WO2002068796A1 - Determination de la forme d"un trou de forage - Google Patents

Determination de la forme d"un trou de forage Download PDF

Info

Publication number
WO2002068796A1
WO2002068796A1 PCT/GB2002/000790 GB0200790W WO02068796A1 WO 2002068796 A1 WO2002068796 A1 WO 2002068796A1 GB 0200790 W GB0200790 W GB 0200790W WO 02068796 A1 WO02068796 A1 WO 02068796A1
Authority
WO
WIPO (PCT)
Prior art keywords
borehole
sensors
shape
determination apparatus
attribute determination
Prior art date
Application number
PCT/GB2002/000790
Other languages
English (en)
Inventor
Graham Arthur Mcelhinney
Original Assignee
Pathfinder Energy Services 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 Pathfinder Energy Services Limited filed Critical Pathfinder Energy Services Limited
Publication of WO2002068796A1 publication Critical patent/WO2002068796A1/fr

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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
    • E21B47/08—Measuring diameters or related dimensions at the borehole
    • E21B47/085—Measuring diameters or related dimensions at the borehole using radiant means, e.g. acoustic, radioactive or electromagnetic

Definitions

  • the present invention relates to a method and apparatus for determining attributes of a borehole.
  • a borehole attribute determination apparatus comprising at least three sensors mounted on a drill, each sensor being arranged to determine a distance from the sensor to an adjacent side of the borehole.
  • the sensors are mounted on the drill head.
  • the use of the term drill head is not intended to limit the location of the sensors so as to be immediately adjacent a cutting tool part of the drill. Instead, it will be understood that the sensors may be located some distance away from the cutting tool part of the drill.
  • the apparatus further comprises processing means arranged to determine an estimated cross-sectional size and shape for the borehole based upon the distances determined by the sensors.
  • the processing means is arranged to use a predetermined estimate of the cross-sectional size of the borehole to determine the estimated cross-sectional size and shape for the borehole.
  • the sensors are acoustic transducers.
  • the apparatus includes means for sending data from the drill head to the surface whilst the drill head remains in the borehole.
  • the invention is advantageous because it allows information regarding the size and shape of the borehole to be sent to at a very low bit rate of transmission.
  • the bit rate is sufficiently low that the information may be sent as 'measurement while drilling' data.
  • the data sending means comprises a valve located in the drill head and arranged to send the data as pressure waves generated by opening and shutting the valve.
  • additional sensors are provided adjacent the at least three sensors, the additional sensors providing complementary information regarding the borehole.
  • the complementary information is stored within the drill head.
  • the apparatus further comprises processing means arranged to combine the complementary information and the estimated cross-sectional size and shape to provide refined estimated characteristics of the borehole.
  • the processing means comprises a neural network.
  • the apparatus is arranged to obtain six or more distance measurements for a given cross sectional location.
  • the apparatus is provided with six sensors arranged to obtain six different distance measurements for a given cross sectional location.
  • the processing means is arranged to use interpolation to refine an estimate of the size and shape of the borehole, or to estimate variation of the size and shape of the borehole between adjacent measurements.
  • each transducer is arranged to emit a pulse, and the thickness of mud cake located at sides of the borehole is determined by monitoring a first received pulse which is reflected from the mud cake and a second received pulse which is reflected from rock located beyond the mud cake.
  • the processing means is arranged to compare estimates of the shape and size of the borehole at a given location which are determined more than once at different time intervals, to allow variation of the shape and size over time to be measured.
  • At least three sensors are provided close to the drill head, and a further at least three sensors are located at a known separation further from the drill head, thereby allowing distance moved by the drill head to be determined by comparing the estimated borehole size and shape that is monitored by the separated sensors.
  • a method of determining borehole characteristics comprising deploying a least three sensors within the borehole, each sensor being arranged to determine a distance from the sensor to an adjacent side of the borehole, and determining an estimated cross-sectional size and shape for the borehole based upon a predetermined estimate of the size of the borehole.
  • the sensors are acoustic transducers. Any other suitable sensor may be used.
  • data is sent from the borehole to the surface whilst the sensors remain in situ.
  • the data is sent as pressure waves by opening and shutting a valve located in the borehole.
  • the invention is advantageous because it allows information regarding the size and shape of the borehole to be sent to at a very low bit rate of transmission.
  • the bit rate is sufficiently low that the information may be sent as 'measurement while drilling' data.
  • additional sensors are provided adjacent the at least three sensors, the additional sensors providing complementary information regarding the borehole.
  • the complementary information is stored in a memory within the borehole, the memory subsequently being removed from the borehole in order to access the memory.
