US20210002983A1 - Chemically treated substrate strips in screens for open hole gravel packing and stand alone screens - Google Patents
Chemically treated substrate strips in screens for open hole gravel packing and stand alone screens Download PDFInfo
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- US20210002983A1 US20210002983A1 US16/460,526 US201916460526A US2021002983A1 US 20210002983 A1 US20210002983 A1 US 20210002983A1 US 201916460526 A US201916460526 A US 201916460526A US 2021002983 A1 US2021002983 A1 US 2021002983A1
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- United States
- Prior art keywords
- inhibitor
- strip
- base pipe
- production string
- fluid
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- 238000012856 packing Methods 0.000 title 1
- 239000000758 substrate Substances 0.000 title 1
- 239000012530 fluid Substances 0.000 claims abstract description 79
- 238000004519 manufacturing process Methods 0.000 claims abstract description 74
- 239000003112 inhibitor Substances 0.000 claims abstract description 70
- 239000000463 material Substances 0.000 claims abstract description 24
- 239000013000 chemical inhibitor Substances 0.000 claims abstract description 23
- 238000000034 method Methods 0.000 claims abstract description 21
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 14
- 239000000126 substance Substances 0.000 claims abstract description 14
- 239000012188 paraffin wax Substances 0.000 claims description 6
- 239000011248 coating agent Substances 0.000 claims description 3
- 238000000576 coating method Methods 0.000 claims description 3
- 238000009825 accumulation Methods 0.000 abstract 1
- 239000003795 chemical substances by application Substances 0.000 description 4
- -1 scale Substances 0.000 description 4
- 238000010276 construction Methods 0.000 description 3
- 239000003607 modifier Substances 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 238000010793 Steam injection (oil industry) Methods 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 150000007513 acids Chemical class 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 239000004568 cement Substances 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000006378 damage Effects 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 239000003995 emulsifying agent Substances 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 230000002401 inhibitory effect Effects 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000002244 precipitate Substances 0.000 description 1
- 239000000700 radioactive tracer Substances 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 238000007670 refining Methods 0.000 description 1
- 239000002455 scale inhibitor Substances 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 230000000638 stimulation Effects 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
Images
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
- E21B37/06—Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting, e.g. eliminating, the deposition of paraffins or like substances
-
- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/08—Screens or liners
- E21B43/088—Wire screens
Definitions
- a production system is used in a wellbore in order to draw fluid from a formation surrounding the wellbore and deliver that fluid to a surface location.
- the fluid from the formation generally includes various chemicals that will deposit on any of the tubulars, screens, pumps, and any other components it comes into contact with as it travels to the surface, thereby forming compositional material such as scale, paraffin, and asphaltenes on these components.
- compositional material such as scale, paraffin, and asphaltenes on these components.
- Such build-up of compositional material can create a significant restriction in the production string, eventually inhibiting the flow of fluid from the formation. Therefore, there is a desire to be able to prevent build-up in a production system.
- a method of preventing production of a compositional material in a production string includes disposing an inhibitor strip in a fluid inflow device of the production string and receiving a fluid at the fluid inflow device from a formation at the inhibitor strip, wherein a chemical inhibitor of the inhibitor strip interacts with a chemical in the fluid to reduce the production of the compositional material in the production string.
- a production string in another aspect, includes a fluid inflow device and an inhibitor strip disposed in contact with the fluid inflow device, the inhibitor strip including a chemical inhibitor therein to interact with chemicals in a fluid flowing through the fluid inflow device to reduce the production of a compositional material in the production string.
- FIG. 1 shows an illustrative production system
- FIG. 2A shows a section of the production string having a fluid inflow device capable of reducing or preventing the scale production within the production string;
- FIG. 2B shows a detailed view of the first fluid inflow device of FIG. 2A ;
- FIG. 3 shows an illustrative inhibitor strip for disposal between the base pipe and wire screen of FIG. 2B ;
- FIGS. 4A and 4B shows cross sections of an inhibitor strip in different embodiments
- FIG. 5 shows a perspective view of a partially constructed fluid inflow device
- FIG. 6 shows a perspective view of a subsequent construction stage of the fluid inflow device
- FIG. 7 shows a perspective view of the fluid inflow device in another embodiment.
