EP0336490A1 - Verfahren zum Steuern eines Bohrvorganges - Google Patents

Verfahren zum Steuern eines Bohrvorganges Download PDF

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Publication number
EP0336490A1
EP0336490A1 EP89200796A EP89200796A EP0336490A1 EP 0336490 A1 EP0336490 A1 EP 0336490A1 EP 89200796 A EP89200796 A EP 89200796A EP 89200796 A EP89200796 A EP 89200796A EP 0336490 A1 EP0336490 A1 EP 0336490A1
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EP
European Patent Office
Prior art keywords
drilling
loading
downhole
torque
recited
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP89200796A
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English (en)
French (fr)
Inventor
Christian Wick
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Anadrill International SA
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Anadrill International SA
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Filing date
Publication date
Application filed by Anadrill International SA filed Critical Anadrill International SA
Publication of EP0336490A1 publication Critical patent/EP0336490A1/de
Withdrawn legal-status Critical Current

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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions

Definitions

  • Another type of interruption to the drilling process may occur with the downhole failure of an electronic circuit or some other component in a measurement while drilling tool. Failures of this nature may reduce the effectiveness of the drilling process and may require a shorter interruption while the drill string is tripped out of the hole and the malfunctioning component or tool replaced.
  • a third type of interruption to the drilling process may occur with the premature wearing of a drill bit or a directional control tool such as a bent housing or stabilizer. It is therefore an object of the current invention to provide quantified information regarding the accumulated load applied to a drilling component in order to provide the basis of an informed decision about when to replace a component or when to perform preventive maintenance.
  • drilling process In addition to the type of failures notes above which reduce the efficiency of the drilling process by occasioning drilling interruptions, it is also possible for the drilling process to be performed without failures but at a less than optimal efficiency.
  • a large variety of different types of drilling bits are currently available to choose from: each designed to function most efficiently under a specific set of circumstances. If the design of a particular bit produces unnecessary vibrations, the drill bit may "skip" or chatter during drilling without permitting its teeth to adequately engage the formation being drilled and its effectiveness is seriously reduced. Detection of conditions in which the bit is functioning in a manner not intended by its designers would permit the driller to either change the drilling conditions to optimize the extraction of formation material or to change the bit by making a bit trip.
  • BHA Bottom Hole Assembly
  • the design of the best Bottom Hole Assembly (BHA) and the selection of the appropriate bit depends heavily on previous empirical observation in offset boreholes in the same field or in boreholes drilled under similar conditions in similar formations in other fields. It is equally not surprising that the BHA design used in a particular job is sometimes not optimally suited for either the drilling conditions as they actually develop or the rock formations actually encountered. It is therefore an object of the present invention to provide a system and method for providing quantified information on the "roughness" of the drilling operation in order to better enable the drilling operator to determine whether the design of the BHA is satisfactory for the conditions and formations encountered.
  • U.S. Patent 4,285,236 describes a system for the coninuous monitoring of both rotary torque and RPM of the drill string.
  • U.S. Patent 4,250,758 describes a system which includes a torque meter that measures dynamic torque while drilling. This system averages the time period of individual oscillations in the torque for a fixed number of oscillations and indicates the lenght of the average time in order to better enable determination of the probable cause of the oscillations.
  • U.S. Reissue Patent 28,436 describes a system for determining the actual failure of a downhole drilling bit by monitoring deviations from the expected characteristic oscillations in the torque of the drill string.
  • U.S. Patent 3,520,375 proposes monitoring a variety of parameters such as RPM, and the stresses and accelerations to which the drill string is subjected accompanied by a comparison to a reference so as to give an indication of the mechanical properties of the rock being penetrated and so as to enable the selection of more suitable drilling parameters.
  • a measure be made of the mechanical load experienced per foot by the downhole components from which is generated an indication of the loading history experienced over time by the downhole components.
  • One parameter from which mechanical load may be determined is the uphole or downhole torque: specifically, the number of times a measure of torque exceeds a predetermined threshold related to the specific tool design specifications.
  • the indication of loading history is then utilized in determinations of when particular components must be replaced or maintained and/or in the determination of subsequent drilling practices such as the control of rate of penetration (ROP) through variation of application of weight on bit and/or rate of turning the drill string (ROT).
  • ROP rate of penetration
  • ROT rate of turning the drill string
  • FIG. 1 there is shown a typical rotary derrick comprising a mast 10 standing on the ground 12 and equipped with lifting gear 14, on which is suspended a drill string 16 formed from pipes joined end to end and carrying at its lower end a drill bit 18 for drilling a well 20 in subsurface formations 50.
