Inflatable Carbon Sealing Element

Abstract

Methods for capturing carbon dioxide in a wellbore may include installing a sealing element in the wellbore. The sealing element swells in the presence of carbon dioxide and may be used to capture carbon. The sealing element may include a carbon-swellable material, such as a carbon-swellable polymer, metal-based materials, or combinations of elastomeric polymers and metal-based materials. The sealing element may also include combinations of different carbon-swellable materials, fillers, or other compounds, and materials that are not carbon-swellable. The sealing element may create a seal, form an anchor, or create a seal and form an anchor in the wellbore after swelling.

Description

Description Title of the invention: INFLATABLE SEAL ELEMENT CARBON technical field

[0001] = A wide variety of sealing elements can be used to limit the flow of fluid in a borehole. The sealing element can swell in presence of a liquid with a high carbon content. The sealing element may swell in presence of carbon dioxide. The sealing element can be used to capture and store carbon dioxide. Brief description of the drawings

[0002] — The characteristics and advantages of the various embodiments will be more fa- They are appreciated when considered in conjunction with the figures that... accompany. The figures should not be interpreted as limiting the modes of realization.

[0003] — Fig. 1 is a schematic illustration of a well system according to certain methods of implementation.

[0004] Figure 2 is an illustration of the well system showing a sealing element with a material that swells in the presence of carbon according to certain embodiments.

[0005] — Figure 3 is a graph showing the equilibrium mole fraction of the carbo- Mineral swimming with a metal-based material in relation to temperature. Detailed description

[0006] — Carbon dioxide sequestration can be carried out in certain formations underground, in the oil and gas industry, which is interested in sequestration underground carbon, an underground formation suitable for the injection of carbon dioxide A reservoir of carbon is called a reservoir. A reservoir can be located underground or at sea. reservoirs are generally located in a depth range from a few hundreds of feet (shallow reservoirs) to a few tens of thousands of feet (ultra-deep reservoirs). To allow the sequestration of dioxide below the surface For carbon extraction, a well is drilled into or adjacent to a reservoir. Fluid is then pumped into the wellbore. A liquid is pumped from the surface towards a reservoir is called injection fluid.

[0007] — As used here, a “fluid” is a substance having a continuous phase that can to flow and conform to the contours of its container when the substance is tested at a temperature of 71 °F (22 °C) and at a pressure of one atmosphere "atm" (0.1 megapascals (MPa). A fluid can be a liquid, a gas, or a super- Critical. A homogeneous fluid has only one phase, whereas a heterogeneous fluid has more than one distinct phase. A colloid is an example of a heterogeneous fluid. A heterogeneous fluid can be a liquid suspension, which comprises a continuous liquid phase and undissolved solid particles as a dispersed phase; an emulsion, which comprises a continuous liquid phase and at least one dispersed phase of immiscible liquid droplets; a foam, which comprises a continuous liquid phase and a gas as a dispersed phase; or a mist, which comprises a continuous gaseous phase and liquid droplets as a dispersed phase. As used here, the term "base fluid" refers to the solvent in a solution or the continuous phase of a heterogeneous fluid and is the liquid that constitutes the largest percentage by volume of a process fluid. In this document, the term "carrier fluid" refers to a liquid that can transport another fluid to the wellbore. A carrier fluid may be at a lower concentration than the other fluid.A well can include, but is not limited to, an oil, gas, or water production well, an injection well, or a geothermal well. As used here, a "well" includes at least one borehole. A borehole can include vertical, inclined, and horizontal portions, and it can be straight, curved, or branched. As used here, the term "borehole" includes any cased and uncased open-hole portion of the borehole. The near-borehole region is the subsurface material and rock of the subsurface formation surrounding the borehole. As used here, a "well" also includes the near-borehole region. The near-borehole region is generally considered to be the area approximately 100 feet radially from the borehole.As used here, "in a subsurface formation" means and includes any part of the well, including within the borehole, in the area near the borehole via the borehole, or within the subsurface formation via the borehole. A borehole section can be either an open hole or a cased hole. In an open-hole borehole section, a production stack may be placed within the borehole. The production stack allows fluids to be introduced into or removed from a distant portion of the borehole. In a cased borehole section, casing is placed within the borehole and may also contain a production stack. A borehole may contain annular space. Examples of annular space include, but are not limited to, the space between the borehole wall and the outside of a production stack in an open-hole borehole; the space between the borehole wall and the outside of a casing in a cased borehole; and the space between the inside of a casing and the outside of a production stack in a cased borehole. It is not uncommon for a borehole to extend several hundred or even several thousand feet into an underground formation. The underground formation A formation can have different zones. A zone is an interval of rock differentiated from the surrounding rocks based on its fossil content or other