WO2016080956A1

WO2016080956A1 - Barrier surface for downhole elastomeric components

Info

Publication number: WO2016080956A1
Application number: PCT/US2014/066024
Authority: WO
Inventors: Jose Angel CARIDAD URENA; Jason Holzmueller; William Goertzen
Original assignee: Schlumberger Canada Limited; Services Petroliers Schlumberger; Schlumberger Holdings Limited; Schlumberger Technology B.V.; Prad Research And Development Limited; Schlumberger Technology Corporation
Priority date: 2014-11-18
Filing date: 2014-11-18
Publication date: 2016-05-26

Abstract

A barrier surface for downhole elastomeric components is provided. In an implementation, an elastomeric component for downhole employment, such as a seal for an electric submersible pump (ESP), is composed of a perfluorinated elastomeric base material protected by a barrier surface layer composed of a fluoropolymer or a polyaryletherketone, to isolate the perfluorinated elastomeric base from high-temperature and chemically aggressive well fluids. The barrier surface layer increases the working life of the elastomeric component by preventing high-temperature hydration of polymer crosslinks in the underlying perfluorinated elastomeric base material, and by increasing lubricity of the outer surface. A blocking agent, such as nanoscale clay, carbon black, talc, mica, silica, graphene, graphite nanoplatelets, metal particles, or metal nanoparticles may also be added to the barrier surface layer to further armor the barrier surface against well fluids.

Description

BARRIER SURFACE FOR DOWNHOLE ELASTOMERIC COMPONENTS

BACKGROUND

[0001] Equipment for downhole deployment in the oil and gas industry may utilize several types of elastomeric parts. Electric submersible pumps (ESPs) for artificial lift, for example, may include elastomeric gaskets, flange seals, o-rings, bladders, labyrinth seals, tubes, and so forth. An elastomeric o- ring, for example, may be installed in the gland of a hardware component of an ESP to keep outside well fluids away from internal dielectric lubricants. For more severe environments, conventional elastomeric components may be made of perfluoroelastomers, which can provide enhanced resistance to many chemicals and greater resistance to high-temperature working fluids.

[0002] In many high-temperature environments, however, such as steam assisted gravity drainage (SAGD) or steam flooding, the aging rate of conventional elastomers is drastically accelerated by temperature. Even conventional perfluoroelastomers, which are impervious to most chemicals, can be vulnerable to early aging and failure under severe enough conditions. The degradation of perfluoroelastomers is not entirely thermally dependent, but rather dependent on a combination of high temperatures and chemical attack from the downhole well fluid. Even high-temperature water alone, when it penetrates into a seal, can be particularly aggressive in attacking polymer crosslinks and accelerating the degradation of the perfluoroelastomer. SUMMARY

[0003] An apparatus described herein includes a downhole equipment component, an elastomeric component associated with the downhole equipment component, and a barrier surface on the elastomeric component to isolate the elastomeric component from a well fluid. An elastomeric component of an electric submersible pump (ESP) includes a perfluorinated elastomer base, and a barrier surface on the perfluorinated elastomer base comprising a fluoropolymer or a polyaryletherketone to isolate the perfluorinated elastomer base from high-temperature well fluids and from chemically aggressive well fluids. A seal for isolating a downhole equipment component from well fluid includes an elastomer base of the seal, and a barrier surface on the elastomer base comprising a fluoropolymer or a polyaryletherketone to isolate the elastomer base from high-temperature well fluids and from chemically aggressive well fluids.

[0004] This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.

BRIEF DESCRIPTION OF THE DRAWINGS

[0005] Certain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements. It should be understood, however, that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein.

[0006] Fig. 1 is a diagram of an example electric submersible pump (ESP) including elastomeric components bearing a protective barrier surface layer.

[0007] Fig. 2 is a diagram of a segment of an elastomeric component surmounted by an example barrier surface against well fluid penetration.

[0008] Fig. 3 is a diagram of a segment of an elastomeric component surmounted by an example barrier surface against well fluid penetration, including a blocking agent.

[0009] Fig. 4 is a diagram of a segment of an elastomeric component surmounted by an example barrier surface against well fluid penetration, including an added lubricity agent.

