WO2013019530A1 - Downhole condition alert system for a drill operator - Google Patents
Downhole condition alert system for a drill operator Download PDFInfo
- Publication number
- WO2013019530A1 WO2013019530A1 PCT/US2012/048243 US2012048243W WO2013019530A1 WO 2013019530 A1 WO2013019530 A1 WO 2013019530A1 US 2012048243 W US2012048243 W US 2012048243W WO 2013019530 A1 WO2013019530 A1 WO 2013019530A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- parameter
- operator
- tubular string
- downhole
- seat
- Prior art date
Links
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- An alert system for a downhole operation includes a tubular string in a borehole, the tubular string having at least one sensor positioned in the borehole for measuring at least one parameter during operation of the tubular string; a unit in data communication with the tubular string and operatively arranged to enable an operator to obtain information regarding operation of the tubular string; a work area positioned proximate to the unit and operatively arranged to receive the operator when the operator is interfacing with the unit; and a vibration module operatively arranged to vibrate the work area or a structure therein, wherein the vibration module is triggered in response to a first parameter being outside of a predetermined range set by a first threshold value.
- a method of alerting an operator during a drilling operation includes measuring at least one parameter of operation of the tubular string with at least one sensor while performing a downhole operation with the tubular string; determining if the at least one parameter is in a predetermined range based on at least one threshold value; and vibrating a work area or a structure therein with a vibration module in response to the at least one parameter being outside of the predetermined range, the work area located proximate to a unit operatively arranged for enabling an operator to obtain information regarding operation of the tubular string.
- Figure 1 is a schematic view of a system for drilling a borehole
- Figure 2 is a schematic top view of a control unit for an operator to remotely control a drilling operation
- Figure 3 shows a set of reference axes.
- the system 10 includes a control unit 12 for enabling an operator to control operation of a drill string 14.
- the drill string 14 terminates in a bottom hole assembly (BHA) 16 having a drill bit 18 for forming a borehole 20.
- BHA bottom hole assembly
- the control unit 12 could be located in a trailer or the like proximate the borehole 20.
- the control unit 12 is arranged to remotely control the operation of the drill string 14 via known means.
- United States Patent No. 7,730,967 (Ballantyne et al.) discloses a borehole drilling system, which Patent is hereby incorporated by reference in its entirety.
- the drill string 14 also includes a plurality of sensors 22 along its length.
- the sensors 22 can measure: borehole pressure and temperature; drilling parameters, such as weight on bit, rotational speed of the drill bit and/or the drill string, the drilling fluid flow rate, etc.; bottomhole assembly conditions or parameters, such as mud motor differential pressure, torque, bit bounce and whirl, etc.; and any other conditions or parameters desired to be known (hereinafter, generally "parameters").
- Exemplary sensors include temperature gages, strain gages, accelerometers, pressure transducers, magnetometers, electrical field strength sensors and other sensors known to one skilled in the art.
- a plurality of accelerometers could be arranged to detect movement of the drill string 14 or a component or portion thereof along the X, Y, and Z axes (see Figure 3) or to sense other parameters indicative of downhole problems. These detected movements and other parameters could be compared, for example, to predetermined maximum and/or minimum threshold values for setting a predetermined range of acceptable values.
- a computer processor 23 or logic unit in the control unit 12, in a sub of the drill string 14, etc., could be arranged to perform the comparison with the threshold values, which values could be stored in any suitable form of memory or data storage.
- bit bounce i.e., axial movement of the drill string 14
- bit whirl i.e., lateral movement of the drill string 14
- stick-slip i.e., torque in the drill string 14
- the control unit 12 enables control of drilling operation and includes, for example, a display device 24, a console 26, and a work area 28 positioned near the display device 24 and/or console 26.
- the display device 24 comprises, for example, a monitor, electronic display panel, etc.
- the display 24 provides the operator with information relating to drilling in various formats, e.g., pictorial, numeric, alphanumeric, etc.
- the console 26 includes various communication, input and/or interfacing devices for enabling the operator to communicate with the control unit 12, e.g., a mouse, keyboard, keypad, joystick, etc.
- the work area 28 is arranged for receiving the operator when the operator is controlling, operating, or otherwise interfacing with the control unit 12.
- the work area 28 is the component or structure on which the operator is physically located in order to operate the control unit 12.
- a floor section 30 and a seat 32 are shown in Figure 2 located in an area convenient for viewing, manipulating, and/or otherwise interfacing with the displays 24 and console 26.
