CA2382974C - Accelerometer caliper while drilling - Google Patents

Accelerometer caliper while drilling Download PDF

Info

Publication number
CA2382974C
CA2382974C CA002382974A CA2382974A CA2382974C CA 2382974 C CA2382974 C CA 2382974C CA 002382974 A CA002382974 A CA 002382974A CA 2382974 A CA2382974 A CA 2382974A CA 2382974 C CA2382974 C CA 2382974C
Authority
CA
Canada
Prior art keywords
caliper
accelerometer
tool body
drill bit
wellbore
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.)
Expired - Lifetime
Application number
CA002382974A
Other languages
French (fr)
Other versions
CA2382974A1 (en
Inventor
Marcel L. Boucher
Brian P. Jarvis
Tim Mccarthy
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.)
ReedHycalog UK Ltd
Original Assignee
Camco International UK 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 Camco International UK Ltd filed Critical Camco International UK Ltd
Publication of CA2382974A1 publication Critical patent/CA2382974A1/en
Application granted granted Critical
Publication of CA2382974C publication Critical patent/CA2382974C/en
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

Links

Classifications

    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00Survey of boreholes or wells
    • E21B47/08Measuring diameters or related dimensions at the borehole

Abstract

An accelerometer caliper while drilling arrangement comprising a drill bit having an axis 12 of rotation and a gauge region 14, a caliper tool body 20, a first accelerometer 24 mounted upon the caliper tool body 20 and arranged to measure acceleration in a first direction 25, and a second accelerometer 28 mounted upon the caliper tool body 20 and arranged to measure acceleration in a second direction 29 orthogonal to the first direction 25, wherein the caliper tool body 20 and the drill bit 10 are coupled to one another in such a manner that the first and second accelerometers 24, 28 are mounted in a known relationship to the drill bit 10.

Description

Accelerometer Caliper While Drilling BACKGROLJND OF THE INVENTION

1. Field of the invention This invention relates to an apparatus for use in accurately detenmining a wellbore caliper. In particular the invention relates to the determination of wellbore caliper whilst a drilling process is taking place. In a practical embodiment, this is achieved by using a plurality of orthogonally mounted accelerometers.
2. Description of related art Typically, a wellbore extending through a formation is not straight, but rather extends in a snake-like fashion through the formation. Such wellbores are often of spiralling form resulting from the rotary motion of the drill bit.

However, the wellbore may also take other forms, for example as a result of the drill bit being deflected from its original path as a result of encountering a change in the structure of the formation through which the wellbore is being drilled.
Even wellbores which are regarded as being straight often have variations in deviation and direction. Although these variations may be small, they can still be of significance when completing a wellbore. By way of example, it is usual to line a wellbore of 8'/2' diameter using a casing having an outer diameter of 7".
Clearly, if the wellbore is exactly straight, this gives a radial clearance of only 3/4". Obviously, where the wellbore is not exactly straight, then there may be regions where there is less clearance, or regions where the provisions of such a casing is not practical and other lining techniques may need to be used.

In practice, wellbores are very rarely exactly straight, indeed with the advent of steerable drilling systems highly deviated and horizontal wellbores are widely used in order to enhance reservoir production. The positioning of a completion string such as a wellbore casing within such a welibore can be a very difficult operation and may result in damage to the completion string. Even where the completion string is not damaged, there is an increased likelihood of impaired production rates.

It will be appreciated from the description above that the geometry and orientation of the wellbore, as well as the way a completion string will sit in the wellbore, play a very important part in determining the effectiveness of the completion during clean up, treatment, cementing/isolation, and production.

A number of techniques are known to permit the measurement of wellbore shape. One such technique involves the use of a tool known as a dipmeter which includes sensors arranged to measure variations in the conductivity of the formation. The dipmeter has calipers arranged to measure the size of the wellbore as the dilxneter passes along the length of the wellbore. Other sensors arranged to measure the deviation and direction of the wellbore may also be provided. In use, the dipmeter is passed along the length of the wellbore and readings are taken using the various sensors. The readings are logged along with the position of the dipmeter at the time the readings are taken and this information is subsequently used to produce a three-dimensional image of the wellbore.

