CA2769935C - Method and system for cleaning fracture ports - Google Patents
Method and system for cleaning fracture ports Download PDFInfo
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- CA2769935C CA2769935C CA2769935A CA2769935A CA2769935C CA 2769935 C CA2769935 C CA 2769935C CA 2769935 A CA2769935 A CA 2769935A CA 2769935 A CA2769935 A CA 2769935A CA 2769935 C CA2769935 C CA 2769935C
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- jetted
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- pulse generator
- fracture port
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- 238000000034 method Methods 0.000 title claims abstract description 22
- 238000004140 cleaning Methods 0.000 title claims abstract description 12
- 239000012530 fluid Substances 0.000 claims abstract description 59
- 238000004519 manufacturing process Methods 0.000 claims abstract description 16
- 230000004936 stimulating effect Effects 0.000 claims abstract description 7
- 238000002955 isolation Methods 0.000 claims description 8
- 239000002253 acid Substances 0.000 claims description 5
- 239000002904 solvent Substances 0.000 claims description 3
- 238000005086 pumping Methods 0.000 claims description 2
- 239000004094 surface-active agent Substances 0.000 claims description 2
- 239000000203 mixture Substances 0.000 claims 1
- 206010017076 Fracture Diseases 0.000 description 28
- 208000010392 Bone Fractures Diseases 0.000 description 27
- 230000015572 biosynthetic process Effects 0.000 description 5
- 238000005755 formation reaction Methods 0.000 description 5
- 239000000126 substance Substances 0.000 description 5
- 230000000638 stimulation Effects 0.000 description 4
- 238000005516 engineering process Methods 0.000 description 3
- 230000008569 process Effects 0.000 description 3
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 2
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 2
- 208000002565 Open Fractures Diseases 0.000 description 2
- 230000009471 action Effects 0.000 description 2
- 239000012267 brine Substances 0.000 description 2
- 238000005553 drilling Methods 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 239000003209 petroleum derivative Substances 0.000 description 2
- 230000037380 skin damage Effects 0.000 description 2
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 1
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- CTQNGGLPUBDAKN-UHFFFAOYSA-N O-Xylene Chemical compound CC1=CC=CC=C1C CTQNGGLPUBDAKN-UHFFFAOYSA-N 0.000 description 1
- 230000006978 adaptation Effects 0.000 description 1
- 229910052791 calcium Inorganic materials 0.000 description 1
- 239000011575 calcium Substances 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000001186 cumulative effect Effects 0.000 description 1
- 238000004090 dissolution Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000000839 emulsion Substances 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 229910052751 metal Inorganic materials 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 150000007524 organic acids Chemical class 0.000 description 1
- 235000005985 organic acids Nutrition 0.000 description 1
- 238000012856 packing Methods 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
- 239000008096 xylene 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
-
- 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
- E21B37/08—Methods or apparatus for cleaning boreholes or wells cleaning in situ of down-hole filters, screens, e.g. casing perforations, or gravel packs
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Cleaning In General (AREA)
Abstract
A method of stimulating or cleaning a fracture port and the immediate near bore well bore area, includes the steps of inserting a downhole assembly on coiled tubing into a production tubing string comprising a fracture port. The downhole assembly includes a fluid pulse generator and jetting tool which is positioned adjacent the fracture port, and fluid is pumped through the tool to create fluid pressure pulses and jet streams of fluid. The method and apparatus does not require isolating the fracture port to be cleaned with packers or seals.
Description
METHOD AND SYSTEM FOR CLEANING FRACTURE PORTS
Field of the Invention
Field of the Invention
[0002] The present invention is directed to a method and system for cleaning out or stimulating fracture ports and the immediate bore hole area.
Background
Background
[0003] An oil or gas well relies on inflow of petroleum products from the subterranean formation it intersects. Productive intervals may be left uncased (open hole) to expose porosity and permit unrestricted wellbore inflow of petroleum products.
Alternately, the hole may be cased with a liner, which is then perforated to permit inflow through the openings created by perforating.
Alternately, the hole may be cased with a liner, which is then perforated to permit inflow through the openings created by perforating.
[0004] Drilling deeper and horizontally into tighter reservoir rock has become more viable in many oil and gas bearing formations. However, it is still challenging to successfully completing these deeper oil and gas reservoirs using horizontal wells. When natural inflow from the well is not economical, the well may require wellbore treatment termed stimulation.