[0010] Fig. 5 is a flow diagram of an example method of protecting an elastomeric component from a high-temperature, chemically aggressive well fluid. DETAILED DESCRIPTION

Overview

[001 1 ] In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure. However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.

[0012] This disclosure describes barrier surfaces for downhole elastomeric components. In an electric submersible pump (ESP), for example, various parts and seals may be made of elastomers, because of the relative inertness of some elastomers to the temperatures, pressures, and chemical attacks inherent in severe downhole environments. Perfluorinated elastomers (perfluoroelastomers) can be employed for high working-temperature applications and for added resistance to chemical attack from corrosives, hydrocarbon solvents, hydrogen sulfide (H₂S) in solution, and so forth. But even the most temperature-resistant and chemical-resistant of the conventional elastomers, such as perfluorinated elastomers, can suffer early failure when subjected to a combination of high-temperature hydration and chemical attack. Once high-temperature water or steam, for example, is able to penetrate the outer surface of a perfluoroelastomer, the polymer crosslinks of the strong chemical structure become vulnerable and begin to degrade. [0013] Example barrier surfaces for downhole elastomers, as described herein, aim to isolate an underlying elastomer from high-temperature hydration and chemical attack imposed by penetrating well fluids, enabling the elastomer, when protected by the barrier surface, to last much longer. Example barrier surfaces (e.g., layers, films, and coatings) for protecting an underlying elastomer may be made of a fluoropolymer or a polyaryletherketone. The barrier surface may additionally include a blocking agent added into the fluoropolymer or polyaryletherketone layer for further prevention of penetration by high -temperature water, steam, and corrosive chemicals. The added blocking agent, for example, may be a clay, carbon black, talc, mica, a nanoclay, a silica, graphene, graphite nanoplatelets, metal particles, or metal nanoparticles, that further armor the barrier surface and the underlying elastomeric component from the well fluid. By slowing the migration of fluid through the barrier surface, the lifetime of the elastomeric component can be extended.

Example Systems

[0014] An elastomer is a polymer with viscoelasticity (having both viscosity and elasticity) and weak inter-molecular forces, generally having a low Young's modulus and high failure strain compared with other materials. Perfluoroelastomers are copolymers of tetrafluoroethylene and perfluorovinyl ether. Low-compression set, high-strength, and high-temperature perfluoro- elastomers can provide excellent resistance to numerous chemicals and may have a high-temperature working range, such as a maximum continuous service temperature of 327 °C (621 °F), for certain polymer grades.

[0015] Such conventional perfluoroelastomeric components, with the ASTM D1418 designation of "FFKM," may be available under trade names such as, for example, SIMRIZ (Simrit-Freudenberg-NOK Sealing Technologies, Elgin, IL), KALREZ (DuPont, Wilmington, Delaware), CHEMRAZ (Greene Tweed, Kulpsville, PA), and PAROFLUOR (Parker Hannifin, Mayfield Heights, OH). These perfluoroelastomers are conventionally used to make o-rings to be used in applications that involve contact with hydrocarbons or highly corrosive fluids, or, when a wide range of temperatures is to be encountered.

[0016] As introduced above, elastomeric components made of perfluoroelastomers are subject to degradation once their surface begins to be penetrated by high-temperature water or stream (or chemical attack), which degrades polymer crosslinks.

[0017] Fig. 1 shows an example submersible pumping system 100 that includes at least one elastomeric component 102 protected by an example barrier surface 104. The elastomeric component 102 may be a seal, such as an o-ring, a flange gasket, etc., or may be a cable grommet, bag, tube, or other elastomeric component 102 that has contact with well fluid. The submersible pumping system 100 may include a variety of sections and components depending on the particular application or environment in which the system is used. Examples of components utilized in submersible pumping system 100 include at least one motor 106, one or more submersible pumps 108, and one or more motor protectors 110 coupled together to form stages, sections, or segments of the submersible pumping system 100, also referred to as an electric submersible pump (ESP) string 100.

[0018] The example submersible pumping system 100 is designed for deployment in a well 112 within a geological formation 114 containing desirable production fluids, such as petroleum. A wellbore 116 is drilled into the formation 114, and, in at least some applications, is lined with a wellbore casing 118. Perforations 120 are formed through wellbore casing 118 to enable flow of fluids between the surrounding formation 114 and the wellbore 116.