Other tools are also known for use in measurin,g the shape of the wellbore.
For example, a tool known as a borehole geometry tool can be used. A tool of this type is similar to a dipmeter but does not include sensors for measuring formation conductivity. Another tool is an ultrasonic borehole imaging (UBI) tool. This tool is used in conjunction with a general purpose inclinometry tool to generate data rept mentative of the wellbore shape and size which data can, if desired, be used to produce a three-dimensional image of the wellbore.

It will be appreciated that knowledge of what is likely to happen downhole as a completion string is inserted into a wellbore is useful in deciding how to complete a wellbore.

Accurate measurement of the wellbore caliper using the above described devices can only be achieved after drilling. Measurement whilst drilling is not practical as it is not possible to determine the absolute position of the tool being used to generate the desired data. Further, where a UBI tool is used, the tool must be rotated relatively slowly as the sensitivity of the tool decreases with increasing speed, making the tool unsuitable for use in a measurement while drilling system.

Measurement of a number of drilling parameters whilst drilling can be achieved. For example, W099/36801 describes an arrangement for nuclear magnetic resonance (NMR) imaging of a weilbore. Such imaging is useful as it can be used to derive information representative of the porosity, fluid composition, the quantity of moveable fluid and the permeability of the fortrnation being drilled. In order to produce useful data, it is important that the sensor of the arrangement is either stationary or is only moving relatively slowly.
Where fast movement is occurring, the results are less useful in determining the values of the parameters as there is an increased risk of significant errors in the results. In order to determine whether or not the NMR readings taken using the tool can be used, the tool is provided with sensors for use in monitoring the motion of the tool. One example of a suitable sensor arrangement is to provide the tool with accelerometers and a suitable control arrangement. The accelerometer readings can be used to produce data representative of the motion of the tool, and the control arrangement can be used to inhibit the production of NMR data when the motion of the tool is such that the NMR readings would be likely to include significant errors. Alternatively, the control arr=angement may be arranged to allow the NMR readings to be made to flag the readings that are likely to contain errors.
SUIvIHI.ARY OF THE INVENTION

According to the present invention there is provided an accelerometer caliper while drilling arrangement comprising a drill bit having an axis of rotation and a gauge region, a caliper tool body, a first accelerometer mounted upon the caliper tool body and arranged to measure acceleration in a first direction, and a second accelerometer mounted upon the caliper tool body and arranged to measure acceleration in a second direction orthogonal to the first direction, wherein the caliper tool body and the drill bit are coupled to one another in such a manner that the first and second accelerometers are mounted in a known relationship to the drill bit.

As the accelerometers are mounted in a known relationship to the drill bit, and as the drill bit defines the edges of the bore, the positions of the accelerometers are kaown and the acceleration readings taken using the accelerometer can be used to ascertain the shape of the wellbore.

Although as described above, only two orthogonally mounted accelerometers are required, it will be appreciated that if a greater number of accelerometers are provided, then it may be possible to increase the accuracy with which caliper readings can be taken. In a preferred arrangement, three accelerometers are used, but it will be appreciated that the invention is not restricted to arrangements including three accelerometers.

It is thought that the accelerometer caliper whilst drilling tool will be able to take welibore caliper diameter measurements with an accuracy of up to about +/-0.06".

If desired, the caliper tool body may form part of the drill bit.

According to one aspect of the invention there is provided a bottom hole assembly comprising a drill bit having an axis of rotation and a gauge region, an accelerometer caliper tool body, a first accelerometer mounted upon the caliper tool body, and arranged to measure acceleration in a first direction, and a second accelerometer mounted upon the caliper tool body and arranged to measure acceleration in a second direction orthogonal to the first direction, wherein the caliper tool body and the drill bit are coupled to one another in such a manner that the first and second accelerometers are mounted in a known relationship to the drill bit, a controller/processor arranged to receive signals from the first and second accelerometers and a mud telemetry transmitter arranged to transmit data under the control of the controller/processor.

6a BRIEF DESCRIPTION OF THE DRAWINGS

The invention will further be described, by way of example, with reference to the accompanying drawings, in which:

Figure 1 is a diagrammatic view illustrating a wellbore and bottom hole assembly including an accelerometer caliper while drilling system;

Figure 2 is a diagrammatic sectional view of part of the caliper while drilling system; and Figure 3 is a diagrammatic view of part of an alternative bottom hole assembly.
DETAILED DESCRIPTION OF THE INVENTION
AND THE PREFERRED EMBODI.MENT

The bottom hole assembly (BHA.) illustrated, diagrammatically, in Figure 1 comprises a drill bit 10 of the rotary drag type which has an axis 12 about which it is rotated, in use, and a gauge region 14. The gauge region 14 bears against the wall 16 of the wellbore, in use.