This is accomplished by pumping stimulation fluids such as fracturing fluids, acid, cleaning chemicals or proppant laden fluids to improve wellbore inflow.
This is accomplished by pumping stimulation fluids such as fracturing fluids, acid, cleaning chemicals or proppant laden fluids to improve wellbore inflow.
[0005] As drilling technology continues to exploit more complex and unconventional reservoirs, completion technology is being designed and developed to effectively stimulate multiple stages along a horizontal wellbore. The growth in multi-stage fracturing has been tremendous due to completion technology that can effectively place fractures in specific =
places in the wellbore. By placing the fracture in specific places in the horizontal wellbore, there is a greater ability to increase the cumulative production in a shorter time frame.
places in the wellbore. By placing the fracture in specific places in the horizontal wellbore, there is a greater ability to increase the cumulative production in a shorter time frame.
[0006] In a conventional multi-stage fracture completion, Fracture ports are intermittently placed along the horizontal wellbore, between open hole packers to isolate each fracture zone.
Following a fracturing operation, it is often necessary to clean out and re-stimulate the fracturing ports and the near bore hole area, if they have plugged or are suffering from wax, scale or asphaltene buildup. Near bore hole buildup of organic or inorganic scale and solids is referred to as skin damage in the industry. Conventionally, cleaning of fracture ports and reversal of skin damage is done by isolating a portion of the production string including the fracture port using tubing run isolation packers, and using fluid pressure and/or chemicals to stimulate or clean out the open fracture port.
Following a fracturing operation, it is often necessary to clean out and re-stimulate the fracturing ports and the near bore hole area, if they have plugged or are suffering from wax, scale or asphaltene buildup. Near bore hole buildup of organic or inorganic scale and solids is referred to as skin damage in the industry. Conventionally, cleaning of fracture ports and reversal of skin damage is done by isolating a portion of the production string including the fracture port using tubing run isolation packers, and using fluid pressure and/or chemicals to stimulate or clean out the open fracture port.
[0007] However, coiled tubing run isolation packers is a time-consuming process to place, set and unset the packers. Furthermore, the packers can fail to be set and seal on the liner. Liners can have detritus materials like scale, corrosion, and metal and mechanical debris, which can cause packers to not set and seal.
[0008] There is a need in the art for alternative and efficient methods of stimulating or cleaning fracture ports.
Summary of the Invention
Summary of the Invention
[0009] In one aspect, the invention comprises a system for stimulating or cleaning a fracture port, comprising an assembly configured to be run on coiled tubing, the assembly comprising a fluid pulse generator and jetting tool, and not comprising an isolation packer or seal.
[0010] In another aspect, the invention may comprise a method of stimulating or cleaning fracture ports, comprising the steps of inserting a tubing string having a downhole assembly configured to be run on coiled tubing, the downhole assembly comprising a fluid pulse generator and jetting tool, and not comprising an isolation packer or seal.
Brief Description of The Drawings
Brief Description of The Drawings
[0011] In the drawings, like elements are assigned like reference numerals.
The drawings are not necessarily to scale, with the emphasis instead placed upon the principles of the present invention. Additionally, each of the embodiments depicted are but one of a number of possible arrangements utilizing the fundamental concepts of the present invention. The drawings are briefly described as follows:
10012] Figure 1 is a schematic view of an oil and gas well having horizontal section and a multi-fracture port completion.
[0013] Figure 2 is an exploded view of one embodiment of fluid pulse generator and jetting tool.
Detailed Description Of Preferred Embodiments [0014] The invention relates to a method and system of treating a series of fracture ports in a wellbore using a fluid pulse generator and jetting tool. When describing the present invention, all terms not defined herein have their common art-recognized meanings. To the extent that the following description is of a specific embodiment or a particular use of the invention, it is intended to be illustrative only, and not limiting of the claimed invention. The following description is intended to cover all alternatives, modifications and equivalents that are included in the spirit and scope of the invention, as defined in the appended claims.