- Other related components and equipment of the unit 12 are well known in the art and are not described in detail herein.
- vibration modules 34a, 34b, 34c, and 34d are shown (collectively, the “vibrations modules 34") for introducing vibrations, oscillations, or other detectable movements into the work area 28 for alerting the operator of a potential downhole problem or issue that requires correction.
- the vibration modules may take any form for inducing movement, such as motorized cam shafts or unbalanced shafts, actuatable pistons or plungers, opposing electromagnets, etc.
- the vibration modules 34 are arranged in data communication with the control unit 12, the sensors 22, and/or the processor 23 and triggered in response to one of the parameters measured by the sensors 22 exceeding or dropping below its corresponding threshold value.
- vibration module 34a is arranged to vibrate the flooring section 30 in the work area 28. Since the operator must be positioned in the work area 28 in order to interface with the control unit 12, vibrations in the floor section 30 will be felt by the operation, regardless of if the operator is standing or sitting on a seat, e.g., the seat 32, located in the work area 28.
- the vibration modules 34b, 34c, and 34d are arranged to vibrate the seat 32 instead of the floor general and can be configured to vibrate the seat differently in response to various downhole events or conditions. For example, in the event that stick-slip is detected (e.g., rotational movement or torque, R in Figure 3, exceeds its threshold value) one of the vibrations modules 34a or 34b could be triggered to cause vibrations to correspondingly rotate the seat 32. That is, by arranging the vibration modules 34b or 34c off-center with respect to the seat 32, triggering only one of these modules will introduce vibrations that slightly rotate the seat 32. This rotation of the seat 32 would indicate to the operator that impermissibly high rotation, torque, or stick-slip, is detected in the drill string 14.
- stick-slip e.g., rotational movement or torque, R in Figure 3
- one of the vibrations modules 34a or 34b could be triggered to cause vibrations to correspondingly rotate the seat 32. That is, by arranging the vibration modules 34b or 34c off-center
- vibration module 34d under the seat to cause the seat 32 to rock back and forth due to its vibrations could be used to indicate that impermissibly high axial movement, or bit bounce, is detected. Triggering both modules 34b and 34c simultaneously would rock the seat 32 side to side and could indicate unacceptably high lateral movement of the drill string 14, i.e., bit whirl.
- different forms of vibrations could be used to indicate different downhole problems, where the different vibrations mimic, imitate, relate to, correspond to, describe, or otherwise represent the condition occurring downhole. This enables the operator to immediately and intuitively recognize a variety of issues occurring downhole without having to focus attention on a display screen, interpret data, etc.
- the strength and frequency of the vibrations should be set so that they do not interfere with the operator's ability to work, but also so that they are not easily missed or ignored. They could also be tuned for the operator's weight, preferences, sensibility, etc. When the operator has taken appropriate action to relieve the undesirable downhole condition, the vibration modules would be signaled to cease vibrating.
- the vibrations can be set to cause some degree of annoyance to the operator, such that the operator is provided with even further motivation to quickly take remedial actions in order to avoid damage to the drill string 14, the BHA 16, the bit 18, etc.
- visual signals accompany the vibrations and are used to indicate to the operator that the system is operating outside of the predetermined norms, e.g., one of the parameters has exceeded or dropped below its corresponding threshold value.
- some portion of the display 24 could be shown in first color (e.g., yellow) for operation approaching the threshold value and with a second color (e.g., red) for operation outside of threshold value.
- the console 26, the work area 28, etc. could be illuminated by lights of these first and second colors.
- the colors or illumination could pulse or flash on and off, between two colors, etc. so that they are readily recognized and not easily missed or ignored.
- the control unit 12 additionally includes one or more audio devices 36 for playing a sound, series of sounds, sound bite, etc. in response to one of the downhole parameters exceeding its corresponding predetermined threshold value.
- a sound or series of sounds could be selected representative of or corresponding to potential issues downhole. That is, the sounds themselves would be selected such that they mimic, sound-like, define, or otherwise inherently represent the detected downhole problems. For example, a whirring noise could play for bit whirl, a knocking or jackhammering noise for bit bounce, etc. Thus, the operator would not just be hearing a generic alarm, but would instead hear sounds representative of the actual problem that needs to be rectified.
- the audio device 36 could take the form of, or be incorporated into, a loud speaker, a headset, headphones, a speaker in data communication with the control unit 12, etc.
