WO2016175876A1 - Flow cotrol in subterranean wells - Google Patents
Flow cotrol in subterranean wells Download PDFInfo
- Publication number
- WO2016175876A1 WO2016175876A1 PCT/US2015/038248 US2015038248W WO2016175876A1 WO 2016175876 A1 WO2016175876 A1 WO 2016175876A1 US 2015038248 W US2015038248 W US 2015038248W WO 2016175876 A1 WO2016175876 A1 WO 2016175876A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- well
- flow
- retainer
- fibers
- conveyed
- Prior art date
Links
- 239000000835 fiber Substances 0.000 claims abstract description 51
- 238000000034 method Methods 0.000 claims abstract description 43
- 230000000717 retained effect Effects 0.000 claims abstract description 5
- 239000000463 material Substances 0.000 claims description 62
- 239000012530 fluid Substances 0.000 claims description 36
- 239000000203 mixture Substances 0.000 claims description 8
- 239000000126 substance Substances 0.000 claims description 7
- 229920001778 nylon Polymers 0.000 claims description 6
- 239000004677 Nylon Substances 0.000 claims description 5
- 239000002253 acid Substances 0.000 claims description 5
- 206010073306 Exposure to radiation Diseases 0.000 claims description 4
- 239000000155 melt Substances 0.000 claims description 4
- 239000004744 fabric Substances 0.000 description 11
- 230000000593 degrading effect Effects 0.000 description 10
- 230000015572 biosynthetic process Effects 0.000 description 9
- 238000005755 formation reaction Methods 0.000 description 9
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 description 8
- 238000011282 treatment Methods 0.000 description 6
- 239000004568 cement Substances 0.000 description 5
- 238000007789 sealing Methods 0.000 description 5
- 229910000019 calcium carbonate Inorganic materials 0.000 description 4
- 238000004891 communication Methods 0.000 description 4
- 239000002657 fibrous material Substances 0.000 description 4
- 239000002245 particle Substances 0.000 description 4
- 239000004633 polyglycolic acid Substances 0.000 description 4
- 229950008885 polyglycolic acid Drugs 0.000 description 4
- 238000005260 corrosion Methods 0.000 description 3
- 230000007797 corrosion Effects 0.000 description 3
- 239000004626 polylactic acid Substances 0.000 description 3
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- -1 etc.) Substances 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 230000008018 melting Effects 0.000 description 2
- 238000002844 melting Methods 0.000 description 2
- 230000005855 radiation Effects 0.000 description 2
- 239000002002 slurry Substances 0.000 description 2
- 238000006467 substitution reaction Methods 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 229910000838 Al alloy Inorganic materials 0.000 description 1
- 229910011255 B2O3 Inorganic materials 0.000 description 1
- 229920003345 Elvax® Polymers 0.000 description 1
- 229910000861 Mg alloy Inorganic materials 0.000 description 1
- 229920003171 Poly (ethylene oxide) Polymers 0.000 description 1
- 239000004743 Polypropylene Substances 0.000 description 1
- 239000004372 Polyvinyl alcohol Substances 0.000 description 1
- 150000007513 acids Chemical class 0.000 description 1
- 238000007792 addition Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000011230 binding agent Substances 0.000 description 1
- 229910021538 borax Inorganic materials 0.000 description 1
- 150000001639 boron compounds Chemical class 0.000 description 1
- 238000009954 braiding Methods 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- DQXBYHZEEUGOBF-UHFFFAOYSA-N but-3-enoic acid;ethene Chemical compound C=C.OC(=O)CC=C DQXBYHZEEUGOBF-UHFFFAOYSA-N 0.000 description 1
- 150000004649 carbonic acid derivatives Chemical class 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 229920001577 copolymer Polymers 0.000 description 1
- 238000012217 deletion Methods 0.000 description 1
- 230000037430 deletion Effects 0.000 description 1
- JKWMSGQKBLHBQQ-UHFFFAOYSA-N diboron trioxide Chemical compound O=BOB=O JKWMSGQKBLHBQQ-UHFFFAOYSA-N 0.000 description 1
- 230000005670 electromagnetic radiation Effects 0.000 description 1
- 239000005038 ethylene vinyl acetate Substances 0.000 description 1
- 239000006023 eutectic alloy Substances 0.000 description 1
- 239000002360 explosive Substances 0.000 description 1
- 238000007667 floating Methods 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000012188 paraffin wax Substances 0.000 description 1
- 229920001200 poly(ethylene-vinyl acetate) Polymers 0.000 description 1
- 229920001155 polypropylene Polymers 0.000 description 1
- 229920001296 polysiloxane Polymers 0.000 description 1
- 229920002451 polyvinyl alcohol Polymers 0.000 description 1
- 239000012858 resilient material Substances 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 235000010339 sodium tetraborate Nutrition 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 239000007779 soft material Substances 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- BSVBQGMMJUBVOD-UHFFFAOYSA-N trisodium borate Chemical compound [Na+].[Na+].[Na+].[O-]B([O-])[O-] BSVBQGMMJUBVOD-UHFFFAOYSA-N 0.000 description 1
- 239000012178 vegetable wax Substances 0.000 description 1
- 239000011345 viscous material Substances 0.000 description 1
- 239000001993 wax Substances 0.000 description 1
- 238000009941 weaving Methods 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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
- E21B33/138—Plastering the borehole wall; Injecting into the formation
Definitions
- This disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, in one example described below, more particularly provides for flow control in wells.