[0019] The example submersible pumping system 100 is deployed in wellbore 116 by a deployment system 122 that may have a variety of configurations. For example, deployment system 122 may comprise tubing 124, such as coiled tubing or production tubing 124, connected to submersible pump 108 by a connector 126. Power is provided to the at least one submersible motor 106 via a power cable 128. The submersible motor 106, in turn, powers a submersible pump 108, which can be used to draw in well fluid through a pump intake 130. Within the submersible pump 108, multiple impellers may be rotated to pump or produce the well fluid through tubing 124 to a desired collection location which may be at the surface 132 of the Earth. [0020] The example ESP 100 is only one example of many types of electric submersible pumps or pumping systems that may have multiple elastomeric components 102. Multiple pump stages that utilize multiple pumps 108 and multiple motors 106 can be added to the ESP lineup to make a longer string. The submersible pump or pumps 108 can also utilize different types of stages, such as centrifugal, mixed flow, radial flow stages, and so forth, each using a different array of elastomeric components 102.

[0021 ] The example ESP system 100 includes one or more elastomeric components 102 with an underlying perfluoroelastomer protected by an example barrier surface 104 against direct contact with aggressive well fluid. The protected elastomeric component 102 may be from a large assortment of component types, such as a flange seal, a thread seal, a gasket, a cap seal, a compression seal, a diaphragm, a diaphragm seal, a ferrofluidic seal, a mechanical packing seal, an o-ring, a piston ring, a glass-to-metal seal, a ceramic-to-metal seal, a heat seal, a hose coupling, a hermetic seal, a grommet, a hydrostatic seal, a hydrodynamic seal, an oil seal ring, a seal protector, a bladder, a bladder tube, a bag, a bellows, a fluid containment chamber, a labyrinth section, a labyrinth protector, a labyrinth seal, a labyrinth tube, a lid seal, a face seal, a plug, a radial shaft seal, a split seal, a wiper seal, a dry gas seal, a lip seal, a cable sheath, a cable armor, and so forth. For harsh environments, one or more of these elastomeric components 102 may be made of a perfluorinated elastomer for resistance to most chemicals and durability at a high working-temperature. The perfluorinated elastomeric component 102 is protected in turn by an example barrier surface 104.

[0022] Fig. 2 shows a segment of an example elastomeric component 102 with barrier surface 104. The elastomeric component 102 may be a seal, such as seal 200 or o-ring 202, or other elastomeric component 102 that has contact with well fluid. In an implementation, the example barrier surface 104 is a polymer layer, film, or coating, bonded or adhered onto the underlying elastomeric component 102. The example barrier surface 104 enhances the chemical resistance of the elastomeric component 102 by isolating the elastomeric component 102 from corrosive and aggressive chemicals 204, such as hot hydrocarbon solvents, hydrogen sulfide (H₂S), and the like. The example barrier surface 104 also provides isolation from surface penetration by high-temperature water and steam 206, thereby avoiding hydration and swelling of the underlying elastomeric component 102, and preserving the integrity of elastomeric polymer crosslinks.

[0023] The aging rate of the elastomeric component 102 is greatly accelerated by increased temperature. By having a chemically stable barrier surface 104 between the elastomeric component 102 and the working fluid 204 & 206, the aging process is relented and the base elastomeric component 102 is able to work against a broader range of fluids and maintain its functionality for a longer period of time.

[0024] The elastomeric component 102 with example barrier surface 104 can be used in many downhole circumstances, such as SAGD or steam flooding, but is especially useful in high-temperature environments and those aiming for very high reliability, such as subsea applications, for example.

[0025] In an implementation, the example barrier surface 104 may be a fluorinated polymeric coating, such as a fluorinated ethylene propylene (FEP), a polytetrafluoroethylene (PTFE), an expanded polytetrafluoroethylene (ePTFE), a perfluoroalkoxy polymer (PFA), an epitaxial co-crystallized alloy (ECA), or an ethylene tetrafluoroethylene (ETFE). These fluorinated polymers are chemically inert, thermally stable, and can be successfully applied and bonded to an underlying elastomeric component 102. An ePTFE barrier surface 104 provides a strong, microporous layer that is chemically inert, resistant to high temperatures, has a low coefficient of friction, and prevents water, steam, and other fluids from passing or even adsorbing onto its outer surface.