characteristics, such as faults or fractures. For example, one zone may have higher permeability compared to another zone. One or more zones of the formation can be isolated within the wellbore through the use of an isolation device. An isolation device can be used for zonal isolation and works to block fluid flow within a tubular element, such as casing, or within an annular space. Blocking fluid flow prevents the fluid from flowing through the isolation device in any direction (either downstream or upstream) and isolates the zone of interest. As used here, the relative term "downstream" means at a location farther from a wellhead.As used here, the relative term "upstream" means at a location closer to the wellhead. In this way, processing techniques can be carried out in the area of ​​interest. Common isolation devices include, but are not limited to, a bridge plug, a sealing gasket, a plug, and cement. Zonal isolation can be achieved by introducing the isolation device into the desired portion of the borehole. The isolation device may include a sealing element. For example, in one embodiment, a bridge plug consists primarily of grout, a plug mandrel, a setting device, and a sealing element, while in another embodiment, a sealing gasket typically consists of a sealing device, a holding or setting device, and an internal passage for fluids. The outside diameter (OD) of the sealing element may be made to expand, after which, upon expansion, the outer diameter of the sealing element engages with the inner wall of the tubular element or formation.By engaging with the inner wall, the isolation device works to block the flow of fluid through the expanding sealing element. Zonal isolation can also be achieved; for example, by inserting a plug into a production column or casing to restrict the flow of fluid through the inside of the production column or casing. Sealing elements can be mechanically hardened or can harden by swelling in the presence of a swelling fluid. For example, some sealing elements can swell in the presence of water and others can swell in the presence of a liquid hydrocarbon. Carbon dioxide is emitted into the atmosphere through various mechanisms. For example, in 2019, approximately 43 billion tons of carbon dioxide were emitted worldwide. The need to reduce global carbon emissions has only increased due to climate change. One technique of Reducing the amount of carbon emitted is called carbon capture. Carbon capture is the process of transporting and storing, or simply storing, carbon dioxide before it is emitted into the atmosphere. Carbon dioxide (CO₂) is often present in produced wellbore fluids. Typically, carbon dioxide is separated from desirable products, such as methane, in the produced fluids during processing. Current oil and gas operations actively avoid carbon-absorbing materials because they are susceptible to explosive gas decompression and the strong solvent properties of the liquid phase, and supercritical CO₂ (SCCO₂) can plasticize polymers and cause changes in the glass transition temperature (Tg). Furthermore, inflatable seals can be damaged by carbon dioxide in the produced fluids.For example, if carbon dioxide is trapped in the sealing element, changes in pressure or temperature can cause a rapid release of carbon dioxide from the sealing element, potentially leading to cracks in the element and even the release of parts of the element. This damage can result in a decrease in the integrity of the sealing element and its failure, so that the sealing element no longer functions as a seal and carbon dioxide can be released into the atmosphere. Thus, there has long been a recognized need to prevent the release of carbon dioxide during oil and gas operations. There has also long been a recognized need to capture and store carbon dioxide within a wellbore. It has been discovered that sealing elements that swell in the presence of carbon dioxide can be placed inside a wellbore. In some applications, the carbon dioxide can be captured by the sealing elements and prevented from being released into the atmosphere. In other applications, the carbon dioxide enhances the performance of the sealing elements and prevents the re-release of the sequestered carbon dioxide into the atmosphere. According to any one of the embodiments, a method for capturing carbon dioxide in an underground formation may include installing a sealing element in a borehole that penetrates the underground formation, in which the sealing element swells in the presence of carbon dioxide to create the seal; and bringing the sealing element into contact with carbon dioxide. According to any one of the embodiments, a well system may include a borehole that penetrates an underground formation; a production column located inside the borehole; and a sealing element located adjacent to the production column, in which the sealing element swells in the presence of carbon dioxide. The various embodiments described apply to the processes and systems without requiring repetition of the different embodiments throughout the procedure. As used herein, any reference to the unit "gallons" refers to US gallons. Referring to the figures, [Fig. 1] represents a well system 10. The well system 10 may include at least one borehole 11. The borehole 11 may penetrate a subsurface formation 12. The borehole 11 includes a well wall 13. The subsurface formation 12 may be part of a reservoir or adjacent to a reservoir. The borehole 11 may include casing 14. The borehole 11 may consist of only a generally vertical borehole section or only a generally horizontal borehole section. One or more production columns, for example, a production column 15, may be installed in the borehole 11. The production column 15 may provide a conduit for fluids to move from the formation to the surface of the borehole 11 or vice