[0015] As used herein, a "a fluid pulse generator and jetting tool" means a tool which may be run into production tubing using coiled tubing, through which a fluid may be pumped. The tool comprises at least one jetted opening, and preferably a plurality of jetted openings, which emit a fluid stream at a relatively high velocity, and a pulse generator which creates pressure pulses in a fluid stream. The fluid pulse generator may also be referred to as a fluidic oscillator.
[0016] In embodiments of the invention, a fluid pulse generator and jetting tool (100) is used to re-stimulate, or clean out fracture ports and the near bore hole area, by incorporating the tool in a wellbore stimulation assembly. The assembly may be a conventional horizontal wellbore (12) assembly which can be used to effect fluid treatment of a formation (10), and may include a tubing string (14) having a lower end (14a) and an upper end extending to surface (not shown). Tubing string (14) includes a plurality of spaced apart ported intervals (16a) to (16e) each including a plurality of fracturing ports (17) opened through the tubing string wall to permit access between the tubing string inner bore (18) and the wellbore.
[0017] A packer (20a) is mounted between the upper-most ported interval (16a) and the surface and further packers (20b) to (20e) are mounted between each pair of adjacent ported 5 intervals. In the illustrated embodiment, a packer (20f) is also mounted below the lower most ported interval (16e) and lower end (14a) of the tubing string. The packers are disposed about the tubing string and selected to seal the annulus between the tubing string and the wellbore wall, when the assembly is disposed in the wellbore. The packers divide the wellbore into isolated segments wherein fluid can be applied to one segment of the well, but is prevented from passing through the annulus into adjacent segments. As will be appreciated the packers can be spaced in any way relative to the ported intervals to achieve a desired interval length or number of ported intervals per segment. In addition, packer (20f) need not be present in some applications.
[0018] The packers may be of any construction, such as conventional solid body-type with at least one rubber or elastomeric packing element.
[0019] Each of the ports may have a mechanism to open and close the openings, such as sliding sleeves. In this embodiment, a sliding sleeve is mounted over each ported interval to close them against fluid flow, but can be moved away from their positions covering the ports to open the ports.
100201 Conventionally, the assembly is run in and positioned downhole with the sliding sleeves each in their closed port position. The sleeves are moved to their open position when the tubing string is ready for use in fluid treatment of the wellbore.
Preferably, the sleeves for each isolated interval between adjacent packers are opened individually to permit fluid flow to one wellbore segment at a time, in a staged, concentrated treatment process.
The sleeves may be actuated by use of a plug or ball inserted into the tubing string, which may be seated into a .. sealing position and activated by fluid pressure. A suitable apparatus is described in US
Patent Application No. 2011/0278010 Al.
[0021] The tubing string is run into the well and the packers are placed between the perforated intervals. If blast joints are included in the tubing string, they are preferably positioned at the same depth as the perforated sections. The packers are then set by mechanical or pressure .. actuation. Once the packers are set, stimulation fluids are then pumped down the tubing string. The packers will divert the fluids to a specific segment of the wellbore. A ball or plug is then pumped to shut off the lower segment of the well and to open a siding sleeve to allow fluid to be forced into the next interval, where packers will again divert fluids into specific segment of the well. The process is continued until all desired segments of the wellbore are .. stimulated or treated. When completed, the treating fluids can be either shut in or flowed back immediately.
[0022] The fracture ports are left open to the formation, allowing ingress of production fluids.
Over time, the fracturing ports may plug or suffer from wax, scale or asphaltene buildup.
Thus, it is often necessary or desirable to clean out or re-stimulate the fracture ports.
Conventionally, this is done by isolating a portion of the production string including the fracture port using isolation packers run inside the tubing string, and using fluid pressure and/or chemicals to stimulate or clean out the open fracture port.
[0023] The applicants have unexpectedly found that a fluid pulse generator and jetting tool positioned within the tubing string and adjacent a fracture port may efficiently clean out a fracture port, without the need to isolate the interval. Therefore, the system of the present invention does not require an isolation packer or seal.
[0024] The fluid pulse generator and jetting tool is a tool which generates fluid pressure pulses and a pressurized fluid stream. One embodiment of the tool (100) is adapted to be run in on coiled tubing with a bottom hole assembly (102). The tool provides at least one, and preferably a plurality of jetted fluid streams, with a pressure pulse generator.