- the production system 100 includes a production string 102 extending from wellhead 104 located at a surface location 106 into a wellbore 108 formed in a formation 110 .
- the production string 102 includes a plurality of tubular members attached end to end, such as tubular members 102 a , 102 b , and 102 c .
- the production string 102 extends through the formation 110 to reach a reservoir 112 in the formation.
- the production string 102 further includes at least one section having a fluid inflow device 114 .
- production string 102 is disposed in the wellbore 108 so as to place the fluid inflow device 114 within the reservoir 112 .
- Packers 120 and 122 can be deployed from the production string 102 in order to isolate an annular section 124 of the wellbore 108 between the fluid inflow device 114 and the reservoir 112 to allow the flow of fluid from the reservoir 112 into the fluid inflow device 114 .
- a pump 128 can be used to pump or direct fluid from the reservoir 112 to the surface location 106 .
- the fluid 125 is pumped from the reservoir 112 into the production string 102 via the fluid inflow device 114 , up through the tubular member 102 a , 102 b , 102 c to reach the wellhead 104 at the surface location 106 through the production string 102 .
- a standpipe 132 at the surface location is used to direct the fluid from the wellhead 104 to a storage facility 130 .
- the fluid 125 includes therein various chemicals which are responsible for a growth of scale on various surfaces of the production system that come into contact with the fluid 125 . These chemicals precipitate from the fluid 125 due to changes in pressure and temperature as the fluid flows through the production system and settles on the various surfaces and/or components.
- This precipitated material, or compositional material refers to scale, paraffin, and/or asphaltene and can result in reduced flow channels in the production string, destruction of the pump 128 , as well as difficulties in downstream refining.
- FIG. 2A shows a section 200 of the production string 102 having a fluid inflow device capable of reducing or preventing the production of compositional material within the production string 102 .
- the section 200 includes a first fluid inflow device 202 and a second fluid inflow device 204 .
- a first connector 206 couples the first fluid inflow device 202 to the second fluid inflow device 204 .
- a second connector 208 can also be used to connect the first fluid inflow device 202 to other components of the production string 102 , including other fluid inflow devices.
- FIG. 2B shows a detailed view of the first fluid inflow device 202 of FIG. 2A .
- the first fluid inflow device 202 includes a base pipe 210 having perforations 212 therein to allow fluid from the formation to flow into an interior 214 of the base pipe 210 and uphole through the production string 102 .
- the base pipe 210 is surrounded by at least one wire screen 216 circumferentially surrounding the base pipe 210 and separated from the base pipe by an annular region 215 .
- the wire screen 216 has holes or apertures that are sized to selectively allow fluid into the first fluid inflow device 202 while keeping out particles greater than the size of the holes.
- the annular region 215 between the base pipe 210 and the wire screen 216 includes one or more scale inhibitor strips 218 disposed therein. Details of the inhibitors strips 218 are shown in FIGS. 3, 4A and 4B .
- FIG. 3 shows an illustrative inhibitor strip 218 for disposal between the base pipe 210 and wire screen 216 of FIG. 2B .
- the inhibitor strip 218 is in the shape of a rectangular cuboid having a length l, width w and thickness t.
- the thickness of the inhibitor strip 218 is selected to allow the inhibitor strip 218 to fit within the annular region 215 between the wire screen 216 and the base pipe 210 .
- the width of the inhibitor strip 218 can be selected to fit along the curved surface of the base pipe to suitable approximation.
- FIGS. 4A and 4B shows cross sections of an inhibitor strip 218 in different embodiments.
- FIG. 4A shows a cross-section 400 of a coated inhibitor strip 218 .
- the cross-section 400 shows a base material 402 having a coating of a chemical inhibitor 404 surrounding its surface.
- FIG. 4B shows a cross-section 401 in which the inhibitor strip 218 includes a base material 402 that is impregnated with the chemical inhibitor 404 .
- the chemical inhibitor 404 reacts with chemicals in the fluid responsible for compositional material production, thereby preventing or reducing scale, paraffin, and/or asphaltene productions.