versa.A downhole tool, for example a 20-piece sealing gasket set, can be introduced into the borehole 11. The sealing assembly 20 can provide an annular seal between the exterior of the production column 15 and the interior of the casing 14 or the wellbore wall 13 to define a first zone 17 and a second zone 18 of the subsurface formation 12. The sealing assembly 20 can also be used between the exterior of a first production column and the interior of a second production column (not shown). The sealing assembly 20 can be used to seal or "compact" the wellbore 11 so that the flow path of fluids in the wellbore 11 can be redirected. It should be noted that the well system 10 illustrated in the drawings and described herein is only one example of a wide variety of well systems in which the various embodiments can be used. For example, the borehole 11 may have a horizontal and a vertical section. It should be clearly understood that the various embodiments are not limited to any of the details of the well system 10, or its components, shown in the drawings or described herein. In addition, the well system 10 may include other components, such as production tubing, screens, and other insulation devices not shown in the drawings. According to any of the embodiments, one or more sealing packs may be introduced into multi-zone completions, between an inner and outer core, and in a vertical and / or horizontal section of the borehole 11.The sealing assembly 20 can be installed in the borehole 11 during oil or gas operations, such as well completion or . well testing operations. The 20 seal assembly may be located in a cased borehole section or an open-hole borehole section. There may also be more than one 20 seal assembly located inside the borehole in a variety of locations; for example, in cased sections, open-hole sections, or combinations thereof. Figure 2 illustrates a sealing assembly 20 when installed at a desired depth in the subsurface formation 12. The sealing assembly 20 may include a sealing element 21. The sealing element 21 may be positioned circumferentially around the outside of the sealing assembly 20. The sealing element 21 may be subjected to axial stresses on its top and / or bottom; for example, via two end rings 23, so that the sealing element 21 expands in a radial direction only. The sealing element 21 swells in the presence of carbon dioxide. As the inflatable material inflates, it can expand radially and seal the annular space, for example in the form of a sealing gasket assembly, or inside the production column, for example in the form of a plug 30 of [Fig. 1]. As shown in [Fig.[2] At the desired installation depth, the sealing element 21 was brought into contact with carbon dioxide and expanded to contact the wellbore wall 13, forming an annular seal. When used in an annular space between the outside of the production column 15 and the inside of a casing 14, after expansion, the sealing element 21 can come into contact with the inside of the casing 14 to form an annular seal. Multiple sealing gasket assemblies 20 can be used in a variety of locations within the wellbore 11. The sealing gasket assembly 20 can also be used to form an annular seal between two separate conduits 22. It should be understood that, although the various embodiments may refer to a "sealing assembly," other downhole tools, such as sleeves and sliding plugs (e.g., bridge plugs, cementing plugs, and fracturing backfill plugs), should not be excluded. For example, as shown in [Fig. 1], a plug 30 can be installed inside the production column 15 or casing 14. The plug 30 may include one or more sealing elements 21 which, after expansion in the presence of carbon dioxide, come into contact with the interior of the production column 15 as illustrated and prevent fluid flow beyond the plug 30. The sealing element 21 may also be located on other downhole tools, such as sliding sleeves, in the form of O-rings, packings, or gland seals. The process includes installing the sealing element in a borehole. The sealing element expands in the presence of carbon dioxide. As used here, the term "inflate" and all its grammatical variants refer to an expansion in volume from a pre-inflated volume. As used here, the sealing element can "inflate" through a variety of mechanisms and does not mean an expansion in volume due solely to carbon dioxide imbibition.The mechanism by which the sealant "swells" can be due to one of the following: adsorption of carbon dioxide where carbon-based atoms / molecules permeate the sealant or adhere to its surface; a chemical reaction; grafting; impregnation; complexation; or incorporation. For example, carbon dioxide may be adsorbed into the pores of the sealant material and cause it to swell without altering its chemistry. Alternatively, carbon dioxide may react chemically with the sealant, and the resulting product has a larger volume than the original volume of the sealant. Volume expansion can occur in one or more dimensions. For example, if the sealing element is located around a gasket mandrel, the outside diameter (OD) of the sealing element may expand, or both the outside diameter and the height may expand. This can be because the inside diameter (ID) of the sealing element is constrained to expand by the gasket mandrel; thus, only the outside diameter, or both the outside diameter and the height, can expand. In any embodiment, the sealing element expands by at least 20%, 120%, or 300% in volume. The sealing element may expand to a sufficient volume to create a seal at its location in the wellbore. In any embodiment, the sealing element does not create a seal until it has expanded in the presence of carbon dioxide. For example, the sealing element may expand to a sufficient volume to create a seal; for example, the outer diameter of the sealing element engages