[go: up one dir, main page]

WO2010036542A2 - Procédé et système d'utilisation d'instruments de puits de forage avec un train de tiges câblé - Google Patents

Procédé et système d'utilisation d'instruments de puits de forage avec un train de tiges câblé Download PDF

Info

Publication number
WO2010036542A2
WO2010036542A2 PCT/US2009/057080 US2009057080W WO2010036542A2 WO 2010036542 A2 WO2010036542 A2 WO 2010036542A2 US 2009057080 W US2009057080 W US 2009057080W WO 2010036542 A2 WO2010036542 A2 WO 2010036542A2
Authority
WO
WIPO (PCT)
Prior art keywords
instrument
wellbore
pipe string
turbine
well logging
Prior art date
Application number
PCT/US2009/057080
Other languages
English (en)
Other versions
WO2010036542A3 (fr
Inventor
Elison Nicholas
Erik Quam
Sylvain Bedouet
Dudi Rendusara
Ricardo Vasques
Nathan Landsiedel
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
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
Publication of WO2010036542A2 publication Critical patent/WO2010036542A2/fr
Publication of WO2010036542A3 publication Critical patent/WO2010036542A3/fr

Links

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
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/0085—Adaptations of electric power generating means for use in boreholes
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/003—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings with electrically conducting or insulating means