- FIG. 1 is a representative partially cross-sectional view of an example of a well system and associated method which can embody principles of this disclosure.
- FIGS. 2A-D are enlarged scale representative partially cross-sectional views of steps in an example of a re- completion method that may be practiced with the system of FIG. 1.
- FIGS. 3A-D are representative partially cross-sectional views of steps in another example of a method that may be practiced with the system of FIG. 1.
- FIG. 4 is an enlarged scale representative elevational view of a flow conveyed device that may be used in the system and methods of FIGS. 1-3D, and which can embody the principles of this disclosure.
- FIG. 5 is a representative elevational view of another example of the flow conveyed device.
- FIGS. 6A & B are representative partially cross- sectional views of the flow conveyed device in a well, the device being conveyed by flow in FIG. 6A, and engaging a casing opening in FIG. 6B.
- FIGS. 7-9 are representative elevational views of examples of the flow conveyed device with a retainer.
- FIG. 1 Representatively illustrated in FIG. 1 is a system 10 for use with a well, and an associated method, which can embody principles of this disclosure.
- system 10 and method are merely one example of an application of the principles of this disclosure in practice, and a wide variety of other examples are possible. Therefore, the scope of this disclosure is not limited at all to the details of the system 10 and method described herein and/or depicted in the drawings.
- a tubular string 12 is conveyed into a wellbore 14 lined with casing 16 and cement 18.
- the tubular string 12 of FIG. 1 comprises coiled tubing
- coil tubing refers to a substantially continuous tubing that is stored on a spool or reel 24.
- the reel 24 could be mounted, for example, on a skid, a trailer, a floating vessel, a vehicle, etc., for transport to a wellsite.
- a control room or cab would typically be provided with instrumentation, computers, controllers, recorders, etc., for controlling equipment such as an injector 26 and a blowout preventer stack 28.
- bottom hole assembly refers to an assembly connected at a distal end of a tubular string in a well. It is not necessary for a bottom hole assembly to be positioned or used at a "bottom” of a hole or well.
- Fluid, slurries, etc. can be flowed from surface into the annulus 30 via, for example, a casing valve 32.
- One or more pumps 34 may be used for this purpose. Fluid can also be flowed to surface from the wellbore 14 via the annulus 30 and valve 32.
- Fluid, slurries, etc. can also be flowed from surface into the wellbore 14 via the tubing 20, for example, using one or more pumps 36. Fluid can also be flowed to surface from the wellbore 14 via the tubing 20.
- one or more flow conveyed devices are used to block or plug openings in the system 10 of FIG. 1.
- the flow conveyed device may be used with other systems, and the flow conveyed device may be used in other methods in keeping with the principles of this disclosure.
- conveyed device examples described below are made of a fibrous material and comprise a "knot" or other enlarged geometry .
- the devices are conveyed into leak paths using pumped fluid.
- the fibrous material "finds" and follows the fluid flow, pulling the enlarged geometry into a restricted portion of a flow path, causing the enlarged geometry and additional strands to become tightly wedged into the flow path thereby sealing off fluid communication.
- the devices can be made of degradable or non-degradable materials.
- the degradable materials can be either self- degrading, or can require degrading treatments, such as, by exposing the materials to certain acids, certain base compositions, certain chemicals, certain types of radiation (e.g., electromagnetic or "nuclear”), or elevated
- the exposure can be performed at a desired time using a form of well intervention, such as, by spotting or circulating a fluid in the well so that the material is exposed to the fluid.
- the material can be an acid
- degradable material e.g., nylon, etc.
- a mix of acid degradable material for example, nylon fibers mixed with particulate such as calcium carbonate
- self-degrading material e.g., poly-lactic acid (PLA), poly-glycolic acid (PGA), etc.
- material that degrades by galvanic action such as, magnesium alloys, aluminum alloys, etc.
- a combination of different self-degrading materials such as, magnesium alloys, aluminum alloys, etc.
- nylon and calcium carbonate could be pumped as a mixture, or the nylon could be pumped first to initiate a seal, followed by calcium carbonate to enhance the seal.
- the device can be made of knotted fibrous materials. Multiple knots can be used with any number of loose ends. The ends can be frayed or un-frayed.
- the fibrous material can be rope, fabric, cloth or another woven or braided structure.
- the device can be used to block open sleeve valves, perforations or any leak paths in a well (such as, leaking connections in casing, corrosion holes, etc.). Any opening through which fluid flows can be blocked with a suitably configured device.
- a well with an existing perforated zone can be re-completed.
- the well can then be re-completed using any desired completion technique. If the devices are degradable, a degrading treatment can then be placed in the well to open up the plugged perforations (if desired).
- multiple formation zones can be perforated and fractured in a single trip of the bottom hole assembly 22 into the well.
- one zone is perforated, the zone is fractured, and then the perforated zone is plugged using one or more devices .