  • Lifting gear 14 comprises a crown block 22, whose spindle is fixed to the top of the mast 10, a vertically mobile travelling block 24, to which is attached a hook 26, a cable 28 passing over blocks 22 and 24 and forming, as from the crown block 22, on one side an inactive portion 30 anchored to a fixed point 32 and on the other side an active portion 34 wound on to the drum of a winch 36.
  • the drill string 16 can be suspended on hook 26 via an injection head 38 connected by a flexible hose 40 to a mud pump 42, which makes it possible to inject into the well 20, via hollow pipes of string 16, drilling mud from a mud pit 43, which can also receive excess mud from the well 20 via bell nipple 39 and flow return line 41.
  • a lifting gear 14 By operation of the lifting gear 14 by means of winch 36, it is possible to raise the drill string 16, its pipes being successively withdrawn from well 20 and unscrewed so as to extract the drill bit 18, or to lower the drill string 16, following the successive rescrewing of the pipes forming it, in order to return the drill bit to the bottom of the well.
  • Drill string 16 is then supported by wedging using wedges or slips in a conical recess of a rotary table 46 mounted on a platform 48 and which is traversed by the drill string. During drilling periods, the drill string 16 is rotated by means of the rotating table 46 via a square pipe or "kelly" 44 mounted at its upper end.
  • a plurality of downhole components including a number of heavy drill collars 54 that make up a bottom hole assembly (BHA) 52.
  • BHA bottom hole assembly
  • a sensor apparatus 56 or MWD is sometimes added to the BHA for the detection of a variety of downhole parameters relating to the drilling process and/or to the properties of the formation 50 being drilled.
  • Typical of the measurements made by the MWD are downhole weight on bit (DWOB), downhole torque (DTOR), gamma ray, electrical resistivity and direction and inclination of the borehole.
  • DWOB downhole weight on bit
  • DTOR downhole torque
  • gamma ray electrical resistivity and direction and inclination of the borehole.
  • the DWOB and DTOR transducer may be constructed in accordance with the invention described in U.S. Patent 4,359,898 to Tanguy et al., which is incorporated herein by reference.
  • the outputs of the MWD 56 are fed to a transmitter in the MWD portion of the BHA, as is, by now, well known in the industry, for generating modulated acoustic signals that are modulated in accordance with the MWD measurements.
  • the signal is detected at the surface by a receiving pressure transducer 62 and processed by a processing means 64 to provide recordable data representative of the downhole measurements.
  • a receiving pressure transducer 62 and processed by a processing means 64 to provide recordable data representative of the downhole measurements.
  • a processing means 64 to provide recordable data representative of the downhole measurements.
  • an acoustic data transmission system is mentioned herein, other types of telemetry systems, of course, may be employed, provided they are capable of transmitting an intelligible signal from downhole to the surface during the
  • the BHA may comprise a large number of different components arranged in a variety of different manners in order to produce a variety of different behaviors.
  • one objective to be achieved by the proper design of the BHA is the directional control of the course of the borehole.
  • the BHA may include a downhole drilling motor with or without a bent housing, a bent sub, full gauge or undergauge stabilizers and reamers etc. Additionally, a large variety of drilling bits are available for selection according to the expected formation and to the type of well to be drilled.
  • FIG. 2 illustrates the processing functions performed within the surface processing means 64. While processing means 64 is illustrated as being at the surface, it should be understood that where a downhole value of torque is available from an MWD tool in the BHA, at least a portion of the processing of the data will preferably be performed downhole in the BHA by a microprocessor before transmission of the data to the surface. In this manner, signal compression may be achieved in order to comply with the rather severe telemetry data transmission rate limitations inherent in a typical MWD telemetry system such as a drilling mud pressure modulation system. Acquiring down hole values of torque for the purposes of this invention is preferable to surface acquisition, since friction effects between the bit and the surface frequently attenuate the torsional shocks generated downhole as they propagate up the drill string to the surface.
  • processing means 64 for each foot drilled, will typically convert the data flow into a statistical representation of the data such as an average value of torque (ATOR) and the standard deviation (TSIG) of torque from that average value.
  • ATOR average value of torque
  • TSIG standard deviation
  • processor 64 in response to a measurement of torque (TOR) and assuming Gaussian statistics, generates the statistical quantities of TSIG and ATOR at 66 and 68 respectively. These values are not only stored by the processor but are subsequently used through statistical analysis to determine the percent of the time that the torque of the drilling system has statistically exceeded a predetermined value or threshold (TREF). This is accomplished at 70 where the difference between the threshold (TREF) and the average value of torque (ATOR) is divided into the standard deviation value (TSIG).
  • threshold threshold
  • the data representative of the torque placed on the drill string follows Gaussian statistics
  • a suitable transform for example, taking the logarithm of the data
  • the raw data may be treated accordingly.
  • the preferred embodiment is described herein to include analysis of torque data that either exhibit Gaussian statistical behavior or which can be made to exhibit Gaussian statistical behavior through an appropriate preprocessing transform.