with the inner diameter of a production string, casing, or wellbore wall to create the seal after exposure to carbon dioxide, such that fluid is prevented or substantially restricted from flowing beyond the sealing element.According to any one embodiment, the sealing element substantially prevents any fluid from flowing beyond the sealing element after the sealing element has swollen. The sealing element can swell to at least a sufficient volume so that the sealing element creates a seal in the well. Drilling. While the sealing element can substantially prevent all fluid from flowing beyond it, it is important to understand that some minute and unintentional amounts of fluid may still escape. Such traces of fluid can unintentionally flow beyond the sealing element. However, these traces must not be significant enough to render the swollen sealing element ineffective as a seal. The sealing element may also swell to form an anchor in the wellbore without creating a seal, or it may form an anchor and create a seal. The sealing element can be made of a carbon-inflatable polymer. The polymer can be a solid material or can be formed as a gel, including a hydrogel. A polymer is a molecule composed of repeating units, generally linked by covalent chemical bonds. A polymer is formed from monomers. During polymer formation, chemical groups and / or protons can be cleaved from the monomers using initiators and / or catalysts to create a reactive monomer site known as a monomer residue. The monomer residue initiates a series of cascading reactions between reactive monomer sites and other monomers, leading first to macromolecules and ultimately forming the polymer through polymerization mechanisms such as addition or condensation reactions. The polymer may also contain pendant functional groups attached to the backbone at various locations along its length.Polymer nomenclature is generally based on the type of monomer residues that make up the polymer. A polymer formed from one type of monomer residue is called a homopolymer. A polymer formed from two or more different types of monomer residues is called a copolymer. The number of repeating units in a polymer is called the polymer chain length. The number of repeating units in a polymer can range from about 11 to over 10,000. In a copolymer, the repeating units of each of the monomer residues can be arranged in various ways along the polymer chain. For example, the repeating units can be random, alternating, periodic, or blocky. The conditions of the polymerization reaction can be adjusted to help control the average number of repeating units (the average chain length) of the polymer. Polymer molecules can be cross-linked.As used here, a "crosslink" and all its grammatical variants is a bond between two or more polymer molecules. Crosslinked polymer molecules can form a polymer network. A polymer has an average molecular weight, which is directly related to the average length of the polymer chain. The average molecular weight of a polymer impacts some of its physical characteristics; for example, its solubility, strength, and dispersibility. For a copolymer, each of the monomers will be repeated a certain number of times (number of repeated units). The average molecular weight (My) of a copolymer can be expressed as follows: M,= = wM, Where w, is the fraction of weight of the molecules whose weight is M. The polymer can be any polymer that swells in the presence of carbon dioxide. Carbon-swelling polymers may have a low glass transition temperature (e.g., less than -55 °C (-67 °F)), moderate polarity, and a low molecular weight (e.g., less than 300,000). The polymer may be an elastomer. An elastomer is a natural or synthetic polymer that possesses elastic properties. Rubber is a common example of an elastomer. The polymer may be polychloroprene or acrylonitrile butadiene rubber. The polymer may also be an amine-based polymer. The amine may be an organic or inorganic polyamine or an amine oligomer. The polymer may also be an aliphatic-based polymer. An example of a chemical reaction for the absorption of carbon dioxide by monoethanolamine is shown below in Equation 1. CO, + 2 HOCH,CH,NH; + HOCH,CH,NH;+ + HOCH.CH,NHCO>Ég,. (1) The polymer can be polyethyleneimine (PEI), which is a combination of an amine-based polymer and an aliphatic-based polymer and uses a reaction mechanism. The nitrogen in PEI can bind to carbon dioxide. Thus, carbon can be bound to various reaction sites of polyamines. Other carbon-swelling polymers include, but are not limited to, monoethanolamine (MEA), dieethanolamine (DEA), diisopropylamine, tetraethylenepentamine (TEPA), dodecylamine, 3-aminopropyltriethoxysilane, tris(2-aminoethyl)amine, aziridine, and poly(l-lysine). These amines can react with carbon dioxide through the presence of primary, secondary, and / or tertiary amine groups. The water content of the borehole can influence the reaction site. For example, reactions to tertiary amines are more likely to occur with a higher water content.Some polymers may not be able to swell in the presence of carbon dioxide. Therefore, the processes may also involve combining water with carbon dioxide above ground or inside the wellbore. Water is polar and can dissociate carbon dioxide, which is nonpolar, into carbonic acid. The polymer can also swell in the presence of carbonic acid, which is considered a mixture of carbon dioxide and a water-based fluid. In addition to swelling, the sealing element can also withstand wellbore pressures and maintain structural integrity within the wellbore. The sealing element may be capable of withstanding a specified pressure. As used here, the term "resist" and all its grammatical variants means without losing structural integrity; for example, without losing the sealing capacity of the component. The sealing element may be capable