[0025] In one embodiment, the bottom hole assembly or BHA (102) comprises an internal check valve (not shown) and attaches to the tubing in a conventional manner.
The bottom of the BHA threadingly engages the top of the top jet sub (104) in a conventional fluid-tight manner. The other components of the tool are fitted together in top to bottom order: a top .. reflective focussing chamber (106), a pulse generator (108), a bottom reflective focussing chamber (110), a down jet sub (112), and a nose jet cone (114).
[0026] Both the top jet sub and the bottom jet subs (104, 112) define a plurality of jetted openings (116), which preferably are angled towards the ends of the tool. In one embodiment, each sub comprises 6 jetted openings located around the periphery of the sub.
[0027] The pulse generator (108) comprises an outer housing (120) and an internal generator (122) which defines at least one angled opening. Fluid under pressure which exits the internal generator will cause the generator to spin within the outer housing. The outer housing defines at least one opening which periodically aligns with the generator angled opening as the generator spins within the outer housing. The generator attaches to the top reflective =
focussing chamber (106) and the bottom reflective focussing chamber (110) with top and bottom cross-overs (124, 126) respectively.
[0028] Each of the top and bottom reflective focussing chambers comprises an inner tube (130) which provides fluid communication between the top jet sub and the bottom jet sub and the pulse generator, and a slotted outer tube (132). The outer tube has an inside diameter which is slightly larger than the outside diameter of the inner tube, creating an annular space therebetween. The outer tube defines a plurality of slots, which preferably are configured diagonally such the slot ends are farther away from the pulse generator than the middle of the slots. The focussing chambers cause pressure pulses to propagate in the annular space between the inner and outer tubes, and reflect back towards the pulse generator.
[0029] The bottom jet sub is similar to the top jet sub and comprises a plurality of jetted openings which are preferably angled away from the pulse generator. The nose jet cone is fitted to the bottom end of the tool, and may comprise a jetted opening, which is preferably aimed away from tool.
[0030] In use, the tool is run into the production tubing using conventional coiled tubing techniques and positioned adjacent a fracture port which is to be treated.
Fluid is pumped under pressure through the coiled tubing and BHA. Upon reaching the tool (100), the fluid is jetted out the jet openings in the top and bottom jet subs, as well as the nose jet cone. The fluid also causes rotation of the generator within the pulse generator outer housing. When the angled opening aligns with the outer housing opening, a pressure pulse is emitted from the pulse generator. As well, the pressure pulse is accompanied by a simultaneous pressure drop at all the jetted openings, resulting in an reverse pressure pulse through the jet openings.
[0031] The fluid which is pumped through the tool may comprise various chemistries designed to remove scale, wax or asphaltene build-up among other objectives, such as the breakdown of emulsions and dispersal of formation fines. For example, the fluid may comprise an acid, such as hydrochloric acid, which may facilitate dissolution of iron and calcium based scales. Organic acids or surfactants may also be effective. The fluid may comprise a solvent component which helps remove hydrocarbon components of the scale, such as wax or asphaltenes, and may help water wet the reservoir.
[0032] Because of the jet and pulse action of the tool, and the chemical action of the injection .. fluid, pressure isolation of the fracture port is not required. The jetted fluid and pressure pulses are effective in cleaning out the fracture port, so long as the tool is appropriately positioned adjacent the fracture port.
[00341 In one example, a tool configured as shown in the Figures was rigged onto coiled tubing and pressure tested. Once the pressure test was complete, the tool is run in hole at a run rate of about 25 m/min while clean brine was slowly pumped (50 1/min) into the tool to ensure the BHA and tool remain clean while running in hole.
[0035] Once near the tubing bottom, the brine fluid rate was increased to above (18)0 1/min and the run rate slowed to about 10 na/min. Fluid was then switched to a xylene solvent while 5 the tool was run towards the toe, while attempting to locate the fracture ports using a collar locator and a measurement schedule.
[0036] Once at the toe, the tool is then slowly pulled out of hole, while locating the terminal fracture port. The fluid was then switched to acid while pulling out of hole.
While in the vicinity of fracture ports, the acid was pumped at a high rate (>(18)0 1/min) and was pumped 10 at a lower rate (50 1/min) between fracture ports. The well was then shut in and the chemical was allowed to soak for a few hours.
