Fluid Barriers For Dissolvable Plugs

BACKGROUND

In horizontal or deviated wells, drag forces may hinder casing from reaching total depth (TD) by exceeding a hook load or a casing buckling capacity. In order to reduce the drag forces, the casing in a horizontal or deviated section may be filled with air or a lightweight fluid for buoyancy. After the casing reaches TD, a rupture disc is burst, and the air or lightweight fluid chamber is filled with fluid.

BRIEF DESCRIPTION OF THE DRAWINGS

These drawings illustrate certain aspects of some of the embodiments of the present disclosure and should not be used to limit or define the disclosure.

FIGS. 1A and 1B illustrate an exemplary process that procures a fluid barrier on opposing ends of a dissolvable salt plug, in accordance with examples of the present disclosure;

FIG. 2 illustrates additional fluid barriers placed on opposing ends of the dissolvable salt plug, in accordance with examples of the present disclosure;

FIG. 3 illustrates a system implementing the dissolvable salt plug, in accordance with examples of the present disclosure;

FIG. 4 illustrates a flow chart for forming fluid barriers on opposing ends of the dissolvable salt plug, in accordance with examples of the present disclosure; and

FIG. 5 illustrates a flow chart for separating fluids in a subterranean formation with a dissolvable salt plug, in accordance with examples of the present disclosure.

DETAILED DESCRIPTION

The present disclosure relates to dissolvable salt plugs that may be utilized to separate fluids within a wellbore. Specifically, systems, methods, and apparatuses of the present disclosure may utilize dissolvable salt plugs that include a film deposited from an emulsion of rubber in water. The film may provide a layer that provides a fluid barrier that is impenetrable by downhole fluids. The film may prevent dissolution of the dissolvable salt plug, as the dissolvable salt plug is run in hole (“RIH”) or disposed in the wellbore.

In certain examples, the dissolvable salt plugs may be utilized with a buoyancy assisted casing tool. The dissolvable salt plug may provide a barrier between a fluid disposed up-hole to the dissolvable salt plug and a lightweight fluid contained in a buoyancy chamber, of the buoyancy assisted casing tool, that is disposed downhole from the dissolvable salt plug. The buoyancy assisted casing tool may be attached to the casing string at a surface of a wellbore before the buoyancy assisted casing tool is moved downhole within a subterranean formation. The fluid disposed up-hole to the dissolvable salt plug may include various fluids utilized for downhole operations in the oilfield. Non-limiting examples of the various fluids include drilling fluids, cement compositions, fresh water, brine, chemical additives, or combinations thereof. The drilling fluids may include oil-based muds or water-based muds, for example.

The lightweight fluid contained within the buoyancy chamber downhole to or below the dissolvable salt plug may have a density that is less than the fluid disposed up-hole to the dissolvable salt plug. Non-limiting examples of the lightweight fluid may include nitrogen, carbon dioxide, air, or combinations thereof.

The dissolvable salt plug contains or seals the lightweight fluid within the buoyancy chamber created by the buoyancy assisted casing tool until TD or a desired depth. At TD, a rupture disc of the buoyancy assisted casing tool may be burst, thereby allowing the dissolvable salt plug to dissolve. Removal of the salt plug releases the lightweight fluid from the buoyancy chamber and allows the buoyancy chamber to fill with the fluid that is disposed up-hole to the dissolvable salt plug. Filling of the buoyancy chamber enables the casing to be prepared for cementing operations.

The films of the present disclosure may replace polyisoprene elastomer diaphragms that may protect (e.g., encompass) a downhole plug as the downhole plug is moved into a wellbore. The polyisoprene elastomer diaphragms may prevent premature dissolution of the dissolvable salt plug. However, the polyisoprene elastomer diaphragms may travel to a float collar or float shoe during RIH and may become trapped in a poppet valve thereof which may hinder fluid flow through the poppet valve (e.g., prevents closure of the valve).

By replacing the polyisoprene elastomer diaphragms with films deposited from an emulsion of rubber in water, the amount of elastomer in the buoyancy assisted casing tool is substantially reduced, as well as risk to the float equipment. Upon contact of the emulsion with the salt surface of the dissolvable salt plug, the rubber instantaneously precipitates on the salt surface. As a solvent of the emulsion evaporates, a film is formed or produced on the contacted salt surface.