- the inhibitor can be a chemical that interacts with chemicals in the formation fluid that otherwise result in scale, paraffin, and/or asphaltene production.
- the chemical inhibitor in or on the inhibitor strips becomes depleted due to the interactions with the chemicals in the fluid.
- the inhibitor strips can be recharged by flowing a fluid chemical inhibitor into the wellbore and into contact with the inhibitor strips.
- FIG. 5 shows a perspective view 500 of a partially constructed fluid inflow device.
- the perspective view 500 includes the base pipe 210 and a first cylindrical arrangement 502 of inhibitor strips 218 arranged around a circumference of the base pipe. The lengths of the inhibitor strips 218 extend or are elongated along a longitudinal axis of the base pipe 210 .
- the first cylindrical arrangement 502 covers a first axial section 504 of the base pipe. A second axial section 506 of the base pipe is shown uncovered.
- FIG. 6 shows a perspective view 600 of a subsequent construction stage of the fluid inflow device.
- a second cylindrical arrangement 602 of inhibitor strips 218 are shown around the second axial section 506 of the base pipe 210 .
- the wire screen 610 is shown over a section of the first cylindrical arrangement 502 . During construction the wire screen 610 can slide along the longitudinal axis of the base pipe 210 to encapsulate each cylindrical arrangement once completed.
- FIG. 7 shows a perspective view 700 of the fluid inflow device in another embodiment.
- a plurality of dividers 702 are formed between the base pipe 710 and the wire screen 716 to form a plurality of drainage channels 704 .
- Inhibitor strips 218 are disposed within the drainage channels, thereby causing the fluid to flow across the inhibitors strips 218 as it flows from the wire screen 716 to the base pipe 710 via the drainage channels.
- Embodiment 1 A method of preventing production of a compositional material in a production string. The method includes disposing an inhibitor strip in a fluid inflow device of the production string; and receiving a fluid at the fluid inflow device from a formation at the inhibitor strip, wherein a chemical inhibitor of the inhibitor strip interacts with a chemical in the fluid to reduce the production of the compositional material in the production string.
- Embodiment 2 The method of any prior embodiment, wherein the fluid inflow device includes a base pipe and a screen forming an annular region around the base pipe, further comprising disposing the inhibitor strip in a channel between the base pipe and the screen.
- Embodiment 3 The method of any prior embodiment, wherein the screen and the base pipe form one or more drainage channels, further comprising disposing the inhibitor strip in the one or more drainage channels.
- Embodiment 4 The method of any prior embodiment, wherein the inhibitor strip is elongated along a longitudinal axis of the base pipe.
- Embodiment 5 The method of any prior embodiment, wherein disposing the inhibitor strip further comprising placing a plurality of inhibitor strips circumferentially around an axial section of the base pipe.
- Embodiment 6 The method of any prior embodiment, wherein the inhibitor strip includes a base material that is one of: (i) coated with the chemical inhibitor; and (ii) impregnated with the chemical inhibitor.
- Embodiment 7 The method of any prior embodiment, further comprising recharging the inhibitor strip with the chemical inhibitor at its location in the wellbore.
- Embodiment 8 The method of any prior embodiment, wherein the compositional material includes at least one of scale, paraffin and asphaltene.
- Embodiment 9 A production string.
- the production string includes a fluid inflow device and an inhibitor strip disposed in contact with the fluid inflow device, the inhibitor strip including a chemical inhibitor therein to interact with chemicals in a fluid flowing through the fluid inflow device to reduce the production of a compositional material in the production string.
- Embodiment 10 The production string of any prior embodiment, further comprising a base pipe of the fluid inflow device, and a screen forming an annular region around the base pipe; wherein the inhibitor strip is disposed within the annular region.
- Embodiment 11 The production string of any prior embodiment, further comprising one or more drainage channels between the base pipe and the screen, wherein the inhibitor strip is disposed within the one or more drainage channels.
- Embodiment 12 The production string of any prior embodiment, wherein the inhibitor strip is elongated along a longitudinal axis of the base pipe.
- Embodiment 13 The production string of any prior embodiment, wherein the inhibitor strip further comprises a plurality of inhibitor strips disposed circumferentially around an axial section of the base pipe.
