US20060070734A1 - System and method for determining forces on a load-bearing tool in a wellbore - Google Patents
System and method for determining forces on a load-bearing tool in a wellbore Download PDFInfo
- Publication number
- US20060070734A1 US20060070734A1 US10/959,558 US95955804A US2006070734A1 US 20060070734 A1 US20060070734 A1 US 20060070734A1 US 95955804 A US95955804 A US 95955804A US 2006070734 A1 US2006070734 A1 US 2006070734A1
- Authority
- US
- United States
- Prior art keywords
- tool
- wellbore
- force
- additional forces
- measured
- 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.)
- Abandoned
Links
- 238000000034 method Methods 0.000 title claims abstract description 11
- 239000012530 fluid Substances 0.000 description 6
- 238000007789 sealing Methods 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 2
- 230000008602 contraction Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 230000000246 remedial effect Effects 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 239000004568 cement Substances 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 229920001971 elastomer Polymers 0.000 description 1
- 239000000806 elastomer Substances 0.000 description 1
- 230000007717 exclusion Effects 0.000 description 1
- 239000011888 foil Substances 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 238000002955 isolation Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 230000004044 response Effects 0.000 description 1
Images
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
- E21B47/00—Survey of boreholes or wells
- E21B47/007—Measuring stresses in a pipe string or casing
-
- 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
- E21B47/00—Survey of boreholes or wells
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)
- Force Measurement Appropriate To Specific Purposes (AREA)
- Earth Drilling (AREA)
Abstract
A system and method for sensing forces on a load-bearing tool located in a wellbore, according to which forces acting on the tool are sensed, and other conditions in the wellbore are measured. The forces on the tool caused by the measured conditions are subtracted from the sensed forces to determine the direct force acting on the tool.
Description
- This invention relates to a system and method for determining forces on a load-bearing tool in a wellbore in a downhole oil and gas recovery operation system.
- An example of a load-bearing tool of the above type is a retrievable packer that is inserted in a wellbore in many oil field applications for the purpose of sealing against the flow of fluid and thus isolate one or more portions of the wellbore for the purposes of treating or producing the well. The packer is suspended from a workstring, or the like, in the wellbore, and includes one or more elastomer elements which are activated, or set, so that the elements are forced against an inner surface of the wellbore, or casing, and compressed to seal against the flow of fluid and therefore to permit isolation of certain zones in the well. The packer can be set by either setting down weight through the workstring which imparts a compressive load to the packer or by picking up on the workstring which imparts a tensile load to the packer. These setting loads or setting forces are referred to as a direct force.
- After being set in the above manner, the packer can be subjected to various additional forces such as those related to workstring pressure and/or annulus pressure or by thermal expansion and contraction that occur when various fluids are pumped down the workstring. Since these forces may change the setting force on the packer and may otherwise adversely affect its operation, it is important that these additional forces be measured and their values either stored or transmitted to the surface in real time so as to permit remedial action.
- To this end, strain gauges have been used to measure the direct force. However, strain gauges are sensitive to other conditions in the wellbore that can cause the additional forces on the packer. Therefore, the strain gauges measure a total force that is the sum of the direct force and the additional forces instead of measuring only the desired direct force.
- In order to correct for this, various forms of mechanical and hydraulic devices have been used in an effort to compensate for the above additional forces caused by the other conditions in the wellbore. However, these compensation systems require additional components that can increase the length, complexity and cost of the system.
- Therefore, what is needed is a system that compensates for the above additional forces while requiring few or no additional components.