The film provides a fluid barrier that is impenetrable by downhole fluids. A thickness of the film may be substantially thinner than the elastomeric diaphragms resulting in less residual polymer debris downhole. A thinner coating of the film produces less debris and reduces the risk of interference with the float equipment operation. Upon dissolution of the salt of the dissolvable salt plug, the film disintegrates. In certain examples, the film be applied by brushing, pouring, or spraying the emulsion onto opposing ends of the dissolvable salt plug. Film thickness may be controlled by applying subsequent layers. The film may be applied to one, both or multiple surfaces that may contact fluids. In some examples, an additional fluid barrier may be fastened to the film by a press-fit, for example.

FIGS. 1A and 1B illustrate an exemplary process that procures a film on opposing ends of a dissolvable salt plug 100 in accordance with examples of the present disclosure. Lateral cross-sectional views of the dissolvable salt plug 100 are illustrated in FIGS. 1A and 1B, for example.

The dissolvable salt plug 100 may be a solid structure or matrix that may include sand and salt, for example. Types of salt included in the dissolvable salt plug 100 may include alkali metal halides and/or alkaline earth metal halides. Specific examples may include, but are not limited to, sodium chloride, potassium chloride, magnesium chloride, calcium chloride, or combinations thereof. The dissolvable salt plug 100 may be made from the salt, water, and sand that are mixed and cured at high temperatures and pressures to form a solid unitary and rigid structure or matrix that may withstand pressures ranging from 9,000 pounds per square inch (“psi”) (62,053 kilopascals (“kPa”) to 10,000 psi (68,948 kPa).

As shown on FIG. 1A, the diameter of the dissolvable salt plug 100 may vary along a length, L, of the dissolvable salt plug 100. In certain examples, the dissolvable salt plug 100 may include a circumferential tapered section 101 including sections S₁and S₂, each of which extends around or about a circumference and along a length, L, of the dissolvable salt plug 100. The dissolvable salt plug 100 may include a first circumference or diameter, D₁, at a first end or up-hole portion 102 (oriented in an up-hole direction), and a second circumference or diameter, D₂, at a second opposing end or downhole portion 104 (oriented in a downhole direction). D₁may be equal to D₂. The diameter of the dissolvable salt plug 100 may decrease from D₁to the smallest diameter, D_s, and increase from D_sto D₂, along L of the dissolvable salt plug 100, as shown. S₁may extend from D₁to D_s. S₂may extend from D_sto D₂.

The diameters of the dissolvable salt plug 100 may correspond with various casing diameters. The diameters may range from about 3 inches (8 cm) to about 9 inches (23 centimeters (cm). For example, the diameters may include 3.5 inches (9 cm), 4.5 inches (11 cm), 5.5 inches (14 cm), or 7 inches (18 cm). Lengths for the dissolvable salt plug 100 may range from about 4 inches (10 cm) to about 8 inches (20 cm), for example.

At least a portion of the dissolvable salt plug 100 may contact an emulsion 106. For example, the up-hole portion 102 and the downhole portion 104 of the dissolvable salt plug 100 may be treated with the emulsion 106. The up-hole portion 102 may be positioned opposite to the downhole portion 104. The up-hole portion 102 may be similar to the downhole portion 104. As shown on a close-up view 108 of a portion 109 of the emulsion 106, the emulsion 106 may be an emulsion of rubber in water. For example, the emulsion 106 may include polymer particles 110 which may be present in a latex solution 112. Upon contact of the emulsion 106 with the up-hole portion 102 and the downhole portion 104 of the dissolvable salt plug 100, the rubber (e.g., the polymer particles 110) instantaneously precipitates on and adheres to the up-hole portion 102 and the downhole portion 104.

As shown on FIG. 1B, the latex solution 112 (e.g., a solvent) may evaporate thereby leaving films 114a and 114b on the up-hole portion 102 and the downhole portion 104 of the dissolvable salt plug 100. The films 114a and 114b may be polymer films made of the polymer particles 110. The film 114a may be similar to the film 114b. Specific examples of suitable polymer films may include, but are not limited to, styrene-butadiene copolymer, acrylonitrile-butadiene styrene copolymer, isobutylene, polyisoprene, polyvinyl alcohol, polyacrylate, or combinations thereof. The polymers by be crosslinked or not crosslinked.