Definitions

  • the invention relates generally to the field of wellbore instruments and well logging methods. More specifically, the invention relates to systems and methods for operating electrically powered instruments in a well using a wired pipe string as a signal communication channel.
  • Well logging instruments are devices configured to move through a wellbore drilled through subsurface rock formations.
  • the devices include one or more sensors and other devices that measure various properties of the subsurface rock formations and/or perform certain mechanical acts on the formations, such as drilling or percussively obtaining samples of the rock formations, and withdrawing samples of connate fluid from the rock formations.
  • Measurements of the properties of the rock formations made by the sensors may be recorded with respect to the instrument axial position (depth) within the wellbore as the instrument is moved along the wellbore. Such recording is referred to as a "well log.”
  • One conveyance technique includes coupling the wireline instruments to the end of a coiled tubing having a wireline disposed therein.
  • the wireline instruments are extended into and withdrawn from the wellbore by extending and retracting the coiled tubing, respectively.
  • a subset of such coiled tubing techniques includes preliminary conveyance of the wireline configurable well logging instruments to a selected depth in the wellbore using a threadedly coupled pipe "string.” See, for example, U.S. Patent No. 5,433,276 issued to Martain et al.
  • Another well logging instrument conveyance technique includes coupling wireline configurable well logging instruments to the end of a drill pipe or similar threadedly coupled pipe string.
  • a wireline is coupled to the instruments using a "side entry sub" which provides a sealable passage from the exterior of the pipe string to the interior thereof.
  • the wireline is extended by operating a conventional winch.
  • drill pipe that includes a signal communication channel. See, for example, U.S. Patent No. 6,641,434 issued to Boyle et al. and assigned to the assignee of the present invention.
  • Such drill pipe has in particular provided substantially increased signal telemetry speed for use with LWD instruments over conventional LWD signal telemetry, which typically is performed by mud pressure modulation or by very low frequency electromagnetic signal transmission.
  • the foregoing drill pipe having a signal communication channel has not proven effective at transmitting electrical power from the surface to an instrument string disposed at a lower end of the pipe. In wireline conveyance of wellbore instrument, electrical power is transmitted from the surface to the instruments in the wellbore.
  • electrical power may be provided by batteries, or by an electric generator operated by flow of fluid through the pipe.
  • the amount of electrical power required by the instruments may be substantially reduced because the signal telemetry device used in MWD/LWD, typically a mud flow modulator, uses a substantial portion of the total electrical power used by the instruments.
  • a wellbore instrument system includes a pipe string extending from earth's surface to a selected depth in a wellbore.
  • the pipe string includes at least one of an electrical conductor and an optical fiber signal channel.
  • a power generator sub is coupled at one end to a lower end of the pipe string.
  • At least one electrically powered wellbore instrument is coupled to the other end of the adapter sub.
  • a method for well surveying includes moving at least one wellbore instrument along a wellbore at one end of a segmented pipe string.
  • the pipe string includes a signal communication channel associated therewith.
  • the method includes generating electrical power to operate the wellbore instrument at a location proximate a downhole end of the segmented pipe string. Measurements from at least one sensor in the instrument are communicated to the signal communication channel. The communicated measurements are detected at a surface end of the communication channel.
  • FIGS. 2 through 5 show examples of an adapter sub.
  • FIG. 6 shows a power generator portion of an adapter sub.
  • FIG. 7 shows another example of an adapter sub including a packer to isolate the well logging instrument from flow.
  • FIG. 8 shows an example of a longitudinal slip joint that may be used in some examples.
  • FIG. 9 shows an example of signal processing devices to adapt wireline configurable well logging instrument telemetry to wired pipe string telemetry.
  • FIG. 10 shows another example wellbore instrument that may be disposed at a lower end of the pipe string shown in FIG. 1.
  • the invention relates to devices for conveying a wellbore instrument or a "string" of such instruments through a wellbore using a wired pipe string for conveyance and signal communication.
  • the wired pipe string may include an electrical generator and power storage module or "sub” for supplying electrical power to operate the instrument and for providing telemetry to signal communication channel in the wired pipe string.
  • the wired pipe string may be assembled and disassembled in segments to effect conveyance in a manner known in the art for conveyance of segmented pipe through a wellbore.
  • a drilling rig 24 or similar lifting device moves a conduit or pipe called a "wired pipe string" 20 within a wellbore 18 that has been drilled through subsurface rock formations, shown generally at 11.
