EP0857855B1 - Bohrlochrichtungsmesssystem - Google Patents

Bohrlochrichtungsmesssystem Download PDF

Info

Publication number
EP0857855B1
EP0857855B1 EP19970300746 EP97300746A EP0857855B1 EP 0857855 B1 EP0857855 B1 EP 0857855B1 EP 19970300746 EP19970300746 EP 19970300746 EP 97300746 A EP97300746 A EP 97300746A EP 0857855 B1 EP0857855 B1 EP 0857855B1
Authority
EP
European Patent Office
Prior art keywords
inclination angle
wellbore
inclinometer
point
downhole
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
EP19970300746
Other languages
English (en)
French (fr)
Other versions
EP0857855A1 (de
Inventor
Patrick E. Dailey
Charles D. Barron
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.)
Halliburton Energy Services Inc
Original Assignee
Halliburton Energy Services Inc
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 Halliburton Energy Services Inc filed Critical Halliburton Energy Services Inc
Priority to EP19970300746 priority Critical patent/EP0857855B1/de
Publication of EP0857855A1 publication Critical patent/EP0857855A1/de
Application granted granted Critical
Publication of EP0857855B1 publication Critical patent/EP0857855B1/de
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

Links

Images

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
    • E21B47/02—Determining slope or direction
    • E21B47/022—Determining slope or direction of the borehole, e.g. using geomagnetism