of withstanding pressures in the range of approximately 100 to approximately 15,000 pounds-force per square inch (psi). According to any embodiment, the carbon-swellable polymer may be selected so that the sealing element is capable of withstanding a specified pressure and that structural integrity is maintained in an acidic environment. Polar polymers, such as polychloroprene, are considered compatible in aqueous and acidic environments. The degree of polymer crosslinking can affect its characteristics. For example, a lower degree of crosslinking results in a greater expansion volume. Conversely, a lower degree of crosslinking can decrease the overall strength and structural integrity of the sealing element. In any one embodiment, the degree of polymer crosslinking is selected so that the sealing element expands to a desired volume in carbon dioxide. The polymer may have a high degree of crosslinking. In some embodiments, the polymer does not form a large crosslinked polymer network. Large polymer networks can prevent the polymer from expanding to the desired volume. The polymer may also be uncrosslinked or have a low degree of crosslinking. Low molecular weight liquid polymers can be crosslinked to form a solid. In these embodiments, the sealing element may further include a filler or other compound that provides increased strength or modifies the properties of the sealing element. For example, an uncrosslinked polymer may be included in the sealing element (which can provide the desired expansion volume), and a highly crosslinked polymer may be included in the sealing element (which can provide the desired strength and structural integrity).The continuous phase of the sealing element can be made of a stronger polymer, and the discontinuous phase can be made of a carbon-inflatable polymer. Combinations of fillers and different polymers with varying degrees of crosslinking can be included in the sealing element to provide the desired expansion and resistance. Combinations of materials can also be used depending on the presence of water in the borehole, the borehole temperature, and the borehole pressures. For example, a filler can be incorporated into the sealing element via a mixture or as a surface coating, for example, to promote water absorption within the sealing element. The filler can be hygroscopic and may include, but is not limited to, silica (including methicillin-resistant silica). soporous, amorphous silica, silica sheets and granules), nanotubes, alumina, zeolite, carbon (including nanotubes, graphene and activated carbon), silicates (including aluminosilicate, clay, halloysite nanotubes and bentonite), cellulose, metal (including titinate nanotubes), microporous resin, glycol (including polyethylene glycol) and metal-based materials or organometallic frame materials, which are discussed in more detail below. The amount of carbon captured by the polymeric sealing element can vary, in part, depending on the materials used to manufacture the sealing element, the wellbore temperature, and the wellbore hydrostatic pressure. For example, depending on drilling conditions, PEI can capture between 5% and 30% by weight of carbon dioxide. The selection of materials (e.g., the exact polymers used and fillers or other compounds), the degree of crosslinking, and the material concentrations can be selected to provide the desired wt% of carbon dioxide captured, including carbon dioxide in water, the desired swelling volume, and the desired strength of the sealing element. Another example of a carbon-inflatable material that can be included in the sealing element is a metal-based material. This metal-based material can include a compound with a framework comprising metallic nodes linked by organic ligand bridges. Examples of metals suitable for metal-based materials include, but are not limited to, magnesium, iron, calcium, aluminum, tin, zinc, beryllium, barium, manganese, or any combination thereof. Preferred metals include magnesium, calcium, and aluminum. The metal-based material may include a metal alloy. As used here, the term "metal alloy" means a mixture of two or more elements, in which at least one of the elements is a metal. The other element(s) may be a nonmetal or a different metal. An example of a metal-nonmetal alloy is steel, which includes the metallic element iron and the nonmetallic element carbon. An example of a metal-metal alloy is bronze, which includes the metallic elements copper and tin. It should be understood that the use of the term "metal" is intended to include both pure metals and metal alloys. Examples of metal alloys suitable for the metal-based material include, but are not limited to, any alloy of magnesium, calcium, aluminum, tin, zinc, beryllium, barium, manganese, or any combination thereof.Preferred metal alloys include magnesium-zinc, magnesium-aluminum, calcium-magnesium, or aluminum-copper alloys. The non-metallic elements of the metal alloy... Metabolic materials may include, but are not limited to, graphite, carbon, silicon, and boron nitride. Metal-based materials can absorb carbon dioxide through a chemical reaction in which the carbon dioxide is captured within the sealing element, causing it to swell. Alternatively, metal-based materials can absorb carbon dioxide through a mineral carbonation process. Metallic silicates are an example of a material that can be used to absorb carbon dioxide via mineral carbonation. Examples of metallic silicates include magnesium silicate (MgSiO₂), iron silicate (FeSiO₄), and carbon silicate (CaSiO₂). Silicates may include olivine (a magnesium and iron silicate) or serpentine. Silicates can also be mafic or ultramafic. Ultramafic minerals typically have a lower silica content and a higher mineral content than mafic minerals.Equations 2 to 4 below show the mineral carbonation reactions of a