  • FIG. 1 is a schematic illustration of a drill head which embodies the invention
  • FIGS 2 to 5 are schematic illustrations of boreholes
  • Figure 6 is a illustration of a three-dimensional measurement of a borehole made using the embodiment of the invention.
  • a drill-head which embodies the invention comprises a cylindrical housing 1 onto which are mounted three stand-off blades 2 and three ultrasonic transducers 3.
  • the transducers are embedded in the drill-head housing 1 to protect them from the harsh environment of the borehole.
  • the drill-head is configured to cut a circular hole under ideal drilling conditions.
  • the circumference of the circular hole that would be cut by the drill head referred to hereafter as the minimum circle, is shown as a broken line 4 in figure 1.
  • Each ultrasonic transducer 3 is used to measure the distance from the transducer to the wall of the borehole by emitting an ultrasonic pulse and measuring the time elapsed until the pulse is reflected back to the transducer.
  • the measured distances are transmitted from the drill head to the surface by opening and shutting a valve located at or adjacent the drill head, the valve being arranged to generate pressure waves which travel along the body of the drill to the surface. Transmission of data to the surface using this method is known in the art. Such transmission typically operates at a data rate of between 1 and 5 bits per second.
  • the data transmitted to the surface may comprise a measurement of the rotation of the drill head.
  • the invention is advantageous because in addition to this measurement, it also allows measurement of the distance of the borehole from the drill head in three directions.
  • the extra amount of data to be transmitted is sufficiently small that it does not exceed the bit rate of the pressure wave based data transmission.
  • the distance data is processed at the surface, for example using a personal computer, to determine the shape of the borehole.
  • the distances measured by the transducers 3 are shown in figure 2.
  • the distances are labelled a, b and c for ease of reference.
  • the borehole 5 shown in figure 2 is much bigger than the minimum circle 4, and is elliptical in shape.
  • the distances a, b and c measured by the transducers are used to determine the shape of the borehole.
  • the shape of the borehole could be determined from the three distance measurements a, b and c by using simple interpolation.
  • interpolation in this manner introduces an error since the longest measured distance, in this case a, will always be interpreted as being the long axis of an ellipse. This is shown on Figure 3, where it can be seen that the interpolated borehole shape 6 does not coincide with the actual borehole 5.
  • the embodiment of the invention overcomes this problem using a geometrical calculation.
  • the geometrical calculation may be understood by firstly considering a circular borehole. Referring to figures 1 and 2, if the drill head 1 is placed anywhere within a circular borehole the vector sum of the three measurements a, b and c will be constant.
  • the borehole is a simple ellipse, as shown in Fig 3, then the vector sum of the three measurements a, b and c is greater.
  • the shape of the borehole is derived using the three measurements a, b and c, together with the constant k which has previously been determined.
  • the constant k is determined on the basis of the size of a circular borehole that it is estimated would be drilled under the known conditions.
  • the shape of the borehole is determined using simultaneous equations which determine which measurement includes the greatest asymmetry. First, an asymmetry value is estimated for each measurement:
  • the asymmetry value is then subtracted from the measured value to provide an estimated corrected value, and the corrected value is checked to see whether, together with the measured values, it would yield a circle:
  • Equation 7 The estimated corrected value is deemed to have been found if one of equations 5-7 yields a zero result. For example if equation 7 yields a zero result then this indicates that the estimated corrected value (c-c') has been correctly determined. This indicates that the value c introduced asymmetry into the measured borehole, and the value c' is a measurement of the asymmetry that was introduced.
  • Using the estimated value k is advantageous because it allows a reasonably good determination of the shape of the borehole to be determined whilst requiring the transmission of only a small amount of data to the surface.
  • Three transducers is considered to be the minimum number required to provide useful information regarding the shape of the borehole.
  • more information regarding the shape of a borehole may be obtained by providing more than three transducers on the drill head housing.
  • the transducers may be arranged about the housing in a single ring.
  • Multiple determinations of distances for a borehole region of interest may be obtained by passing the transducers over the region of interest several times, i.e. moving the drill-head back and forth through the region of interest. This is often done during the making of connections, reaming and hole cleaning, new runs etc.
  • the multiple readings would not provide any additional information if they simply measured the same distances twice.
  • Multiple determinations may be obtained using several sets of transducers spaced out along the housing. Using six transducers at once is equivalent to rotating once between two readings taken using three transducers. The result is six transducer distance measurements in different directions, for example as shown in figure 4. The six distance measurements allow the direction and magnitude of the major axis of the ellipse to be determined with greater certainty.