- Embodiment 14 The production string of any prior embodiment, wherein the inhibitor strip includes a base material that is one of: (i) coated with the chemical inhibitor; and (ii) impregnated with the chemical inhibitor.
- Embodiment 15 The production string of any prior embodiment, wherein the inhibitor strip is capable of being recharged with additional chemical inhibitor when deployed in a wellbore.
- the teachings of the present disclosure may be used in a variety of well operations. These operations may involve using one or more treatment agents to treat a formation, the fluids resident in a formation, a wellbore, and/or equipment in the wellbore, such as production tubing.
- the treatment agents may be in the form of liquids, gases, solids, semi-solids, and mixtures thereof.
- Illustrative treatment agents include, but are not limited to, fracturing fluids, acids, steam, water, brine, anti-corrosion agents, cement, permeability modifiers, drilling muds, emulsifiers, demulsifiers, tracers, flow improvers etc.
- Illustrative well operations include, but are not limited to, hydraulic fracturing, stimulation, tracer injection, cleaning, acidizing, steam injection, water flooding, cementing, etc.
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- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- Chemical & Material Sciences (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Dispersion Chemistry (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Physical Or Chemical Processes And Apparatus (AREA)
Abstract
Description
- In the resource recovery industry, a production system is used in a wellbore in order to draw fluid from a formation surrounding the wellbore and deliver that fluid to a surface location. The fluid from the formation generally includes various chemicals that will deposit on any of the tubulars, screens, pumps, and any other components it comes into contact with as it travels to the surface, thereby forming compositional material such as scale, paraffin, and asphaltenes on these components. Such build-up of compositional material can create a significant restriction in the production string, eventually inhibiting the flow of fluid from the formation. Therefore, there is a desire to be able to prevent build-up in a production system.
- In one aspect, a method of preventing production of a compositional material in a production string is disclosed. The method includes disposing an inhibitor strip in a fluid inflow device of the production string and receiving a fluid at the fluid inflow device from a formation at the inhibitor strip, wherein a chemical inhibitor of the inhibitor strip interacts with a chemical in the fluid to reduce the production of the compositional material in the production string.
- In another aspect, a production string is disclosed. The production string includes a fluid inflow device and an inhibitor strip disposed in contact with the fluid inflow device, the inhibitor strip including a chemical inhibitor therein to interact with chemicals in a fluid flowing through the fluid inflow device to reduce the production of a compositional material in the production string.
- The following descriptions should not be considered limiting in any way. With reference to the accompanying drawings, like elements are numbered alike:
-
FIG. 1 shows an illustrative production system; -
FIG. 2A shows a section of the production string having a fluid inflow device capable of reducing or preventing the scale production within the production string; -
FIG. 2B shows a detailed view of the first fluid inflow device ofFIG. 2A ; -
FIG. 3 shows an illustrative inhibitor strip for disposal between the base pipe and wire screen ofFIG. 2B ; -
FIGS. 4A and 4B shows cross sections of an inhibitor strip in different embodiments; -
FIG. 5 shows a perspective view of a partially constructed fluid inflow device; -
FIG. 6 shows a perspective view of a subsequent construction stage of the fluid inflow device; and -
FIG. 7 shows a perspective view of the fluid inflow device in another embodiment. - A detailed description of one or more embodiments of the disclosed apparatus and method are presented herein by way of exemplification and not limitation with reference to the Figures.