  • the wired pipe string 20 may be extended into the wellbore 18 by threadedly coupling together end to end a number of segments ("joints") 22 of wired drill pipe.
  • Wired drill pipe is structurally similar to ordinary drill pipe and includes at least one electrical conductor or at least one optical fiber associated with each pipe joint to act as a signal communication channel.
  • Wired drill pipe includes some form of signal coupling to communicate signals along the channel between pipe joints when the pipe joints are coupled end to end as shown in FIG. 1. See, as a non-limiting example, U.S. Patent No. 6,641,434 issued to Boyle et al. and assigned to the assignee of the present invention for a description of a type of wired drill pipe that can be used with the present invention.
  • the wired pipe string 20 may include an assembly or "string" of wellbore instruments at a lower end thereof.
  • the wellbore instrument string may include wireline configurable well logging instruments 13 coupled to a lower end thereof.
  • the term "wireline configurable well logging instruments” or a string of such instruments means one or more well logging instruments that can be conveyed through a wellbore using armored electrical cable (“wireline”), and which cannot be used in a pipe string for conducting drilling operations as a part of the pipe string.
  • Wireline configurable well logging instruments are thus distinguishable from "logging while drilling” (“LWD”) instruments, which are configurable to be used during drilling operations and form part of the pipe string itself.
  • LWD logging while drilling
  • LWD and related drill string instrumentation may also be used as the wellbore instrument(s).
  • the pipe string 20 may be used to turn and axially urge a drill bit (FIG. 10) into the bottom of the wellbore 18 to increase its length (depth).
  • a pump 32 lifts drilling fluid ("mud") 30 from a tank 28 or pit and discharges the mud 30 under pressure through a standpipe 34 and flexible conduit 35 or hose, through the top drive 26 and into an interior passage (not shown separately in FIG. 1) inside the pipe string 20.
  • mud drilling fluid
  • the mud 30 exits the drill string 20 through courses or nozzles (not shown separately) in the drill bit (FIG. 10), where it then cools and lubricates the drill bit and lifts drill cuttings generated by the drill bit (FIG. 10) to the Earth's surface.
  • the pipe string 20 may be withdrawn from the wellbore 18, and an adapter sub 12 and the well logging instrument string 13 may be coupled to the end of the pipe string 20.
  • the pipe string 20 may then be reinserted into the wellbore 18 so that the instruments 13 may be moved through, for example, a highly inclined portion 18A of the wellbore 18 which would be inaccessible using armored electrical cable ("wireline”) to move the instruments 24.
  • the pump 32 may be operated to provide fluid flow to operate one or more turbines (not shown in FIG. 1) in the well logging instrument string 13 to provide power to operate certain devices in the well logging instrument string 13.
  • signals detected by various devices are selected to be included in a telemetry transceiver (FIG. 9) in the adapter sub 12 for communication along the signal channel in the wired pipe string 20.
  • a telemetry transmitter 36A can be used to wirelessly transmit signals from the wired pipe string 20 to a receiver 36B.
  • the wired pipe string 20 may be freely moved, assembled, disassembled and rotated without the need to make or break a wired electrical or optical signal connection.
  • Signals from the receiver 36B which may be electrical and/or optical signals, for example, may be conducted (such as by wire or cable) to a recording unit 38 for decoding and interpretation using techniques well known in the art.
  • the decoded signals typically correspond to the measurements made by one or more of the sensors in the well logging instruments 10, 14, 16.
  • Other sensors known in the art include, without limitation, density sensors, neutron porosity sensors, acoustic travel time or velocity sensors, seismic sensors, neutron induced gamma spectroscopy sensors and microresistivity (imaging) sensors.
  • the functions performed by the adapter sub 12 may include providing a mechanical coupling (explained below) between the lowermost threaded connection on the pipe string 20 and an uppermost connection on the well logging instruments 13.
  • the adapter sub 12 may also include one or more devices (explained below) for producing electrical and/or hydraulic power to operate various parts of the well logging instruments 13.
  • the adapter sub may include signal processing and recording devices (explained below) for selecting signals from the well logging instrument 13 for transmission to the surface using the wired pipe string 20 and recording signals in a suitable storage or recording device (explained below) in the adapter sub 12.
  • top drive 26 may be substituted by a swivel, kelly, kelly bushing and rotary table (none shown in FIG. 1) for rotating the pipe string 20 while providing a pressure sealed passage through the pipe string 20 for the mud 30. Accordingly, the invention is not limited in scope to use with top drive drilling systems.
  • FIG. 2 shows one example of the adapter sub 12.
  • Wired drill pipe such as in the above provided example, is known to have digital signal telemetry capacity between one hundred thousand and one million bits per second. Wired drill pipe known in the art, however, does not efficiently transmit electrical power.