  • any rotation around the long (z) axis will give three extra readings. These can be used to determine the direction of the long axis of an ellipse. They also allow the asymmetry to be solved in a different way from before.
  • the rate of change of the distance measurements a to a', b to b' and c to c' is dependent on their positions with respect to the long axis of the ellipse.
  • the distance, a to a' increasing (+) rapidly will indicate that it is closer to the long axis of the ellipse, whilst b to b' is decreasing slowly and is moving away from the long axis.
  • the position (rotation) of the long axis and its length may be derived from the measurement of a.a',b,b',c and c'.
  • interpolation there are various standard methods for interpolation that may be used to determine the shape of an elliptical borehole, for example the method described above. It is preferred in many methods to determine the length and direction (rotation) of the long axis of the ellipse, and then use this as a starting point for the interpolation.
  • the embodiment of the invention may be used to determine the length and direction (rotation) of the long axis of the ellipse by for example taking multiple measurements as described above.
  • Interpolation may be applied along the long axis of the borehole, i.e. to generate a three-dimensional representation of the borehole.
  • a three-dimensional representation of the borehole may be generated and displayed to an operator as the borehole is being drilled.
  • the shape of a borehole is governed by the mechanical/chemical properties of the rock into which the borehole is drilled, the mechanics of the drill bit, the properties of the drilling fluid and the deviations in the path of the well bore.
  • Properties that may be measured by sensors mounted on the drill head include density, porosity, gamma ray, sonic-velocity, shear wave, resistivity, nuclear magnetic resonance data, weight on bit, rpm of the drill string, drilling fluid properties, etc.
  • Information about these properties may be used to assist in the analysis of the shape of the borehole. For example, from a 'logging whilst drilling' (LWD) tool it may be possible to derive information on the physical and chemical properties of the rock, from the mud analysis the drilling fluid properties can be determined.
  • the rate of penetration, weight on bit, rpm and torque can be measured. This data is not sent to the surface using the pressure wave method, since the amount of data generated significantly exceeds the available bandwidth. Instead, the data is stored and is read when the drill head returns to the surface. The data may be used to assist in the analysis of the shape of the borehole
  • the formation was a homogenous firm sandstone one may expect the borehole to be circular and similar in radius to the drill bit. If the formation was a friable an isotropic clay stone, drilled with under balanced mud. The borehole maybe expected to be elliptical along the major axis of stress within the clay stone.
  • the ultrasound used for the measurement of distance can also be used to determine the thickness of the mud cake.
  • This cake is caused by the loss of fluid to the rock formation surrounding the borehole. When the fluid is lost the surface of the rock acts as a filter and particles build up on its surface. If the formation (rock) is very permeable then the build up can happen quickly and the cake can be thick.
  • the acoustic wave will reflect of both the surface of the mud cake and the rock surface. The difference between these two measurements is the thickness of the mud cake. This information may be very useful when analysing a fluid reservoir. Information about the permeability is of prime importance for maximising oil and gas production.
  • the analysis of the returned acoustic wave can be carried out within the down hole tool and the results sent to the surface as mud cake thickness.
  • Changes in the shape of the borehole over time can be caused by slow swelling clays, washing out of the formations by the borehole fluid, abrasion by stabilisers and other drill string components etc. These can be analysed at any time by repeating measurement over the section of interest within the borehole. This provides an extra dimension to the shape of the borehole i.e. how it changes with time.
  • FIG. 6 An example of a 3D view generated using the invention is shown in figure 6.
  • the embodiment of the invention may be used to measure distance travelled with improved accuracy. This may be done by locating two sets of acoustic transducers at a known separation (for example 100 feet) along a pipe, close to the drill head. A shape feature of the bore will be monitored by the first set of transducers and communicated to the surface. Subsequently, the same shape feature will be monitored by the second set of transducers, indicating that the drill head has travelled the distance of the known transducer separation (100 feet in this example). Continuous monitoring allows the distance travelled to be continually derived.
  • An advantage of the invention is that it allows the direction of stress within a reservoir to be determined using logs and images. This information can be useful when determining well placement for recovery and well drill ability.
  • the depth of the drill head from the surface may be determined using a known standard measurement which is performed from the surface.
  • the embodiment of the invention may use a standard DNSC tool.
  • Software used may be EXCEL1 macros, AUTOCAD 2000, 3D STUDIO MAX 3.