Definitions

  • the present invention relates to a downhole directional measurement system. More particularly, the invention relates to a system for determining the inclination of a bottom-hole assembly as part of a measurement while drilling (“MWD”) system or a logging while drilling (“LWD”) system, and to a system for determining the inclination of the hole at the drill bit to permit more precise control of the direction in which the bottom-hole assembly is drilled. Still more particularly, the present invention relates to an MWD system that indirectly determines the inclination of the hole at the drill bit by using measurements from two separate inclinometer sensors positioned at discrete locations in the bottom-hole assembly.
  • MWD measurement while drilling
  • LWD logging while drilling
  • Such information typically includes the location and orientation of the wellbore and drilling assembly, earth formation properties, and drilling environmental parameters downhole.
  • Directional information relating to surveying the location of the wellbore, and controlling or "steering" the drilling assembly, will be discussed later.
  • Oil well logging has been known in the industry for many years as a technique for providing information to a driller regarding the particular earth formation being drilled.
  • a probe or "sonde” housing formation sensors is lowered into the borehole after some or all of the well has been drilled, and is used to determine certain characteristics of the formations traversed by the borehole.
  • the sonde is supported by a conductive wireline, which attaches to the sonde at the upper end. Power is transmitted to the sensors and instrumentation in the sonde through the conductive wireline. Similarly, the instrumentation in the sonde communicates information to the surface by electrical signals transmitted through the wireline.
  • MWD measurement-while-drilling
  • LWD logging while drilling
  • MWD sensor The most common type of MWD sensor is a directional or directional orientation (synonymous terms) sensor.
  • Directional MWD sensors typically comprise a three axis accelerometer and a three axis magnetometer, housed together in the same directional orientation sensor. See “State of the Art in MWD," International MWD Society (January 1993).
  • drill string tubing is made of steel, which is a magnetic material.
  • the sub housing the directional sensors typically comprises a length of tubing made of a non-magnetic material.
  • the sub containing the directional sensors is positioned a relatively large distance above the drill bit and/or motor. For example, when a motor is used in the bottomhole assembly, the directional sensor typically is located approximately 50 feet or more above the drill bit.
  • wellbore directional measurements can be made as follows: a three axis accelerometer measures the earth's gravitational field vector, relative to the tool axis and a point along the circumference of the tool called the tool face scribe line. From this measurement, the inclination of the bottomhole assembly can be determined to provide an indication of the deviation of the wellbore with respect to vertical.
  • the three axis accelerometer also provides a measure of "tool face angle," which is the orientation (rotational about the tool axis) angle between the scribe line and the high side of the wellbore.
  • a three axis magnetometer measures the earth's magnetic field vector in a similar manner. From the combined magnetometer and accelerometer data, the azimuth and magnetic tool face angle of the tool may be determined. As one skilled in the art will understand, azimuth is the horizontally projected direction of the wellbore relative to North.
  • the inclination measured by the three axis accelerometer in the directional sub may or may not be a fair representation of the inclination at the bit.
  • the build rate of the well may exceed 10° per 100 feet.
  • the inclination measured at the directional sensor may not accurately reflect the inclination at the bit. Inclination is an extremely important parameter for the driller to consider when making decisions regarding course changes and corrections, and the like.
  • GB 2,086,055A discloses a borehole survey system for surveying a borehole or mine shaft to determine its trajectory using a sensing probe with two spaced sets of accelerometers in sections measuring the components of the gravity vector along orthogonal axes at successive positions along the borehole.
  • the two sets of accelerometers are connected by a pipe or cable which is flexible to bend but torsionally stiff.
  • the angular orientation of the two accelerometer sets relative to each other about the borehole axis is fixed by the pipe or cable so that any difference in orientation of the two sets is a function of the local trajectory of the borehole.
  • Two sets of accelerometer output signals representing gravity vector components at positions spaced apart along the axis of the borehole are utilized to derive the borehole inclination at each position as well as the change in borehole azimuth angle between the positions of the accelerometer sets.
