WO2011029026A1 - Scale-up device for testing bit balling characteristics - Google Patents
Scale-up device for testing bit balling characteristics Download PDFInfo
- Publication number
- WO2011029026A1 WO2011029026A1 PCT/US2010/047855 US2010047855W WO2011029026A1 WO 2011029026 A1 WO2011029026 A1 WO 2011029026A1 US 2010047855 W US2010047855 W US 2010047855W WO 2011029026 A1 WO2011029026 A1 WO 2011029026A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- bit
- test
- container
- replica bit
- formation
- Prior art date
Links
- 238000012360 testing method Methods 0.000 title claims abstract description 100
- 238000013341 scale-up Methods 0.000 title description 2
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 50
- 239000012530 fluid Substances 0.000 claims abstract description 26
- 238000005553 drilling Methods 0.000 claims abstract description 23
- 238000005520 cutting process Methods 0.000 claims abstract description 19
- 238000013461 design Methods 0.000 claims abstract description 15
- 238000000034 method Methods 0.000 claims abstract description 11
- 230000000694 effects Effects 0.000 claims abstract description 8
- 239000004927 clay Substances 0.000 claims description 18
- 239000000463 material Substances 0.000 claims description 18
- 239000011435 rock Substances 0.000 claims description 15
- 239000000203 mixture Substances 0.000 claims description 12
- 230000035515 penetration Effects 0.000 claims description 5
- 239000004579 marble Substances 0.000 claims description 4
- 238000004891 communication Methods 0.000 claims description 3
- 230000008878 coupling Effects 0.000 claims description 2
- 238000010168 coupling process Methods 0.000 claims description 2
- 238000005859 coupling reaction Methods 0.000 claims description 2
- 238000005086 pumping Methods 0.000 claims description 2
- 238000010998 test method Methods 0.000 claims description 2
- 238000005755 formation reaction Methods 0.000 description 34
- 238000004364 calculation method Methods 0.000 description 3
- 230000007246 mechanism Effects 0.000 description 3
- 239000007787 solid Substances 0.000 description 3
- 230000009471 action Effects 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 230000006835 compression Effects 0.000 description 2
- 238000007906 compression Methods 0.000 description 2
- 239000011343 solid material Substances 0.000 description 2
- 101100366322 Arabidopsis thaliana ADC1 gene Proteins 0.000 description 1
- 101150032645 SPE1 gene Proteins 0.000 description 1
- 238000009825 accumulation Methods 0.000 description 1
- 238000004458 analytical method Methods 0.000 description 1
- 239000002734 clay mineral Substances 0.000 description 1
- 238000013480 data collection Methods 0.000 description 1
- 229910003460 diamond Inorganic materials 0.000 description 1
- 239000010432 diamond Substances 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 239000007769 metal material Substances 0.000 description 1
- 230000000116 mitigating effect Effects 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 230000037361 pathway Effects 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
- 238000012552 review Methods 0.000 description 1
- 230000000087 stabilizing effect Effects 0.000 description 1
- 229910001220 stainless steel Inorganic materials 0.000 description 1
- 239000010935 stainless steel Substances 0.000 description 1
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
- E21B10/00—Drill bits
-
- 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
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01M—TESTING STATIC OR DYNAMIC BALANCE OF MACHINES OR STRUCTURES; TESTING OF STRUCTURES OR APPARATUS, NOT OTHERWISE PROVIDED FOR
- G01M99/00—Subject matter not provided for in other groups of this subclass
- G01M99/008—Subject matter not provided for in other groups of this subclass by doing functionality tests
Definitions
- Bit balling also known as balling or balling up, refers to the collection of sticky consolidated material, usually drill cuttings, on drill pipe, drill collars, bits, etc. A bit with such material attached to it is often referred to as a "balled-up bit.” Balling up is frequently the result of inadequate hydraulic energy or undesirable interaction between drilling fluid and the cuttings.
- Bit balling is one problem that is frequently encountered when drilling through clay. The problem is caused by the tendency of hydrated clay minerals to stick or adhere to the bit and bottom-hole assembly of a drill string. From an operations standpoint, bit balling is evidenced by increased pump pressures as the flow pathway through the well bore annulus becomes blocked, reduced rates of penetration, blocked shaker screens, a required over-pull tension that occurs due to a restricted annulus when tripping pipe, and possible stuck pipe.
