WO2008016965A1 - Cleaning apparatus and method - Google Patents
Cleaning apparatus and method Download PDFInfo
- Publication number
- WO2008016965A1 WO2008016965A1 PCT/US2007/074954 US2007074954W WO2008016965A1 WO 2008016965 A1 WO2008016965 A1 WO 2008016965A1 US 2007074954 W US2007074954 W US 2007074954W WO 2008016965 A1 WO2008016965 A1 WO 2008016965A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- wellbore
- fluid
- spinner
- coaxial pipe
- nozzles
- Prior art date
Links
- 238000004140 cleaning Methods 0.000 title claims abstract description 46
- 238000000034 method Methods 0.000 title claims abstract description 21
- 239000012530 fluid Substances 0.000 claims abstract description 54
- 238000005086 pumping Methods 0.000 claims abstract description 4
- 238000004519 manufacturing process Methods 0.000 claims description 12
- 238000004891 communication Methods 0.000 claims description 5
- 238000005520 cutting process Methods 0.000 claims description 4
- 239000002245 particle Substances 0.000 claims description 4
- 239000011435 rock Substances 0.000 claims description 3
- 230000015572 biosynthetic process Effects 0.000 description 9
- 238000005755 formation reaction Methods 0.000 description 9
- 238000005553 drilling Methods 0.000 description 5
- 239000007788 liquid Substances 0.000 description 4
- 239000007787 solid Substances 0.000 description 4
- 230000007423 decrease Effects 0.000 description 3
- 230000007246 mechanism Effects 0.000 description 3
- 230000000903 blocking effect Effects 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- 239000002253 acid Substances 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 230000002301 combined effect Effects 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 239000003112 inhibitor Substances 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000010297 mechanical methods and process Methods 0.000 description 1
- 230000005226 mechanical processes and functions Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 230000000284 resting effect Effects 0.000 description 1
- 230000035939 shock Effects 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 230000000638 stimulation Effects 0.000 description 1
- 239000000126 substance 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
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
- E21B37/02—Scrapers specially adapted therefor
- E21B37/04—Scrapers specially adapted therefor operated by fluid pressure, e.g. free-piston scrapers
-
- 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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/10—Valve arrangements in drilling-fluid circulation systems
- E21B21/103—Down-hole by-pass valve arrangements, i.e. between the inside of the drill string and the annulus
Definitions
- the present inventions relate to a cleaning apparatus and a method for cleaning debris from a wellbore. Background
- Formation damage is defined as a reduction in permeability around a wellbore, which is the consequence of drilling, completion, injection, attempted stimulation or production of the well.
- the mechanism of formation damage varies from well to well; however the transport of solids into and out of the wellbore is consistently an important factor.
- Drilling mud, drilling fluids drill-in fluids, fluid loss inhibitors, and other similar fluids can invade permeable formations, replacing native fluids adjacent to the wellbore. During replacement, solid particles invade the formation and reduce its permability by blocking flow channels. This blockage in the flow channels causes formation damage, which can result insignificant decreases in well productivity and resulting economic loss.
- Cavitation generally refers to the formation and instantaneous collapse of innumerable tiny vapor bubbles within a fluid subjected to rapid and intense pressure changes.
- a liquid subjected to a low pressure (tensile stress) above a threshold ruptures and forms vaporous cavities.
- the local ambient pressure at a point in the liquid falls below the liquid's vapor pressure at the local ambient temperature, the liquid can undergo a phase change, creating largely empty voids termed cavitation bubbles.
- Downhole cleaning via cavitation involves attaching a cavitation tool to the end of the coiled tubing, drill pipe or work string. To do so, the production or drilling must be stopped while the cleaning apparatus is run into the hole. Fluid pumped through the tool drives a mechanical process that induces cavitation, and a flare of bubbles is released. The combined effects of the flow impact, the suction effects of the decaying bubble flare, and the implosion shock waves of the cavitation are effective to mobilize and remove debris that may be trapped in the wellbore.