As illustrated in a close-up view 116 of a portion 111 of the film 114a, the film 114a may include interconnected layers 113 of the polymer particles 110, in some examples. That is, a layer 113 (e.g., 2-10 layers) may be added as needed. The films 114a and 114b may each have a thickness of 0.1 millimeter (“mm”) through 2 mm, in certain examples. In other examples, the films 114a and 114b may each have a thickness of 0.5 mm to 10 mm or 0.1 mm to 2 mm. The films 114a and 114b may attach or adhere to and completely cover the up-hole portion 102 and the downhole portion 104 of the dissolvable salt plug 100, respectively. The films 114a and 114b may provide impenetrable seals (e.g., fluid barriers) that prevent fluid (e.g., a drilling fluid, water) from penetrating the dissolvable salt plug 100 from the up-hole portion 102 (e.g., fluid penetration from an up-hole direction) and the downhole portion 104 (e.g., fluid penetration from a downhole direction) of the salt plug 100. In some examples, the dissolvable salt plug 100 may only be dissolvable upon contacting the circumferential tapered section 101 with fresh water (e.g., water with less than 500 parts per million (“ppm”) of dissolved salts). That is, the circumferential tapered section 101 may be a section of the salt plug 100 that receives the fresh water for dissolution of the dissolvable salt plug 100. As the salt plug 100 is dissolved, the films 114a and 114b disintegrate. In certain examples, an additional fluid barrier may be placed over each of the films 114a and/or 114b to assist with sealing and to distribute any fluid pressure received over the films 114a and/or 114b to prevent any damage to the films 114a and/or 114b.

FIG. 2 illustrates additional barriers 200a and 200b attached to the film 114a and the film 114b of the dissolvable salt plug 100, in accordance with examples of the present disclosure. Each of the barriers 200a and 200b may include a rubber (e.g., a polymer) that is placed over and adjacent to the films 114a and 114b to assist with sealing the up-hole portion 102 and the downhole portion 104 of the dissolvable salt plug 100. The barriers 200a and 200b may be fluid barriers with a thickness less than 1 mm, for example. The barriers 200a and 200b may be press-fitted onto the up-hole portion 102 and the downhole portion 104. The barriers 200a and 200b may completely cover the films 114a and 114b. As noted above, the barriers 200a and 200b may be placed over the films 114a and 114b to assist with sealing the dissolvable salt plug 100 from fluid present in the up-hole and downhole directions of a wellbore (e.g., the wellbore 302 shown on FIG. 3).

The barriers 200a and 200b may also distribute any fluid pressure received or exerted over the films 114a and 114b to prevent any damage to the films 114a and 114b. For example, the dissolvable salt plug 100 may be pressurized by a column of fluid within a wellbore during RIH. Further, the dissolvable salt plug 100 may be displacing a fluid (e.g., a drilling fluid) in the wellbore which may also exert fluid pressure against the film 114b. After dissolution of the dissolvable salt plug 100, the barriers 200a and 200b may collapse and be circulated out of the wellbore.

In some examples, the dissolvable salt plug 100 may be disposed within a seat 202 of a downhole tool. A shape or profile of the seat 202 may correspond to a shape or profile of the dissolvable salt plug 100 (including the circumferential tapered section 101) to ensure a snug fit between the seat 202 and the dissolvable salt plug 100.

FIG. 3 illustrates a system 300 comprising the dissolvable salt plug 100 in accordance with examples of the present disclosure. In some examples, the system 300 may be located at a well site. A wellbore 302 (e.g., a wellbore drilled for hydrocarbon recovery) may extend from a surface 306 into a subterranean formation 308. The wellbore 302 may include a horizontal or deviated section 304. The section 304 may be angled or may deviate more than 10° from a vertical section 305 of the wellbore 302. Although illustrated onshore, the wellbore 302 may be located offshore in certain examples. The wellbore 302 may be fluidly coupled to surface equipment such as a pump 310 and fluid storage 312 via conduits 314 and 316, for example. The fluid storage 312 (e.g., a container or pit) may store various fluids such as fresh water, brine, cement compositions, drilling fluids, or chemical additives, that may be pumped downhole, for example. Although not illustrated, the system 300 may also include other equipment utilized at a well site to at least assemble, disassemble, or move various components and/or materials into and out of the wellbore 302, as should be understood by one of skill in the art, with the benefit of this disclosure.