  • the accelerometer signals and a signal representing the position of the probe along the length of the borehole are combined to provide a three dimensional representation of the borehole trajectory, relative to a reference point eg the termination of the borehole at the surface.
  • the present invention solves the shortcomings and deficiencies of the prior art by providing a system for indirectly determining inclination at the bottom of a wellbore.
  • the system includes a standard directional sensor located in its normal position in the wellbore.
  • a second inclinometer is positioned in the bottomhole assembly as close to the drill bit as possible. In situations where a motor is used, the second inclinometer is positioned just above the motor.
  • the second inclinometer provides a second reference point (B) of inclination at a position closer to the bit than the location (A) of the standard inclination measurement.
  • the present invention uses the first and second inclination measurements, together with information regarding the configuration of the bottomhole assembly (BHA), and may also include the use of drilling tendencies to extrapolate the inclination of the wellbore at the drill bit.
  • configuration when used herein in reference to the bottomhole assembly, includes but is not limited to, the geometry and material properties of the BHA, and also includes stabilization type(s) (gauge, shape, etc.) and point(s) (or position), and bit type and characteristics as well.
  • the first and second inclination measurements provide two points of reference which, taken together with information regarding the configuration of the bottomhole assembly between the inclinometers (segment C) and between the drill bit and second inclinometer (segment D), and other information relating to drilling tendencies, can provide relatively accurate information regarding inclination at the bit, using an appropriate BHA model.
  • the information relating to the configuration of the BHA typically is entered into the surface processor and can be stored in memory for retrieval later. Other parameters also can be used in the BHA model to increase the accuracy with which the wellbore inclination angle at the bit is determined.
  • the MWD system includes a downhole processor or controller for controlling the operation of the MWD sensors, including the second inclinometer.
  • the downhole processor obtains desired information from the sensors, encodes that information, and transmits that information to the surface processor via a mud pulse signal.
  • the present invention provides a downhole directional measurement system to determine an inclination angle ⁇ of a wellbore at a point in either a definable vicinity of the wellbore bottom or in a projected path of the wellbore, comprising:
  • the means for storing information relating to the configuration of the bottomhole assembly stores configuration information relating to the configuration of the bottomhole assembly between the first measurement point (a) and the second measurement point (b) and between the second measurement point (b) and the point at which the inclination angle ⁇ is to be determined.
  • the system may form part of an MWD system or a wireline system.
  • a surface processor is preferably coupled to said first inclinometer and said second inclinometer for receiving said signals therefrom, and for producing the inclination angle ⁇ .
  • a controller is preferably positioned downhole, which connects electrically to said first and second inclinometers.
  • the controller may selectively activate said inclinometers.
  • a mud pulser is connected to said downhole controller for transmitting a mud pulse signal indicative of the output signals from said first and second inclinometers.
  • the controller may include a memory for storing information relating to the configuration of the bottomhole drilling assembly.
  • the controller can use said configuration information and said output signals from said first and second inclinometer to determine said inclination angle ⁇ .
  • a stabilizer may also be provided, and said configuration information may include the location and size of said stabilizer.
  • a bend may be provided in said system and said configuration information may include the degree and location of the bend.
  • the system includes a sensor for measuring additional directional information, and providing an output signal indicative thereof.
  • the downhole controller may connect electrically to said sensor and receives said output signal from said sensor.
  • the controller may use drilling tendency information and said output signals from said first and second inclinometer to determine said inclination angle ⁇ .
  • the drilling tendency information may include weight-on-bit.
  • upstream and downstream are used to denote the relative position of certain components with respect to the direction of flow of the drilling mud.