- the present inventions include a method for cleaning debris from a wellbore having a top and a bottom comprising inserting cleaning tool comprising a coaxial pipe in the wellbore, pumping fluid through the cleaning tool to create a fluid flow in a direction towards the bottom of the wellbore, converting the fluid flow into rotary mechanical power, agitating the debris by cavitation with at least one vortex spinner having a plurality of spinner blades, and allowing the debris to flow towards the top of the wellbore thereby cleaning the wellbore.
- the present inventions include an apparatus for cleaning a wellbore comprising a coaxial pipe with a first end and a second end, at least one vortex spinner operatively connectable to the coaxial pipe between the first end and the second end, and a fluid divider arranged inside the coaxial pipe.
- Figure 1 illustrates a side view of one embodiment of a cleaning tool during production.
- Figure 2 illustrates a close-up side view of the one embodiment of the downhole cleaning tool.
- Figure 3 illustrates a side view of another embodiment of the cleaning tool.
- Figure 4 illustrates a top view of the cleaning tool.
- Figure 5 illustrates a top view of the cleaning tool with a ball dropped to deactivate one of the nozzles.
- Figure 6 illustrates a side view of the cleaning tool with a ball dropped to deactivate one of the nozzles.
- Figure 7 illustrates a side view of another embodiment of the cleaning tool during production.
- the term “horizontal” or “deviated” well is used to describe an oil or gas well drilled at an angle at least 30 degrees from vertical.
- the term “debris” is used to mean cuttings, pieces of rock chips, gravel, fines, asphaltenes, solids deposited to reduce fluid loss, and other particles that may interfere with the production or operation of a well.
- one embodiment of downhole cleaning tool 100 is shown installed in wellbore 101 during production.
- Cleaning tool 100 is attached to a portion of tubing 102 and lowered into the well.
- the cleaning tool is shown integrated with the production tubing.
- the cleaning tool may be inserted into the well with a wireline, stinger, or another joint of tubing.
- only one cleaning tool is depicted; however, multiple tools may be installed at various intervals along the tubing to increase cleaning efficiency.
- Cleaning tool 100 may be made up of coaxial pipe 103, fluid divider 104, and vortex spinner 105 connectable around the circumference of the coaxial pipe.
- Connectors 106 hold the spinner in place, decrease friction of vortex spinner 105 while rotating, and seal the fluid flow from interior pipe to outside.
- Figure 2 shows a close-up view of a portion of the downhole cleaning tool from Figure 1 in which connectors 106 are roller bearings, or any similar connection apparatus.
- Vortex spinner 105 comprises spinner housing 107, interior spinner blades 108, and exterior spinner blades 109.
- fluid is pumped down production tubing 102 through cleaning tool 100 towards the bottom of the wellbore as represented by arrow 110.
- fluid divider 104 may be removed from the design.
- the fluid hits interior spinner blades 108 and rotates vortex spinner 105 at a speed sufficient to induce cavitation.
- the interior and exterior spinner blades and may be connected to the vortex spinner in any arrangement; however, a spiral, helical, or slanted configuration is preferred.
- Vortex spinner 105 and exterior spinner blades 109 agitates the fluid in annulus 112 and releases debris attached to the wall of the wellbore. The fluid then may pass through the rest of the assembly.
- Mobilized debris may be circulated along annulus 112 (according to arrow 111) to the surface.
- Figure 3 shows an alternative embodiment of the downhole cleaning tool.
- nozzles 301 may be attached to vortex spinner 105 to enhance the cleaning process. The number of nozzles and angles at which the nozzles are positioned may be adjusted based on well conditions.
- the nozzles may be equipped with nozzles heads (not shown) to direct fluid as it exists the nozzle.
- the nozzles may be threaded or otherwise manufactured to direct fluid flow.