[0026] In an implementation, the example barrier surface 104 may be a polymer from the polyaryletherketone family, such as a poly ether ether ketone (PEEK), a poly ether ketone (PEK), a poly ether ketone ether ketone ketone (PEKEKK), a poly ether ketone ketone (PEKK), or a poly (aryl) ether ether ketone ketone PEEKK. These polyaryletherketones are also chemically inert, thermally stable, and can be readily applied and bonded to an underlying elastomeric component 102.

[0027] Fig. 3 shows an additional blocking agent 302 (not to scale) added to the barrier surface 104 of an example elastomeric component 102. In an implementation, the example barrier surface 104 is combined with the blocking agent 302 to further reduce permeability of the barrier surface 104 to well fluids. In an implementation, the blocking agent 302 is a fiber, particle, or flake, with a high aspect-ratio in the example barrier surface 104. The blocking agent 302 may be of nanoscale size (1 -100 nanometers), that is, nanofibers, nanoparticles, or nanoflakes. High aspect-ratio means that a length of each nanofiber or nanoparticle of the blocking agent 302 is greater than a diameter of the nanofiber or nanoparticle, or that a diameter of each nanoflake of the blocking agent 302 is greater than a thickness of the nanoflake. This geometry of the blocking agent 302 orients the blocking agent 302 flat (longest side parallel) to the surface of the elastomeric component 102 bearing the barrier surface 104.

[0028] The example blocking agent 302 may include one or more of clay, talc, mica, nanoclay, silica, graphene, carbon black, graphite nanoplatelets, metal particles or nanoparticles, or other organic or inorganic material that can be compounded with the polymer of the barrier surface 104 to make the barrier surface 104 more impervious to well fluid. The example blocking agent 302 improves the already significant blocking properties of the barrier surface 104 against well fluids.

[0029] Besides acting as a chemical and hydration barrier, the example barrier surface 104 can provide additional benefits, e.g., when the elastomeric component 102 is a seal, because of a low coefficient of friction of the fluoropolymer or polyaryletherketone elastomer making up the barrier surface 104. The low coefficient of friction allows the barrier surface 104 to slide within a gland, for example, when pressure cycles occur in the ESP 100. This lubricity of the example barrier surface 104 prevents adhesion to gland walls or a hardware surface, and prevents material loss that can compromise sealing.

[0030] Fig. 4 shows an additional lubricity agent 402 (not to scale) added to the example barrier surface 104 of an example elastomeric component 102. The elastomer of the barrier surface 104, e.g., a fluoropolymer or a polyaryletherketone, may already have a slippery quality from the inherently low coefficient of friction of this elastomer. In an implementation, the additional lubricity agent 402 may be an additional ingredient, such as one of the blocking agents 302 described above (e.g., graphite), or another dry lubricant, for example, such as molybdenum disulfide (MoS₂), hexagonal boron nitride ("white graphite"), or tungsten disulfide (WS₂). The blocking agent 302 and the lubricity agent 402 may be the same agent, as in the case of graphite, or may be different agents combined in the elastomer of the barrier surface 104. To reiterate, the elastomer itself, of the barrier surface 104, already has a low coefficient of friction, providing a native lubricity that assists in the longevity of the elastomeric component 102 bearing the example barrier surface 104, but an additional lubricity agent 402 may also be added.

[0031 ] An example barrier surface 104 may be created on an underlying elastomeric component 102 in various ways, depending on the constitution of the elastomers in the underlying elastomeric component 102, the barrier surface 104, the blocking agent 302, when added, and the lubricity agent 402, when added. For example, a finished elastomeric component 102 with barrier surface 104 can be cold cast, injection molded, and so forth, depending on size and thickness. A large elastomeric component 102 for an ESP may have a barrier surface layer 104 that is 2-3 mils thick (i.e., 2-3 thousandths of an inch, or 0.05-0.07 millimeters).

[0032] In an implementation, the barrier surface 104 is applied as a film by hand, by dipping, or as a spray, onto a finished elastomeric component 102, and attaches through adhesion and sometimes hysteresis. The barrier surface 104 applied in this manner may include one or both of the blocking agent 302 and the lubricity agent 402.