-
FIG. 1 is an schematic/elevational view of a downhole tool including an embodiment of a system according to the invention. -
FIG. 2 is a partial schematic, enlarged, side view of the embodiment ofFIG. 1 . -
FIG. 3 is a schematic view of the electronics used in the embodiment ofFIG. 1 . - Referring to
FIG. 1 , thereference numeral 10 refers to a wellbore penetrating a subterranean ground formation F for the purpose of recovering hydrocarbon fluids from the formation F. A load-bearingtool 12 is lowered into thewellbore 10 to a predetermined depth by aworkstring 14, which can be in the form of coiled tubing, jointed tubing, drill pipe, or the like, which is connected to the upper end of thetool 12. Thetool 12 is shown generally inFIG. 1 and will be described in detail later. - The
workstring 14 extends from arig 16 located above ground and extending over thewellbore 10. Therig 16 is conventional and, as such, includes support structure, a motor driven winch, or the like, and other associated equipment for lowering thetool 12, via theworkstring 14, to a predetermined depth in thewellbore 10. - The upper portion of the
wellbore 10 can be lined with acasing 20 which is cemented in thewellbore 10 by introducing cement in an annulus formed between the inner surface of thewellbore 10 and the outer surface of thecasing 20, all in a conventional manner. Aproduction tubing 22 having a diameter greater than that of thetool 12, but less than that of thecasing 20, may also be installed in thewellbore 10 in a conventional manner and extends from the ground surface to a predetermined depth in thecasing 20. - As viewed in
FIG. 2 , thetool 12 has anupper portion 12 a that supports a series of sensing and measuring devices that will be described, and a lower portion that is in the form of apacker 12 b. - When actuated, or set, the
tool 12 engages the corresponding inner wall portion of thecasing 20 for the purpose of sealing against the passage of fluids across thetool 12. - A series of
sensors 34 are mounted to theupper portion 12 a of thetool 12 to sense a direct force. Eachsensor 34 can be in the form of a metal foil strain gauge whose resistance varies in response to various forces applied thereto, which forces are largely in the form of tensile and compressive stresses on thetool 12 caused by setting thetool 12. Although only foursensors 34 are shown, it is understood that this number can vary. - As stated above, the
sensors 34 are sensitive to other conditions in thewellbore 10 that can cause additional forces to act on thetool 12. Examples of these conditions include the temperature in thewellbore 10, pressure in theworkstring 14, and/or differential pressure across thetool 12. To compensate for this a series ofpressure gauges 36 andtemperature gauges 38 are also mounted to theupper portion 12 a of thetool 12. Thegauges wellbore 10 that affect thetool 12, and output corresponding signals. Although only twopressure gauges 36 and twotemperature gauges 38 are shown mounted to thetool 12, it is understood that this number can vary.Pressure gauges 36 may for example be located in a cavity in thetool 12 and connected by ports to the interior of theworkstring 14 and an annulus formed between the outer surface of thetool 12 and the inner wall portion of thecasing 20. - A
processor 40 is also mounted to theupper portion 12 a of thetool 12, and, as shown inFIGS. 2 and 3 , is electrically connected to thesensors 34 and thegauges processor 40 receives the above output signals from thesensors 34 and thegauges - In operation, the
tool 12 is lowered to a predetermined depth in thewellbore 10 via theworkstring 14, and thepacker 12 b is then set in a conventional manner. In performing this sealing function, thetool 12 is subjected to various forces, described below, in connection with the oil recovery process. - The
sensors 34 sense a total force acting on thetool 12 and output corresponding signals to theprocessor 40. This total force includes the direct force on thetool 12 caused by setting thetool 12. However, thesensors 34 also sense the additional forces caused by other conditions in thewellbore 10 such as forces caused by thermal expansion and contraction that occur when various fluids are pumped down theworkstring 14. - In order to determine these additional forces, the
gauges workstring 14, the differential pressure across thetool 12, and/or the temperature in thewellbore 10 around thetool 12 and output corresponding signals to theprocessor 40. - The
processor 40 includes a readable medium, or software, including instructions for execution by theprocessor 40, for calculating the direct force on thetool 12 from the total force and the additional forces in accordance with well known engineering principles. The additional force components are subtracted from the total force on thetool 12 measured by thesensors 34 to arrive at the direct force on thetool 12. Theprocessor 40 then stores data based on these forces for downloading after thetool 12 is removed from the well, or theprocessor 40 can be designed to output a corresponding signal that is transmitted to therig 16 in any conventional manner. This data is collected at therig 16 and used to determine if the direct force caused by setting thetool 12 is such that remedial action is required. - It is understood that variations may be made in the foregoing without departing from the scope of the invention. Examples of some variations are as follows:
-
- (1) The number, the particular type, location, and the relative orientation, of the
sensors 34 and thegauges - (2) The
gauges wellbore 10 that cause the additional forces on thetool 12, and therefore other devices can be used. - (3) Only one of the
gauges - (4) The
upper portion 12 a of thetool 12 could be eliminated and theentire tool 12 could be in the form of a packer, in which case thesensors 34, thegauges processor 40 would be mounted on the packer. - (5) The type of tool to which the
sensors 34, thegauges processor 40 are mounted can include any load-bearing tool or sub connected to the tool that is insertable in thewellbore 10 in the above manner. - (6) A mandrel could be provided that is connected to, or forms part of, the
tool 12 and is adapted to receive thesensors 34, thegauges processor 40. - (7) The
tool 12, or other load-bearing tool, can be part of a tool assembly including other tools (not shown) for performing other operations in thewellbore 10. - (8) The spatial references used above, such as “upward”, “downward”, “vertical”, “radial”, etc. are for the purpose of illustration only and do not limit the specific orientation or location of the structure described above.
- (1) The number, the particular type, location, and the relative orientation, of the
- The foregoing descriptions of specific embodiments of the present invention have been presented for purposes of illustration and description. They are not intended to be exhaustive or to limit the invention to the precise forms disclosed, and obviously many modifications and variations are possible in light of the above teaching. The embodiments were chosen and described in order to best explain the principles of the invention and its practical application, to thereby enable others skilled in the art to best utilize the invention and various embodiments with various modifications as are suited to the particular use contemplated. It is intended that the scope of the invention be defined by the claims appended hereto and their equivalents.