10037] As will be apparent to those skilled in the art, various modifications, adaptations and variations of the foregoing specific disclosure can be made without departing from the scope of the invention claimed herein.
The drawings are not necessarily to scale, with the emphasis instead placed upon the principles of the present invention. Additionally, each of the embodiments depicted are but one of a number of possible arrangements utilizing the fundamental concepts of the present invention. The drawings are briefly described as follows:
10012] Figure 1 is a schematic view of an oil and gas well having horizontal section and a multi-fracture port completion.
[0013] Figure 2 is an exploded view of one embodiment of fluid pulse generator and jetting tool.
Detailed Description Of Preferred Embodiments [0014] The invention relates to a method and system of treating a series of fracture ports in a wellbore using a fluid pulse generator and jetting tool. When describing the present invention, all terms not defined herein have their common art-recognized meanings. To the extent that the following description is of a specific embodiment or a particular use of the invention, it is intended to be illustrative only, and not limiting of the claimed invention. The following description is intended to cover all alternatives, modifications and equivalents that are included in the spirit and scope of the invention, as defined in the appended claims.
[0015] As used herein, a "a fluid pulse generator and jetting tool" means a tool which may be run into production tubing using coiled tubing, through which a fluid may be pumped. The tool comprises at least one jetted opening, and preferably a plurality of jetted openings, which emit a fluid stream at a relatively high velocity, and a pulse generator which creates pressure pulses in a fluid stream. The fluid pulse generator may also be referred to as a fluidic oscillator.
[0016] In embodiments of the invention, a fluid pulse generator and jetting tool (100) is used to re-stimulate, or clean out fracture ports and the near bore hole area, by incorporating the tool in a wellbore stimulation assembly. The assembly may be a conventional horizontal wellbore (12) assembly which can be used to effect fluid treatment of a formation (10), and may include a tubing string (14) having a lower end (14a) and an upper end extending to surface (not shown). Tubing string (14) includes a plurality of spaced apart ported intervals (16a) to (16e) each including a plurality of fracturing ports (17) opened through the tubing string wall to permit access between the tubing string inner bore (18) and the wellbore.
[0017] A packer (20a) is mounted between the upper-most ported interval (16a) and the surface and further packers (20b) to (20e) are mounted between each pair of adjacent ported 5 intervals. In the illustrated embodiment, a packer (20f) is also mounted below the lower most ported interval (16e) and lower end (14a) of the tubing string. The packers are disposed about the tubing string and selected to seal the annulus between the tubing string and the wellbore wall, when the assembly is disposed in the wellbore. The packers divide the wellbore into isolated segments wherein fluid can be applied to one segment of the well, but is prevented from passing through the annulus into adjacent segments. As will be appreciated the packers can be spaced in any way relative to the ported intervals to achieve a desired interval length or number of ported intervals per segment. In addition, packer (20f) need not be present in some applications.
[0018] The packers may be of any construction, such as conventional solid body-type with at least one rubber or elastomeric packing element.
[0019] Each of the ports may have a mechanism to open and close the openings, such as sliding sleeves. In this embodiment, a sliding sleeve is mounted over each ported interval to close them against fluid flow, but can be moved away from their positions covering the ports to open the ports.
100201 Conventionally, the assembly is run in and positioned downhole with the sliding sleeves each in their closed port position. The sleeves are moved to their open position when the tubing string is ready for use in fluid treatment of the wellbore.
Preferably, the sleeves for each isolated interval between adjacent packers are opened individually to permit fluid flow to one wellbore segment at a time, in a staged, concentrated treatment process.
The sleeves may be actuated by use of a plug or ball inserted into the tubing string, which may be seated into a .. sealing position and activated by fluid pressure. A suitable apparatus is described in US
Patent Application No. 2011/0278010 Al.
[0021] The tubing string is run into the well and the packers are placed between the perforated intervals. If blast joints are included in the tubing string, they are preferably positioned at the same depth as the perforated sections. The packers are then set by mechanical or pressure .. actuation. Once the packers are set, stimulation fluids are then pumped down the tubing string. The packers will divert the fluids to a specific segment of the wellbore. A ball or plug is then pumped to shut off the lower segment of the well and to open a siding sleeve to allow fluid to be forced into the next interval, where packers will again divert fluids into specific segment of the well. The process is continued until all desired segments of the wellbore are .. stimulated or treated. When completed, the treating fluids can be either shut in or flowed back immediately.