- Drilling rates can be significantly reduced by bit balling - the unwanted accumulation of reactive drill solids on the drilling surfaces and in the junk slots of the bit. Balling is mitigated by improving drilling fluid characteristics/properties and bit design. Optimization of the combined system in the laboratory can be expensive and time- consuming. Summary
- the claimed subject matter is generally directed to a test apparatus for testing and studying the effects of mud chemistry and bit design on bit balling.
- the apparatus includes a replica bit coupled to a rotary drive and having at least on nozzle, a test container, a test formation located within the container through which the replica bit will be driven, wherein the test formation includes a plurality of layers of pre-manufactured cuttings.
- the apparatus further includes a lifting device for applying a force to the bottom of the test container to drive the test formation into the replica bit while the replica bit is rotated by the rotary drive, a second container within which is a drilling fluid, a conduit providing fluid communication from the second container to the replica bit, and a pump for circulating drilling fluid from the second container through the conduit to the replica bit.
- the claimed subject matter is generally directed to a method of testing the effects of mud chemistry and bit design on bit balling.
- the method includes mixing a plurality of mixtures of ground rock material and reactive clay, layering the mixtures into a test container to create a test formation, coupling a replica bit to a rotary drive, fluidly connecting the replica bit to a second container containing drilling fluid, positioning the replica bit within the test container to a position above the test formation, rotating the replica bit, pumping fluid from the container to the replica bit, and lifting the test formation to the rotating replica bit so that the bit rotates into the formation.
- Figure 1 is a view of the test apparatus.
- Figure 2 is a view of the test apparatus.
- Figure 3 is a side view of a replica bit.
- Figure 4 is a bottom view of a replica bit.
- Figures 5a and 5b are a bottom and a side view of a replica bit with pointers showing the direction of replica bit nozzles.
- Figure 6 is a schematic of a bit balling cuttings sample maker.
- Figure 7 is a view of data that may be collected and/or calculated by a computer.
- Figures 8 - 13 are photographs of replica bits with various degrees of balling.
- the claimed subject matter relates to a test apparatus 10 for testing the effects of mud chemistry and bit design, hydraulics, weight on bit, and rotary speed on bit balling.
- the test apparatus 10 includes a rotary drive 12 coupled to a replica bit 14.
- the replica bit 14 is rotated by the rotary drive 12 through a test formation 16 located within a test container 18.
- a lifting device 20, such as an air cylinder, hydraulic cylinder, or other lifting mechanism may be located beneath the test container 18 and applies an upward force to the bottom of the test container 18.
- Drilling fluid (not directly shown) is contained in a second container 22.
- a pump 24 is used to circulate drilling fluid from second container 22 to replica bit 14.
- a camera 26 may be included to record video and/or still photographs for documentation of the test.
- a computer may be used to record data from the test and to perform calculations from the data as will be described. [0018] Referring to Figs. 3 and 4, a replica bit 14 is shown.
- the replica bit 14 may be of any reduced size. Applicants have found that a 2.5 inch replica was sufficient to simulate a full size polycrystalline diamond compact (PDC) bit. While a 2.5 inch replica bit was used, the invention is not limited by the size of the bit.
- PDC polycrystalline diamond compact
- the replica bit 14 is a three-dimensionally printed, plastic model of a PDC bit.
- the replica bit 14 includes at least one nozzle 28.
- the replica bit 14 includes nozzles 28 that are aimed in various directions, consistent with a full size actual PDC bit, as shown by the pointers 30 extending from each nozzle.
- the replica bit 14 is coated with stainless steel flakes or other metallic finish to simulate the metal from which actual PDC bits are comprised. Further, it is noted that tolerances on the printed replica bit are within acceptable tolerances of an actual bit.
- the replica bit 14 drilling fluid is pumped through the replica bit 14 in a manner consistent with a full-sized PDC bit in a drilling environment.
- the nozzles 28 are in fluid communication with a conduit directing fluid into the bit. Drilling fluid is communicated towards the test formation 16 through the nozzles 28.