  • upstream from another, it is intended to mean that drilling mud flows first through the first component before flowing through the second component.
  • the terms as “above”, “upper” and “below” are used to identify the relative position of components in the bottom hole assembly, with respect to the distance to the surface of the well, measured along the borehole path.
  • inclination angle of the wellbore at the bit or similar phrases which relate to the inclination angle at the bottom of the wellbore, are used herein to refer to the inclination angle of the wellbore at a point located either in the definable vicinity of the borehole bottom, or in the projected path of the wellbore, (which has not yet been drilled). These phrases do not limit the ultimately desired inclination angle to the wellbore inclination angle at the bottom of the wellbore (ie., the bit location during drilling).
  • a typical drilling installation which includes a drilling rig 10, constructed at the surface of the well, supporting a drill string.
  • the drill string penetrates through a rotary table 31 and into a borehole that is being drilled through earth formations.
  • the drill string includes a Kelly at its upper end, drill pipe 34 coupled to the Kelly, and a bottomhole assembly 75 (commonly referred to as a "BHA") coupled to the lower end of the drill pipe 34.
  • BHA bottomhole assembly 75
  • the BHA 75 typically includes drill collars, directional MWD sensors located in a non-magnetic section 60, other MWD sensors positioned in a separate collar section 55, a downhole motor 40, a drill bit 32 and one or more stabilizer(s) (not shown) for penetrating through earth formations to create the borehole.
  • the drill collars (which also may be non-magnetic so as not to interfere with the MWD measurements) are used, in accordance with conventional techniques, to add weight to the drill bit 32 and to stiffen the BHA 75, thereby enabling the BHA 75 to transmit weight to the drill bit 32 without buckling.
  • the weight applied through the drill collars to the bit 32 permits the drill bit to penetrate the underground formations.
  • drilling fluid or mud is pumped from a mud pit 55 at the surface through the kelly hose, into the drill pipe, to the drill bit 32, in the direction of arrows 68.
  • the drilling fluid rises back to the surface, in the direction of arrows 70, through the annular area between the drill pipe 34 and the borehole, where it is filtered and returned to the mud pit 55.
  • the drilling fluid is used to lubricate the drill bit 32 and to remove cuttings from the borehole.
  • a downhole motor or turbine 40 may be used downhole to rotate the drill bit 32 as an alternative, or in addition to, rotating the drill string from the surface.
  • the BHA 75 typically is defined as all of the downhole components from the top of the drill collars, down to and including the drill bit 32, including downhole motor 40.
  • a downhole motor 40 is an optional component which may be omitted from the BHA 75 if desired.
  • the BHA 75 preferably includes a measurement while drilling system 30 (referred to herein as an "MWD system"), which may be considered part of the drill collar section.
  • the MWD system 30 typically includes directional MWD sensors 38, 39 housed in the non-magnetic sub 60 (or drill collar), and can include formation sensors 51, as well.
  • the formation sensors 51 may include gamma, resistivity, and other sensors (ie sonic, density and neutron sensors) in accordance with normal industry practice.
  • drilling mechanics sensors may be provided, such as weight-on-bit (WOB), torque-on-bit (TOB), shock, vibration, etc. See generally "State of the Art in MWD," International MWD Society (January 19, 1993).
  • a downhole controller 65 preferably controls the operation of a signalling unit and orchestrates the operation of the MWD sensors and components. As shown in Figure 2, the controller 65 may be located in sub 60 or elsewhere in the MWD system 30.
  • the downhole data signalling unit 35 preferably is provided as part of the MWD system 30 and in used to transmit sensed values to a surface receiver 105 via a mud pulse acoustic signal.
  • the downholes system may also include the capability of receiving mud pulse signals from the surface to control the operation or activation of certain MWD sensors or other downhole components.
  • the signalling unit in the preferred embodiment comprises a mud pulser unit housed in a non-magnetic sub in accordance with conventional industry practice.
  • the downhole controller 65 may include appropriate data encoding circuitry, which produces sequentially encoded digital data signals representative of the measurements obtained by the downhole sensors.
  • the controller 65 processes the data received from the sensors and produces encoded signals indicative of a portion or all of the received signals for transmission to the surface via a mud pulse signal.
  • the controller 65 also may make decisions based upon the processed data.