[0022] The fracture ports are left open to the formation, allowing ingress of production fluids.
Over time, the fracturing ports may plug or suffer from wax, scale or asphaltene buildup.
Thus, it is often necessary or desirable to clean out or re-stimulate the fracture ports.
Conventionally, this is done by isolating a portion of the production string including the fracture port using isolation packers run inside the tubing string, and using fluid pressure and/or chemicals to stimulate or clean out the open fracture port.
[0023] The applicants have unexpectedly found that a fluid pulse generator and jetting tool positioned within the tubing string and adjacent a fracture port may efficiently clean out a fracture port, without the need to isolate the interval. Therefore, the system of the present invention does not require an isolation packer or seal.
[0024] The fluid pulse generator and jetting tool is a tool which generates fluid pressure pulses and a pressurized fluid stream. One embodiment of the tool (100) is adapted to be run in on coiled tubing with a bottom hole assembly (102). The tool provides at least one, and preferably a plurality of jetted fluid streams, with a pressure pulse generator.
[0025] In one embodiment, the bottom hole assembly or BHA (102) comprises an internal check valve (not shown) and attaches to the tubing in a conventional manner.
The bottom of the BHA threadingly engages the top of the top jet sub (104) in a conventional fluid-tight manner. The other components of the tool are fitted together in top to bottom order: a top .. reflective focussing chamber (106), a pulse generator (108), a bottom reflective focussing chamber (110), a down jet sub (112), and a nose jet cone (114).
[0026] Both the top jet sub and the bottom jet subs (104, 112) define a plurality of jetted openings (116), which preferably are angled towards the ends of the tool. In one embodiment, each sub comprises 6 jetted openings located around the periphery of the sub.
[0027] The pulse generator (108) comprises an outer housing (120) and an internal generator (122) which defines at least one angled opening. Fluid under pressure which exits the internal generator will cause the generator to spin within the outer housing. The outer housing defines at least one opening which periodically aligns with the generator angled opening as the generator spins within the outer housing. The generator attaches to the top reflective =
focussing chamber (106) and the bottom reflective focussing chamber (110) with top and bottom cross-overs (124, 126) respectively.
[0028] Each of the top and bottom reflective focussing chambers comprises an inner tube (130) which provides fluid communication between the top jet sub and the bottom jet sub and the pulse generator, and a slotted outer tube (132). The outer tube has an inside diameter which is slightly larger than the outside diameter of the inner tube, creating an annular space therebetween. The outer tube defines a plurality of slots, which preferably are configured diagonally such the slot ends are farther away from the pulse generator than the middle of the slots. The focussing chambers cause pressure pulses to propagate in the annular space between the inner and outer tubes, and reflect back towards the pulse generator.
[0029] The bottom jet sub is similar to the top jet sub and comprises a plurality of jetted openings which are preferably angled away from the pulse generator. The nose jet cone is fitted to the bottom end of the tool, and may comprise a jetted opening, which is preferably aimed away from tool.
[0030] In use, the tool is run into the production tubing using conventional coiled tubing techniques and positioned adjacent a fracture port which is to be treated.
Fluid is pumped under pressure through the coiled tubing and BHA. Upon reaching the tool (100), the fluid is jetted out the jet openings in the top and bottom jet subs, as well as the nose jet cone. The fluid also causes rotation of the generator within the pulse generator outer housing. When the angled opening aligns with the outer housing opening, a pressure pulse is emitted from the pulse generator. As well, the pressure pulse is accompanied by a simultaneous pressure drop at all the jetted openings, resulting in an reverse pressure pulse through the jet openings.
[0031] The fluid which is pumped through the tool may comprise various chemistries designed to remove scale, wax or asphaltene build-up among other objectives, such as the breakdown of emulsions and dispersal of formation fines. For example, the fluid may comprise an acid, such as hydrochloric acid, which may facilitate dissolution of iron and calcium based scales. Organic acids or surfactants may also be effective. The fluid may comprise a solvent component which helps remove hydrocarbon components of the scale, such as wax or asphaltenes, and may help water wet the reservoir.