Casing string 318 may be disposed within the wellbore 302. An annulus 319 may be defined between the casing string 318 and the wellbore 302. A tool 320 (e.g., a downhole tubular connected via threads to the casing string 318) may be a section of the casing string 318. The tool 320 may be a buoyancy assisted casing tool. At the surface 306, the casing string may be made up with the tool 320 before the casing string 318 is moved into the wellbore 302. The tool 320 may be exposed to the wellbore 302 (i.e., the casing 318 does not cover the tool 320).

The tool 320 may create a buoyancy chamber 322 which may be sealed between the dissolvable salt plug 100 and a float shoe or float collar 325, for example. The dissolvable salt plug 100 may be positioned within the seat 202 of the tool 320. The buoyancy chamber 322 may be filled with a fluid 323. The fluid 323 may include a gas such as nitrogen, carbon dioxide, or air, for example. The buoyancy chamber 322 may be disposed down-hole from the salt plug 100 and may be filled with fluid that has a lower specific gravity than fluid in the wellbore 302 in which the tool 320 and the casing string 318 is run. Buoyancy of the buoyancy chamber 322 may be adjusted via selection of a specific fluid or an amount of that specific fluid contained within the buoyancy chamber 322, for example.

The films 114a and 114b of the dissolvable salt plug 100 provide fluid barriers to separate the fluid 323 of the tool 320 from a fluid 326 disposed up-hole to the dissolvable salt plug 100. The film 114a may contact the fluid 326 and the film 114b may contact the fluid 323. The fluid 326 may have a density or specific gravity that is greater than a density or specific gravity of the fluid 323. The fluid 326 may include various fluids, such as fresh water, brine, cement compositions, drilling fluids, or chemical additives, that may be pumped downhole, for example.

The tool 320 may also include a rupture disc 324 positioned adjacent or in close proximity to the dissolvable salt plug 100. The rupture disc 324 may be made of metal and may be in fluid communication with the fluid 326. The rupture disc 324 may have a rupture pressure greater than the hydraulic pressure encountered by the casing string 318 as the casing string 318 is RIH (e.g., run into the wellbore 302), in order to prevent premature bursting of the rupture disc 324. The rupture disc 324 may withstand pressures ranging from 5,000 psi through 40,000 psi, for example.

As noted above, the casing string 318 may be made up at the surface 306 to include the tool 320. That is, the tool 320 is in an interconnected (connecting end to end via threads) series of individual tubulars of the casing string 318. After connecting the tool 320 to the casing string 318, the casing string 318 and the tool 320 are run into the wellbore 302 until friction drag on the casing string 318 caused by a wellbore fluid 327 and/or walls of the wellbore 302, prevents the casing string 318 from moving any further downhole within the wellbore 302 or until the desired depth for the casing has been achieved. The wellbore fluid 327 may include fluid similar to that of the fluid 326. After progressive movement of the casing string ceases, circulating equipment at the surface 306 such as the pump 312 may circulate the fluid 326 through the casing string 318 such that the rupture disc 324 bursts. Bursting of the rupture disc 324 may allow fresh water to contact the circumferential tapered section 101 thereby releasing the dissolvable salt plug 100. Once the dissolvable salt plug 100 is removed, the fluid above or up-hole to the dissolvable salt plug 100 is released to displace the lightweight fluid or gas from below or downhole to the dissolvable salt plug 100. The lightweight material can either percolate within the casing string 318 to the surface 306 or be circulated outside the casing string 318 into the annulus 319 to be displaced to the surface 306.

FIG. 4 illustrates a flow chart 400 for treating a salt plug with an emulsion to form an impenetrable film or fluid barrier on opposing ends of the salt plug in accordance with examples of the present disclosure. At step 402, opposing ends of a salt plug (e.g., the up-hole portion 102 and the downhole portion 104 of the dissolvable salt plug 100 shown on FIGS. 1A, 1B, and 2) may be treated with an emulsion of rubber in water (e.g., the emulsion 106). The emulsion 106 may be applied, as at least one layer, to the up-hole portion 102 and the downhole portion 104 by brushing, pouring, or spraying the emulsion 106 onto a surface of the up-hole portion 102 and the downhole portion 104.