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  • Physics & Mathematics (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geophysics (AREA)
  • Electromagnetism (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics And Detection Of Objects (AREA)
  • Length Measuring Devices Characterised By Use Of Acoustic Means (AREA)

Abstract

L"invention concerne un appareil de détermination des attributs d"un trou de forage comprenant au moins trois capteurs montés sur une tête de forage, chaque capteur étant disposé de manière à déterminer une distance entre le capteur et un côté adjacent du trou de forage. Les capteurs sont, de préférence, des transducteurs acoustiques qui exécutent des diamétrages au niveau de deux distances séparées de la tête de forage, lesquelles peuvent subséquemment être comparées afin de détecter les changements de dimension et de forme du trou de forage.
PCT/GB2002/000790 2001-02-27 2002-02-27 Determination de la forme d"un trou de forage WO2002068796A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GBGB0104838.8A GB0104838D0 (en) 2001-02-27 2001-02-27 Pathfinder
GB0104838.8 2001-02-27

Publications (1)

Publication Number Publication Date
WO2002068796A1 true WO2002068796A1 (fr) 2002-09-06

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WO (1) WO2002068796A1 (fr)

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2004059126A1 (fr) * 2002-12-31 2004-07-15 Services Petroliers Schlumberger Procedes et appareil de mesures de vitesse par ultrason dans des fluides de forage
US7628213B2 (en) 2003-01-30 2009-12-08 Specialised Petroleum Services Group Limited Multi-cycle downhole tool with hydraulic damping
EP2273067A1 (fr) 2009-06-09 2011-01-12 Soilmec S.p.A. Dispositif d'excavation, analyse de profil de l'excavation elle-même et procédé associé
EP2472291A1 (fr) * 2010-12-30 2012-07-04 Services Pétroliers Schlumberger Procédé pour détermination d'épaisseur de cake
WO2016080977A1 (fr) * 2014-11-19 2016-05-26 Halliburton Energy Services, Inc. Caractérisation de forme de trou de forage
WO2020081206A1 (fr) * 2018-10-16 2020-04-23 Halliburton Energy Services, Inc. Mesure dynamique et de mouvement d'outil de fond de trou à multiples transducteurs ultrasonores
CN112033317A (zh) * 2020-09-02 2020-12-04 中煤科工集团西安研究院有限公司 一种载人提升舱逃生孔三维数据在线测量方法
US11741359B2 (en) 2020-05-29 2023-08-29 Saudi Arabian Oil Company Systems and procedures to forecast well production performance for horizontal wells utilizing artificial neural networks

Citations (7)

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Publication number Priority date Publication date Assignee Title
GB2094473A (en) * 1981-03-10 1982-09-15 Standard Oil Co Method and apparatus for logging boreholes
US4548282A (en) * 1982-05-22 1985-10-22 Wirth Maschinen-Und Bohrgerate-Fabrik Gmbh Method for sinking boreholes
GB2200452A (en) * 1986-12-29 1988-08-03 Shell Int Research Acoustic determination of mudcake thickness
US5091644A (en) * 1991-01-15 1992-02-25 Teleco Oilfield Services Inc. Method for analyzing formation data from a formation evaluation MWD logging tool
EP0646697A1 (fr) * 1993-09-30 1995-04-05 Halliburton Company Dispositif et méthode pour mesurer les dimensions dans un trou de sorage
GB2328746A (en) * 1997-08-29 1999-03-03 Dresser Ind Determining the shape of an earth borehole and measuring the acoustic velocity in the earth formation
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