- steps in an example of a method in which the bottom hole assembly 22 of FIG. 1 can be used in re-completing a well are
- the well has existing perforations 38 that provide for fluid communication between an earth formation zone 40 and an interior of the casing 16. However, it is desired to re- complete the zone 40, in order to enhance the fluid
- Plugs 42 in the perforations can be flow conveyed devices, as described more fully below. In that case, the plugs 42 can be conveyed through the casing 16 and into engagement with the perforations 38 by fluid flow 44.
- new perforations 46 are formed through the casing 16 and cement 18 by use of an abrasive jet perforator 48.
- the bottom hole assembly 22 includes the perforator 48 and a
- the new perforations 38 could be formed in any location in keeping with the principles of this disclosure.
- the circulating valve assembly 50 controls flow between the coiled tubing 20 and the perforator 48, and controls flow between the annulus 30 and an interior of the tubular string 12.
- the plugs could be deployed into the tubular string 12 and conveyed by fluid flow 52 through the tubular string prior to the perforating operation.
- a valve 54 of the circulating valve assembly 50 could be opened to allow the plugs 42 to exit the tubular string 12 and flow into the interior of the casing 16 external to the tubular string.
- FIG. 2D the zone 40 has been fractured by applying increased pressure to the zone after the perforating operation.
- the plugs 42 prevent the pressure applied to fracture the zone 40 via the
- the plugs 42 may remain in the perforations 38 and continue to prevent flow through the perforations, or the plugs may degrade, if desired, so that flow is
- FIG. 1 can be used in completing multiple zones 40a-c of a well are representatively illustrated.
- the multiple zones 40a-c are each perforated and fractured during a single trip of the tubular string 12 into the well.
- the tubular string 12 has been deployed into the casing 16, and has been positioned so that the perforator 48 is at the first zone 40a to be completed.
- the perforator 48 is then used to form perforations 46a through the casing 16 and cement 18, and into the zone 40a.
- the zone 40a has been fractured by applying increased pressure to the zone via the perforations 46a.
- the fracturing pressure may be applied, for example, via the annulus 30 from the surface (e.g., using the pump 34 of FIG. 1), or via the tubular string 12 (e.g., using the pump 36 of FIG. 1).
- the scope of this disclosure is not limited to any particular fracturing means or technique, or to the use of fracturing at all.
- the plugs 42a may be conveyed by flow 44 through the casing 16 (e.g., as in FIG. 2B), or by flow 52 through the tubular string 12 (e.g., as in FIG. 2C).
- the tubular string 12 is repositioned in the casing 16, so that the perforator 48 is now located at the next zone 40b to be completed.
- the perforator 48 is then used to form perforations 46b through the casing 16 and cement 18, and into the zone 40b.
- the tubular string 12 may be repositioned before or after the plugs 42a are deployed into the well.
- the zone 40b has been fractured by applying increased pressure to the zone via the perforations 46b.
- the fracturing pressure may be applied, for example, via the annulus 30 from the surface (e.g., using the pump 34 of FIG. 1), or via the tubular string 12 (e.g., using the pump 36 of FIG. 1).
- the perforations 46b are plugged by deploying plugs 42b into the well and
- the plugs 42b may be conveyed by flow 44 through the casing 16, or by flow 52 through the tubular string 12.
- the tubular string 12 is repositioned in the casing 16, so that the perforator 48 is now located at the next zone 40c to be completed.
- the perforator 48 is then used to form perforations 46c through the casing 16 and cement 18, and into the zone 40c.
- the tubular string 12 may be repositioned before or after the plugs 42b are deployed into the well.
- the zone 40c has been fractured by applying increased pressure to the zone via the perforations 46c.
- the fracturing pressure may be applied, for example, via the annulus 30 from the surface (e.g., using the pump 34 of FIG. 1), or via the tubular string 12 (e.g., using the pump 36 of FIG. 1).
- the plugs 42a, b are degraded and no longer prevent flow through the perforations 46a, b. Thus, as depicted in FIG. 3D, flow is permitted between the interior of the casing 16 and each of the zones 40a-c.
- the plugs 42a, b may be degraded in any manner.
- the plugs 42a, b may degrade in response to application of a degrading treatment, in response to passage of a certain period of time, or in response to exposure to elevated downhole temperature.
- the degrading treatment could include exposing the plugs 42a, b to a particular type of radiation, such as electromagnetic radiation (e.g., light having a certain wavelength or range of wavelengths, gamma rays, etc.) or "nuclear" particles (e.g., gamma, beta, alpha or neutron) .
- the plugs 42a, b may degrade by galvanic action or by dissolving.
- the plugs 42a, b may degrade in response to exposure to a particular fluid, either naturally occurring in the well (such as water or hydrocarbon fluid), or
- zones 40a-c may be sections of a single earth formation, or they may be sections of separate formations.
- FIG. 4 an example of a flow conveyed device 60 that can incorporate the principles of this disclosure is representatively illustrated.
- the device 60 may be used for any of the plugs 42, 42a, b described above in the method examples of FIGS. 2A-3D, or the device may be used in other methods .
