-20 中国石油集团川庆钻探工程有限公司 一种固井安全作业密度窗口测定方法
US11566514B2 (en) 2020-10-19 2023-01-31 Halliburton Energy Services, Inc. Bottomhole choke for managed pressure cementing
CN120649844A (zh) * 2025-08-18 2025-09-16 中国石油大学(华东) 一种基于井口甲烷吸附的井喷控制方法

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2002050398A1 (en) * 2000-12-18 2002-06-27 Impact Engineering Solutions Limited Cloded loop fluid-handing system for well drilling
US6662110B1 (en) * 2003-01-14 2003-12-09 Schlumberger Technology Corporation Drilling rig closed loop controls
WO2005017308A1 (en) * 2003-08-19 2005-02-24 Shell Internationale Research Maatschappij B.V. Drilling system and method
US20100161227A1 (en) * 2008-12-18 2010-06-24 Robert Paul Deere Method and apparatus for recording and using down hole sensor and diagnostic events in measurement while drilling
WO2013103561A1 (en) * 2012-01-06 2013-07-11 Halliburton Energy Services. Inc. Segregating flowable materials in a well

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2002050398A1 (en) * 2000-12-18 2002-06-27 Impact Engineering Solutions Limited Cloded loop fluid-handing system for well drilling
US6662110B1 (en) * 2003-01-14 2003-12-09 Schlumberger Technology Corporation Drilling rig closed loop controls
WO2005017308A1 (en) * 2003-08-19 2005-02-24 Shell Internationale Research Maatschappij B.V. Drilling system and method
US20100161227A1 (en) * 2008-12-18 2010-06-24 Robert Paul Deere Method and apparatus for recording and using down hole sensor and diagnostic events in measurement while drilling
WO2013103561A1 (en) * 2012-01-06 2013-07-11 Halliburton Energy Services. Inc. Segregating flowable materials in a well

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN110446826A (zh) * 2017-03-21 2019-11-12 韦尔泰克油田解决方案股份公司 井下传感器系统
CN110593856A (zh) * 2019-10-21 2019-12-20 中国石油集团川庆钻探工程有限公司 一种固井安全作业密度窗口测定方法
US11566514B2 (en) 2020-10-19 2023-01-31 Halliburton Energy Services, Inc. Bottomhole choke for managed pressure cementing
CN120649844A (zh) * 2025-08-18 2025-09-16 中国石油大学(华东) 一种基于井口甲烷吸附的井喷控制方法

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