Patent Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2094473A (en) * 1981-03-10 1982-09-15 Standard Oil Co Method and apparatus for logging boreholes
US4548282A (en) * 1982-05-22 1985-10-22 Wirth Maschinen-Und Bohrgerate-Fabrik Gmbh Method for sinking boreholes
GB2200452A (en) * 1986-12-29 1988-08-03 Shell Int Research Acoustic determination of mudcake thickness
US5091644A (en) * 1991-01-15 1992-02-25 Teleco Oilfield Services Inc. Method for analyzing formation data from a formation evaluation MWD logging tool
EP0646697A1 (fr) * 1993-09-30 1995-04-05 Halliburton Company Dispositif et méthode pour mesurer les dimensions dans un trou de sorage
GB2328746A (en) * 1997-08-29 1999-03-03 Dresser Ind Determining the shape of an earth borehole and measuring the acoustic velocity in the earth formation
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

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
MARANUK C A: "ACOUSTIC MWD CALIPER IMPROVES ACCURACY WITH DIGITAL-SIGNAL TECHNOLOGY", OIL AND GAS JOURNAL, PENNWELL PUBLISHING CO. TULSA, US, vol. 96, no. 9, 2 March 1998 (1998-03-02), pages 80 - 82,84-85,87, XP000767764, ISSN: 0030-1388 *

Cited By (14)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2004059126A1 (fr) * 2002-12-31 2004-07-15 Services Petroliers Schlumberger Procedes et appareil de mesures de vitesse par ultrason dans des fluides de forage
EP1441105A1 (fr) * 2002-12-31 2004-07-28 Services Petroliers Schlumberger Méthode et dispositif pour mesurer la vitesse d'ultrasons dans les fluides de forage
US7418865B2 (en) 2002-12-31 2008-09-02 Schlumberger Technology Corporation Method and apparatus for ultrasound velocity measurements in drilling fluids
US7628213B2 (en) 2003-01-30 2009-12-08 Specialised Petroleum Services Group Limited Multi-cycle downhole tool with hydraulic damping
EP2273067A1 (fr) 2009-06-09 2011-01-12 Soilmec S.p.A. Dispositif d'excavation, analyse de profil de l'excavation elle-même et procédé associé
US8065813B2 (en) 2009-06-09 2011-11-29 Soilmec S.P.A. Excavation device and profile analyses of the excavation itself and associated method
EP2472291A1 (fr) * 2010-12-30 2012-07-04 Services Pétroliers Schlumberger Procédé pour détermination d'épaisseur de cake
US9081121B2 (en) 2010-12-30 2015-07-14 Schlumberger Technology Corporation Method for a mud cake thickness determination
WO2016080977A1 (fr) * 2014-11-19 2016-05-26 Halliburton Energy Services, Inc. Caractérisation de forme de trou de forage
US10509140B2 (en) 2014-11-19 2019-12-17 Halliburton Energy Services, Inc. Borehole shape characterization
WO2020081206A1 (fr) * 2018-10-16 2020-04-23 Halliburton Energy Services, Inc. Mesure dynamique et de mouvement d'outil de fond de trou à multiples transducteurs ultrasonores
US11519255B2 (en) 2018-10-16 2022-12-06 Halliburton Energy Services, Inc. Downhole tool dynamic and motion measurement with multiple ultrasound transducer
US11741359B2 (en) 2020-05-29 2023-08-29 Saudi Arabian Oil Company Systems and procedures to forecast well production performance for horizontal wells utilizing artificial neural networks
CN112033317A (zh) * 2020-09-02 2020-12-04 中煤科工集团西安研究院有限公司 一种载人提升舱逃生孔三维数据在线测量方法

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