- fluid is pumped down along arrow 110, a portion may pass through nozzle 301 to agitate debris 302 and loosen it from the wellbore. The rest of the fluid continues through the tool to activate rotate the components to induce cavitation.
- Figure 4 shows a top view of the embodiment of the downhole cleaning tool from
- Coaxial pipe 103 is shown encircled by vortex spinner 105.
- a plurality of nozzles 301 extend through vortex spinner 105. In this embodiment, four nozzles are shown; however more could be included in a variety of arrangements.
- Each nozzle may be equipped with a nozzle head 402 at its end, which can be adjusted to set the angle at which fluid exists the tool.
- Each nozzle may be connected to a hole in the inner wall of vortex spinner 105.
- Fluid breaker 403 encircles the inner wall of vortex spinner 105 beneath the holes leading to the nozzles.
- fluid flows across fluid divider 104 and experiences an increase in velocity.
- the fluid divider could be omitted and the vortex spinner driven with the natural velocity of the fluid.
- a portion of the fluid hits interior spinner blades 108 and causes coaxial pipe 103 (or is it vortex spinner 105?) to rotate at a specified speed.
- a different portion of the fluid may enter nozzles 301 and is shot against the formation to loosen debris. The rest of the fluid may continue through the tool to activate the cavitation process via vortex spinners 105.
- One possible path of the fluid is shown by arrows 404; however, others paths are possible.
- controllable passageways capable of stopping fluid communication in one or all of the nozzles may be used.
- a ball 501 may be dropped to deactivate the nozzle.
- Figure 5 shows a top view of the tool with ball 501 resting on fluid breaker 403 and blocking the hole, which leads the leftmost nozzle.
- Figure 6 shows a side view of the same scenario.
- another mechanism known in the industry to block flow such as a flapper valve.
- the vortex spinners may be removed and replaced with pipe 301 so that the tool is simplified to only include the nozzle cleaning mechanism. Any other method that achieves the effect of the controllable passageways may be used.
- Advantages of some embodiments of the invention may include one or more of the following: • Allows the assembly of one or multiple fluid-driven rotary cleaning subs as needed anywhere in the completion eliminating the limitations of tools that may only be installed at the end of the tubing
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- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (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)
- Mechanical Engineering (AREA)
- Cleaning By Liquid Or Steam (AREA)
- Cleaning In General (AREA)
Abstract
A method for cleaning debris from a wellbore having a top and a bottom comprising inserting cleaning tool comprising a coaxial pipe in the wellbore, pumping fluid through the cleaning tool to create a fluid flow in a direction towards the bottom of the wellbore, converting the fluid flow into rotary mechanical power, agitating the debris by cavitation with at least one vortex spinner having a plurality of spinner blades, and allowing the debris to flow towards the top of the wellbore thereby cleaning the wellbore.
Description
CLEANING APPARATUS AND METHOD
Field of Invention
The present inventions relate to a cleaning apparatus and a method for cleaning debris from a wellbore. Background
Formation damage is defined as a reduction in permeability around a wellbore, which is the consequence of drilling, completion, injection, attempted stimulation or production of the well. The mechanism of formation damage varies from well to well; however the transport of solids into and out of the wellbore is consistently an important factor. Drilling mud, drilling fluids drill-in fluids, fluid loss inhibitors, and other similar fluids can invade permeable formations, replacing native fluids adjacent to the wellbore. During replacement, solid particles invade the formation and reduce its permability by blocking flow channels. This blockage in the flow channels causes formation damage, which can result insignificant decreases in well productivity and resulting economic loss.
A variety of techniques have been developed to remove formation damage. Acidization is probably the most commonly applied technique; however this solution may often result in corrosion of the wellbore equipment and chemical incompatibilities. Additionally large volumes of acid are very expensive and can be problematic in horizontal completions. Formation damage may also be limited somewhat by pretreating the fluids used in drilling, fracturing, and perforation; however this is not an option for correcting post-completion damage.