The drill 10 is mounted upon a caliper tool 18 which comprises a body of diameter slightly smaller than the diameter of the gauge region 14 of the drill bit 10. As the body 20 is slightly smaller in diameter than the gauge region 14, it will be appreciated that, when the bottom hole assembly is in a straight part of the wellbore, the tool body 20 is radially spaced from the wall 16 of the wellbore.

The body 20 has mounted thereon three accelerometers or acceleration sensors 22. Two of the sensors 22 are mounted at the periphery of the body 20 and lie upon a diameter of the body 20. These two sensors are denoted by the reference numerals 24, 26. It will be appreciated from Figure 2 that these sensors 24, 26 are oppositely orientated relative to one another and are sensitive to lateral acceleration of the body 20 in a fust direction 25, and to be sensitive to angular acceleration of the tool body 20. The third sensor, denoted by reference numera128, is orientated to measure lateral acceleration in a direction 29 perpendicular to, or orthogonal to, the first direction 25 in which the sensors 24, 26 are sensitive to lateral acceleration.

The tool body 20 is connected to a drill string 30 which supports the bottom hole assembly. If desired, the bottom hole assembly may include a number of other components. For example, it may include a stabiliser 32, a mud pulse telemetry transmitter 34 and where the system of which the bottom hole assembly forms part takes the form of a steerable drilling system, then the bottom hole assembly may include a bias unit 36 arranged to apply a side loading to the drill bit 10 to cause the formation of a curve in the wellbore (as shown), or it may include a downhole motor for rotating the drill bit, and a bent component positionable, by controlling the angular position of the drill string, to control the direction in which drilling is taking place.

In use, whilst drilling is taking pWe, the caliper too118 is controlled in such a manner as to produce sensor readings representative of the accelerations experienced by the tool 18. By double integration of the sensor readings, the sensor readings can be converted into data representative of the radial position of the too118 relative to the wall 16 of the wellbore.

As the too118 is physically secured to the drill bit 10, the positions of the accelmometers 24 relative to the drill bit 10 are known and fixed. If the position of the wall 16 relative to the sensors is known, and the positions of the sensors are known, then the absolute position and shape of the wall 16 of the wellbore can be determined.

The drill bit 10 should normally lie substantially on the axis of the part of the bore being drilled. As described hereinbefore, where the wellbore is straight, the tool 18 should not engage the wall 16 of the wellbore, and so any acceleration of the tool body should be as a result of instructions modifying the drilling parameters, for example changing the direction of drilling, and as these accelerations are expected, they can be accounted for and can, if desired, be used to monitor the effect of alteration of the drilling parameters. If the bottom hole assembly is not located within a straight part of the bore, then the tool body may move into contact with the wall of the borehole. In these circumstances, the sensors will produce signais representative of the accelerations experienced by the tool 18 occurring as a result of the tool body 20 colliding or otherwise engaging with the wall of the wellbore.

In practice, the fornlation of straight parts of a wellbore occurs relatively infi-equently as the rotary motion of the drill bits tends to result in the formation of wellbores of spiral form, and these spiralling wellbores are often regarded as being 'straight', even though completion of these parts of the wellbore may be complicated due to their shape. The apparatus described hereinbefore can be used to monitor the formation of these spiralling parts of the wellbore, and the data derived used in determining how completion can best be effected.

As mentioned above, the acceleration readings are double integrated to produce data representative of the positions of the sensors at the time that the accelerations were sensed. As the positions of the sensors are fixed relative to 5 the drill bit, and as some information about the position of the drill bit is known, for example the distance downhole of the drill bit and the fact that it lies on the axis of the wellbore, a three-dimensional image of the wellbore can be derived.

The caliper tool 18 may be operated in several ways. In a simple mode of operation, the caliper tool 18 may simply store the. acceleration readings for 10 subsequent interpretation once the tool 18 has been returned to the surface.