  • the analysis is performed to determine an indication of the number of occurances that the selected parameter (torque) exceeds a predetermined threshold.
  • the stalling torque of the rotary table may be used as a threshold in order to generate a mechanical load signal indicative of drilling roughness and a loading history signal.
  • the invention is broadly enough conceived to include parameters other than torque that may be useful in characterizing mechanical load placed on the drill string, such as vibrations, accelerations, string rotation speed (RPM) or pump pressure.
  • the invention is also broad enough to include the direct comparison of the monitored parameter (torque or other value indicative of load) with a predetermined threshold with a count made of those events which exceed the threshold.
  • Another variation within the scope of the invention is to generate a load signal which varies not only as a function of the number of times that the threshold is exceeded but also as a function of a measure of the magnitude by which the threshold is exceeded. In this manner, the greater tendancy for large excusions above the threshold to produce damage (fatigue) than minor excusions above the threshold can be taken into account.
  • the threshold itself may be selected, either from mechanical engineering fatigue analysis theory or from empirical observation as that value for which excusions above the threshold will significantly contribute to a shortened mechanical lifetime.
  • Graphical display of the value of CYC in the form of a depth varying log produces a useful quantitative indication of the "roughness" of the drilling process.
  • this log may enable the driller to immediately react to the "roughness” of the drilling operation and to modify his drilling practices in order to minimize the "roughness".
  • Such feedback to the drilling process may enable the avoidance of downhole failure of the components of the BHA, thereby significantly improving the drilling operation.
  • Figure 3 shows an example of a log of CYC at 82.
  • Figure 3 also shows a log of TCYC at 84 which stands for the sum or accumulation over depth of the torsional loading placed on the drill string.
  • This loading history signal calculated at 74 in Fig. 2, is useful to the driller as a quantitative indication of the total abuse to which the drill string (bit) has been subjected.
  • This loading history will enable the driller to evaluate the expected lifetime of the drilling components so that he will be able to use the equipment up to the end of its useful life without incurring downhole failures of the equipment which would be probable without knowledge of the loading history.
  • the loading history TCYC as illustrated in figure 3 is returned to zero after the replacement of each bit in order to track bit loading through each of their useful lives.
  • Equivalent shock time is a time index calculated from the loading history of the component. Simply conceptualized, a component that has experienced benign drilling conditions and a component used for the same period of time but under abusive conditions, will have different life expectancies. "Equivalent Shock Time” is therefore a synthetic period of time calculated to express the time that a component has been used in drilling while also taking into consideration the severity of the drilling conditions and a tool design factor for dynamic loading (FDES).
  • FDES tool design factor for dynamic loading
  • EQST may be divided at 78 by the total drilling time (T) to derive a dynamic shock factor (FDYN) which may also be used as an indication of the roughness of the drilling conditions. Utilization of equivalent shock time in establishing maintenance schedules, rather than actual time of use, will permit more effective preventive maintenance programs. EQST may also be used as an indication of component reliability.
  • T total drilling time
  • FDYN dynamic shock factor
  • processor 64 responds at 76 to the determination of the ratio of TSIG divided by (TREF-ATOR) and rate of penetration to calculate values of EQST on a foot by foot bases.
  • a constant, design factor (FDES) specific to the particular equipment under consideration, may be included in the calculation to more properly tailor EQST to the particular equipment.
  • FDES design factor
  • the parameter (FDYN) or dynamic shock factor is produced at 78.
  • CYC, TCYC, EQST and FDYN are delivered by processor 64 to a printer 80 which generates depth varying logs to which the driller may refer in order to optimize his drilling practices.
  • CYC and EQST are both signals indicative of mechanical loading while TCYC and the summation of EQST over time are signals indicative of loading history.
  • other parameters such as accelerations, vibrations, RPM, and pump pressure may function as signals indicative of mechanical loading and loading history.
  • replacing the bit with a more suitable bit for the drilling conditions replacing a straight blade stabilizer with a helical stabilizer, replacing a stablizer with a roller reamer, changing the rate of rotation of the drilling components, changing the weight placed on the drilling components, and replacing a drilling component having a high loading history with one having a lower loading history are non-limiting examples of measures that the driller may take to modify the drilling operation, it is also contemplated that determination of a replacement or maintenance schedule in response to mechanical loading which exceeds a threshold are also practices that have an effect on the drilling operation.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)
EP89200796A 1988-04-05 1989-03-29 Verfahren zum Steuern eines Bohrvorganges Withdrawn EP0336490A1 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB8807890A GB2216925A (en) 1988-04-05 1988-04-05 Method for controlling a drilling operation
GB8807890 1988-04-05