A recent development in the area of hole cleaning is the use of the principle of cavitation for removing debris such as cuttings, pieces of rock chips, gravel, fines, asphaltenes, solids deposited to reduce fluid loss, and other particles that may interfere with the production or operation of a well. Cavitation generally refers to the formation and instantaneous collapse of innumerable tiny vapor bubbles within a fluid subjected to rapid and intense pressure changes. A liquid subjected to a low pressure (tensile stress) above a threshold ruptures and forms vaporous cavities. When the local ambient pressure at a point in the liquid falls below the liquid's vapor pressure at the local ambient temperature, the liquid can undergo a phase change, creating largely empty voids termed cavitation bubbles.
Downhole cleaning via cavitation involves attaching a cavitation tool to the end of the coiled tubing, drill pipe or work string. To do so, the production or drilling must be stopped
while the cleaning apparatus is run into the hole. Fluid pumped through the tool drives a mechanical process that induces cavitation, and a flare of bubbles is released. The combined effects of the flow impact, the suction effects of the decaying bubble flare, and the implosion shock waves of the cavitation are effective to mobilize and remove debris that may be trapped in the wellbore. Summary of the Invention
The present inventions include a method for cleaning debris from a wellbore having a top and a bottom comprising inserting cleaning tool comprising a coaxial pipe in the wellbore, pumping fluid through the cleaning tool to create a fluid flow in a direction towards the bottom of the wellbore, converting the fluid flow into rotary mechanical power, agitating the debris by cavitation with at least one vortex spinner having a plurality of spinner blades, and allowing the debris to flow towards the top of the wellbore thereby cleaning the wellbore.
The present inventions include an apparatus for cleaning a wellbore comprising a coaxial pipe with a first end and a second end, at least one vortex spinner operatively connectable to the coaxial pipe between the first end and the second end, and a fluid divider arranged inside the coaxial pipe. Brief Description of the Drawings
The present invention is better understood by reading the following description of non- limitative embodiments with reference to the attached drawings, wherein like parts of each of the figures are identified by the same reference characters, and which are briefly described as follows:
Figure 1 illustrates a side view of one embodiment of a cleaning tool during production. Figure 2 illustrates a close-up side view of the one embodiment of the downhole cleaning tool.
Figure 3 illustrates a side view of another embodiment of the cleaning tool.
Figure 4 illustrates a top view of the cleaning tool.
Figure 5 illustrates a top view of the cleaning tool with a ball dropped to deactivate one of the nozzles.
Figure 6 illustrates a side view of the cleaning tool with a ball dropped to deactivate one of the nozzles.
Figure 7 illustrates a side view of another embodiment of the cleaning tool during production. Detailed Description
For the purpose of this application, the terms used shall be understood as follows. The term "horizontal" or "deviated" well is used to describe an oil or gas well drilled at an angle at least 30 degrees from vertical. The term "debris" is used to mean cuttings, pieces of rock chips, gravel, fines, asphaltenes, solids deposited to reduce fluid loss, and other particles that may interfere with the production or operation of a well.
Referring to Figure 1, one embodiment of downhole cleaning tool 100 is shown installed in wellbore 101 during production. Cleaning tool 100 is attached to a portion of tubing 102 and lowered into the well. In this embodiment, the cleaning tool is shown integrated with the production tubing. Alternatively the cleaning tool may be inserted into the well with a wireline, stinger, or another joint of tubing. In the embodiment shown, only one cleaning tool is depicted; however, multiple tools may be installed at various intervals along the tubing to increase cleaning efficiency.
Cleaning tool 100 may be made up of coaxial pipe 103, fluid divider 104, and vortex spinner 105 connectable around the circumference of the coaxial pipe. Connectors 106 hold the spinner in place, decrease friction of vortex spinner 105 while rotating, and seal the fluid flow from interior pipe to outside. Figure 2 shows a close-up view of a portion of the downhole cleaning tool from Figure 1 in which connectors 106 are roller bearings, or any similar connection apparatus. Vortex spinner 105 comprises spinner housing 107, interior spinner blades 108, and exterior spinner blades 109.