- the device 60 example of FIG. 4 includes multiple fibers 62 extending outwardly from an enlarged body 64. As depicted in FIG. 4, each of the fibers 62 has a lateral dimension (e.g., a thickness or diameter) that is
- a size e.g., a thickness or diameter
- the body 64 can be dimensioned so that it will
- the body 64 can be formed so that it is somewhat larger than a diameter of the
- the bodies 64 of the devices can be formed with a variety of dimensions (such as holes caused by corrosion of the casing 16).
- lines 66 that extend outwardly from the body 64.
- lines 66 there are two such lines 66, but any number of lines (including one) may be used in other examples.
- the lines 66 may be in the form of one or more ropes, in which case the fibers 62 could comprise frayed ends of the rope(s).
- the body 64 could be formed by one or more knots in the rope(s).
- the body 64 can comprise a fabric or cloth, the body could be formed by one or more knots in the fabric or cloth, and the fibers 62 could extend from the fabric or cloth.
- the body 64 is formed by a double overhand knot in a rope, and ends of the rope are frayed, so that the fibers 62 are splayed outward. In this manner, the fibers 62 will cause significant fluid drag when the device 60 is deployed into a flow stream, so that the device will be effectively “carried” by, and "follow," the flow.
- the body 64 could have other shapes, the body could be hollow or solid, and the body could be made up of one or multiple materials.
- the fibers 62 are not
- FIG. 5 another example of the device 60 is representatively illustrated.
- four sets of the fibers 62 are joined by a
- the body 64 is formed by one or more knots in the lines 66.
- FIG. 5 demonstrates that a variety of different
- the opening 68 is a perforation formed through a sidewall 70 of a tubular string 72 (such as, a casing, liner, tubing, etc.).
- a tubular string 72 such as, a casing, liner, tubing, etc.
- the opening 68 could be another type of opening, and may be formed in another type of structure.
- the device 60 is deployed into the tubular string 72 and is conveyed through the tubular string by fluid flow 74 .
- the fibers 62 of the device 60 enhance fluid drag on the device, so that the device is influenced to displace with the flow 74 .
- the device 60 Since the flow 74 (or a portion thereof) exits the tubular string 72 via the opening 68 , the device 60 will be influenced by the fluid drag to also exit the tubular string via the opening 68 .
- one set of the fibers 62 first enters the opening 68 , and the body 64 follows.
- the body 64 is appropriately dimensioned, so that it does not pass through the opening 68 , but instead is lodged or wedged into the opening.
- the body 64 may be received only partially in the opening 68 , and in other examples the body may be entirely received in the opening.
- the body 64 may completely or only partially block the flow 74 through the opening 68 . If the body 64 only
- any remaining fibers 62 exposed to the flow in the tubular string 72 can be carried by that flow into any gaps between the body and the opening 68 , so that a combination of the body and the fibers
- the device 60 may partially block flow through the opening 68 , and another material (such as, calcium carbonate, PLA or PGA particles) may be deployed and conveyed by the flow 74 into any gaps between the device and the opening, so that a combination of the device and the material completely blocks flow through the opening.
- the device 60 may permanently prevent flow through the opening 68 , or the device may degrade to eventually permit flow through the opening. If the device 60 degrades, it may be self-degrading, or it may be degraded in response to any of a variety of different stimuli. Any technique or means for degrading the device 60 (and any other material used in conjunction with the device to block flow through the opening 68 ) may be used in keeping with the scope of this disclosure .
- FIGS. 7 - 9 additional examples of the device 60 are representatively illustrated.
- the device 60 is surrounded by,
- a retainer 80 encapsulated in, molded in, or otherwise retained by, a retainer 80 .
- the retainer 80 aids in deployment of the device 60 , particularly in situations where multiple devices are to be deployed simultaneously. In such situations, the retainer 80 for each device 60 prevents the fibers 62 and/or lines 66 from becoming entangled with the fibers and/or lines of other devices.
- the retainer 80 could in some examples completely enclose the device 60 .
- the retainer 80 could be in the form of a binder that holds the fibers 62 and/or lines 66 together, so that they do not become
- the retainer 80 could have a cavity therein, with the device 60 (or only the fibers 62 and/or lines 66 ) being contained in the cavity. In other examples, the retainer 80 could be molded about the device 60 (or only the fibers 62 and/or lines 66 ) .
- the retainer 80 dissolves, disperses or otherwise degrades, so that the device is capable of sealing off an opening 68 in the well, as described above.
- the retainer 80 can be made of a material 82 that degrades in a wellbore environment .
- the retainer material 82 may degrade after deployment into the well, but before arrival of the device 60 at the opening 68 to be plugged. In other examples, the retainer material 82 may degrade at or after arrival of the device 60 at the opening 68 to be plugged. If the device 60 also comprises a degradable material, then preferably the
- retainer material 82 degrades prior to the device material.
- the material 82 could, in some examples, melt at elevated wellbore temperatures.
- the material 82 could be chosen to have a melting point that is between a temperature at the earth's surface and a temperature at the opening 68, so that the material melts during transport from the surface to the downhole location of the opening.
- the material 82 could, in some examples, dissolve when exposed to wellbore fluid.