  • the adapter sub 12, therefore, may include a turbine 41 that is rotated by flow of drilling fluid moved by the pump (32 in FIG. 1) as explained above.
  • the turbine 41 may be disposed in a housing 40 therefor.
  • the turbine housing 40 may include threaded connections configured to couple to the lowermost threaded connection on the wired pipe string 20.
  • Use of the terms “generator” and “alternator” herein is intended to be interchangeable in that use of either direct current electric generators or alternating current generators is within the scope of this invention, and the term “generator” as used below and in the appended claims is intended to include both types of device within its scope.
  • Electrical output from the generator 43 may be conditioned to operate various components in the well logging instruments in a power conditioner module 44.
  • the turbine 41 in some examples may have a controllable response to fluid flow, such as by controllable blade pitch, a controllable brake (not shown) or controllable bypass ports (FIG. 6).
  • Other methods include a controllable distance between the rotor and stator (either passive - based on the thrust force of the flow / rotational speed or actively controlled) or variable distance between the tips of the turbine blades and the housing (by moving either the turbine or the housing axially relative to the other, with one or both having a coned shape). Again, this could be achieved passively based on the thrust force, the rotational speed or combination of the two, or it could be controlled actively. These last two methods effectively alter the efficiency of the turbine.
  • Such controllable turbine response feature may provide proper operation of the generator 43 under widely variable electrical load conditions.
  • a formation fluid sampling and pressure testing instrument may be coupled to the power conditioner module 44, either directly or through other well logging instruments.
  • a formation fluid sampling and pressure testing instrument is described in U.S. Patent No. 6,659,177 issued to Bolze et al. and assigned to the assignee of the present invention.
  • Formation testing instruments may include a power/control and signal processing module ("FT power”) 46 and a pump module (“FT pump out”) 48.
  • the pump out 48 may include a fluid pump 47 that is operable at a controllable rate, and is selectively coupled, using solenoid operated valves (not shown), to a probe (not shown) placed in contact with the formation (11 in FIG. 1).
  • the fluid pump 47 is used for, among other purposes, withdrawing samples of connate fluid from the formations (11 in FIG. 1).
  • Certain details of the formation testing instrument (10 in FIG. 1) are not relevant to the invention and are not shown herein for clarity of the illustration.
  • the fluid pump 47 may be operated by an electric motor 45. Additional electrical power provided by the generator 43 may be used to operate the other well logging instruments (14, 16 in FIG. 1) coupled to the wired pipe string (20 in FIG. 1).
  • FIG. 3 shows another example of the adapter sub 12.
  • the example adapted sub shown in FIG. 3 includes a turbine 41 as in the previous example.
  • hydraulic power provided by the hydraulic pump 49 may drive an hydraulic motor 51 which itself drives the generator 43. Remaining components of the well logging instruments may be as in the previous example.
  • FIG. 4 shows another example in which the hydraulic pump provides hydraulic power to directly operate the pump 47 A in the formation testing instrument (10 in FIG. 1). Part of the hydraulic power provided by the hydraulic pump 49 may drive an hydraulic motor 51A to operate the generator 43A as in the example of FIG. 3. Because the formation tester pump 47A can consume a very large amount of power, in the example of FIG. 4 it may be possible to use a much smaller generator 43A than the examples shown in FIGS. 2 and 3.
  • the second turbine 4 IB can provide power to operate the formation tester pump 47B directly or through hydraulic conversion
  • the first turbine 41 A may provide power to operate the generator 43B for all electrical consumption of the well logging instruments (10, 14, 16 in FIG. 1).
  • FIG. 6 An example of the adapter sub is shown in more detail in FIG. 6.
  • housing 40 may include an upper threaded connection 50 configured to couple to the lowermost threaded coupling on the wired pipe string (20 in FIG. 1).
  • Such threaded coupling may include a communication device 52 disposed in a thread shoulder 5OA of the upper threaded connection 50.
  • the communication device may be electromagnetic, as explained, for example, in the Boyle et al. patent referred to above.
  • the housing 40 may include one or more controllable bypass valves 54.
  • the controllable bypass valves 54 may be operated, for example, by solenoids (not shown) to selectively enable part of the fluid flow through the pipe string (20 in FIG. 1) to be diverted into the wellbore (18 in FIG. 1) above turbine 41, thus reducing the output of the turbine 41.
  • the housing 40 may include fixed discharge ports 56 below the turbine 41 to enable fluid flow to operate the turbine 41.
  • the housing may include a lower threaded connection 58 that is configured to couple to an upper threaded connection 60 in the well logging instrument string, shown as power module 44 of the formation testing instrument, although the particular well logging instrument that couples to the adapter sub 12 is not a limit on the scope of the present invention.