  • the present invention preferably includes a conventional MWD system 30, which includes at least a directional sensor.
  • the present invention adds a second inclinometer 80 that connects electrically and mechanically to the conventional MWD system 30.
  • the second inclinometer 80 is positioned in the bottom hole assembly as close as possible to the drill bit 32.
  • the non-magnetic section 60 contains the directional sensors 38,39.
  • the directional sensors 38,39 in sub 60 are selected and adapted as required for the particular drilling operation, to measure such downhole parameters as the inclination and azimuth of the BHA at point A.
  • the directional MWD sensors 38,39 typically comprise a three axis magnetometer and a three axis accelerometer, preferably housed together in the same sub 60. See “State of the Art in MWD,” International MWD Society (January 1993), the teachings of which are incorporated herein.
  • the non-magnetic section 60 containing the directional sensors is positioned a relatively large distance above the drill bit (approximately 15.24 m (50 feet) or more when a motor is used), in accordance with normal practice.
  • the three axis accelerometer 39 measures the earth's gravitational vector, relative to the tool axis and a point along the circumference of the tool called the scribe line. From this measurement, the inclination angle ⁇ of the bottomhole assembly at point A can be obtained.
  • the three axis accelerometer also provides a measure of "tool face,” which is the angle between the scribe line (which may be located on a particular took), relative to the high side of the wellbore.
  • the three axis magnetometer 38 measures the earth's magnetic field vector relative to the axis of the tool, and to the same tool face scribe line to thereby determine the magnetic tool face. From combined magnetometer and accelerometer readings, the azimuth of the tool at point A may be determined.
  • the inclination measured by the three axis accelerometer in the directional MWD system 30 represents the inclination at point A. This inclination may or may not be a fair representation of the inclination at the bit 32.
  • directional sensor 80 preferably is provided in the bottomhole assembly 75 below the conventional MWD system 30. If a motor 40 is included in the bottomhole assembly 75, the directional sensor preferably is located directly above the motor 40.
  • the directional sensor 80 preferably comprises a three axis inclinometer for measuring the inclination angle ⁇ of the BHA 75 at point B.
  • a single z axis inclinometer may be used instead of the three axis inclinometer in horizontal drilling applications (where drilling is being performed between approximately 20° and 160° of inclination).
  • the inclination angle ⁇ measured by inclinometer 80 at point B is used in conjunction with the inclination angle ⁇ reading from the three axis inclinometer at point A, along with other BHA and drilling tendency information, to indirectly determine the inclination angle ⁇ of the wellbore at the drill bit 32, through the use of an inclination extrapolation model, as described below.
  • step 202 the downhole controller 65 obtains inclination information from the first inclinometer sensor 39 reflecting the inclination angle ⁇ at point A.
  • step 204 the controller 65 obtains an inclination reading from inclinometer 80 reflecting the inclination angle ⁇ at point B.
  • the controller preferably sends a mud pulse signal to the surface processor 100 reflecting these values to enable the surface processor to perform steps 206 and 208.
  • downhole controller 65 may perform these steps if the necessary configuration information is available or provided to controller 65.
  • step 206 surface processor retrieves information relating to the configuration of BHA 75 at segments C and D.
  • Segment C represents the configuration of BHA 75 between the two inclinometers 39, 80.
  • Segment D represents the configuration of BHA 75 between inclinometer 80 and the bit.
  • the surface processor 100 applies the known data to an appropriate BHA model, which preferably is similar to a conventional program used by most drillers to predict the drilling path of a BHA. See e.g. J.S. Williamson, et al. "Predicting Bottomhole Assembly Performance," IADC/SPE 14764, presented in Dallas, Texas on February 10-12, 1986, the teaching of which are incorporated by reference.
  • the known values include inclination angle ⁇ at point A, inclination angle ⁇ at point B, the configuration (including orientation and length) of segments C and D, and other data indicative of drilling tendencies, including weight-on-bit, size and location of stabilizers, and the location and degree of bend angles of bent subs and bent housings. See U.S. Patent No. Re. 33,751, the teachings of which are incorporated by reference. From these values, and with the use of an appropriate inclination extrapolation model, the inclination angle ⁇ of the hole at the drill bit can be determined with a reasonable degree of accuracy in step 208.