representative metallic silicate with carbon dioxide and possibly water. (Mg,Fe)25i0,+2CO, — 2(Mg,Fe)CO,+SiO0zÉgq, (2) 6(Mg,Fe)2Si04 + 12h,0 + 6CO,>2(Mg,Fe):Si2Os(OH). + 2Fe:04 + 8H; + 6MgCO; + 2Si0, Eq. (3) (Mg,Fe)-Si,O-(OH),+3CO,— 3(Mg,Fe)CO,+2Si0,+2H;0 Eq,. (4) Metallic silicates can absorb more carbon dioxide than some carbon-swelling polymeric materials. For example, metallic silicates can absorb 100% by weight of carbon dioxide. With high CO activity, equation 2 is the most likely reaction to occur and will form serpentine-free magnesite. Examining equation 2 for magnesium silicate, we can see that the reaction of one mole of magnesium silicate with carbon dioxide requires 37 cc of carbon-swelling metallic silicate and yields 56 cc of magnesium carbonate and 45 cc of silicon dioxide. Therefore, there is a 270% volumetric expansion of the carbon-swelling material. Other metal-based materials that swell with carbon include not only silicates but also zirconates (e.g., lithium zirconate with an absorption of 13% by weight), aluminates (e.g., lithium aluminate), oxides (e.g., lithium oxide with an absorption of 140% by weight and calcium oxides with an absorption of 19% by weight), and hydroxides (e.g., calcium hydroxide with an absorption of 33%, magnesium silicate hydroxide, and sodium hydroxide). The metal-based material can be selected to provide the desired carbon absorption and swelling. Figure 3 is a graph showing the equilibrium shape of a material based on Metal can change into other forms with a change in temperature. As can be seen in [Fig. 3], the metal-based material can absorb carbon over a wide range of temperatures and hydrostatic pressures, and the equilibrium shape can change to compensate for temperature and pressure changes in the borehole. Another example of a metal-based material that can be included in the seal element is an organometallic framework material. An organometallic framework material is an inorganic-organic hybrid material composed of aggregates of metal ions or metal ions and organic bridging ligands. The carbon dioxide absorption of metal-based materials can depend on wellbore temperatures. Compared to carbon-swelling polymers, an organometallic framework material can absorb more CO₂ at lower temperatures. Therefore, the expansion volume of the seal element at lower temperatures can be much greater with organometallic framework materials than with polymeric materials.As an example, a metal-organic framework material known as UMCM-1-NH2-MA is a crystalline material from the University of Michigan in which several organic ligands are synthesized under solvothermal conditions with two different pore channels. The free -NH₂ functionality of the organic component is available to react with the alkyl anhydride to form the corresponding amide functionality, thereby increasing moisture stability and CO₂ adsorption. UMCM-1-NH2-MA absorbs 2 wt% of carbon dioxide at 18 bar at 25 °C. Another organometallic framework material based on a porous coordination network and known as PCN-5 absorbs 21 wt% of CO₂ at 1 bar at -78 °C. In any embodiment, the organometallic framework material has a high surface area to mass ratio.For example, the material may have a surface determination by the Brunauer-Emmet-Teller (BET) process greater than 1 m² per gram or preferably greater than 100 m² per gram. As mentioned earlier regarding the discussion of carbon-swelling polymer materials, the sealing element can comprise more than one type of carbon-swelling material, along with binders, fillers, or other compounds. For example, the continuous phase of the sealing element can be made from a carbon-swelling polymer, a polymer that does not swell in the presence of carbon dioxide, combinations of inflatable and non-swelling polymers, and a discrete phase of the metal-based material. In this way, the sealing element can be designed to absorb and capture a desired amount of carbon at various temperatures and pressures, inflate to the desired volume, and maintain the required strength and structural integrity. A non-limiting example includes a combination of a metal-based material and polymers so that there is constant volumetric expansion over a wide temperature range using the negative temperature coefficient of the organometallic framework material and the positive temperature coefficient of the polymers. The processes involve bringing the sealing element into contact with carbon dioxide. The carbon dioxide may be located in a subsurface formation or in the wellbore. Carbon dioxide may be part of a formation fluid. Carbon dioxide may come into contact with the sealing element during the production of the formation fluid, for example. The formation fluid may also contain water. Carbon dioxide can react with water to form carbonic acid. Depending on the carbon-swellable material included in the sealing element, the sealing element may swell in the presence of carbonic acid. Carbon dioxide can also be injected into the wellbore. The carbon dioxide for injection can be in gaseous, liquid, or supercritical liquid form. Carbon dioxide can also be injected into the wellbore in a carrier fluid. The carrier fluid may include water and other components. The injection fluid, which contains carbon dioxide and possibly carbonic acid if water is present, can come into contact with the sealing element. In this way, the carbon dioxide can be captured by the sealing element and prevented from being released into the atmosphere. The processes may also include the recovery of the downhole tool; for example, the assembly of the sealing pack. The downhole tool or certain components of the downhole tool may be milled. As another example, the sealing element may be brought or allowed to transform at least partially into a pre-swollen state. The downhole tool may then be recovered from the