Alternatively, the tool may be atranged to process the data to determine the shape of the bore as the readings are being made. In either case, if desired, the tool 18 may be connected to a system for transmitting data, either in its raw form or its processed form, to the surface to enable an operator to see the shape of the wellbore whilst the tool 18 is within the wellbore. Typically, such transmission of data could be performed using a mud pulse telemetry technique and the transmitter 34.

In order to reduce the quantity of data that must be stored or transmitted, the apparatus may be designed or controlled in such a manner as to permit sensor readings to be taken relatively infiNuently where it is sensed that the wellbore is relatively straight or where the tool occupies a portion of the wellbore of little interest to the operator, the frequency of taking readings, and hence the quality of the data resolution, increasing when it is sensed that the tool occupies a non-straight portion of the wellbore or the tool is located within a portion of the wellbore of greater interest to the operator.

Although in the description hereinbefore the tool body 20 is of diameter and position such that it does not engage the wellbore when the bottom hole assembly is located within a straight part of the wellbore, this need not be the case. If desired, the tool body could be designed in such a manner as to promote engagement between the tool body and the wall of the wellbore in order to increase the number of positive accelerometer readings. For example, the tool body 20 could be located eccentrically relative to the axis of the drill bit as shown in Figure 3. In such circumstances, the shape and position of the tool body must be taken into account when interpreting the sensor readings.

In a modification, rather than mounting the acceleration sensors 22 on a separate caliper tool body 20 secured to the drill bit 10, the caliper tool body 20 may form part of the drill bit 10 (also as shown in Figure 3).

The foregoing descxiption is intended to be illustrative only and it will be appreciated by those skilled in the art that various changes may be made to the embodiments described without departing from the scope of the invention.

Claims (8)

1. An accelerometer caliper while drilling device comprising:
a drill bit having an axis of rotation and a gauge region;
a caliper tool body;
a first accelerometer mounted upon the caliper tool body and arranged to measure acceleration in a first direction; and a second accelerometer mounted upon the caliper tool body and arranged to measure acceleration in a second direction orthogonal to the first direction;
wherein the caliper tool body and the drill bit are coupled to one another in such a manner that the first and second accelerometers are mounted in a known relationship to the drill bit.
2. The accelerometer caliper while drilling device of claim 1, wherein an additional accelerometer is mounted upon the caliper tool body.
3. The accelerometer caliper while drilling device of claim 2, wherein the additional accelerometer is mounted diametrically opposite the first accelerometer.
4. The accelerometer caliper while drilling device of claim 1, wherein at least one of the accelerometers is located at a periphery of the caliper tool body.
5. The accelerometer caliper while drilling device of any one of claims 1 to 4, wherein the caliper tool body is located eccentrically relative to the drill bit.
6. The accelerometer caliper while drilling device of any one of claims 1 to 5, further comprising a magnetometer.
7. A bottom hole assembly comprising a drill bit having an axis of rotation and a gauge region, an accelerometer caliper tool body, a first accelerometer mounted upon the caliper tool body, and arranged to measure acceleration in a first direction, and a second accelerometer mounted upon the caliper tool body and arranged to measure acceleration in a second direction orthogonal to the first direction, wherein the caliper tool body and the drill bit are coupled to one another in such a manner that the first and second accelerometers are mounted in a known relationship to the drill bit, a controller/processor arranged to receive signals from the first and second accelerometers and a mud telemetry transmitter arranged to transmit data under the control of the controller/processor.
8. The bottom hole assembly of claim 7, further comprising a magnetometer.
CA002382974A 2001-04-24 2002-04-23 Accelerometer caliper while drilling Expired - Lifetime CA2382974C (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US09/841659 2001-04-24
US09/841,659 US6467341B1 (en) 2001-04-24 2001-04-24 Accelerometer caliper while drilling

Publications (2)

Publication Number Publication Date
CA2382974A1 CA2382974A1 (en) 2002-10-24
CA2382974C true CA2382974C (en) 2009-07-14

Family

ID=25285409

Family Applications (1)

Application Number Title Priority Date Filing Date
CA002382974A Expired - Lifetime CA2382974C (en) 2001-04-24 2002-04-23 Accelerometer caliper while drilling

Country Status (6)

Country Link
US (1) US6467341B1 (en)
EP (1) EP1253285B1 (en)
AT (1) ATE479825T1 (en)
CA (1) CA2382974C (en)
DE (1) DE60237489D1 (en)
NO (1) NO20021817L (en)