- a combination of the above embodiments would enable an operator to be informed of possible problems by use of three of the operator's primary senses.
- the alert signals can be tailored to represent the actual events that are occurring so that the operator intuitively appreciates the problem without having to focus on a screen or display, interpret data, etc.
- a plurality of different conditions are uniquely communicated to the operator via a different one of the operator's senses, e.g., stick-slip by visual color changing, bit whirl by playing a whirring sound, and bit bounce by vibrations.
- alert features of the current invention are applicable to any other downhole operation, such as circulation, tripping, reaming, etc. and that any appropriate tubular string could be utilized.
- alerts as described above, whether vibratory, audible, and/or visual could be transmitted according to the above embodiments to multiple locations, people, etc. simultaneously.
- the feedback or alerts would be communicated to personnel who only monitor and do not control the downhole operations (as noted above, monitoring personnel and others also generally referred to herein as operators for ease of discussion).
Abstract
Description
Claims
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
GB1322548.7A GB2506061B (en) | 2011-07-29 | 2012-07-26 | Downhole condition alert system for a drill operator |
BR112014001541-4A BR112014001541B1 (en) | 2011-07-29 | 2012-07-26 | system and method of alerting an operator during a drilling operation |
NO20131696A NO345207B1 (en) | 2011-07-29 | 2013-12-18 | Well condition alarm system for a drilling operator |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/194,440 US8695692B2 (en) | 2011-07-29 | 2011-07-29 | Downhole condition alert system for a drill operator |
US13/194,440 | 2011-07-29 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2013019530A1 true WO2013019530A1 (en) | 2013-02-07 |
Family
ID=47596277
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2012/048243 WO2013019530A1 (en) | 2011-07-29 | 2012-07-26 | Downhole condition alert system for a drill operator |
Country Status (6)
Country | Link |
---|---|
US (1) | US8695692B2 (en) |
BR (1) | BR112014001541B1 (en) |
GB (1) | GB2506061B (en) |
NO (1) | NO345207B1 (en) |
SA (1) | SA112330739B1 (en) |
WO (1) | WO2013019530A1 (en) |
Families Citing this family (12)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10922955B2 (en) | 2011-02-28 | 2021-02-16 | Vireo Tech, Llc | Battery interconnected smoke detector system |
US10431055B2 (en) * | 2011-02-28 | 2019-10-01 | Vireo Tech, Llc | Battery interconnected alert device system with vibrational alert |
US9222308B2 (en) * | 2012-06-21 | 2015-12-29 | Schlumberger Technology Corporation | Detecting stick-slip using a gyro while drilling |
US20140099175A1 (en) * | 2012-10-04 | 2014-04-10 | Mark Guidry | Alarm systems and methods for preventing improper lifting of tubular members |
US20140097960A1 (en) * | 2012-10-04 | 2014-04-10 | Mark Guidry | Alarm systems and methods for preventing improper lifting of tubular members |
EA033474B1 (en) * | 2012-11-13 | 2019-10-31 | Exxonmobil Upstream Res Co | Method to detect drilling dysfunctions |
US9085958B2 (en) | 2013-09-19 | 2015-07-21 | Sas Institute Inc. | Control variable determination to maximize a drilling rate of penetration |
US9163497B2 (en) | 2013-10-22 | 2015-10-20 | Sas Institute Inc. | Fluid flow back prediction |
US10316653B2 (en) * | 2013-11-13 | 2019-06-11 | Schlumberger Technology Corporation | Method for calculating and displaying optimized drilling operating parameters and for characterizing drilling performance with respect to performance benchmarks |
WO2017082882A1 (en) * | 2015-11-10 | 2017-05-18 | Halliburton Energy Services, Inc. | Downhole component control assembly |
US10982526B2 (en) * | 2018-05-22 | 2021-04-20 | Baker Hughes, A Ge Company, Llc | Estimation of maximum load amplitudes in drilling systems independent of sensor position |
GB2576225A (en) * | 2018-08-10 | 2020-02-12 | Mhwirth As | Drilling systems and methods |
Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5273122A (en) * | 1991-02-25 | 1993-12-28 | Elf Aquitaine Production | Automatic method for monitoring the vibrational state of a drill string |