[0032] Because of the jet and pulse action of the tool, and the chemical action of the injection .. fluid, pressure isolation of the fracture port is not required. The jetted fluid and pressure pulses are effective in cleaning out the fracture port, so long as the tool is appropriately positioned adjacent the fracture port.
[00341 In one example, a tool configured as shown in the Figures was rigged onto coiled tubing and pressure tested. Once the pressure test was complete, the tool is run in hole at a run rate of about 25 m/min while clean brine was slowly pumped (50 1/min) into the tool to ensure the BHA and tool remain clean while running in hole.
[0035] Once near the tubing bottom, the brine fluid rate was increased to above (18)0 1/min and the run rate slowed to about 10 na/min. Fluid was then switched to a xylene solvent while 5 the tool was run towards the toe, while attempting to locate the fracture ports using a collar locator and a measurement schedule.
[0036] Once at the toe, the tool is then slowly pulled out of hole, while locating the terminal fracture port. The fluid was then switched to acid while pulling out of hole.
While in the vicinity of fracture ports, the acid was pumped at a high rate (>(18)0 1/min) and was pumped 10 at a lower rate (50 1/min) between fracture ports. The well was then shut in and the chemical was allowed to soak for a few hours.
10037] As will be apparent to those skilled in the art, various modifications, adaptations and variations of the foregoing specific disclosure can be made without departing from the scope of the invention claimed herein.
Claims (13)
1. A system for stimulating or cleaning a fracture port of a production tubing string, and an immediate near bore well bore area surrounding the production tubing string and defining an annulus therebetween, the system comprising an assembly configured to be run on coiled tubing into the production tubing string, the assembly comprising a fluid pulse generator and jetting tool, and not comprising an isolation packer or seal within the production tubing string.
2. The system of claim 1 wherein the fluid pulse generator and jetting tool comprises an elongate tool having a top jetted sub, and a bottom jetted sub, separated by a pulse generator.
3. The system of claim 2 wherein each of the top and bottom jetted subs comprises a plurality of jetted openings distributed around the periphery of the top and bottom jetted subs.
4. The system of claim 3 wherein at least a portion of the jetted openings are angled away from the pulse generator.
5. The system of claim 2 further comprising a nose jet cone having a jetted opening.
6. A method of stimulating or cleaning at least one fracture port of a production tubing string, and an immediate near bore well bore area surrounding the production tubing string and defining an annulus therebetween, the method comprising the steps of inserting a downhole assembly configured to be run on coiled tubing into the production tubing string comprising the at least one fracture port, the downhole assembly comprising a fluid pulse generator and jetting tool, positioning the tool adjacent the at least one fracture port, and pumping fluid through the tool to create fluid pressure pulses and jet streams of fluid, wherein said method does not include a step of isolating the fracture port to be cleaned within the production tubing string.
7. The method of claim 6 wherein the fluid pulse generator and jetting tool comprises an elongate tool having a top jetted sub, and a bottom jetted sub, separated by a pulse generator.
8. The method of claim 7 wherein each of the top and bottom jetted subs comprises a plurality of jetted openings distributed around the periphery of the top and bottom jetted subs.
9. The method of claim 8 wherein at least a portion of the jetted openings are angled away from the pulse generator.
10. The method of claim 7 further comprising a nose jet cone having a jetted opening.
11. The method of claim 6 wherein the production tubing string comprises a horizontal section having a plurality of fracture ports, and the fluid pulse generator and jetting tool is advanced or retracted from fracture port to fracture port along the horizontal section.
12. The method of claim 6 wherein the fluid pumped through the tool has a different chemistry as the tool is advanced from fracture port to fracture port, than when it is retracted from fracture port to fracture port.
13. The method of claim 6 or 12 wherein the fluid pumped comprises an acid, a surfactant, a solvent, or mixtures thereof.