Families Citing this family (32)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1617648A4 (en) * 2003-04-16 2008-06-25 Sharp Kk Radio terminal, base device, wireless system, radio terminal control method, radio terminal control program, and computer-readable recording medium in which that program has been recorded
US7243719B2 (en) * 2004-06-07 2007-07-17 Pathfinder Energy Services, Inc. Control method for downhole steering tool
US7669668B2 (en) * 2004-12-01 2010-03-02 Schlumberger Technology Corporation System, apparatus, and method of conducting measurements of a borehole
US8297378B2 (en) 2005-11-21 2012-10-30 Schlumberger Technology Corporation Turbine driven hammer that oscillates at a constant frequency
US7641003B2 (en) 2005-11-21 2010-01-05 David R Hall Downhole hammer assembly
US8267196B2 (en) 2005-11-21 2012-09-18 Schlumberger Technology Corporation Flow guide actuation
US8528664B2 (en) 2005-11-21 2013-09-10 Schlumberger Technology Corporation Downhole mechanism
US7753144B2 (en) 2005-11-21 2010-07-13 Schlumberger Technology Corporation Drill bit with a retained jack element
US8360174B2 (en) 2006-03-23 2013-01-29 Schlumberger Technology Corporation Lead the bit rotary steerable tool
US7549489B2 (en) 2006-03-23 2009-06-23 Hall David R Jack element with a stop-off
US8522897B2 (en) 2005-11-21 2013-09-03 Schlumberger Technology Corporation Lead the bit rotary steerable tool
US8297375B2 (en) 2005-11-21 2012-10-30 Schlumberger Technology Corporation Downhole turbine
US8225883B2 (en) 2005-11-21 2012-07-24 Schlumberger Technology Corporation Downhole percussive tool with alternating pressure differentials
US8316964B2 (en) 2006-03-23 2012-11-27 Schlumberger Technology Corporation Drill bit transducer device
US7571780B2 (en) 2006-03-24 2009-08-11 Hall David R Jack element for a drill bit
US7398837B2 (en) * 2005-11-21 2008-07-15 Hall David R Drill bit assembly with a logging device
US7954401B2 (en) 2006-10-27 2011-06-07 Schlumberger Technology Corporation Method of assembling a drill bit with a jack element
US7866416B2 (en) 2007-06-04 2011-01-11 Schlumberger Technology Corporation Clutch for a jack element
US8781746B2 (en) * 2007-08-30 2014-07-15 Precision Energy Services, Inc. System and method for obtaining and using downhole data during well control operations
US7967083B2 (en) 2007-09-06 2011-06-28 Schlumberger Technology Corporation Sensor for determining a position of a jack element
US7721826B2 (en) 2007-09-06 2010-05-25 Schlumberger Technology Corporation Downhole jack assembly sensor
US8438917B2 (en) * 2007-09-13 2013-05-14 The Trustees Of Columbia University In The City Of New York Methods of long-term gravimetric monitoring of carbon dioxide storage in geological formations
US8245792B2 (en) * 2008-08-26 2012-08-21 Baker Hughes Incorporated Drill bit with weight and torque sensors and method of making a drill bit
US8701799B2 (en) 2009-04-29 2014-04-22 Schlumberger Technology Corporation Drill bit cutter pocket restitution
US9238958B2 (en) * 2009-09-10 2016-01-19 Baker Hughes Incorporated Drill bit with rate of penetration sensor
US9410377B2 (en) * 2012-03-16 2016-08-09 Baker Hughes Incorporated Apparatus and methods for determining whirl of a rotating tool
US9567844B2 (en) * 2013-10-10 2017-02-14 Weatherford Technology Holdings, Llc Analysis of drillstring dynamics using angular and linear motion data from multiple accelerometer pairs
US10641919B2 (en) 2016-12-14 2020-05-05 Rock Visualization Technology, Llc Passive cased well image logging
US11608735B2 (en) 2018-04-27 2023-03-21 Halliburton Energy Services, Inc. Drill bit position measurement
US11566519B2 (en) * 2020-03-12 2023-01-31 Saudi Arabian Oil Company Laser-based monitoring tool
US11466559B2 (en) * 2020-07-31 2022-10-11 Baker Hughes Oilfield Operations Llc Downhole tool sensor arrangements and associated methods and systems
US11500121B1 (en) 2021-07-29 2022-11-15 Rock Visualization Technology, Llc Gamma ray logging tool assembly