Publications (1)

Publication Number Publication Date
EP0336490A1 true EP0336490A1 (de) 1989-10-11

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EP89200796A Withdrawn EP0336490A1 (de) 1988-04-05 1989-03-29 Verfahren zum Steuern eines Bohrvorganges

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EP (1) EP0336490A1 (de)
GB (1) GB2216925A (de)
NO (1) NO891404L (de)

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6170317B1 (en) 1998-02-05 2001-01-09 Tamrock Oy Arrangement for detecting a need for maintaining a hydraulic breaking apparatus
US8170800B2 (en) 2009-03-16 2012-05-01 Verdande Technology As Method and system for monitoring a drilling operation
EP3677748A1 (de) * 2010-04-27 2020-07-08 National Oilwell Varco, L.P. System und verfahren zur bestimmung der gebrauchsdauer von bohrstangen
CN113123777A (zh) * 2019-12-30 2021-07-16 中铁二局集团有限公司 一种用于隧道塌方救援的大口径钻机钻进过程控制方法

Citations (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3324717A (en) * 1963-10-28 1967-06-13 Mobil Oil Corp System and method for optimizing drilling operations
US3520375A (en) * 1969-03-19 1970-07-14 Aquitaine Petrole Method and apparatus for measuring mechanical characteristics of rocks while they are being drilled
US3593807A (en) * 1969-12-11 1971-07-20 Frank J Klima Drilling apparatus
US3605919A (en) * 1969-05-16 1971-09-20 Automatic Drilling Mach Drilling rig control
USRE28436E (en) * 1970-12-28 1975-06-03 Method op determining downhole occurences in well drilling using rotary torque oscillation measurements
US4064749A (en) * 1976-11-11 1977-12-27 Texaco Inc. Method and system for determining formation porosity
US4250758A (en) * 1978-12-22 1981-02-17 Texaco Inc. Combination for use in a rotary drilling system with torque meter
US4285236A (en) * 1979-11-23 1981-08-25 Dresser Industries, Inc. Rotary torque and rpm indicator for oil well drilling rigs
FR2485616A1 (fr) * 1980-06-27 1981-12-31 Pk I Systeme de commande automatique d'un appareil de forage du sol par rotation
EP0163426A1 (de) * 1984-05-03 1985-12-04 Anadrill International SA Verfahren und Vorrichtung zur Überwachung von Bohrbedingungen