Claims (27)
1. A method of determining a direct force acting on a load-bearing tool connected to a workstring, comprising the steps of:
sensing a total force acting on the tool when located in a wellbore, wherein the total force comprises the direct force acting on the tool and additional forces acting on the tool;
measuring at least one condition in the wellbore that causes the additional forces;
calculating the additional forces from the measured condition; and
subtracting the additional forces from the sensed total force to determine the direct force acting on the tool.
2. The method of claim 1 wherein the measured condition is the temperature in the wellbore around the tool.
3. The method of claim 1 wherein the measured condition is the differential pressure across the tool.
4. The method of claim 1 wherein the measured condition is the pressure in the workstring.
5. The method of claim 1 wherein the steps of calculating and subtracting are done by a processor that receives signals corresponding to the sensed total force and measured conditions.
6. The method of claim 1 wherein the direct force is a tensile or compressive stress on the tool.
7. The method of claim 1 wherein the tool comprises a packer, and the direct force is a force used to set the packer.
8. A system for determining a direct force acting on a load-bearing tool connected to a workstring, comprising:
at least one sensor for sensing a total force acting on the tool when located in a wellbore, wherein the total force comprises the direct force acting on the tool and additional forces acting on the tool;
at least one gauge for measuring at least one condition in the wellbore that causes additional forces on the tool; and
a processor for calculating the additional forces on the tool resulting from the measured conditions, and subtracting the additional forces from the sensed total force to determine the direct force.
9. The system of claim 8 wherein the measured conditions include the temperature in the wellbore around the tool.
10. The system of claim 8 wherein the measured conditions include the differential pressure across the tool.
11. The system of claim 8 wherein the measured conditions include the pressure in the workstring.
12. The system of claim 8 wherein the processor receives signals corresponding to the sensed total force and measured conditions.
13. The system of claim 8 wherein the direct force is a tensile or compressive stress on the tool.
14. The system of claim 8 wherein the tool comprises a packer, and the direct force is a force used to set the packer.
15. A processor readable medium comprising a plurality of instructions for execution by at least one processor, wherein the instructions are for:
receiving an input corresponding to a total force acting on a tool when located in a wellbore, wherein the total force comprises a direct force acting on the tool and additional forces acting on the tool;
receiving an input corresponding to at least one measured condition in the wellbore that causes the additional forces on the tool;
calculating the additional forces resulting from the measured condition; and
subtracting the additional forces from the total force to determine the direct force acting on the tool.
16. The medium of claim 15 wherein the measured condition is the temperature in the wellbore around the tool.
17. The medium of claim 15 wherein the measured condition is the differential pressure across the tool.
18. The medium of claim 15 wherein the measured conditions include the pressure in a workstring connected to the tool.
19. The medium of claim 15 wherein the direct force is a tensile or compressive stress on the tool.
20. The medium of claim 15 wherein the tool comprises a packer, and the direct force is a force used to set the packer.
21. A system of determining a direct force acting on a load-bearing tool connected to a workstring, comprising:
means for sensing a total force acting on the tool when located in a wellbore, wherein the total force comprises the direct force acting on the tool and additional forces acting on the tool;
means for measuring at least one condition in the wellbore that causes the additional forces; and
means for calculating the additional forces resulting from the measured condition and subtracting the additional forces from the total force to determine the direct force.
22. The system of claim 21 wherein the measured condition is the temperature in the wellbore around the tool.
23. The system of claim 21 wherein the measured condition is the differential pressure across the tool.
24. The system of claim 21 wherein the measured condition is the pressure in the workstring.
25. The system of claim 21 wherein the means for calculating and subtracting is a processor that receives signals corresponding to the total force and measured conditions.