Family Cites Families (71)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US1819923A (en) 1928-10-26 1931-08-18 Schlumberger Prospection Electrical process and apparatus for the determination of the nature of the geological formations traversed by drill holes
US1913293A (en) 1931-09-02 1933-06-06 Schlumberger Conrad Electrical process for the geological investigation of the porous strata traversed by drill holes
US2476137A (en) 1942-05-16 1949-07-12 Schlumberger Well Surv Corp Method of positioning apparatus in boreholes
US2524031A (en) 1945-10-01 1950-10-03 Jan J Arps Apparatus for logging wells
US2573137A (en) 1950-04-21 1951-10-30 Halliburton Oil Well Cementing Electric well logging system
US2677790A (en) 1951-12-05 1954-05-04 Jan J Arps Borehole logging by intermittent signaling
US3058532A (en) 1953-07-15 1962-10-16 Dresser Ind Drill bit condition indicator and signaling system
US2925251A (en) 1954-03-05 1960-02-16 Jan J Arps Earth well borehole drilling and logging system
US3345867A (en) 1964-09-03 1967-10-10 Arps Corp Method and apparatus for measuring rock bit wear while drilling
US3455158A (en) 1967-11-29 1969-07-15 Texaco Inc Logging while drilling system
US4095865A (en) 1977-05-23 1978-06-20 Shell Oil Company Telemetering drill string with piped electrical conductor
US4216536A (en) 1978-10-10 1980-08-05 Exploration Logging, Inc. Transmitting well logging data
US4445578A (en) 1979-02-28 1984-05-01 Standard Oil Company (Indiana) System for measuring downhole drilling forces
US4324297A (en) 1980-07-03 1982-04-13 Shell Oil Company Steering drill string
US4455278A (en) 1980-12-02 1984-06-19 Skf Industrial Trading & Development Company, B.V. Method for producing an object on which an exterior layer is applied by thermal spraying and object, in particular a drill bit, obtained pursuant to this method
ZA823430B (en) 1981-05-22 1983-03-30 Coal Industry Patents Ltd Drill pipe sections
US4346591A (en) 1981-08-21 1982-08-31 Evans Robert F Sensing impending sealed bearing and gage failure
US4445734A (en) 1981-12-04 1984-05-01 Hughes Tool Company Telemetry drill pipe with pressure sensitive contacts
FR2530876A1 (en) 1982-07-21 1984-01-27 Inst Francais Du Petrole ASSEMBLY FOR AN ELECTRICAL CONNECTION THROUGH A FORMED DRIVE OF MULTIPLE ELEMENTS
US4518888A (en) 1982-12-27 1985-05-21 Nl Industries, Inc. Downhole apparatus for absorbing vibratory energy to generate electrical power
US4697650A (en) * 1984-09-24 1987-10-06 Nl Industries, Inc. Method for estimating formation characteristics of the exposed bottomhole formation
US4599904A (en) * 1984-10-02 1986-07-15 Nl Industries, Inc. Method for determining borehole stress from MWD parameter and caliper measurements
US4662458A (en) 1985-10-23 1987-05-05 Nl Industries, Inc. Method and apparatus for bottom hole measurement
US4884071A (en) 1987-01-08 1989-11-28 Hughes Tool Company Wellbore tool with hall effect coupling
US4788544A (en) 1987-01-08 1988-11-29 Hughes Tool Company - Usa Well bore data transmission system
US4903245A (en) 1988-03-11 1990-02-20 Exploration Logging, Inc. Downhole vibration monitoring of a drillstring
US4914433A (en) 1988-04-19 1990-04-03 Hughes Tool Company Conductor system for well bore data transmission
US4829489A (en) 1988-06-01 1989-05-09 Western Atlas International, Inc. Method of determining drill string velocity
GB2228326B (en) 1988-12-03 1993-02-24 Anadrill Int Sa Method for determining the instantaneous rotation speed of a drill string
US4958517A (en) 1989-08-07 1990-09-25 Teleco Oilfield Services Inc. Apparatus for measuring weight, torque and side force on a drill bit
US5058077A (en) 1990-10-09 1991-10-15 Baroid Technology, Inc. Compensation technique for eccentered MWD sensors
US5091644A (en) 1991-01-15 1992-02-25 Teleco Oilfield Services Inc. Method for analyzing formation data from a formation evaluation MWD logging tool
US5160925C1 (en) 1991-04-17 2001-03-06 Halliburton Co Short hop communication link for downhole mwd system
US5313829A (en) 1992-01-03 1994-05-24 Atlantic Richfield Company Method of determining drillstring bottom hole assembly vibrations
FR2688026B1 (en) 1992-02-27 1994-04-15 Institut Francais Petrole SYSTEM AND METHOD FOR ACQUIRING PHYSICAL DATA RELATED TO A CURRENT DRILLING.
US5629623A (en) 1992-07-30 1997-05-13 Schlumberger Technology Corporation Pulsed nuclear magnetism tool for formation evaluation while drilling
US5923167A (en) 1992-07-30 1999-07-13 Schlumberger Technology Corporation Pulsed nuclear magnetism tool for formation evaluation while drilling
US5705927A (en) 1992-07-30 1998-01-06 Schlumberger Technology Corporation Pulsed nuclear magnetism tool for formation evaluation while drilling including a shortened or truncated CPMG sequence