- the test formation 16 includes pre-manufactured cuttings 32 made from ground rock material blended with predetermined concentrations of reactive clay and compressed for proper consistency. The distribution of particle sizes and formation characteristics are selected to simulate that achieved under actual drilling conditions.
- the test formation 16 may include a plurality of layers 34 of pre- manufactured cuttings 32. Each layer 34 may have a different ratio of ground rock material to reactive clay so that the layers higher in the formation have a greater amount of reactive clay than the layers lower in the formation.
- the layers that are lower in the formation may include a greater amount of ground rock material than the layers higher in the formation. Alternatively, the layers may be homogenous in as much as the layers may have the same amounts of ground rock material and reactive clay.
- the ground rock material may include shale and/or marble, for example. Further, the amount of reactive clay in the lower layers may be less than that of the higher layers.
- the test formation is created one layer at a time and each layer may be several inches thick.
- the lowermost layer may be made from a ground rock material, such as shale and/or marble, and an amount of reactive clay.
- the material is mixed and loaded into the test container 18.
- a piston or other weighted compression device is used to compress the mixture to a predetermined height or with a predetermined compressive pressure.
- a second layer of material may be mixed with the same amount or a lesser or greater amount of ground rock material or another material and a second amount of reactive clay, wherein the second amount of reactive clay may be less than, equal to, or greater than the first amount of reactive clay found in the lower layer.
- This second mixture is loaded into the test container 18 and a piston or other weighted compression means is used to compress the mixture to a predetermined height or with a predetermined compressive force. Successive layers are formed in the same manner.
- FIG. 6 another way to create a test formation is shown.
- the test container 18 is located within an outer vessel 36.
- a stabilizing fluid 38 may be introduced between the test container 18 and the outer vessel 36 to remove any air between the two items.
- Seals 40 may be used to seal the interfaces between the test container 18 and the outer vessel 36.
- the fluid 38 may be pressurized to help prevent any deformation of the test container 18 when the pre- manufactured cuttings 32 are compressed.
- the material for the lowermost layer 34 of pre-manufactured cuttings 32 is mixed, as previously described, and poured into the test container 18.
- a piston 42 is used to compress the mixture to a predetermined height or with a predetermined pressure.
- a drain 44 may be included to bleed off any fluid.
- the test container 18 is preferably cylindrical to represent the wellbore walls, although it may have other cross sectional shapes.
- the test container 18 may be transparent so that the test can be viewed and/or recorded by an external camera.
- the inner diameter of the test container 18 must be larger than the outer diameter of the replica bit 14 but not so much larger that the bit performance cannot be easily viewed through the container. It is noted, however, that if an external camera is not being used, the test container 18 need not be transparent.
- the test container 18 may be retained such that it is able to rotate slightly with increasing torque. That is, as the replica bit 14 is rotated into the simulated formation, some amount of resistance may be transferred to the test container 18.
- the test container 18 may be provided with a torsion spring or similar mechanism to allow the test container 18 to rotate a relatively small amount, such as less than 25 °.
- the test container 18 containing the test formation 16 is lifted towards the replica bit 14 as the test is conducted. This may be performed by a lifting device 20, such as an air or hydraulic cylinder, located beneath the test container 18 or by another mechanism, such as a pulley system or rack and pinion, for example. Any device to lift the container relative to the longitudinally stationary replica bit 14 may suffice. This configuration advantageously allows a camera to be placed in a stationary location outside of the test container 18 and to capture bit performance. Alternatively, the test container 18 may be held longitudinally stationary while the replica bit 14 is driven rotationally into the simulated formation.
- a lifting device 20 such as an air or hydraulic cylinder
- the replica bit 14 is coupled directly or indirectly to the rotary drive 12 and located within the test container 18 above the test formation 16.
- a camera 26 may be used to document the test. Testing can be videotaped for documentation and detailed review. Referring to Fig. 2, the camera 26 may be mounted in a fixed location and, when used, would be focused on the replica bit 14.
- a solid color background 48 may be attached to the test fixture 50.
- sensors may be used to measure data that may be collected by a computer 46 and displayed on a monitor.