- the material 82 could be chosen so that the material begins dissolving as soon as it is deployed into the wellbore 14 and contacts a certain fluid (such as, water, brine, hydrocarbon fluid, etc.) therein.
- a certain fluid such as, water, brine, hydrocarbon fluid, etc.
- the fluid that initiates dissolving of the material 82 could have a certain pH range that causes the material to dissolve.
- the material 82 could melt or dissolve in the well.
- Various other stimuli such as, passage of time, elevated pressure, flow, turbulence, etc.
- the material 82 could degrade in response to any one, or a combination, of: passage of a predetermined period of time in the well, exposure to a predetermined temperature in the well, exposure to a predetermined fluid in the well, exposure to radiation in the well and exposure to a predetermined chemical composition in the well.
- the scope of this disclosure is not limited to any particular stimulus or technique for dispersing or degrading the material 82 , or to any particular type of material.
- the material 82 can remain on the device 60 , at least partially, when the device engages the opening 68 .
- the material 82 could continue to cover the body 64 (at least partially) when the body engages and seals off the opening 68 .
- the material 82 could advantageously comprise a relatively soft, viscous and/or resilient material, so that sealing between the device 60 and the opening 68 is enhanced.
- Suitable relatively low melting point substances that may be used for the material 82 can include wax (e.g., paraffin wax, vegetable wax), ethylene-vinyl acetate
- Suitable relatively soft substances that may be used for the material 82 can include a soft silicone composition or a viscous liquid or gel.
- Suitable dissolvable materials can include PLA, PGA, anhydrous boron compounds (such as anhydrous boric oxide and anhydrous sodium borate), polyvinyl alcohol, polyethylene oxide, salts and carbonates.
- anhydrous boron compounds such as anhydrous boric oxide and anhydrous sodium borate
- polyvinyl alcohol such as polyethylene oxide, salts and carbonates.
- the retainer 80 is in a cylindrical form.
- the device 60 is encapsulated in, or molded in, the retainer material 82 .
- the fibers 62 and lines 66 are, thus, prevented from becoming entwined with the fibers and lines of any other devices 60 .
- the retainer 80 is in a spherical form.
- the device 60 is compacted, and its compacted shape is retained by the retainer material 82.
- a shape of the retainer 80 can be chosen as appropriate for a
- the retainer 80 is in a cubic form.
- any type of shape polyhedron, spherical, cylindrical, etc. may be used for the retainer 80, in keeping with the
- the device 60 may be used to block flow through openings in a well, with the device being uniquely configured so that its conveyance with the flow is enhanced.
- the method can comprise: a device 60 introduced into the well being conveyed by flow 74 in the well, and the device 60 comprising a plurality of fibers 62 extending outwardly from a body 64.
- a retainer 80 retains the fibers 62.
- the retainer 80 may comprise a degradable material 82.
- the material 82 may degrade between the device 60 being introduced into the well and the device engaging an opening 68 in the well.
- the material 82 may melt or dissolve in the well .
- the method can include the body 64 engaging an opening 68 in the well.
- the opening 68 may comprise a perforation. In other examples, the opening 68 could be in a valve, at a corrosion location, a point of leakage, etc.
- the body 64 can prevent flow through the opening 68.
- the fibers 62 may be joined together and form one or more lines 66 extending outwardly from the body 64.
- the lines 66 can comprise one or more ropes.
- the body 64 can comprise a fabric or cloth.
- the body 64 can comprise at least one knot.
- Other structures such as, spheres, oblong structures, etc. may be used in other examples.
- the body 64 can comprise a non-degradable or a
- the body 64 may be self-degrading, or the body may degrade in response to application of a
- the method can include the material degrading in response to at least one of: passage of a predetermined period of time in the well, exposure to a predetermined temperature in the well, exposure to a
- the method can include deploying the device 60 into the well after fracturing a formation zone 40a, b.
- the device 60 may be deployed, and the formation zone 40a, b may be
- single trip is used to indicate only a single deployment of a tubular string into a well.
- the tubular string may be retrieved from the well at a conclusion of the single trip, or the tubular string may not be retrieved from the well.
- the system 10 can comprise a flow conveyed device 60 conveyed through a tubular string 72 by flow 74 in the tubular string.
- the flow conveyed device 60 can comprise a body 64 with a plurality of fibers 62 extending outwardly from the body.
- a retainer 80 at least partially encloses the flow conveyed device 60.
- the retainer 80 may release the fibers 62 in the well.
- the retainer 80 can comprise a degradable material 82, a material that dissolves in the well, and/or a material that melts in the well.
- the flow conveyed device 60 may engage an opening 68 in a sidewall 70 of the tubular string 72. At least a portion of the fibers 62 can be conveyed into the opening 68 by flow 74 through the opening.
- the body 64 may extend across and seal off the opening 68.
- the opening 68 can comprise a perforation. The scope of this disclosure is not limited to any particular type of opening.
- the device 60 can comprise a degradable body 64, and a plurality of fibers 62 joined to the body. Each of the fibers 62 has a lateral dimension that is substantially smaller than a size of the body 64. The fibers 62 are retained by a retainer 80.
- the retainer 80 may degrade in response to passage of a predetermined period of time, in response to exposure to a predetermined fluid, in response to exposure to a
- the fibers 62 may comprise a nylon material.