Family Cites Families (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3703096A (en) * 1970-12-28 1972-11-21 Chevron Res Method of determining downhole occurrences in well drilling using rotary torque oscillation measurements
US3746102A (en) * 1971-10-22 1973-07-17 Dresser Ind Automatic drilling break alarm and shutdown system
CA1134257A (en) * 1979-02-28 1982-10-26 Keith K. Millheim System for measuring downhole drilling forces
NO162881C (no) * 1983-06-23 1990-02-28 Teleco Oilfield Services Inc Fremgangsmaate og apparat for deteksjon av fluiduminnstroemninger i borehull.
US4606415A (en) * 1984-11-19 1986-08-19 Texaco Inc. Method and system for detecting and identifying abnormal drilling conditions

Patent Citations (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3324717A (en) * 1963-10-28 1967-06-13 Mobil Oil Corp System and method for optimizing drilling operations
US3520375A (en) * 1969-03-19 1970-07-14 Aquitaine Petrole Method and apparatus for measuring mechanical characteristics of rocks while they are being drilled
US3605919A (en) * 1969-05-16 1971-09-20 Automatic Drilling Mach Drilling rig control
US3593807A (en) * 1969-12-11 1971-07-20 Frank J Klima Drilling apparatus
USRE28436E (en) * 1970-12-28 1975-06-03 Method op determining downhole occurences in well drilling using rotary torque oscillation measurements
US4064749A (en) * 1976-11-11 1977-12-27 Texaco Inc. Method and system for determining formation porosity
US4250758A (en) * 1978-12-22 1981-02-17 Texaco Inc. Combination for use in a rotary drilling system with torque meter
US4285236A (en) * 1979-11-23 1981-08-25 Dresser Industries, Inc. Rotary torque and rpm indicator for oil well drilling rigs
FR2485616A1 (fr) * 1980-06-27 1981-12-31 Pk I Systeme de commande automatique d'un appareil de forage du sol par rotation
EP0163426A1 (de) * 1984-05-03 1985-12-04 Anadrill International SA Verfahren und Vorrichtung zur Überwachung von Bohrbedingungen

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
THE OIL AND GAS JOURNAL, 8th January 1968, pages 55-64; F.H. DEILY et al.: "New drilling-research tool shows what happens down hole" *

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6170317B1 (en) 1998-02-05 2001-01-09 Tamrock Oy Arrangement for detecting a need for maintaining a hydraulic breaking apparatus
DE19905281B4 (de) * 1998-02-05 2005-09-08 Tamrock Oy Anordnung zum Erkennen des Wartungsbedarfs eines hydraulischen Brechgeräts
US8170800B2 (en) 2009-03-16 2012-05-01 Verdande Technology As Method and system for monitoring a drilling operation
US8332153B2 (en) 2009-03-16 2012-12-11 Verdande Technology As Method and system for monitoring a drilling operation
US8615363B2 (en) 2009-03-16 2013-12-24 Verdande Technology As Method and system for monitoring a drilling operation
EP3677748A1 (de) * 2010-04-27 2020-07-08 National Oilwell Varco, L.P. System und verfahren zur bestimmung der gebrauchsdauer von bohrstangen
CN113123777A (zh) * 2019-12-30 2021-07-16 中铁二局集团有限公司 一种用于隧道塌方救援的大口径钻机钻进过程控制方法

Also Published As

Publication number Publication date
NO891404D0 (no) 1989-04-04
GB2216925A (en) 1989-10-18
GB8807890D0 (en) 1988-05-05
NO891404L (no) 1989-10-06

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