borehole with a recovery tool, such as a fishing tool. An example of at least partially transforming the sealing element into a pre-swollen state may include increasing the temperature in the area adjacent to the sealing element. For example, heating PEI above a threshold temperature results in the release of at least some of the captured carbon, leading to a decrease in the volume of the sealing element and allowing the downhole tool to be recovered.The threshold temperature varies depending on the shape of the PEI, the water content of the environment and the hydrostatic pressure, and can range from 45 °C to 200 °C (113 °F to 392 °F). One embodiment of this disclosure is a process for capturing carbon in a subsurface formation comprising: the installation of a sealing element in a borehole that penetrates the subsurface formation, in in which the sealing element swells in the presence of carbon dioxide; and the contacting of the sealing element with carbon dioxide. Optionally, the method further includes the sealing element being part of a packing assembly, downhole tool, or plug, and the sealing element creating a seal, forming an anchor, or creating a seal and forming an anchor in the wellbore after the sealing element is brought into contact with carbon dioxide. Optionally, the method further includes the sealing element swelling in a range of 20% to 300% by volume.Optionally, the method further includes the sealing element inflating to a sufficient volume so that it creates the seal by engaging within an inside diameter of a production column, casing, or wellbore wall after the sealing element has been brought into contact with carbon dioxide, thereby preventing or substantially restricting fluid flow beyond the sealing element. Optionally, the method further includes the sealing element comprising a carbon-inflatable polymer.Optionally, the process further comprises the fact that the carbon-inflatable polymer is an elastomer, Optionally, the process further comprises the fact that the carbon-inflatable polymer is selected from rubber, an amine-based polymer or an aliphatic-based polymer, Optionally, the process further comprises the fact that the carbon-inflatable polymer is selected from the group consisting of polychloroprene rubber, acrylonitrile butadiene rubber, polyethyleneimine, monoethanolamine, diethanolamine, diisopropylamine, tetraethylenepentamine, dodecylamine, 3-aminopropyltriethoxysilane, the . tris(2-aminoethyl)amine, aziridine, poly(l-lysine), and combinations thereof. Optionally, the process further comprises the carbon-inflatable polymer being a non-crosslinked polymer or having a low degree of crosslinking. Optionally, the process further comprises the sealing element further comprising a non-carbon-inflatable polymer, a filler, or combinations thereof. Optionally, the process further comprises the sealing element comprising a metal-based material, wherein the metal-based material is a compound comprising a metal framework and metal nodes linked together by organic ligand bridges. Optionally, the process further includes selecting a metal from the metal-based material from the group consisting of magnesium, iron, calcium, aluminum, tin, zinc, beryllium, barium, manganese, alloys of any of the preceding elements, and combinations thereof.Optionally, the process further includes selecting the metal-based material from among metal silicates, metal zirconates, metal aluminates, metal oxides, or metal hydroxides. Optionally, the... The process further includes the fact that the metal-based material is an organometallic backbone material. Optionally, the process further includes the fact that the sealing element further comprises a continuous phase of an elastomeric material and a discrete phase of the metal-based material in particulate form. Optionally, the process further includes the fact that the elastomeric material is a carbon-inflatable polymer, a non-carbon-inflatable polymer, or combinations thereof. Optionally, the process further includes the fact that the sealing element withstands pressures between 100 and 15,000 pounds per square inch. Optionally, the process further includes the fact that a subsurface formation fluid comprises carbon dioxide or an injection fluid comprises carbon dioxide. Another embodiment of this disclosure is a well system comprising: a drill well that penetrates a subsurface formation; a production column located within the drill well; and a sealing element located adjacent to the production column, the sealing element expanding in the presence of carbon dioxide. Optionally, the well system also includes the sealing element being part of a packing assembly, downhole tool, or plug, and the sealing element creating a seal, forming an anchor, or creating a seal and forming an anchor in the drill well after the sealing element has come into contact with carbon dioxide. Optionally, the well system further includes the sealing element expanding in a range of 20% to 300% by volume.Optionally, the well system further includes the fact that the sealing element inflates to a sufficient volume so that it creates a seal by engaging with the inside diameter of a production column, casing, or wellbore wall after the sealing element has been brought into contact with carbon dioxide, thereby preventing or substantially restricting fluid flow beyond the sealing element. Optionally, the well system further includes the fact that the sealing element comprises a carbon-inflatable polymer. Optionally, the well system further includes the fact that the carbon-inflatable polymer is an elastomer. Optionally, the well system further includes the fact that the carbon-inflatable polymer is selected from rubber, an amine-based polymer, or an aliphatic-based polymer.Optionally, the well system further includes the fact that the carbon inflatable