- Referring to
FIG. 1 , anillustrative production system 100 is shown. Theproduction system 100 includes aproduction string 102 extending fromwellhead 104 located at asurface location 106 into awellbore 108 formed in aformation 110. Theproduction string 102 includes a plurality of tubular members attached end to end, such astubular members production string 102 extends through theformation 110 to reach areservoir 112 in the formation. Theproduction string 102 further includes at least one section having afluid inflow device 114. While only a singlefluid inflow device 114 is shown for illustrative purposes, in various embodiments, a plurality of fluid inflow devices and related components can be deployed along theproduction string 102. In various embodiments,production string 102 is disposed in thewellbore 108 so as to place thefluid inflow device 114 within thereservoir 112. Packers 120 and 122 can be deployed from theproduction string 102 in order to isolate anannular section 124 of thewellbore 108 between thefluid inflow device 114 and thereservoir 112 to allow the flow of fluid from thereservoir 112 into thefluid inflow device 114. Apump 128 can be used to pump or direct fluid from thereservoir 112 to thesurface location 106. During production, thefluid 125 is pumped from thereservoir 112 into theproduction string 102 via thefluid inflow device 114, up through thetubular member wellhead 104 at thesurface location 106 through theproduction string 102. Astandpipe 132 at the surface location is used to direct the fluid from thewellhead 104 to astorage facility 130. - The
fluid 125 includes therein various chemicals which are responsible for a growth of scale on various surfaces of the production system that come into contact with thefluid 125. These chemicals precipitate from thefluid 125 due to changes in pressure and temperature as the fluid flows through the production system and settles on the various surfaces and/or components. This precipitated material, or compositional material, refers to scale, paraffin, and/or asphaltene and can result in reduced flow channels in the production string, destruction of thepump 128, as well as difficulties in downstream refining. -
FIG. 2A shows asection 200 of theproduction string 102 having a fluid inflow device capable of reducing or preventing the production of compositional material within theproduction string 102. Thesection 200 includes a firstfluid inflow device 202 and a secondfluid inflow device 204. Afirst connector 206 couples the firstfluid inflow device 202 to the secondfluid inflow device 204. Asecond connector 208 can also be used to connect the firstfluid inflow device 202 to other components of theproduction string 102, including other fluid inflow devices. -
FIG. 2B shows a detailed view of the firstfluid inflow device 202 ofFIG. 2A . The firstfluid inflow device 202 includes abase pipe 210 havingperforations 212 therein to allow fluid from the formation to flow into aninterior 214 of thebase pipe 210 and uphole through theproduction string 102. Thebase pipe 210 is surrounded by at least onewire screen 216 circumferentially surrounding thebase pipe 210 and separated from the base pipe by anannular region 215. Thewire screen 216 has holes or apertures that are sized to selectively allow fluid into the firstfluid inflow device 202 while keeping out particles greater than the size of the holes. Theannular region 215 between thebase pipe 210 and thewire screen 216 includes one or morescale inhibitor strips 218 disposed therein. Details of theinhibitors strips 218 are shown inFIGS. 3, 4A and 4B . -
FIG. 3 shows anillustrative inhibitor strip 218 for disposal between thebase pipe 210 andwire screen 216 ofFIG. 2B . Theinhibitor strip 218 is in the shape of a rectangular cuboid having a length l, width w and thickness t. The thickness of theinhibitor strip 218 is selected to allow theinhibitor strip 218 to fit within theannular region 215 between thewire screen 216 and thebase pipe 210. The width of theinhibitor strip 218 can be selected to fit along the curved surface of the base pipe to suitable approximation. -
FIGS. 4A and 4B shows cross sections of aninhibitor strip 218 in different embodiments.FIG. 4A shows across-section 400 of a coatedinhibitor strip 218. Thecross-section 400 shows abase material 402 having a coating of achemical inhibitor 404 surrounding its surface.FIG. 4B shows across-section 401 in which theinhibitor strip 218 includes abase material 402 that is impregnated with thechemical inhibitor 404. As fluid flows across the inhibitor strip, thechemical inhibitor 404 reacts with chemicals in the fluid responsible for compositional material production, thereby preventing or reducing scale, paraffin, and/or asphaltene productions. The inhibitor can be a chemical that interacts with chemicals in the formation fluid that otherwise result in scale, paraffin, and/or asphaltene production. - Over time, the chemical inhibitor in or on the inhibitor strips becomes depleted due to the interactions with the chemicals in the fluid. At a selected time, the inhibitor strips can be recharged by flowing a fluid chemical inhibitor into the wellbore and into contact with the inhibitor strips.