- data may be collected by another data collection device.
- data collected may include time, torque on the replica bit 14, and revolutions per minute, i.e. rotary speed, of the replica bit 14.
- the computer 46 may be used to perform various calculations used in the analysis of drill bits. For example, a Weight on Bit (WOB) calculation may be performed from data collected on the force being applied to the replica bit 14 by the test formation 16 as it is lifted towards the replica bit 14 and as the replica bit 14 "drills" through the test formation 16.
- WOB Weight on Bit
- a Rate of Penetration (ROP) may be calculated as the test is conducted based on the displacement of the test container 18.
- MSE Mechanical Specific Energy
- Test formations can consist of ground rock material blended with specific concentrations of reactive clay compressed to the proper consistency for testing.
- Bits can be coated with metallic materials to simulate the surface of actual bits. Testing can be conducted with different fluid designs. Equipment capable of calculating mechanical specific energy to aid in evaluation.
- the use of pre-manufactured cuttings provides consistently sized cuttings.
- a formation can be precisely formulated.
- formations can be repeatably formulated which allows a better comparison of bit designs.
- bits "printed" on a 3-Dimensional printer from a 3- Dimensional CAD drawing can be used to easily check new bit designs.
Landscapes
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Mechanical Engineering (AREA)
- Geophysics (AREA)
- General Physics & Mathematics (AREA)
- Investigating Strength Of Materials By Application Of Mechanical Stress (AREA)
- Earth Drilling (AREA)
Abstract
Description
Claims
Priority Applications (5)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/393,124 US20120152011A1 (en) | 2009-09-03 | 2010-03-10 | Scale-Up Device For Testing Bit Balling Characteristics |
CA2772761A CA2772761A1 (en) | 2009-09-03 | 2010-09-03 | Scale-up device for testing bit balling characteristics |
GB1205428.4A GB2486141B (en) | 2009-09-03 | 2010-09-03 | Scale-up device for testing bit balling characteristics |
MX2012002636A MX2012002636A (en) | 2009-09-03 | 2010-09-03 | Scale-up device for testing bit balling characteristics. |
NO20120269A NO20120269A1 (en) | 2009-09-03 | 2012-03-09 | Upscaling device for testing drill bit reclining properties |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US23970309P | 2009-09-03 | 2009-09-03 | |
US61/239,703 | 2009-09-03 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2011029026A1 true WO2011029026A1 (en) | 2011-03-10 |
Family
ID=43649666
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2010/047855 WO2011029026A1 (en) | 2009-09-03 | 2010-09-03 | Scale-up device for testing bit balling characteristics |
Country Status (6)
Country | Link |
---|---|
US (1) | US20120152011A1 (en) |
CA (1) | CA2772761A1 (en) |
GB (1) | GB2486141B (en) |
MX (1) | MX2012002636A (en) |
NO (1) | NO20120269A1 (en) |
WO (1) | WO2011029026A1 (en) |
Families Citing this family (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2011044427A2 (en) * | 2009-10-09 | 2011-04-14 | Schlumberger Canada Limited | Automated sidewall coring |
US10472912B2 (en) | 2014-08-25 | 2019-11-12 | Schlumberger Technology Corporation | Systems and methods for core recovery |
CN105715211B (en) * | 2016-03-09 | 2018-03-02 | 中国石油大学(华东) | Steel grit jet impulse broken rock comprehensive experimental device |
Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP0417055B1 (en) * | 1989-08-28 | 1994-06-15 | Atlas Copco Construction and Mining Technique AB | Device for positioning of a drill bit |
US20060073982A1 (en) * | 2004-10-05 | 2006-04-06 | M-I L.L.C. | Shale hydration inhibition agent and method of use |
US20070119626A9 (en) * | 2000-04-13 | 2007-05-31 | Weatherford/Lamb, Inc. | Apparatus and methods for drilling a wellbore using casing |