Landscapes

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

Claims (10)

  1. Ein direktionales Tieflochmeßsystem für das Bestmimen eines Neigungswinkels  eines Bohrlochs an einem Punkt (32) entweder in der definierbaren Nähe des Bohrlochbodens oder in einem projizierten Pfad des Bohrlochs, welches das Folgende umfasst:
    ein Bohrlochgerät (75), welches das Folgende umfasst: einen ersten Neigungsmesser (39) für das Messen eines ersten Neigungswinkels α an einem ersten Meßpunkt (a) über dem Punkt (32), an welchem der Neigungswinkel  bestimmt werden soll, und das Produzieren eines indikativen Ausgabesignls; und
    einen zweiten Neigungsmesser (80) für das Messen eines zweiten Neigungswinkels β an einem zweiten Meßpunkt (b) über dem Punkt (32), an welchem der Neigungswinkel  bestimmt werden soll, und das Produzieren eines indikativen Ausgabesignls; und
    ein Apparat für das Speichern von Information bezüglich der Konfigurierung des Bohrlochgerätes (75), wobei das vorgenannte System weiter durch das Folgende charakterisiert wird:
    ein Apparat (65, 100) für das Bestimmen des Neigungswinkels  des Bohrlochs durch das Extrapolieren mit Hilfe der vorgenannten Konfigurierinformation und der vorgenannten gemessenen Neigungswinkel α und β.
  2. Ein direktionales Tieflochmeßsystem nach Anspruch 1, bei dem der vorgenannte Apparat für das Speichern von Information bezüglich der Konfigurierung des Bohrlochgerätes Konfigurierinformation speichert, die sich auf das Konfigurieren des Bohrlochgerätes zwischen dem ersten Meßpunkt (a) und dem zweiten Meßpunkt (b), und zwischen dem zweiten Meßpunkt (b) und dem Punkt (32) bezieht, an dem der Neigungswinkel  bestimmt werden soll.
  3. Ein System nach Anspruch 1 oder 2, das weiter einen Oberflächen-Prozessor (100) umfasst, welcher die Ausgabesignale des ersten Neigungsmessers (39) und des zweiten Neigungsmessers (80) empfängt, und den Neigungswinkel  des Bohrlochs durch das Extrapolieren der vorgenannten Konfigurierinformation und der vorgenannten Neigungswinkel α und β bestimmt.
  4. Ein System nach Anspruch 3, das weiter einen Sensor (38) für das Messen von zusätzlicher direktionaler Information umfasst, und ein indikatives Ausgabesignal liefert, und wobei der vorgenannte Oberflächen-Prozessor (105) die vorgenannte zusätzliche direktionale Information empfängt, und die vorgenannten Ausgabesignale von den vorgenannten ersten (39) und zweiten Neigungsmessern (80) als Teil eines Spülschlammpulssignals empfängt, und diese Signale für das Bestimmen des vorgenannten Neigungswinkels  verwendet.
  5. Ein System nach Anspruch 1, 2 oder 3, das weiter einen Kontroller (65) in dem Tiefloch umfasst, welcher elektrisch mit dem ersten (39) und dem zweiten (80) Neigungsmesser verbunden ist.
  6. Ein System nach Anspruch 5, bei dem der vorgenannte Kontroller (65) wahlweise die vorgenannten Neigungsmesser (39, 80) aktiviert.
  7. Ein System nach Anspruch 5 oder 6, das weiter einen Spülschlammpulsierer (35) umfasst, der mit dem vorgenannten Tiefloch-Kontroller (65) verbunden ist und ein Spülschlammpulssignal überträgt, das für die Ausgabesignale von dem ersten (39) und dem zweiten (80) Neigungsmesser indikativ ist.
  8. Ein System nach Anspruch 5, 6 oder 7, bei dem der vorgenannte Kontroller (65) einen Speicher für das Aufzeichnen von Information bezüglich der Konfigurierung des Bohrlochgerätes (75) umfasst.
  9. Ein System nach Anspruch 7 oder 8, bei dem der vorgenannte Kontroller (65) die vorgenannte Konfigurierinformation und die vorgenannten Ausgabesignale von den vorgenannten ersten (39) und zweiten (80) Neigungsmessern für das Bestimmen des vorgenannten Neigungswinkels  verwendet.
  10. Ein System nach Anspruch 9, das weiter ein Stabilisiergerät umfasst, und bei dem die vorgenannte Konfigurierinformation den Standort und die Grösse des vorgenann ten Stabilisiergerätes einschliesst.
EP19970300746 1997-02-06 1997-02-06 Bohrlochrichtungsmesssystem Expired - Lifetime EP0857855B1 (de)

Priority Applications (1)

Application Number Priority Date Filing Date Title
EP19970300746 EP0857855B1 (de) 1997-02-06 1997-02-06 Bohrlochrichtungsmesssystem

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP19970300746 EP0857855B1 (de) 1997-02-06 1997-02-06 Bohrlochrichtungsmesssystem

Publications (2)

Publication Number Publication Date
EP0857855A1 EP0857855A1 (de) 1998-08-12
EP0857855B1 true EP0857855B1 (de) 2002-09-11

Family

ID=8229206

Family Applications (1)

Application Number Title Priority Date Filing Date
EP19970300746 Expired - Lifetime EP0857855B1 (de) 1997-02-06 1997-02-06 Bohrlochrichtungsmesssystem

Country Status (1)

Country Link
EP (1) EP0857855B1 (de)

Families Citing this family (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2000009857A1 (en) * 1998-08-17 2000-02-24 Sasol Mining (Proprietary) Limited Method and apparatus for exploration drilling
GB9818117D0 (en) * 1998-08-19 1998-10-14 Halliburton Energy Serv Inc Surveying a subterranean borehole using accelerometers
DE19837546C2 (de) * 1998-08-19 2001-07-26 Bilfinger Berger Bau Meßvorrichtung zum Bestimmen der Ausrichtung und des Verlaufs eines Bohrgestänges
DE19846137C2 (de) * 1998-10-07 2002-08-29 Keller Grundbau Gmbh Verfahren und Vorrichtung zum Vermessen eines Bohrlochs
EP1126129A1 (de) * 2000-02-18 2001-08-22 Brownline B.V. Litesystem zum Horizontalrichtbohren
GB2581674B (en) 2017-12-15 2022-05-18 Halliburton Energy Services Inc Azimuth determination while rotating
GB2587944B (en) * 2018-08-02 2022-07-06 Halliburton Energy Services Inc Inferring orientation parameters of a steering system for use with a drill string