FR2700806B1 (en) 1993-01-27 1995-03-17 Elf Aquitaine Method for determining variations in the morphology of a wellbore.
US5720355A (en) 1993-07-20 1998-02-24 Baroid Technology, Inc. Drill bit instrumentation and method for controlling drilling or core-drilling
BE1007274A5 (en) 1993-07-20 1995-05-09 Baroid Technology Inc Method for controlling the head of drilling core drilling or device and installation for implementing the method.
US5358059A (en) * 1993-09-27 1994-10-25 Ho Hwa Shan Apparatus and method for the dynamic measurement of a drill string employed in drilling
US5511037A (en) 1993-10-22 1996-04-23 Baker Hughes Incorporated Comprehensive method of processing measurement while drilling data from one or more sensors
FR2713700B1 (en) 1993-12-08 1996-03-15 Inst Francais Du Petrole Method and system for controlling the stability of the rotation speed of a drilling tool.
US5473158A (en) 1994-01-14 1995-12-05 Schlumberger Technology Corporation Logging while drilling method and apparatus for measuring formation characteristics as a function of angular position within a borehole
US5475309A (en) 1994-01-21 1995-12-12 Atlantic Richfield Company Sensor in bit for measuring formation properties while drilling including a drilling fluid ejection nozzle for ejecting a uniform layer of fluid over the sensor
FR2720439B1 (en) 1994-05-24 1996-07-05 Inst Francais Du Petrole Method and system for analyzing the behavior of a drill string.
FR2720440B1 (en) 1994-05-24 1996-07-05 Inst Francais Du Petrole Method and system for transmitting a drilling signal.
NO315670B1 (en) 1994-10-19 2003-10-06 Anadrill Int Sa Method and apparatus for measuring drilling conditions by combining downhole and surface measurements
US5581024A (en) 1994-10-20 1996-12-03 Baker Hughes Incorporated Downhole depth correlation and computation apparatus and methods for combining multiple borehole measurements
US5842149A (en) 1996-10-22 1998-11-24 Baker Hughes Incorporated Closed loop drilling system
EP1632643B1 (en) 1995-02-16 2011-06-01 Baker Hughes Incorporated Method and apparatus for monitoring and recording of operating conditions of a downhole drill bit during drilling operations
FR2732403B1 (en) 1995-03-31 1997-05-09 Inst Francais Du Petrole METHOD AND SYSTEM FOR PREDICTING THE APPEARANCE OF MALFUNCTION DURING DRILLING
US5899958A (en) 1995-09-11 1999-05-04 Halliburton Energy Services, Inc. Logging while drilling borehole imaging and dipmeter device
US5740036A (en) 1995-09-15 1998-04-14 Atlantic Richfield Company Method and apparatus for analyzing geological data using wavelet analysis
US5748471A (en) 1996-03-29 1998-05-05 Otatco, Inc. Well collar identification method
US5767674A (en) 1996-04-17 1998-06-16 Griffin; Douglas D. Apparatus for protecting a magnetic resonance antenna
US5947213A (en) 1996-12-02 1999-09-07 Intelligent Inspection Corporation Downhole tools using artificial intelligence based control
WO1998017894A2 (en) 1996-10-22 1998-04-30 Baker Hughes Incorporated Drilling system with integrated bottom hole assembly
US6081116A (en) 1997-04-21 2000-06-27 Baker Hughes Incorporated Nuclear magnetic resonance apparatus and method for geological applications
US5883583A (en) 1997-07-16 1999-03-16 Schlumberger Technology Corporation Imaging a completion string in a wellbore
US5987385A (en) 1997-08-29 1999-11-16 Dresser Industries, Inc. Method and apparatus for creating an image of an earth borehole or a well casing
US6057784A (en) 1997-09-02 2000-05-02 Schlumberger Technology Corporatioin Apparatus and system for making at-bit measurements while drilling
US5886303A (en) 1997-10-20 1999-03-23 Dresser Industries, Inc. Method and apparatus for cancellation of unwanted signals in MWD acoustic tools
US6111408A (en) 1997-12-23 2000-08-29 Numar Corporation Nuclear magnetic resonance sensing apparatus and techniques for downhole measurements
EP1057047B1 (en) 1998-01-16 2008-08-06 Halliburton Energy Services, Inc. Method and apparatus for nuclear magnetic resonance measuring while drilling
US6023164A (en) 1998-02-20 2000-02-08 Numar Corporation Eccentric NMR well logging apparatus and method
US6205851B1 (en) * 1998-05-05 2001-03-27 Baker Hughes Incorporated Method for determining drill collar whirl in a bottom hole assembly and method for determining borehole size
US6065219A (en) 1998-06-26 2000-05-23 Dresser Industries, Inc. Method and apparatus for determining the shape of an earth borehole and the motion of a tool within the borehole
US6158529A (en) 1998-12-11 2000-12-12 Schlumberger Technology Corporation Rotary steerable well drilling system utilizing sliding sleeve
US6109372A (en) 1999-03-15 2000-08-29 Schlumberger Technology Corporation Rotary steerable well drilling system utilizing hydraulic servo-loop