26. The system of claim 21 wherein the direct force is a tensile or compressive stress on the tool.
27. The system of claim 21 wherein the tool comprises a packer, and the direct force is a force used to set the packer.
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/959,558 US20060070734A1 (en) | 2004-10-06 | 2004-10-06 | System and method for determining forces on a load-bearing tool in a wellbore |
CA002522125A CA2522125A1 (en) | 2004-10-06 | 2005-10-03 | A system and method for determining forces on a load-bearing tool in a wellbore |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/959,558 US20060070734A1 (en) | 2004-10-06 | 2004-10-06 | System and method for determining forces on a load-bearing tool in a wellbore |
Publications (1)
Publication Number | Publication Date |
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US20060070734A1 true US20060070734A1 (en) | 2006-04-06 |
Family
ID=36124387
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US10/959,558 Abandoned US20060070734A1 (en) | 2004-10-06 | 2004-10-06 | System and method for determining forces on a load-bearing tool in a wellbore |
Country Status (2)
Country | Link |
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US (1) | US20060070734A1 (en) |
CA (1) | CA2522125A1 (en) |
Cited By (18)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN101353961A (en) * | 2007-07-26 | 2009-01-28 | 普拉德研究及开发股份有限公司 | Well bore logging detector and manufacture method thereof |
US20090071645A1 (en) * | 2007-09-18 | 2009-03-19 | Kenison Michael H | System and Method for Obtaining Load Measurements in a Wellbore |
US8393393B2 (en) | 2010-12-17 | 2013-03-12 | Halliburton Energy Services, Inc. | Coupler compliance tuning for mitigating shock produced by well perforating |
US8397814B2 (en) | 2010-12-17 | 2013-03-19 | Halliburton Energy Serivces, Inc. | Perforating string with bending shock de-coupler |
US8397800B2 (en) | 2010-12-17 | 2013-03-19 | Halliburton Energy Services, Inc. | Perforating string with longitudinal shock de-coupler |
US8714252B2 (en) | 2011-04-29 | 2014-05-06 | Halliburton Energy Services, Inc. | Shock load mitigation in a downhole perforation tool assembly |
US8875796B2 (en) | 2011-03-22 | 2014-11-04 | Halliburton Energy Services, Inc. | Well tool assemblies with quick connectors and shock mitigating capabilities |
US8978817B2 (en) | 2012-12-01 | 2015-03-17 | Halliburton Energy Services, Inc. | Protection of electronic devices used with perforating guns |
US8978749B2 (en) | 2012-09-19 | 2015-03-17 | Halliburton Energy Services, Inc. | Perforation gun string energy propagation management with tuned mass damper |
US8985200B2 (en) | 2010-12-17 | 2015-03-24 | Halliburton Energy Services, Inc. | Sensing shock during well perforating |
US9091152B2 (en) | 2011-08-31 | 2015-07-28 | Halliburton Energy Services, Inc. | Perforating gun with internal shock mitigation |
WO2014184586A3 (en) * | 2013-05-17 | 2015-08-13 | Halliburton Manufacturing And Services Limited | Monitoring and transmitting wellbore data to surface |
US9297228B2 (en) | 2012-04-03 | 2016-03-29 | Halliburton Energy Services, Inc. | Shock attenuator for gun system |
US9416648B2 (en) | 2013-08-29 | 2016-08-16 | Schlumberger Technology Corporation | Pressure balanced flow through load measurement |
US9598940B2 (en) | 2012-09-19 | 2017-03-21 | Halliburton Energy Services, Inc. | Perforation gun string energy propagation management system and methods |
US9631446B2 (en) | 2013-06-26 | 2017-04-25 | Impact Selector International, Llc | Impact sensing during jarring operations |
US9951602B2 (en) | 2015-03-05 | 2018-04-24 | Impact Selector International, Llc | Impact sensing during jarring operations |
US10871064B2 (en) | 2015-09-02 | 2020-12-22 | Halliburton Energy Services, Inc. | Determining downhole forces using pressure differentials |
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CN101353961A (en) * | 2007-07-26 | 2009-01-28 | 普拉德研究及开发股份有限公司 | Well bore logging detector and manufacture method thereof |
WO2009014934A2 (en) * | 2007-07-26 | 2009-01-29 | Schlumberger Canada Limited | Sensor and insulation layer structure for well logging instruments |
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US8397814B2 (en) | 2010-12-17 | 2013-03-19 | Halliburton Energy Serivces, Inc. | Perforating string with bending shock de-coupler |
US8397800B2 (en) | 2010-12-17 | 2013-03-19 | Halliburton Energy Services, Inc. | Perforating string with longitudinal shock de-coupler |
US8408286B2 (en) | 2010-12-17 | 2013-04-02 | Halliburton Energy Services, Inc. | Perforating string with longitudinal shock de-coupler |
US8490686B2 (en) | 2010-12-17 | 2013-07-23 | Halliburton Energy Services, Inc. | Coupler compliance tuning for mitigating shock produced by well perforating |
US8985200B2 (en) | 2010-12-17 | 2015-03-24 | Halliburton Energy Services, Inc. | Sensing shock during well perforating |
US8393393B2 (en) | 2010-12-17 | 2013-03-12 | Halliburton Energy Services, Inc. | Coupler compliance tuning for mitigating shock produced by well perforating |
US9206675B2 (en) | 2011-03-22 | 2015-12-08 | Halliburton Energy Services, Inc | Well tool assemblies with quick connectors and shock mitigating capabilities |
US8875796B2 (en) | 2011-03-22 | 2014-11-04 | Halliburton Energy Services, Inc. | Well tool assemblies with quick connectors and shock mitigating capabilities |
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