  • the adapter sub 12 may include a turbine housing 40 as in the previous examples, in which may be disposed the turbine 41 and generator 43.
  • the housing 40 in FIG. 7 can include a flow diverter 40A to direct flow from within the pipe string back up the wellbore (18 in FIG. 1).
  • an inflatable packer 62 may be disposed between the turbine housing 40 and the uppermost portion of the well logging instrument string, which may be the power conditioner module 44.
  • the inflatable packer 62 may be any type known in the art and may be inflated using wellbore fluid or hydraulic fluid, for example. When the packer 62 is inflated, fluid moving above the packer 62 is prevented from affecting those portions of the well logging instruments below the packer 62. Such isolation may reduce the possibility of probe seal failure when extracting samples of formation fluid, for example.
  • a longitudinal slip joint may be included in the well logging instrument string.
  • the longitudinal slip joint can also be used to compensate for thermal expansion of the wired pipe string (20 in FIG. 1) due to temperature changes.
  • An example slip joint is shown at 70 in FIG. 8.
  • the slip joint may include an upper housing 72 engaged, for example, with the turbine housing 40, and a lower housing 74 engaged with the power conditioner module 44.
  • the upper 72 and lower 74 housings slidably engage each other and may be sealed using o-rings 76 or similar sealing device that enables relative longitudinal movement between the upper and lower housings.
  • the digital data handling rate (bandwidth) of typical wired pipe strings is about 1 million bits per second.
  • typical wireline configurable well logging instruments strings can generate signal data at large multiples of the bandwidth of typical wired pipe strings. Accordingly, it is desirable to use the available wired pipe string bandwidth to communicate to the surface those signals from the well logging instrument string (13 in FIG. 1) that are most valuable to obtain substantially as they are measured (in "real time”). Other data that are not typically valuable to obtain in real time, for example, instrument diagnostic measurements may be stored in a local data storage device. It is also desirable to be able to change the particular signals transmitted to the surface in real time, as well as to change the sample rate of such real time transmission.
  • certain well logging measurements such as induction resistivity corresponding to large lateral distance from the wellbore, change relatively slowly with change in axial position of the well logging instrument string. It may be possible to send such measurements to the surface at relatively slow rates (e.g., 1-100 Hz), while measurements that change more rapidly (e.g. microresistivity measurements made for wellbore imaging) may be transmitted at much higher rates (e.g., 1 KHz to 1000 KHz).
  • FIG. 9 An example signal processing and recording unit that can perform the foregoing telemetry conversion and formatting is shown in block diagram form in FIG. 9.
  • the communication device 52 (also shown FIG. 6) in that couples signals to the signal communication channel in the wired pipe string is in signal communication with a telemetry transceiver 80 ("WDP transceiver") configured to communicate signals in the telemetry format used for the wired pipe string (20 in FIG. 1).
  • the WDP transceiver 80 is preferably bidirectional.
  • a command decoder 82 may interrogate the telemetry signals from the WDP transceiver 80 to detect any commands originating from the recording unit (38 in FIG. 1). Such commands may include instructions to deploy the formation tester (10 in FIG.
  • Commands may also include instructions to send different instrument measurement signals from the well logging instrument string (13 in FIG. 1) to the recording unit (38 in FIG. 1) over the wired pipe string.
  • Another type of instruction that may be detected in the command decoder 82 is time/depth records. As the pipe string is moved along the wellbore, the axial position in the wellbore (depth) of a reference point on the pipe string or on the instrument string may be used to indicate the depth of each instrument sensor in the instrument string. The depth is typically determined by measuring the elevation of the top drive (26 in FIG. 1) and adding to the elevation the length of all the individual components of the pipe string and instrument string.
  • the elevation may be recorded automatically in the recording unit (38 in FIG. 1) by use of appropriate sensors on the drilling unit (24 in FIG. 1).
  • the time/depth data may be used to generate a record with respect to depth of measurements made by the various sensors in the instrument string.
  • the command decoder 82 may transmit instructions to change the data sent over the wired pipe string to an intermediate telemetry transceiver 86.
  • the intermediate telemetry transceiver 86 receives well logging instrument measurements from the instrument string by signal connection to a well logging instrument telemetry transceiver 88 in the instrument string 13.
  • the well logging instrument telemetry transceiver 88 may be the same type as used in any wireline configurable well logging instrument string, and is preferably configured to transmit signals over an armored electrical cable ("wireline") when the instrument string is deployed on a wireline.
  • wireline armored electrical cable
  • all well logging instrument signals that would be transmitted over the wireline if so connected are communicated to the intermediate telemetry transceiver 86.