- the fibers 62 can extend from one or more ropes, fabrics or cloths in some examples .
- the body 64 may be degradable by exposure to an acid.
- structures disclosed as being separately formed can, in other examples, be integrally formed and vice versa.
Landscapes
- 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)
- Optical Fibers, Optical Fiber Cores, And Optical Fiber Bundles (AREA)
Abstract
Description
Claims
Priority Applications (57)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
AU2015393421A AU2015393421B2 (en) | 2015-04-28 | 2015-06-29 | Flow control in subterranean wells |
CA2957681A CA2957681C (en) | 2015-04-28 | 2015-06-29 | Flow control in subterranean wells |
MX2017001809A MX2017001809A (en) | 2015-04-28 | 2015-06-29 | Flow cotrol in subterranean wells. |
US15/062,669 US9523267B2 (en) | 2015-04-28 | 2016-03-07 | Flow control in subterranean wells |
CA2928256A CA2928256C (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
US15/138,685 US10233719B2 (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
CA2928257A CA2928257C (en) | 2015-04-28 | 2016-04-26 | Plugging device deployment in subterranean wells |
AU2016202614A AU2016202614B2 (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
CA2928237A CA2928237C (en) | 2015-04-28 | 2016-04-26 | Fibrous barriers and deployment in subterranean wells |
CA3177228A CA3177228A1 (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
AU2016202619A AU2016202619B2 (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
AU2016256383A AU2016256383B2 (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
US15/138,327 US9567824B2 (en) | 2015-04-28 | 2016-04-26 | Fibrous barriers and deployment in subterranean wells |
AU2016202616A AU2016202616B2 (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
MX2016005411A MX2016005411A (en) | 2015-04-28 | 2016-04-26 | Fibrous barriers and deployment in subterranean wells. |
CA2928236A CA2928236C (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
MX2016005409A MX2016005409A (en) | 2015-04-28 | 2016-04-26 | Plugging device deployment in subterranean wells. |
US15/138,378 US9567825B2 (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
CA2992763A CA2992763C (en) | 2015-04-28 | 2016-04-26 | Fibrous barriers and deployment in subterranean wells |
MX2016005421A MX2016005421A (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells. |
US15/138,968 US9745820B2 (en) | 2015-04-28 | 2016-04-26 | Plugging device deployment in subterranean wells |
MX2016005422A MX2016005422A (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells. |
MX2016005414A MX2016005414A (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells. |
US15/138,449 US9708883B2 (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
CA2983253A CA2983253C (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
MX2017013752A MX2017013752A (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells. |
US15/138,408 US9567826B2 (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
AU2016202612A AU2016202612B2 (en) | 2015-04-28 | 2016-04-26 | Fibrous barriers and deployment in subterranean wells |
CA2928245A CA2928245C (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
CA2928239A CA2928239C (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
AU2016202620A AU2016202620A1 (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
US15/567,779 US10655427B2 (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
AU2016202624A AU2016202624B2 (en) | 2015-04-28 | 2016-04-26 | Plugging device deployment in subterranean wells |
MX2016005420A MX2016005420A (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells. |
PCT/US2016/029314 WO2016176181A1 (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
US15/296,342 US9816341B2 (en) | 2015-04-28 | 2016-10-18 | Plugging devices and deployment in subterranean wells |
US15/347,535 US10641070B2 (en) | 2015-04-28 | 2016-11-09 | Flow control in subterranean wells |
US15/390,941 US10738564B2 (en) | 2015-04-28 | 2016-12-27 | Fibrous barriers and deployment in subterranean wells |
US15/391,014 US10738566B2 (en) | 2015-04-28 | 2016-12-27 | Flow control in subterranean wells |
US15/390,976 US10738565B2 (en) | 2015-04-28 | 2016-12-27 | Flow control in subterranean wells |
US15/622,016 US10513653B2 (en) | 2015-04-28 | 2017-06-13 | Flow control in subterranean wells |
US15/658,697 US11002106B2 (en) | 2015-04-28 | 2017-07-25 | Plugging device deployment in subterranean wells |
AU2017216597A AU2017216597B2 (en) | 2015-04-28 | 2017-08-18 | Flow control in subterranean wells |
AU2017218948A AU2017218948B2 (en) | 2015-04-28 | 2017-08-21 | Fibrous barriers and deployment in subterranean wells |
AU2017219082A AU2017219082B2 (en) | 2015-04-28 | 2017-08-25 | Flow control in subterranean wells |
US15/726,160 US10513902B2 (en) | 2015-04-28 | 2017-10-05 | Plugging devices and deployment in subterranean wells |
AU2017276220A AU2017276220B2 (en) | 2015-04-28 | 2017-12-13 | Flow control in subterranean wells |