-
FIG. 5 shows aperspective view 500 of a partially constructed fluid inflow device. Theperspective view 500 includes thebase pipe 210 and a firstcylindrical arrangement 502 of inhibitor strips 218 arranged around a circumference of the base pipe. The lengths of the inhibitor strips 218 extend or are elongated along a longitudinal axis of thebase pipe 210. The firstcylindrical arrangement 502 covers a firstaxial section 504 of the base pipe. A secondaxial section 506 of the base pipe is shown uncovered. -
FIG. 6 shows a perspective view 600 of a subsequent construction stage of the fluid inflow device. A secondcylindrical arrangement 602 of inhibitor strips 218 are shown around the secondaxial section 506 of thebase pipe 210. Thewire screen 610 is shown over a section of the firstcylindrical arrangement 502. During construction thewire screen 610 can slide along the longitudinal axis of thebase pipe 210 to encapsulate each cylindrical arrangement once completed. -
FIG. 7 shows aperspective view 700 of the fluid inflow device in another embodiment. A plurality ofdividers 702 are formed between thebase pipe 710 and thewire screen 716 to form a plurality ofdrainage channels 704. Inhibitor strips 218 are disposed within the drainage channels, thereby causing the fluid to flow across the inhibitors strips 218 as it flows from thewire screen 716 to thebase pipe 710 via the drainage channels. - Set forth below are some embodiments of the foregoing disclosure:
- Embodiment 1. A method of preventing production of a compositional material in a production string. The method includes disposing an inhibitor strip in a fluid inflow device of the production string; and receiving a fluid at the fluid inflow device from a formation at the inhibitor strip, wherein a chemical inhibitor of the inhibitor strip interacts with a chemical in the fluid to reduce the production of the compositional material in the production string.
- Embodiment 2. The method of any prior embodiment, wherein the fluid inflow device includes a base pipe and a screen forming an annular region around the base pipe, further comprising disposing the inhibitor strip in a channel between the base pipe and the screen.
- Embodiment 3. The method of any prior embodiment, wherein the screen and the base pipe form one or more drainage channels, further comprising disposing the inhibitor strip in the one or more drainage channels.
- Embodiment 4. The method of any prior embodiment, wherein the inhibitor strip is elongated along a longitudinal axis of the base pipe.
- Embodiment 5. The method of any prior embodiment, wherein disposing the inhibitor strip further comprising placing a plurality of inhibitor strips circumferentially around an axial section of the base pipe.
- Embodiment 6. The method of any prior embodiment, wherein the inhibitor strip includes a base material that is one of: (i) coated with the chemical inhibitor; and (ii) impregnated with the chemical inhibitor.
- Embodiment 7. The method of any prior embodiment, further comprising recharging the inhibitor strip with the chemical inhibitor at its location in the wellbore.
- Embodiment 8. The method of any prior embodiment, wherein the compositional material includes at least one of scale, paraffin and asphaltene.
- Embodiment 9. A production string. The production string includes a fluid inflow device and an inhibitor strip disposed in contact with the fluid inflow device, the inhibitor strip including a chemical inhibitor therein to interact with chemicals in a fluid flowing through the fluid inflow device to reduce the production of a compositional material in the production string.
- Embodiment 10. The production string of any prior embodiment, further comprising a base pipe of the fluid inflow device, and a screen forming an annular region around the base pipe; wherein the inhibitor strip is disposed within the annular region.
- Embodiment 11. The production string of any prior embodiment, further comprising one or more drainage channels between the base pipe and the screen, wherein the inhibitor strip is disposed within the one or more drainage channels.
- Embodiment 12. The production string of any prior embodiment, wherein the inhibitor strip is elongated along a longitudinal axis of the base pipe.
- Embodiment 13. The production string of any prior embodiment, wherein the inhibitor strip further comprises a plurality of inhibitor strips disposed circumferentially around an axial section of the base pipe.
- Embodiment 14. The production string of any prior embodiment, wherein the inhibitor strip includes a base material that is one of: (i) coated with the chemical inhibitor; and (ii) impregnated with the chemical inhibitor.
- Embodiment 15. The production string of any prior embodiment, wherein the inhibitor strip is capable of being recharged with additional chemical inhibitor when deployed in a wellbore.