  • the WDP telemetry transceiver 80 for communication over the wired pipe string.
  • Remaining well logging instrument signals may be communicated to a mass data storage device 84 such as a solid state memory or hard drive.
  • the mass data storage device 84 may also receive and store the same signals that are transmitted to the surface over the wired pipe string.
  • the foregoing components, including the WDP telemetry 80, mass data storage 84, command decoder 82 and intermediate telemetry 86 may be enclosed in the adapter sub 12 in some examples. In other examples, the foregoing components may be enclosed in a separate housing (not shown) that is itself coupled to the adapter sub 12 and to the instrument string 13.
  • the invention as explained above may be used in conjunction with a number of other drilling and measurement devices known in the art.
  • Non-limiting examples of such other devices may include the following.
  • the wireline configurable well logging instruments may be inserted into a sleeve or a drill collar to protect them from being damaged during rotation and/or lateral movement, and can enable fluid pumped from the surface to flow around them for cooling purposes.
  • a sleeve or drill collar may cover less than the entire string of well logging instruments, thus allowing sections of the instrument string to come into direct contact with the formations (11 in FIG. 1) for measurement or sample extraction purposes.
  • a drill bit may be added at the bottom of the instrument string to allow drilling to continue while logging or between logging / sampling operations in conjunction with a drilling motor.
  • the motor and/or a rotary steerable directional drilling system may be included between the drill bit and the well logging instruments to improve drilling efficiency and allow controlling the trajectory of the wellbore (18 in FIG. 1).
  • Logging while drilling (“LWD”) and/or measurement while drilling (“MWD”) instruments known in the art may be included at any location in the wired pipe string (20 in FIG. 1) to enable alternative measurements, or as a contingency to the failure of the well logging instrument string or failure of communication using the wired pipe string.
  • LWD Logging while drilling
  • MWD measurement while drilling
  • Stabilizers, reamers or wear bands may be placed on the foregoing sleeve or on a drill collar for directional control, wellbore conditioning, hole opening or other reasons.
  • Existing measurement while drilling telemetry technology mud pressure modulation telemetry
  • a bottom hole assembly (“BHA") 13A may include LWD instruments, such as a resistivity measuring device 80, and a combination sensor 82 including a directional sensor (including wellbore direction sensor D and wellbore inclination sensor I) and nuclear well logging sensors (including natural gamma ray sensor GR, density sensor DE and neutron sensor N).
  • LWD instruments such as a resistivity measuring device 80
  • combination sensor 82 including a directional sensor (including wellbore direction sensor D and wellbore inclination sensor I) and nuclear well logging sensors (including natural gamma ray sensor GR, density sensor DE and neutron sensor N).
  • the particular arrangement of sensors shown in FIG. 10 is only meant to illustrate a possible BHA configuration and is not in any way intended to limit the scope of the invention.
  • the foregoing sensors 80, 82 may be coupled to the lower end of the wired pipe string 20.
  • Examples of the foregoing sensors include those used to provide services sold under the service marks CDR and CDN, which are service marks of an affiliate of the assignee of the present invention.
  • a lower end of the sensor arrangement, shown at the bottom of combined sensor 82 may include a rotary steerable directional drilling system 84, which may include selectively operable pads 84A to urge the BHA 13A in a selected direction to change the trajectory of the wellbore.
  • An example of a rotary steerable direction drilling system is one used to provide services sold under the service mark POWERDRIVE, which is a service mark of an affiliate of the assignee of the present invention.
  • the lowermost end of the BHA 13A will typically include a drill bit 86 to increase the axial length (depth) of the wellbore by drilling.
  • the adapter sub of the previously described examples may be modified into another type of adapter sub 12A which may include electric generation and signal communications devices as explained above, and may include a power storage device 12B, such as batteries or large capacitors (energy storage devices) to store electrical power produced, for example, by operation of a turbine in response to flow of drilling fluid through the pipe string.
  • the adapter sub 12A in FIG. 10 would not need any form of mud flow bypass if the lower end is configured to be coupled to LWD and/or MWD instrument (which are usually disposed inside one or more drill collars having mud passages therethrough).
  • the power storage device 12B may provide sufficient power to operate all the sensors in the BHA 13 A.
  • the power storage device 12A may operate a wireline configurable instrument string as shown in and as explained with reference to FIGS. 6 and 9. While the invention has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments can be devised which do not depart from the scope of the invention as disclosed herein. Accordingly, the scope of the invention should be limited only by the attached claims.