AU2017279758A AU2017279758B2 (en) | 2015-04-28 | 2017-12-21 | Flow control in subterranean wells |
US16/214,174 US10641057B2 (en) | 2015-04-28 | 2018-12-10 | Flow control in subterranean wells |
US16/238,838 US10767442B2 (en) | 2015-04-28 | 2019-01-03 | Flow control in subterranean wells |
US16/264,766 US10907430B2 (en) | 2015-04-28 | 2019-02-01 | Plugging devices and deployment in subterranean wells |
US16/264,758 US10900312B2 (en) | 2015-04-28 | 2019-02-01 | Plugging devices and deployment in subterranean wells |
AU2019201177A AU2019201177B2 (en) | 2015-04-28 | 2019-02-20 | Flow control in subterranean wells |
AU2019219723A AU2019219723B2 (en) | 2015-04-28 | 2019-08-19 | Flow control in subterranean wells |
US16/597,183 US11427751B2 (en) | 2015-04-28 | 2019-10-09 | Flow control in subterranean wells |
AU2020256342A AU2020256342B2 (en) | 2015-04-28 | 2020-10-13 | Flow control in subterranean wells |
US17/813,359 US11851611B2 (en) | 2015-04-28 | 2022-07-19 | Flow control in subterranean wells |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US14/698,579 US9834663B2 (en) | 2005-11-25 | 2015-04-28 | Composition for forming a transparent coating film including hollow silica particles |
US14/698,579 | 2015-04-28 |
Related Parent Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US14/698,578 Continuation-In-Part US10641069B2 (en) | 2015-04-28 | 2015-04-28 | Flow control in subterranean wells |
Related Child Applications (4)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US14/698,578 Continuation-In-Part US10641069B2 (en) | 2015-04-28 | 2015-04-28 | Flow control in subterranean wells |
US15/138,968 Continuation-In-Part US9745820B2 (en) | 2015-04-28 | 2016-04-26 | Plugging device deployment in subterranean wells |
US15/567,779 Continuation-In-Part US10655427B2 (en) | 2015-04-28 | 2016-04-26 | Flow control in subterranean wells |
US17/813,359 Continuation-In-Part US11851611B2 (en) | 2015-04-28 | 2022-07-19 | Flow control in subterranean wells |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2016175876A1 true WO2016175876A1 (en) | 2016-11-03 |
Family
ID=57200686
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2015/038248 WO2016175876A1 (en) | 2015-04-28 | 2015-06-29 | Flow cotrol in subterranean wells |
Country Status (1)
Country | Link |
---|---|
WO (1) | WO2016175876A1 (en) |
Cited By (18)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10502014B2 (en) | 2017-05-03 | 2019-12-10 | Coil Solutions, Inc. | Extended reach tool |
US10513653B2 (en) | 2015-04-28 | 2019-12-24 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10513902B2 (en) | 2015-04-28 | 2019-12-24 | Thru Tubing Solutions, Inc. | Plugging devices and deployment in subterranean wells |
US10641057B2 (en) | 2015-04-28 | 2020-05-05 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10655426B2 (en) | 2016-04-06 | 2020-05-19 | Thru Tubing Solutions, Inc. | Methods of completing a well and apparatus therefor |
US10738564B2 (en) | 2015-04-28 | 2020-08-11 | Thru Tubing Solutions, Inc. | Fibrous barriers and deployment in subterranean wells |
US10738565B2 (en) | 2015-04-28 | 2020-08-11 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10738566B2 (en) | 2015-04-28 | 2020-08-11 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10767442B2 (en) | 2015-04-28 | 2020-09-08 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10774612B2 (en) | 2015-04-28 | 2020-09-15 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10851615B2 (en) | 2015-04-28 | 2020-12-01 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US11002106B2 (en) | 2015-04-28 | 2021-05-11 | Thru Tubing Solutions, Inc. | Plugging device deployment in subterranean wells |
US11022248B2 (en) | 2017-04-25 | 2021-06-01 | Thru Tubing Solutions, Inc. | Plugging undesired openings in fluid vessels |
CN114033331A (en) * | 2021-03-24 | 2022-02-11 | 中国石油天然气集团有限公司 | Rope knot type temporary plugging agent and temporary plugging method |
CN114032079A (en) * | 2021-03-25 | 2022-02-11 | 中国石油天然气集团有限公司 | Consolidation type temporary plugging agent and temporary plugging method |
US11293578B2 (en) | 2017-04-25 | 2022-04-05 | Thru Tubing Solutions, Inc. | Plugging undesired openings in fluid conduits |
CN115612468A (en) * | 2022-09-21 | 2023-01-17 | 中国石油化工股份有限公司 | Knot temporary plugging ball and preparation method and application thereof |
US11851611B2 (en) | 2015-04-28 | 2023-12-26 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5908073A (en) * | 1997-06-26 | 1999-06-01 | Halliburton Energy Services, Inc. | Preventing well fracture proppant flow-back |
US20040129460A1 (en) * | 2002-08-01 | 2004-07-08 | Macquoid Malcolm | Method for using coconut coir as a lost circulation material for well drilling |
WO2007066254A2 (en) * | 2005-12-05 | 2007-06-14 | Schlumberger Canada Limited | Degradable material assisted diversion or isolation |
US20070187099A1 (en) * | 2006-02-10 | 2007-08-16 | Ling Wang | Methods and Compositions for Sealing Fractures, Voids, and Pores of Subterranean Rock Formations |