During operation, fluid is pumped down production tubing 102 through cleaning tool 100 towards the bottom of the wellbore as represented by arrow 110. When the fluid moves through fluid divider 104, the pressure decrease causes the velocity of the fluid to increase. Alternatively fluid divider 104 may be removed from the design. The fluid hits interior spinner blades 108 and rotates vortex spinner 105 at a speed sufficient to induce cavitation. The interior and exterior spinner blades and may be connected to the vortex spinner in any arrangement; however, a spiral, helical, or slanted configuration is preferred. Vortex spinner 105 and exterior spinner blades 109 agitates the fluid in annulus 112 and releases debris attached to the wall of the wellbore. The fluid then may pass through the rest of the assembly. Mobilized debris may be circulated along annulus 112 (according to arrow 111) to the surface.
Figure 3 shows an alternative embodiment of the downhole cleaning tool. In this embodiment, nozzles 301 may be attached to vortex spinner 105 to enhance the cleaning process. The number of nozzles and angles at which the nozzles are positioned may be adjusted based on well conditions. Optionally the nozzles may be equipped with nozzles heads (not shown) to direct fluid as it exists the nozzle. Optionally the nozzles may be threaded or otherwise manufactured to direct fluid flow. When fluid is pumped down along arrow 110, a portion may pass through nozzle 301 to agitate debris 302 and loosen it from the wellbore. The rest of the fluid continues through the tool to activate rotate the components to induce cavitation. Figure 4 shows a top view of the embodiment of the downhole cleaning tool from
Figure 3 in wellbore 101. Coaxial pipe 103 is shown encircled by vortex spinner 105. A plurality of nozzles 301 extend through vortex spinner 105. In this embodiment, four nozzles are shown; however more could be included in a variety of arrangements. Each nozzle may be equipped with a nozzle head 402 at its end, which can be adjusted to set the angle at which fluid exists the tool. Each nozzle may be connected to a hole in the inner wall of vortex spinner 105. Fluid breaker 403 encircles the inner wall of vortex spinner 105 beneath the holes leading to the nozzles.
During operation, fluid flows across fluid divider 104 and experiences an increase in velocity. Alternatively, the fluid divider could be omitted and the vortex spinner driven with the natural velocity of the fluid. A portion of the fluid hits interior spinner blades 108 and causes coaxial pipe 103 (or is it vortex spinner 105?) to rotate at a specified speed. A different portion of the fluid may enter nozzles 301 and is shot against the formation to loosen debris. The rest of the fluid may continue through the tool to activate the cavitation process via vortex spinners 105. One possible path of the fluid is shown by arrows 404; however, others paths are possible.
When the operator no longer requires the use of one of the nozzles, controllable passageways capable of stopping fluid communication in one or all of the nozzles may be used. In one embodiment, a ball 501 may be dropped to deactivate the nozzle. Figure 5 shows a top view of the tool with ball 501 resting on fluid breaker 403 and blocking the hole, which leads the leftmost nozzle. Figure 6 shows a side view of the same scenario. Alternatively another mechanism known in the industry to block flow such as a flapper valve. Alternatively, as shown in Figure 7, the vortex spinners may be removed and replaced with pipe 301 so that the tool is simplified to only include the nozzle cleaning
mechanism. Any other method that achieves the effect of the controllable passageways may be used.
Advantages of some embodiments of the invention may include one or more of the following: • Allows the assembly of one or multiple fluid-driven rotary cleaning subs as needed anywhere in the completion eliminating the limitations of tools that may only be installed at the end of the tubing
• Eliminates additional trips required to disassemble and insert a cleaning assembly
• Reduces or eliminates backreaming • Prevents settling of drill cuttings
• Increases lifetime of completion equipment and other downhole tools
Those of skill in the art will appreciate that many modifications and variations are possible in terms of the disclosed embodiments, configurations, materials, and methods without departing from their spirit and scope. Accordingly, the scope of the claims appended hereafter and their functional equivalents should not be limited by particular embodiments described and illustrated herein, as these are merely exemplary in nature.