[0033] A thin barrier surface layer 104 can be applied to an underlying perfluoroelastomeric base, for example, by solvent-based dispersion, spraying, dipping, etc., with baking or heat consolidation, for example. The blocking agent 302 and lubricity agent 402, when used, can be mixed during polymerization of the fluoropolymer or polyaryletherketone base of the barrier surface layer 104. When the elastomeric component 102 is a seal, the seal can be made by thin cake molding and consolidation, or by adhering the barrier surface 104 to the perfluoroelastomeric base in a second step.

Example Method

[0034] Fig. 5 shows an example method 500 of protecting an elastomer for downhole use in an aggressive well fluid. The well fluid may be aggressive due to high -temperature, chemically active species in the well fluid, or both. In the flow diagram, operations are shown in individual blocks.

[0035] At block 502, an elastomeric component for downhole utility is manufactured using a perfluoroelastomer. The perfluoroelastomer provides resistance to high-temperature hydration and high-temperature chemical attack from the well fluid.

[0036] At block 504, the perfluoroelastomeric component is covered with a barrier surface of a fluoropolymer or a polyaryletherketone, to enhance shielding the perfluoroelastomeric component from high-temperature and chemically active well fluid.

[0037] A blocking agent may be added to the barrier surface layer, to further armor the barrier surface against attack and penetration by high- temperature hydration and high-temperature chemical attack. The blocking agent may be a clay, carbon black, talc, mica, silica, graphene, metal particles, or nanoscale versions of the above agents, such as a nanoclay, graphite nanoplatelets, metal nanoparticles, and so forth.

Conclusion

[0038] Although a few embodiments of the disclosure have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure. Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.

Claims

1 . An apparatus, comprising:

a downhole equipment component;

an elastomeric component associated with the downhole equipment component; and

a barrier surface on the elastomeric component to isolate the elastomeric component from a well fluid.

2. The apparatus of claim 1 , wherein the elastomeric component comprises a perfluorinated elastomer; and

wherein the barrier surface comprises a fluorinated polymeric coating selected from the group consisting of a fluorinated ethylene propylene (FEP), a polytetrafluoroethylene (PTFE), an expanded polytetrafluoroethylene (ePTFE), a perfluoroalkoxy polymer (PFA), an epitaxial co-crystallized alloy (ECA), and an ethylene tetrafluoroethylene (ETFE).

3. The apparatus of claim 1 , wherein the elastomeric component comprises a perfluorinated elastomer; and

wherein the barrier surface comprises a polyaryletherketone (PAEK) selected from the group consisting of a poly ether ketone (PEK), a polyether ether ketone (PEEK), a poly ether ketone ether ketone ketone (PEKEKK), a poly ether ketone ketone (PEKK), and a poly ether ether ketone ketone (PEEKK).

4. The apparatus of claim 1 , wherein the barrier surface isolates the elastomeric component from penetration by a high-temperature well fluid and isolates the elastomeric component from chemical attack by a chemically aggressive well fluid.

5. The apparatus of claim 4, wherein the barrier surface prevents high-temperature hydration and subsequent degradation of polymer crosslinks of an elastomer of the elastomeric component.

6. The apparatus of claim 1 , wherein the elastomeric component is selected from the group consisting of a flange seal, a thread seal, a gasket, a cap seal, a compression seal, a diaphragm, a diaphragm seal, a ferrofluidic seal, a mechanical packing seal, an o-ring, a piston ring, a glass-to-metal seal, a ceramic-to-metal seal, a heat seal, a hose coupling, a hermetic seal, a grommet, a hydrostatic seal, a hydrodynamic seal, an oil seal ring, a seal protector, a bladder, a bladder tube, a bag, a bellows, a fluid containment chamber, a labyrinth section, a labyrinth protector, a labyrinth seal, a labyrinth tube, a lid seal, a face seal, a plug, a radial shaft seal, a split seal, a wiper seal, a dry gas seal, a lip seal, a cable sheath, and a cable armor.

7. The apparatus of claim 1 , wherein the barrier surface further comprises an additional blocking agent to reduce a permeability of the barrier surface.

8. The apparatus of claim 7, wherein the additional blocking agent comprises a nanoscale component selected from the group consisting of a clay, a carbon black, a talc, a mica, a nanoclay, a silica, a graphene, graphite nanoplatelets, metal particles, and metal nanoparticles.