US20020148644A1 (en) * | 2000-11-07 | 2002-10-17 | Schultz Roger L. | Differential sensor measurement method and apparatus to detect a drill bit failure and signal surface operator |
US20060020390A1 (en) * | 2004-07-22 | 2006-01-26 | Miller Robert G | Method and system for determining change in geologic formations being drilled |
US20070175633A1 (en) * | 2006-01-30 | 2007-08-02 | Schlumberger Technology Corporation | System and Method for Remote Real-Time Surveillance and Control of Pumped Wells |
Family Cites Families (14)
Publication number | Priority date | Publication date | Assignee | Title |
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GB2338253B (en) | 1998-06-12 | 2000-08-16 | Schlumberger Ltd | Power and signal transmission using insulated conduit for permanent downhole installations |
AU767533B2 (en) * | 1999-01-27 | 2003-11-13 | Compumedics Limited | Vigilance monitoring system |
US6871712B2 (en) | 2001-07-18 | 2005-03-29 | The Charles Machine Works, Inc. | Remote control for a drilling machine |
US7026945B2 (en) * | 2003-08-27 | 2006-04-11 | Bobby Dwyane Hill | Alarm device interface system |
NO321851B1 (en) | 2003-08-29 | 2006-07-10 | Offshore Resource Group As | Apparatus and method for object imaging and material type identification in a fluid-carrying pipeline by means of X-rays and gamma rays |
US7596481B2 (en) | 2004-03-16 | 2009-09-29 | M-I L.L.C. | Three-dimensional wellbore analysis and visualization |
US7730967B2 (en) | 2004-06-22 | 2010-06-08 | Baker Hughes Incorporated | Drilling wellbores with optimal physical drill string conditions |
US20060285436A1 (en) | 2005-06-06 | 2006-12-21 | Rene Virgillo Mayorga Lopez | Intelligent system for use in subterranean drilling applications |
US7472745B2 (en) | 2006-05-25 | 2009-01-06 | Baker Hughes Incorporated | Well cleanup tool with real time condition feedback to the surface |
US7334839B1 (en) * | 2006-10-11 | 2008-02-26 | Benjamin Malerba | Motor vehicle seat assembly |
US7624831B2 (en) | 2007-07-03 | 2009-12-01 | Helmerich & Payne, Inc. | Method and apparatus for moving in formation the modular components of a drilling rig from well to well |
US8499855B2 (en) | 2008-02-18 | 2013-08-06 | Vermeer Manufacturing Company | Devices and methods for horizontal directional drilling with a boring tool library |
US7819183B2 (en) | 2008-06-16 | 2010-10-26 | Halliburton Energy Services, Inc. | Work string controller |
US8109333B2 (en) | 2009-05-07 | 2012-02-07 | Baker Hughes Incorporated | Indicator and method |
-
2011
- 2011-07-29 US US13/194,440 patent/US8695692B2/en active Active
-
2012
- 2012-07-26 BR BR112014001541-4A patent/BR112014001541B1/en active IP Right Grant
- 2012-07-26 WO PCT/US2012/048243 patent/WO2013019530A1/en active Application Filing
- 2012-07-26 GB GB1322548.7A patent/GB2506061B/en active Active
- 2012-07-29 SA SA112330739A patent/SA112330739B1/en unknown
-
2013
- 2013-12-18 NO NO20131696A patent/NO345207B1/en unknown
Patent Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5273122A (en) * | 1991-02-25 | 1993-12-28 | Elf Aquitaine Production | Automatic method for monitoring the vibrational state of a drill string |
US20020148644A1 (en) * | 2000-11-07 | 2002-10-17 | Schultz Roger L. | Differential sensor measurement method and apparatus to detect a drill bit failure and signal surface operator |
US20060020390A1 (en) * | 2004-07-22 | 2006-01-26 | Miller Robert G | Method and system for determining change in geologic formations being drilled |
US20070175633A1 (en) * | 2006-01-30 | 2007-08-02 | Schlumberger Technology Corporation | System and Method for Remote Real-Time Surveillance and Control of Pumped Wells |
Also Published As
Publication number | Publication date |
---|---|
NO345207B1 (en) | 2020-11-02 |
US8695692B2 (en) | 2014-04-15 |
BR112014001541B1 (en) | 2020-10-13 |
GB2506061B (en) | 2019-02-20 |
SA112330739B1 (en) | 2015-07-07 |
GB201322548D0 (en) | 2014-02-12 |
BR112014001541A2 (en) | 2017-02-14 |
GB2506061A (en) | 2014-03-19 |
NO20131696A1 (en) | 2014-01-29 |
US20130025851A1 (en) | 2013-01-31 |
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