Claims
1. A method for cleaning debris from a wellbore having a top and a bottom comprising: inserting cleaning tool comprising a coaxial pipe in the wellbore; pumping fluid through the cleaning tool to create a fluid flow in a direction towards the bottom of the wellbore; converting the fluid flow into rotary mechanical power; agitating the debris by cavitation with at least one vortex spinner having a plurality of spinner blades; and allowing the debris to flow towards the top of the wellbore thereby cleaning the wellbore.
2. The method of claim 1 wherein agitating is performed by allowing the fluid to hit the plurality of spinner blades thereby rotating the coaxial pipe.
3. The method of claim 2 wherein converting is performed by pumping the fluid across a fluid divider towards the bottom of the wellbore and allowing the fluid to hit the plurality of spinner blades thereby turning the at least one vortex spinner.
4. The method of claim 3 wherein the coaxial pipe has a plurality of nozzles which create fluid communication between the interior of the coxaxial pipe and an annulus defined by the area between the coaxial pipe and the wellbore.
5. The method of claim 4 further comprising allowing some of the fluid to pass through the plurality of nozzles to enhance clearning.
6. The method of claim 5 further comprising controllable passageways capable of stopping fluid communication in the plurality of nozzles when desired.
7. The method of claim 6 wherein a plurality of nozzle heads are attached to the plurality of nozzles and adjusted to optimize cleaning.
8. The method of claim 7 wherein the debris is cuttings, pieces of rock chips, gravel, fines, and other particles located on the wellbore, inside perforations shot into the wellbore, or on tools installed in the wellbore.
9. The method of claim 8 wherein the inserting is performed by integrating the cleaning tool with the production tubing.
10. The method of claim 8 wherein the inserting is performed by lowering the cleaning tool into the well with a wireline, stinger, or other tubing.
11. An apparatus for cleaning a wellbore comprising: a coaxial pipe with a first end and a second end; at least one vortex spinner operatively connectable to the coaxial pipe between the first end and the second end; and a fluid divider arranged inside the coaxial pipe.
12. The apparatus of claim 1 wherein the at least one vortex spinner comprises a spinner housing, a set of interior spinner blades, and a set of exterior spinner blades.
13. The apparatus of claim 12 wherein the at least one vortex spinner is connectable to the coaxial pipe with rollers or bearings whereby the spinner housing is rotatable around an axis substantially parallel to the wellbore.
14. The apparatus of claim 13 wherein the first end of the coaxial pipe is connected to a first tubular; wherein the first tubular is selected from the group consisting of production tubing, wireline, workstrings, stingers, and other tubing.
15. The apparatus of claim 14 wherein the second end of the coaxial pipe is connected to a second tubular wherein the first tubular is selected from the group consisting of production tubing, wireline, workstrings, stingers, and other tubing.
16. The apparatus of claim 11 further comprising a plurality of nozzles located on the coaxial pipe; wherein the plurality of nozzles create fluid communication between the interior of the coaxial pipe and an annulus defined by the area between the coaxial pipe and the wellbore.