Also Published As

Publication number Publication date
ATE479825T1 (en) 2010-09-15
DE60237489D1 (en) 2010-10-14
US20020152806A1 (en) 2002-10-24
US6467341B1 (en) 2002-10-22
CA2382974A1 (en) 2002-10-24
EP1253285B1 (en) 2010-09-01
NO20021817D0 (en) 2002-04-18
NO20021817L (en) 2002-10-25
EP1253285A3 (en) 2003-07-16
EP1253285A2 (en) 2002-10-30

Similar Documents

Publication Publication Date Title
CA2382974C (en) Accelerometer caliper while drilling
US7743654B2 (en) System, method and apparatus for petrophysical and geophysical measurements at the drilling bit
CA2664522C (en) Instantaneous measurement of drillstring orientation
US7114565B2 (en) Measurement-while-drilling assembly using real-time toolface oriented measurements
US20180223646A1 (en) Gravity acceleration measurement apparatus and extraction method in a rotating state
US9464519B2 (en) Method and apparatus for detecting gamma radiation downhole
CA2881918C (en) Method and apparatus for communicating incremental depth and other useful data to downhole tool
US20070203651A1 (en) Magnetic measurements while rotating
EP1700138B1 (en) Orientation sensor for mwd applications
WO2002044760A2 (en) Rib-mounted logging-while-drilling (lwd) sensors
EP3724447B1 (en) Systems and methods for downhole determination of drilling characteristics
US20150106016A1 (en) Measurement calibration apparatus, methods, and systems
CN110637146A (en) Method for motion measurement of an instrument in a borehole
US6898967B2 (en) Azimuthal resistivity using a non-directional device
US6552334B2 (en) Wellbore caliper measurement method using measurements from a gamma-gamma density
US20180347339A1 (en) Systems and Methods for Detecting Downhole Tool Location Inside a Borehole
GB2377490A (en) Using a gamma-gamma density instrument to determine wellbore diameter and shape
GB2603081A (en) Azimuth determination while rotating

Legal Events

Date Code Title Description
EEER Examination request
MKEX Expiry

Effective date: 20220425