Landscapes

  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)
  • Insulated Conductors (AREA)

Abstract

La présente invention concerne un système d'instruments de puits de forage comprenant un train de tiges s'étendant dans un puits de forage de la surface de la terre jusqu'à une profondeur sélectionnée. Le train de tiges comporte au moins un conducteur électrique ou un canal de signalisation par fibre optique, voire les deux. Une extrémité d'une réduction de tiges à générateur électrique est couplée à une extrémité inférieure du train de tiges. Au moins un instrument de puits de forage à alimentation électrique est couplé à l'autre extrémité de la réduction de tiges de l'adaptateur.
PCT/US2009/057080 2008-09-25 2009-09-16 Procédé et système d'utilisation d'instruments de puits de forage avec un train de tiges câblé WO2010036542A2 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US12/237,558 US20100071910A1 (en) 2008-09-25 2008-09-25 Method and system for using wellbore instruments with a wired pipe string
US12/237,558 2008-09-25

Publications (2)

Publication Number Publication Date
WO2010036542A2 true WO2010036542A2 (fr) 2010-04-01
WO2010036542A3 WO2010036542A3 (fr) 2010-05-20

Family

ID=42036451

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2009/057080 WO2010036542A2 (fr) 2008-09-25 2009-09-16 Procédé et système d'utilisation d'instruments de puits de forage avec un train de tiges câblé

Country Status (2)

Country Link
US (1) US20100071910A1 (fr)
WO (1) WO2010036542A2 (fr)

Families Citing this family (15)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8302687B2 (en) 2004-06-18 2012-11-06 Schlumberger Technology Corporation Apparatus for measuring streaming potentials and determining earth formation characteristics
US8136591B2 (en) * 2009-06-01 2012-03-20 Schlumberger Technology Corporation Method and system for using wireline configurable wellbore instruments with a wired pipe string
US9574425B2 (en) * 2012-07-12 2017-02-21 Halliburton Energy Services, Inc. Downhole power generation using hydraulic flow regulation
US9664027B2 (en) * 2012-07-20 2017-05-30 Merlin Technology, Inc. Advanced inground operations, system and associated apparatus
EP2708695A1 (fr) 2012-09-13 2014-03-19 Services Pétroliers Schlumberger Système de commande de vitesse de turbine pour outil de fond de trou
EP2743445A1 (fr) * 2012-12-11 2014-06-18 Welltec A/S Système électrique de fond de trou
GB2509931B (en) * 2013-01-17 2020-07-01 Tendeka Bv Apparatus for power generation
WO2015116343A1 (fr) * 2014-01-31 2015-08-06 Harry Bailey Curlett Procédé et système de production de ressources souterraines
AU2014396153B2 (en) * 2014-06-04 2017-09-28 Halliburton Energy Services, Inc. Fracture treatment analysis based on seismic detection in horizontal and vertical wellbore sections
WO2017172563A1 (fr) 2016-03-31 2017-10-05 Schlumberger Technology Corporation Direction et communication de train de tiges d'équipement
US11811273B2 (en) 2018-06-01 2023-11-07 Franklin Electric Co., Inc. Motor protection device and method for protecting a motor
US10454267B1 (en) 2018-06-01 2019-10-22 Franklin Electric Co., Inc. Motor protection device and method for protecting a motor
US11408280B2 (en) 2018-12-17 2022-08-09 Halliburton Energy Services, Inc. Real-time monitoring of wellbore drill cuttings
WO2020204917A1 (fr) 2019-04-03 2020-10-08 Halliburton Energy Services, Inc. Gestion en temps réel de couple, de résistance et de vibrations excessifs dans un train de tiges de forage
US11976537B2 (en) * 2022-03-02 2024-05-07 Oilfield Equipment Development Center Limited Downhole wellbore systems for generating electricity

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5285204A (en) * 1992-07-23 1994-02-08 Conoco Inc. Coil tubing string and downhole generator
US20060248949A1 (en) * 2005-05-03 2006-11-09 Halliburton Energy Services, Inc. Multi-purpose downhole tool
US20060260798A1 (en) * 2005-05-21 2006-11-23 Hall David R Wired Tool String Component