- The use of the terms “a” and “an” and “the” and similar referents in the context of describing the invention (especially in the context of the following claims) are to be construed to cover both the singular and the plural, unless otherwise indicated herein or clearly contradicted by context. Further, it should be noted that the terms “first,” “second,” and the like herein do not denote any order, quantity, or importance, but rather are used to distinguish one element from another. The modifier “about” used in connection with a quantity is inclusive of the stated value and has the meaning dictated by the context (e.g., it includes the degree of error associated with measurement of the particular quantity).
- The teachings of the present disclosure may be used in a variety of well operations. These operations may involve using one or more treatment agents to treat a formation, the fluids resident in a formation, a wellbore, and/or equipment in the wellbore, such as production tubing. The treatment agents may be in the form of liquids, gases, solids, semi-solids, and mixtures thereof. Illustrative treatment agents include, but are not limited to, fracturing fluids, acids, steam, water, brine, anti-corrosion agents, cement, permeability modifiers, drilling muds, emulsifiers, demulsifiers, tracers, flow improvers etc. Illustrative well operations include, but are not limited to, hydraulic fracturing, stimulation, tracer injection, cleaning, acidizing, steam injection, water flooding, cementing, etc.
- While the invention has been described with reference to an exemplary embodiment or embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications may be made to adapt a particular situation or material to the teachings of the invention without departing from the essential scope thereof. Therefore, it is intended that the invention not be limited to the particular embodiment disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the claims. Also, in the drawings and the description, there have been disclosed exemplary embodiments of the invention and, although specific terms may have been employed, they are unless otherwise stated used in a generic and descriptive sense only and not for purposes of limitation, the scope of the invention therefore not being so limited.
Claims (15)
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
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US16/460,526 US20210002983A1 (en) | 2019-07-02 | 2019-07-02 | Chemically treated substrate strips in screens for open hole gravel packing and stand alone screens |
PCT/US2020/040108 WO2021003092A1 (en) | 2019-07-02 | 2020-06-29 | Chemically treated substrate strips in screens for open hole gravel packing and stand alone screens |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US16/460,526 US20210002983A1 (en) | 2019-07-02 | 2019-07-02 | Chemically treated substrate strips in screens for open hole gravel packing and stand alone screens |
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US20210002983A1 true US20210002983A1 (en) | 2021-01-07 |
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ID=74065661
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US16/460,526 Abandoned US20210002983A1 (en) | 2019-07-02 | 2019-07-02 | Chemically treated substrate strips in screens for open hole gravel packing and stand alone screens |
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US (1) | US20210002983A1 (en) |
WO (1) | WO2021003092A1 (en) |
Citations (1)
Publication number | Priority date | Publication date | Assignee | Title |
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US20060011345A1 (en) * | 2004-07-15 | 2006-01-19 | Delaloye Richard J | Method and apparatus for downhole artificial lift system protection |
Family Cites Families (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US7117947B2 (en) * | 2003-07-30 | 2006-10-10 | Conoco Phillips Company | Well chemical treatment utilizing plunger lift delivery system |
US8016040B2 (en) * | 2008-11-26 | 2011-09-13 | Schlumberger Technology Corporation | Fluid loss control |
US8950491B2 (en) * | 2012-01-06 | 2015-02-10 | Odessa Separator, Inc. | Downhole assembly for treating wellbore components, and method for treating a wellbore |
EP2908925A4 (en) * | 2012-10-17 | 2016-07-20 | Absolute Completion Technologies Ltd | Wellbore screen, filter medium, and method |
MX2017012043A (en) * | 2015-03-27 | 2018-03-06 | Carbo Ceramics Inc | Methods and compositions for use of proppant surface chemistry and internal porosity to consolidate proppant particulates. |
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2019
- 2019-07-02 US US16/460,526 patent/US20210002983A1/en not_active Abandoned
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2020
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US20060011345A1 (en) * | 2004-07-15 | 2006-01-19 | Delaloye Richard J | Method and apparatus for downhole artificial lift system protection |
Non-Patent Citations (1)
Title |
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Schlumberger Oilfield Glossary, Scale, retrieved 09/07/22 from https://glossary.slb.com/en/terms/s/scale (Year: 2022) * |
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