9. The apparatus of claim 8, wherein the nanoscale component comprises one of a nanofiber, a nanoparticle, or a nanoflake;

wherein the nanoscale component has a high aspect-ratio; wherein a length of each nanofiber or nanoparticle of the nanoscale component is greater than a diameter of the nanofiber or nanoparticle, or a diameter of each nanoflake of the nanoscale component is greater than a thickness of the nanoflake.

10. The apparatus of claim 1 , wherein the barrier surface includes an additional lubricity agent providing an enhanced low coefficient of friction to prevent an adhesion of the barrier surface to the downhole equipment component and allowing the elastomeric component to slide with respect to a surface of the downhole equipment component.

11 . The apparatus of claim 10, wherein the additional lubricity agent is selected from the group consisting of graphite, molybdenum disulfide (MoS₂), hexagonal boron nitride, and tungsten disulfide (WS₂).

12. The apparatus of claim 1 , wherein the barrier surface comprises a polyaryletherketone with a blocking agent comprising graphite nanoparticles.

13. An elastomeric component of an electric submersible pump (ESP), comprising:

a perfluorinated elastomer base of the elastomeric component; and a barrier surface on the perfluorinated elastomer base comprising one of a fluoropolymer or a polyaryletherketone to isolate the perfluorinated elastomer base from high-temperature well fluids and from chemically aggressive well fluids.

14. The elastomeric component of an ESP of claim 13, wherein the elastomeric component is selected from the group consisting of a flange seal, a thread seal, a gasket, a cap seal, a compression seal, a diaphragm, a diaphragm seal, a ferrofluidic seal, a mechanical packing seal, an o-ring, a piston ring, a glass-to- metal seal, a ceramic-to-metal seal, a heat seal, a hose coupling, a hermetic seal, a grommet, a hydrostatic seal, a hydrodynamic seal, an oil seal ring, a seal protector, a bladder, a bladder tube, a bag, a bellows, a fluid containment chamber, a labyrinth section, a labyrinth protector, a labyrinth seal, a labyrinth tube, a lid seal, a face seal, a plug, a radial shaft seal, a split seal, a wiper seal, a dry gas seal, a lip seal, a cable sheath, and a cable armor.

15. The elastomeric component of an ESP of claim 13, further comprising a blocking agent to reduce a permeability of the barrier surface.

16. The elastomeric component of an ESP of claim 15, wherein the blocking agent is selected from the group consisting of a clay, a carbon black, a talc, a mica, a nanoclay, a silica, a graphene, graphite nanoplatelets, metal particles, and metal nanoparticles.

17. The elastomeric component of an ESP of claim 16, wherein the blocking agent comprises one of a nanofiber, a nanoparticle, or a nanoflake; and wherein the blocking agent has a high aspect ratio, wherein a length of each nanofiber or nanoparticle of the nanoscale component is greater than a diameter of the nanofiber or nanoparticle, or a diameter of each nanoflake of the nanoscale component is greater than a thickness of the nanoflake.

18. A seal for isolating a downhole equipment component from a well fluid, comprising:

an elastomer base of the seal; and

a barrier surface on the elastomer base comprising one of a fluoropolymer or a polyaryletherketone to isolate the elastomer base from high -temperature well fluids and from chemically aggressive well fluids.

19. The seal of claim 18, wherein the barrier surface is selected from the group consisting of a fluorinated ethylene propylene (FEP), a polytetrafluoroethylene (PTFE), an expanded polytetrafluoroethylene (ePTFE), a perfluoroalkoxy polymer (PFA), an epitaxial co-crystallized alloy (ECA), an ethylene tetrafluoroethylene (ETFE), a polyaryletherketone (PAEK), a poly ether ketone (PEK), a poly ether ether ketone (PEEK), a poly ether ketone ether ketone ketone (PEKEKK), a poly ether ketone ketone (PEKK), and a poly ether ether ketone ketone (PEEKK).

20. The seal of claim 19, further comprising a blocking agent to reduce a permeability of the barrier surface; and

wherein the blocking agent is selected from the group consisting of a clay, a carbon black, a talc, a mica, a nanoclay, a silica, a graphene, graphite nanoplatelets, metal particles, and metal nanoparticles.