Family Cites Families (15)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2501777B1 (fr) * 1981-03-13 1986-08-29 Inst Francais Du Petrole Methode et dispositif pour effectuer, a l'aide d'outils specialises, des operations telles que des mesures, dans des portions de puits fortement inclinees sur la verticale, ou horizontales
US4693316A (en) * 1985-11-20 1987-09-15 Halliburton Company Round mandrel slip joint
US5568838A (en) * 1994-09-23 1996-10-29 Baker Hughes Incorporated Bit-stabilized combination coring and drilling system
US5433276A (en) * 1994-10-17 1995-07-18 Western Atlas International, Inc. Method and system for inserting logging tools into highly inclined or horizontal boreholes
US6092416A (en) * 1997-04-16 2000-07-25 Schlumberger Technology Corporation Downholed system and method for determining formation properties
US6659177B2 (en) * 2000-11-14 2003-12-09 Schlumberger Technology Corporation Reduced contamination sampling
US6641434B2 (en) * 2001-06-14 2003-11-04 Schlumberger Technology Corporation Wired pipe joint with current-loop inductive couplers
US7114578B2 (en) * 2002-04-19 2006-10-03 Hutchinson Mark W Method and apparatus for determining drill string movement mode
WO2004072682A1 (fr) * 2003-02-11 2004-08-26 Noble Drilling Services, Inc. Source d'energie sismique a utiliser pendant le forage d'un puits
US20060100968A1 (en) * 2004-11-05 2006-05-11 Hall David R Method for distributing electrical power to downhole tools
US7190084B2 (en) * 2004-11-05 2007-03-13 Hall David R Method and apparatus for generating electrical energy downhole
US7504963B2 (en) * 2005-05-21 2009-03-17 Hall David R System and method for providing electrical power downhole
US7913773B2 (en) * 2005-08-04 2011-03-29 Schlumberger Technology Corporation Bidirectional drill string telemetry for measuring and drilling control
US20070044959A1 (en) * 2005-09-01 2007-03-01 Baker Hughes Incorporated Apparatus and method for evaluating a formation
US7819206B2 (en) * 2007-07-13 2010-10-26 Baker Hughes Corporation System and method for logging with wired drillpipe

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5285204A (en) * 1992-07-23 1994-02-08 Conoco Inc. Coil tubing string and downhole generator
US20060248949A1 (en) * 2005-05-03 2006-11-09 Halliburton Energy Services, Inc. Multi-purpose downhole tool
US20060260798A1 (en) * 2005-05-21 2006-11-23 Hall David R Wired Tool String Component

Also Published As

Publication number Publication date
US20100071910A1 (en) 2010-03-25
WO2010036542A3 (fr) 2010-05-20

Similar Documents

Publication Publication Date Title
US20100071910A1 (en) Method and system for using wellbore instruments with a wired pipe string
US8544534B2 (en) Power systems for wireline well service using wired pipe string
US8136591B2 (en) Method and system for using wireline configurable wellbore instruments with a wired pipe string
US9347277B2 (en) System and method for communicating between a drill string and a logging instrument
US9187957B2 (en) Method for motion compensation using wired drill pipe
US20150090444A1 (en) Power systems for wireline well service using wired pipe string
US6427783B2 (en) Steerable modular drilling assembly
CA2587884C (fr) Appareil de forage modulaire a transmission d'energie et/ou de donnees
RU2413841C2 (ru) Система двусторонней телеметрии по бурильной колонне для измерений и управления бурением
US8827006B2 (en) Apparatus and method for measuring while drilling
US9309748B2 (en) Power generation via drillstring pipe reciprocation
US8708041B2 (en) Method and system for using wireline configurable wellbore instruments with a wired pipe string
CN101253304A (zh) 用于测量和钻探控制的双向钻柱遥测技术
US20130222149A1 (en) Mud Pulse Telemetry Mechanism Using Power Generation Turbines
NO333729B1 (no) Anordning og fremgangsmate for telemetri langs en borestreng med nedihulls drivkjede
CN101210489A (zh) 用于在有线钻杆中确定故障位置的方法和设备
CN113586040A (zh) 泥浆脉冲发生器及其操作方法
US20240117677A1 (en) Bha with electric directional drilling motor
US20210156200A1 (en) Nanocrystalline tapes for wireless transmission of electrical signals and power in downhole drilling systems
US20210047886A1 (en) Nanocrystalline tapes for wireless transmission of electrical signals and power in downhole drilling systems
AU2023356779A1 (en) Bha with electric directional drilling motor
MXPA99007196A (en) Measuring the pressure of formation during drilling using a non-rotate shirt

Legal Events

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

Ref document number: 09816708

Country of ref document: EP

Kind code of ref document: A2

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 09816708

Country of ref document: EP

Kind code of ref document: A2