Priority Applications (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2769935A CA2769935C (en) | 2012-02-28 | 2012-02-28 | Method and system for cleaning fracture ports |
| US13/649,775 US20130220618A1 (en) | 2012-02-28 | 2012-10-11 | Method and system for cleaning fracture ports |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2769935A CA2769935C (en) | 2012-02-28 | 2012-02-28 | Method and system for cleaning fracture ports |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2769935A1 CA2769935A1 (en) | 2013-08-28 |
| CA2769935C true CA2769935C (en) | 2020-04-14 |
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Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2769935A Active CA2769935C (en) | 2012-02-28 | 2012-02-28 | Method and system for cleaning fracture ports |
Country Status (2)
| Country | Link |
|---|---|
| US (1) | US20130220618A1 (en) |
| CA (1) | CA2769935C (en) |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| NO339191B1 (en) * | 2013-09-06 | 2016-11-14 | Hydra Systems As | Method of isolating a permeable zone in an underground well |
| FR3016004A1 (en) * | 2013-12-27 | 2015-07-03 | France Regeneration Technology | DEVICE FOR CLEANING AND REGENERATING DRILLING WELLS |
| CN104234682B (en) * | 2014-07-14 | 2016-02-03 | 山西蓝焰煤层气集团有限责任公司 | A kind ofly be applicable to separate stratum fracturing of continuous oil pipe method that is many, girdle |
| WO2017143459A1 (en) * | 2016-02-25 | 2017-08-31 | Advancing Pump Technology Corp. | Electric motor and rod-driven rotary gear pumps |
| WO2018004691A1 (en) * | 2016-07-01 | 2018-01-04 | Halliburton Energy Services, Inc. | Installation of signal cables through coiled tubing using dissolvable bullets |
| US10465480B2 (en) | 2017-12-06 | 2019-11-05 | Michael W. Dennis | Cleanout tools and related methods of operation |
| CN110273652B (en) * | 2018-03-14 | 2021-06-01 | 中国石油天然气股份有限公司 | Oil production well acid pickling pipe column structure and acid pickling method of oil production well |
| WO2020023286A1 (en) * | 2018-07-27 | 2020-01-30 | Baker Hughes, A Ge Company, Llc | Distributed fluid injection system for wellbores |
| CN111075395B (en) * | 2019-12-28 | 2022-01-28 | 中国海洋石油集团有限公司 | Pressure wave intelligence sliding sleeve |
| CN111577234B (en) * | 2020-06-05 | 2022-06-07 | 中国石油天然气集团有限公司 | Pulse horizontal well volume fracturing device and horizontal well volume fracturing method |
Family Cites Families (12)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4612986A (en) * | 1984-06-04 | 1986-09-23 | Fosdick Jr Frank D | Well cleaning apparatus and treating method |
| US4991653A (en) * | 1989-11-08 | 1991-02-12 | Halliburton Company | Wash tool |
| US5135051A (en) * | 1991-06-17 | 1992-08-04 | Facteau David M | Perforation cleaning tool |
| US5195585A (en) * | 1991-07-18 | 1993-03-23 | Otis Engineering Corporation | Wireline retrievable jet cleaning tool |
| US5228508A (en) * | 1992-05-26 | 1993-07-20 | Facteau David M | Perforation cleaning tools |
| US5564500A (en) * | 1995-07-19 | 1996-10-15 | Halliburton Company | Apparatus and method for removing gelled drilling fluid and filter cake from the side of a well bore |
| US5603378A (en) * | 1995-11-02 | 1997-02-18 | Alford; George | Well cleaning tool |
| US6029746A (en) * | 1997-07-22 | 2000-02-29 | Vortech, Inc. | Self-excited jet stimulation tool for cleaning and stimulating wells |
| US7036594B2 (en) * | 2000-03-02 | 2006-05-02 | Schlumberger Technology Corporation | Controlling a pressure transient in a well |
| US7007865B2 (en) * | 2003-08-14 | 2006-03-07 | Rex A. Dodd | Self-adjusting nozzle |
| WO2010088679A2 (en) * | 2009-02-02 | 2010-08-05 | Schlumberger Canada Limited | Bottom hole assembly for wellbore operations |
| US8528649B2 (en) * | 2010-11-30 | 2013-09-10 | Tempress Technologies, Inc. | Hydraulic pulse valve with improved pulse control |
-
2012
- 2012-02-28 CA CA2769935A patent/CA2769935C/en active Active
- 2012-10-11 US US13/649,775 patent/US20130220618A1/en not_active Abandoned
Also Published As
| Publication number | Publication date |
|---|---|
| CA2769935A1 (en) | 2013-08-28 |
| US20130220618A1 (en) | 2013-08-29 |
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