17. The apparatus of claim 16 further comprising a plurality of nozzle heads attached to the plurality of nozzles.
18. The apparatus of claim 17 further comprising controllable passageways capable of stopping fluid communication in the plurality of nozzles when desired.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/376,023 US20100000738A1 (en) | 2006-08-03 | 2007-08-01 | Cleaning apparatus and methods |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US82136006P | 2006-08-03 | 2006-08-03 | |
US60/821,360 | 2006-08-03 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2008016965A1 true WO2008016965A1 (en) | 2008-02-07 |
Family
ID=38544043
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2007/074954 WO2008016965A1 (en) | 2006-08-03 | 2007-08-01 | Cleaning apparatus and method |
Country Status (2)
Country | Link |
---|---|
US (1) | US20100000738A1 (en) |
WO (1) | WO2008016965A1 (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
RU2563903C1 (en) * | 2014-10-07 | 2015-09-27 | Общество с ограниченной ответственностью "ПРОМГИДРОСЕТИ" | Device for cleaning and recovery of serviceability of water-bearing and oil-and-gas wells |
Families Citing this family (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN111992157B (en) * | 2020-08-31 | 2022-06-24 | 浙江工业大学 | Method and device for preparing monoglyceride based on hydrodynamic cavitation reinforcement |
RU2757385C1 (en) * | 2021-04-09 | 2021-10-14 | Андрей Иванович Ипатов | Device for cleaning horizontal well bore from slurry |
CN114059975A (en) * | 2021-12-28 | 2022-02-18 | 四川涪瑞威尔能源技术有限公司 | Underground tool for removing abandoned well |
US11982164B2 (en) * | 2022-08-29 | 2024-05-14 | Saudi Arabian Oil Company | Artificial lift systems using cavitation |
Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3656565A (en) * | 1970-09-23 | 1972-04-18 | Fred K Fox | Rotary drilling tool |
US4909325A (en) * | 1989-02-09 | 1990-03-20 | Baker Hughes Incorporated | Horizontal well turbulizer and method |
US4919204A (en) * | 1989-01-19 | 1990-04-24 | Otis Engineering Corporation | Apparatus and methods for cleaning a well |
US5158140A (en) * | 1989-12-11 | 1992-10-27 | Societe Nationale Elf Aquitaine (Production) | Apparatus and method for cleaning out an underground well |
GB2341405A (en) * | 1998-02-25 | 2000-03-15 | Specialised Petroleum Serv Ltd | Circulation tool with valve operated by dropped ball |
Family Cites Families (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US68917A (en) * | 1867-09-17 | Stephen | ||
US1230666A (en) * | 1917-05-14 | 1917-06-19 | David A Carden | Cleaning device for wells. |
-
2007
- 2007-08-01 US US12/376,023 patent/US20100000738A1/en not_active Abandoned
- 2007-08-01 WO PCT/US2007/074954 patent/WO2008016965A1/en active Application Filing
Patent Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3656565A (en) * | 1970-09-23 | 1972-04-18 | Fred K Fox | Rotary drilling tool |
US4919204A (en) * | 1989-01-19 | 1990-04-24 | Otis Engineering Corporation | Apparatus and methods for cleaning a well |
US4909325A (en) * | 1989-02-09 | 1990-03-20 | Baker Hughes Incorporated | Horizontal well turbulizer and method |
US5158140A (en) * | 1989-12-11 | 1992-10-27 | Societe Nationale Elf Aquitaine (Production) | Apparatus and method for cleaning out an underground well |
GB2341405A (en) * | 1998-02-25 | 2000-03-15 | Specialised Petroleum Serv Ltd | Circulation tool with valve operated by dropped ball |
Non-Patent Citations (2)
Title |
---|
BAKKER, T.W. ET AL.: "Cavitator for effective well cleaning", SPE 75352, 10 April 2002 (2002-04-10), pages 1 - 4, XP002455132 * |
CRABTREE, M. ET AL.: "Fighting Scale - Removal and Prevention", OILFIELD REVIEW, 1999, Elsevier, Amsterdam NL, pages 30 - 45, XP002455131, Retrieved from the Internet <URL:http://www.slb.com/media/services/resources/oilfieldreview/ors99/aut99/fighting.pdf> [retrieved on 20071016] * |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
RU2563903C1 (en) * | 2014-10-07 | 2015-09-27 | Общество с ограниченной ответственностью "ПРОМГИДРОСЕТИ" | Device for cleaning and recovery of serviceability of water-bearing and oil-and-gas wells |
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US20100000738A1 (en) | 2010-01-07 |
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