US7261168B2 (en) * | 2004-05-21 | 2007-08-28 | Halliburton Energy Services, Inc. | Methods and apparatus for using formation property data |
US20080164071A1 (en) * | 2006-12-18 | 2008-07-10 | Patel Suresh G | Superabrasive cutting elements with enhanced durability and increased wear life, and drilling apparatus so equipped |
US20080233388A1 (en) * | 2004-01-30 | 2008-09-25 | Mitsubishi Materials Corporation | Surface-Coated Cutting Tool Made of Hard Metal and Manufacturing Method for Same |
Family Cites Families (10)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5637795A (en) * | 1995-11-01 | 1997-06-10 | Shell Oil Company | Apparatus and test methodology for measurement of bit/stabilizer balling phenomenon in the laboratory |
US7187784B2 (en) * | 1998-09-30 | 2007-03-06 | Florida State University Research Foundation, Inc. | Borescope for drilled shaft inspection |
NO312921B1 (en) * | 1999-07-05 | 2002-07-15 | Sinvent As | Multitest compilation for evaluation, detection and monitoring of processes at elevated pressure |
DE10059890A1 (en) * | 2000-12-01 | 2002-06-20 | Hte Ag | Method for producing a large number of building blocks of a material library |
WO2004097159A2 (en) * | 2003-04-24 | 2004-11-11 | Shell Internationale Research Maatschappij B.V. | Thermal processes for subsurface formations |
US7614294B2 (en) * | 2006-09-18 | 2009-11-10 | Schlumberger Technology Corporation | Systems and methods for downhole fluid compatibility |
US7695542B2 (en) * | 2006-11-30 | 2010-04-13 | Longyear Tm, Inc. | Fiber-containing diamond-impregnated cutting tools |
CA2599085A1 (en) * | 2007-06-22 | 2008-12-22 | Canadian Energy Services L.P. | Lubricating agent and method for improving lubricity in a drilling system |
US20090308599A1 (en) * | 2008-06-13 | 2009-12-17 | Halliburton Energy Services, Inc. | Method of enhancing treatment fluid placement in shale, clay, and/or coal bed formations |
WO2010096538A1 (en) * | 2009-02-18 | 2010-08-26 | Smith International, Inc. | Matrix body fixed cutter bits |
-
2010
- 2010-03-10 US US13/393,124 patent/US20120152011A1/en not_active Abandoned
- 2010-09-03 CA CA2772761A patent/CA2772761A1/en not_active Abandoned
- 2010-09-03 WO PCT/US2010/047855 patent/WO2011029026A1/en active Application Filing
- 2010-09-03 GB GB1205428.4A patent/GB2486141B/en not_active Expired - Fee Related
- 2010-09-03 MX MX2012002636A patent/MX2012002636A/en not_active Application Discontinuation
-
2012
- 2012-03-09 NO NO20120269A patent/NO20120269A1/en not_active Application Discontinuation
Patent Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP0417055B1 (en) * | 1989-08-28 | 1994-06-15 | Atlas Copco Construction and Mining Technique AB | Device for positioning of a drill bit |
US20070119626A9 (en) * | 2000-04-13 | 2007-05-31 | Weatherford/Lamb, Inc. | Apparatus and methods for drilling a wellbore using casing |
US20080233388A1 (en) * | 2004-01-30 | 2008-09-25 | Mitsubishi Materials Corporation | Surface-Coated Cutting Tool Made of Hard Metal and Manufacturing Method for Same |
US7261168B2 (en) * | 2004-05-21 | 2007-08-28 | Halliburton Energy Services, Inc. | Methods and apparatus for using formation property data |
US20060073982A1 (en) * | 2004-10-05 | 2006-04-06 | M-I L.L.C. | Shale hydration inhibition agent and method of use |
US20080164071A1 (en) * | 2006-12-18 | 2008-07-10 | Patel Suresh G | Superabrasive cutting elements with enhanced durability and increased wear life, and drilling apparatus so equipped |
Also Published As
Publication number | Publication date |
---|---|
NO20120269A1 (en) | 2012-05-18 |
CA2772761A1 (en) | 2011-03-10 |
GB2486141A (en) | 2012-06-06 |
GB201205428D0 (en) | 2012-05-09 |
MX2012002636A (en) | 2012-06-27 |
GB2486141B (en) | 2014-04-09 |
US20120152011A1 (en) | 2012-06-21 |
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