Family Cites Families (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
SU746094A2 (ru) * 1976-12-27 1980-07-07 Московский Ордена Трудового Красного Знамени Институт Нефтехимической И Газовой Промышленности Им. И.М.Губкина Устройство контрол положени забо
AU533909B2 (en) * 1980-10-23 1983-12-15 Sundstrand Data Control, Inc. Bore-hole survey apparatus
SU1439223A1 (ru) * 1987-03-03 1988-11-23 Всесоюзный Научно-Исследовательский И Проектно-Конструкторский Институт Геофизических Методов Исследований,Испытания И Контроля Нефтегазоразведочных Скважин Устройство дл контрол положени забо
CA2024061C (en) * 1990-08-27 2001-10-02 Laurier Emile Comeau System for drilling deviated boreholes

Also Published As

Publication number Publication date
EP0857855A1 (de) 1998-08-12

Similar Documents

Publication Publication Date Title
US5646611A (en) System and method for indirectly determining inclination at the bit
US7207215B2 (en) System, method and apparatus for petrophysical and geophysical measurements at the drilling bit
US7730967B2 (en) Drilling wellbores with optimal physical drill string conditions
US6184685B1 (en) Mulitiple spacing resistivity measurements with receiver arrays
US7591314B2 (en) Measurement-while-fishing tool devices and methods
US4445578A (en) System for measuring downhole drilling forces
US8286729B2 (en) Real time misalignment correction of inclination and azimuth measurements
CN103998713B (zh) 用于自动钻压传感器校准和调节钻柱的屈曲的系统和方法
US4662458A (en) Method and apparatus for bottom hole measurement
US6206108B1 (en) Drilling system with integrated bottom hole assembly
AU2015346664B2 (en) Methods and apparatus for monitoring wellbore tortuosity
US8362915B2 (en) System and method for determining stretch or compression of a drill string
WO2019240994A1 (en) Gas ratio volumetrics for reservoir navigation
US11867051B2 (en) Incremental downhole depth methods and systems
WO1998017894A9 (en) Drilling system with integrated bottom hole assembly
US11414976B2 (en) Systems and methods to control drilling operations based on formation orientations
EP0857855B1 (de) Bohrlochrichtungsmesssystem
CA1134257A (en) System for measuring downhole drilling forces
US20230102885A1 (en) Drilling system with directional survey transmission system and methods of transmission

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): FR GB NL

17P Request for examination filed

Effective date: 19980820

AKX Designation fees paid

Free format text: FR GB NL

RBV Designated contracting states (corrected)

Designated state(s): FR GB NL

17Q First examination report despatched

Effective date: 20000929

GRAG Despatch of communication of intention to grant

Free format text: ORIGINAL CODE: EPIDOS AGRA

GRAG Despatch of communication of intention to grant

Free format text: ORIGINAL CODE: EPIDOS AGRA

GRAH Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOS IGRA

GRAH Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOS IGRA

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): FR GB NL

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

ET Fr: translation filed
PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

26N No opposition filed

Effective date: 20030612

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: NL

Payment date: 20110216

Year of fee payment: 15

REG Reference to a national code

Ref country code: NL

Ref legal event code: V1

Effective date: 20120901

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20120901

REG Reference to a national code

Ref country code: FR

Ref legal event code: PLFP

Year of fee payment: 20

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GB

Payment date: 20160127

Year of fee payment: 20

Ref country code: FR

Payment date: 20160125

Year of fee payment: 20

REG Reference to a national code

Ref country code: GB

Ref legal event code: PE20

Expiry date: 20170205

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Free format text: LAPSE BECAUSE OF EXPIRATION OF PROTECTION

Effective date: 20170205