At step 404, upon contacting the emulsion 106 with a salt surface of the up-hole portion 102 and/or the downhole portion 104 of the dissolvable salt plug 100, polymer particles (e.g., the polymer particles 110 shown on FIGS. 1A and 1B) of the emulsion 106 may precipitate onto the up-hole portion 102 and the downhole portion 104 of the dissolvable salt plug 100 to completely cover each end of the dissolvable salt plug 100.

At step 406, after precipitation of the polymer particles 110, a solvent of the emulsion 106 (e.g., the latex solution 112 shown on FIG. 1A) may evaporate (e.g., due to ambient conditions or a dryer/heater), thereby producing impenetrable seals or fluid barriers comprising films (e.g., the films 114a and 114b shown on FIGS. 1B and 2) on the up-hole portion 102 and the downhole portion 104 of the dissolvable salt plug 100. Multiple layers (e.g., 2-10 layers) of the emulsion 106 may be applied to the films 114a and 114b, as desired, to provide increasing layers of sealing protection (e.g., the layers 113 shown on FIG. 1B).

At step 408, an additional rubber barrier (e.g., the barriers 200a and 200b) may be positioned (e.g., press fitted) over the films 114a and 114b to protect the films.

FIG. 5 illustrates a flow chart 500 for separating fluids in the subterranean formation 308 with the dissolvable salt plug 100, in accordance with examples of the present disclosure. At step 502, a casing string (e.g., the casing string 318 shown on FIG. 3) is run into a wellbore (e.g., the wellbore 302 shown on FIG. 3) until friction drag on the casing string 318 caused by fluid (e.g., drilling fluid) and/or walls of the wellbore 302 prevents the casing string 318 from moving any further downhole within the wellbore 302 (i.e., the casing string 318 has landed (e.g., TD has been reached) within the wellbore 302). The casing string 318 may include the tool 320 comprising the buoyancy chamber 322 sealed with the dissolvable salt plug 100 (e.g., shown on FIG. 3).

At step 504, the dissolvable salt plug 100 separates an up-hole fluid such as the fluid 326 shown on FIG. 3 from a lightweight fluid contained in the tool 320 such as the fluid 323 also shown on FIG. 3. The dissolvable salt plug 100 may include fluid barriers or the films 114a and 114b disposed on opposing ends, and thus may only dissolve upon the circumferential tapered portion 101 contacting fresh water, as best shown on FIG. 2.

To facilitate understanding of various aspects of the present disclosure, the following example is provided.

Example

To evaluate the effectiveness of the latex coating, a core with a 1-inch (2.54 cm) diameter and a length of approximately 2 inches (5.08 cm), was taken from a sand/salt plug. The core was placed in a Hassler sleeve. A 1 mm to 2 mm latex coating was applied to a top surface of the core. After drying the film, 150 psi (1034 kPa) of pressure was applied to the film with water. No penetration was observed over a time period of 1 week. The temperature of the test assembly was increased to 150° F. (65.6° C.), and again no leakage was observed after 24 hours.

Accordingly, the present disclosure may provide systems, methods, and apparatuses that may utilize dissolvable salt plugs with a film deposited from an emulsion of rubber in water. The systems, methods, and apparatus may include any of the various features disclosed herein, including one or more of the following statements.

Statement 1. A dissolvable plug comprising: a first end comprising a first fluid barrier, the first fluid barrier comprising a polymer film; and a second end opposite to the first end, the second end comprising a second fluid barrier, the second fluid barrier comprising a polymer film; wherein the dissolvable plug comprises a solid structure made of a sand and salt mixture.

Statement 2. The dissolvable plug of the statement 1, wherein a tapered section extends from the first end to the second end, wherein the tapered section does not comprise any fluid barrier.

Statement 3. The dissolvable plug of the statement 2, further comprising an additional fluid barrier disposed on each of the first and second fluid barrier.

Statement 4. The dissolvable plug of the statement 3, wherein the additional fluid barrier comprises a rubber.

Statement 5. The dissolvable plug of any of the preceding statements, wherein a sand of the sand and salt mixture comprises alkali metal halides or alkaline earth metal halides.

Statement 6. The dissolvable plug of any of the preceding statements, wherein the dissolvable plug comprises sodium chloride, potassium chloride, magnesium chloride, calcium chloride, or combinations thereof.

Statement 7. The dissolvable plug of any of the preceding statements, wherein a length of the dissolvable plug ranges from 4 inches to 8 inches.