US20120285695A1 (en) * | 2011-05-11 | 2012-11-15 | Schlumberger Technology Corporation | Destructible containers for downhole material and chemical delivery |
-
2015
- 2015-06-29 WO PCT/US2015/038248 patent/WO2016175876A1/en active Application Filing
Patent Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5908073A (en) * | 1997-06-26 | 1999-06-01 | Halliburton Energy Services, Inc. | Preventing well fracture proppant flow-back |
US20040129460A1 (en) * | 2002-08-01 | 2004-07-08 | Macquoid Malcolm | Method for using coconut coir as a lost circulation material for well drilling |
WO2007066254A2 (en) * | 2005-12-05 | 2007-06-14 | Schlumberger Canada Limited | Degradable material assisted diversion or isolation |
US20070187099A1 (en) * | 2006-02-10 | 2007-08-16 | Ling Wang | Methods and Compositions for Sealing Fractures, Voids, and Pores of Subterranean Rock Formations |
US20120285695A1 (en) * | 2011-05-11 | 2012-11-15 | Schlumberger Technology Corporation | Destructible containers for downhole material and chemical delivery |
Cited By (24)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10900312B2 (en) | 2015-04-28 | 2021-01-26 | Thru Tubing Solutions, Inc. | Plugging devices and deployment in subterranean wells |
US11242727B2 (en) | 2015-04-28 | 2022-02-08 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10513902B2 (en) | 2015-04-28 | 2019-12-24 | Thru Tubing Solutions, Inc. | Plugging devices and deployment in subterranean wells |
US10641057B2 (en) | 2015-04-28 | 2020-05-05 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10655427B2 (en) | 2015-04-28 | 2020-05-19 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10774612B2 (en) | 2015-04-28 | 2020-09-15 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10738564B2 (en) | 2015-04-28 | 2020-08-11 | Thru Tubing Solutions, Inc. | Fibrous barriers and deployment in subterranean wells |
US10738565B2 (en) | 2015-04-28 | 2020-08-11 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10738566B2 (en) | 2015-04-28 | 2020-08-11 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10767442B2 (en) | 2015-04-28 | 2020-09-08 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US11851611B2 (en) | 2015-04-28 | 2023-12-26 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10851615B2 (en) | 2015-04-28 | 2020-12-01 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US11002106B2 (en) | 2015-04-28 | 2021-05-11 | Thru Tubing Solutions, Inc. | Plugging device deployment in subterranean wells |
US10907430B2 (en) | 2015-04-28 | 2021-02-02 | Thru Tubing Solutions, Inc. | Plugging devices and deployment in subterranean wells |
US11427751B2 (en) | 2015-04-28 | 2022-08-30 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10513653B2 (en) | 2015-04-28 | 2019-12-24 | Thru Tubing Solutions, Inc. | Flow control in subterranean wells |
US10655426B2 (en) | 2016-04-06 | 2020-05-19 | Thru Tubing Solutions, Inc. | Methods of completing a well and apparatus therefor |
US11022248B2 (en) | 2017-04-25 | 2021-06-01 | Thru Tubing Solutions, Inc. | Plugging undesired openings in fluid vessels |
US11293578B2 (en) | 2017-04-25 | 2022-04-05 | Thru Tubing Solutions, Inc. | Plugging undesired openings in fluid conduits |
US10502014B2 (en) | 2017-05-03 | 2019-12-10 | Coil Solutions, Inc. | Extended reach tool |
CN114033331A (en) * | 2021-03-24 | 2022-02-11 | 中国石油天然气集团有限公司 | Rope knot type temporary plugging agent and temporary plugging method |
CN114032079A (en) * | 2021-03-25 | 2022-02-11 | 中国石油天然气集团有限公司 | Consolidation type temporary plugging agent and temporary plugging method |
CN115612468A (en) * | 2022-09-21 | 2023-01-17 | 中国石油化工股份有限公司 | Knot temporary plugging ball and preparation method and application thereof |
CN115612468B (en) * | 2022-09-21 | 2023-11-10 | 中国石油化工股份有限公司 | Rope knot temporary blocking ball and preparation method and application thereof |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
AU2019201177B2 (en) | Flow control in subterranean wells | |
US9523267B2 (en) | Flow control in subterranean wells | |
US10738566B2 (en) | Flow control in subterranean wells | |
US10738565B2 (en) | Flow control in subterranean wells | |
WO2016175876A1 (en) | Flow cotrol in subterranean wells | |
AU2020210316B2 (en) | Plugging device deployment | |
AU2017219082B2 (en) | Flow control in subterranean wells |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 15891004 Country of ref document: EP Kind code of ref document: A1 |
|
ENP | Entry into the national phase |
Ref document number: 2957681 Country of ref document: CA |
|
WWE | Wipo information: entry into national phase |
Ref document number: MX/A/2017/001809 Country of ref document: MX |
|
ENP | Entry into the national phase |
Ref document number: 2015393421 Country of ref document: AU Date of ref document: 20150629 Kind code of ref document: A |
|
NENP | Non-entry into the national phase |
Ref country code: DE |
|
122 | Ep: pct application non-entry in european phase |
Ref document number: 15891004 Country of ref document: EP Kind code of ref document: A1 |