Statement 8. A system for separating fluids in a wellbore, the system comprising: a dissolvable plug comprising: a first end comprising a first fluid barrier, the first fluid barrier comprising a polymer film; and a second end opposite to the first end, the second end comprising a second fluid barrier, the second fluid barrier comprising a polymer film; wherein the plug comprises a solid structure made of a sand and salt mixture; and casing extending in a direction that deviates at least 10° from a vertical direction, the dissolvable plug positioned in the casing.

Statement 9. The system of the statement 8, wherein a deviated section of the casing comprises a buoyancy assisted casing tool comprising a buoyancy chamber.

Statement 10. The system of the statement 9, wherein the dissolvable plug separates a first fluid from a second fluid, wherein the first fluid is up-hole from the dissolvable plug, wherein the second fluid is downhole from the dissolvable plug.

Statement 11. The system of the statement 10, wherein the first fluid is different from the second fluid.

Statement 12. The system of the statement 11, wherein the first fluid has a specific gravity that is greater than a specific gravity of the second fluid.

Statement 13. The system of the statement 12, wherein the second fluid is disposed in the buoyancy chamber.

Statement 14. The system of any of the statements 8-13, wherein the second fluid comprises nitrogen, carbon dioxide, or air.

Statement 15. A method for producing at least one fluid barrier on a salt plug, the method comprising: contacting a first end of the salt plug with an emulsion of rubber in water; evaporating a solvent of the emulsion; and forming at least one layer of polymer particles on the first end to protect the first end from fluid penetration.

Statement 16. The method of the statement 15, further comprising contacting a second end of the salt plug with the emulsion of rubber in water, the second end opposite from the first end; evaporating the solvent of the emulsion; and forming a second layer of polymer particles on the first end to protect the first end from fluid penetration.

Statement 17. The method of the statement 15 or the statement 16, wherein contacting the first and second ends of the salt plug comprises contacting the first and second ends of the salt plug with a latex solution comprising the polymer particles.

Statement 18. The method of any of the statements 15-17, wherein evaporating the solvent comprises evaporating a latex solution.

Statement 19. The method of any of the statements 15-18, further comprising disposing an additional fluid barrier on the at least one layer of polymer particles.

Statement 20. The method of any of the statements 15-19, further comprising disposing an additional fluid barrier on the second layer of polymer particles.

It should be understood that, although individual examples may be discussed herein, the present disclosure covers all combinations of the disclosed examples, including, without limitation, the different component combinations, method step combinations, and properties of the system. It should be understood that the compositions and methods are described in terms of “comprising,” “containing,” or “including” various components or steps, the compositions and methods may also “consist essentially of” or “consist of” the various components and steps. Moreover, the indefinite articles “a” or “an,” as used in the claims, are defined herein to mean one or more than one of the elements that it introduces. The term “coupled” means directly or indirectly connected.

For the sake of brevity, only certain ranges are explicitly disclosed herein. However, ranges from any lower limit may be combined with any upper limit to recite a range not explicitly recited, as well as, ranges from any lower limit may be combined with any other lower limit to recite a range not explicitly recited, in the same way, ranges from any upper limit may be combined with any other upper limit to recite a range not explicitly recited. Additionally, whenever a numerical range with a lower limit and an upper limit is disclosed, any number and any included range falling within the range are specifically disclosed. In particular, every range of values (of the form, “from about a to about b,” or, equivalently, “from approximately a to b,” or, equivalently, “from approximately a-b”) disclosed herein is to be understood to set forth every number and range encompassed within the broader range of values even if not explicitly recited. Thus, every point or individual value may serve as its own lower or upper limit combined with any other point or individual value or any other lower or upper limit, to recite a range not explicitly recited.

Therefore, the present examples are well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. The particular examples disclosed above are illustrative only and may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Although individual examples are discussed, the disclosure covers all combinations of all of the examples. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. Also, the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee. It is therefore evident that the particular illustrative examples disclosed above may be altered or modified and all such variations are considered within the scope and spirit of those examples. If there is any conflict in the usages of a word or term in this specification and one or more patent(s) or other documents that may be incorporated herein by reference, the definitions that are consistent with this specification should be adopted.

	Number	Date	Country
Parent	16850440	Apr 2020	US
Child	17682005		US

Fluid Barriers For Dissolvable Plugs

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