polymer is chosen from the group consisting of polychloroprene rubber, acrylonitrile butadiene rubber, polyethyleneimine, monoethanolamine, diethanolamine, diisopropylamine, tetraethylenepentamine, dodecylamine, 3-aminopropyltriethoxysilane, tris(2-aminoethyl)amine, aziridine, and . poly(l-lysine) and combinations thereof. Optionally, the well system further includes the carbon-inflatable polymer being a non-crosslinked polymer or having a low degree of crosslinking. Optionally, the well system further includes the sealing element further comprising a non-carbon-inflatable polymer, a filler, or combinations thereof. Optionally, the well system further includes the sealing element comprising a metal-based material, wherein the metal-based material is a compound comprising a metallic framework and metal nodes linked together by organic ligand bridges. Optionally, the well system further includes a metal of the metal-based material being selected from the group consisting of magnesium, iron, calcium, aluminum, tin, zinc, beryllium, barium, manganese, alloys of any of the preceding elements, and combinations thereof.Optionally, the well system further includes the fact that the metal-based material is selected from among metal silicates, metal zirconates, metal aluminates, metal oxides, or metal hydroxides. Optionally, the well system further includes the fact that the metal-based material is an organometallic framework material. Optionally, the well system further includes the fact that the sealing element further comprises a continuous phase of an elastomeric material and a discrete phase of the metal-based material in particulate form. Optionally, the well system further includes the fact that the elastomeric material is a carbon-inflatable polymer, a non-carbon-inflatable polymer, or combinations thereof. Optionally, the well system further includes the fact that the sealing element withstands pressures between 100 and 15,000 pounds per square inch.Optionally, the well system further includes the fact that an underground formation fluid contains carbon dioxide or that an injection fluid contains carbon dioxide. Another embodiment of this disclosure is a downhole tool comprising: a mandrel; and a sealing element located adjacent to the mandrel, the sealing element expanding in the presence of carbon dioxide. Optionally, the downhole tool further comprises the fact that the sealing element is part of a packing assembly, downhole tool, or plug, and that the sealing element creates a seal, forms an anchor, or creates a seal and forms an anchor in the wellbore after the sealing element has been brought into contact with carbon dioxide. Optionally, the downhole tool further comprises the fact that the sealing element expands in a range of 20% to 300% by volume.Optionally, the downhole tool further includes the fact that the sealing element swells to a sufficient volume so that the sealing element creates the seal by engaging in an inner diameter of a column of . production of a casing or wellbore wall after the sealing element has been brought into contact with carbon dioxide, thereby preventing or substantially restricting fluid flow beyond the sealing element. Optionally, the downhole tool further includes the fact that the sealing element comprises a carbon-inflatable polymer. Optionally, the downhole tool further includes the fact that the carbon-inflatable polymer is an elastomer. Optionally, the downhole tool further includes the fact that the carbon-inflatable polymer is selected from rubber, an amine-based polymer, or an aliphatic-based polymer.Optionally, the downhole tool further includes the fact that the carbon inflatable polymer is chosen from the group consisting of polychloroprene rubber, acrylonitrile butadiene rubber, polyethyleneimine, monoethanolamine, diethanolamine, diisopropylamine, tetraethylenepentamine, dodecylamine, . 3-Aminopropyltriethoxysilane, tris(2-aminoethyl)amine, aziridine, poly(l-lysine), and combinations thereof. Optionally, the downhole tool further includes the fact that the carbon-inflatable polymer is a non-crosslinked polymer or has a low degree of crosslinking. Optionally, the downhole tool further includes the fact that the sealing element comprises a non-carbon-inflatable polymer, a filler, or combinations thereof. Optionally, the downhole tool further includes the fact that the sealing element comprises a metal-based material, the metal-based material being a compound comprising a metal framework and metal nodes that are linked together by organic ligand bridges.Optionally, the downhole tool further includes the fact that a metal of the metal-based material is selected from the group consisting of magnesium, iron, calcium, aluminum, tin, zinc, beryllium, barium, manganese, alloys of any of the preceding elements, and combinations thereof. Optionally, the downhole tool further includes the fact that the metal-based material is selected from among metal silicates, metal zirconates, metal aluminates, metal oxides, or metal hydroxides. Optionally, the downhole tool further includes the fact that the metal-based material is an organometallic framework material. Optionally, the downhole tool further includes the fact that the sealing element comprises a continuous phase of an elastomeric material and a discrete phase of the metal-based material in particulate form.Optionally, the downhole tool further includes the fact that the elastomeric material is a carbon inflatable polymer, a non-carbon inflatable polymer, or combinations thereof. Optionally, the downhole tool further includes the sealing element that withstands pressures between 100 and 15,000 pounds per square inch. Optionally, the downhole tool. further includes the fact that an underground formation fluid includes carbon dioxide or that an injection fluid includes carbon dioxide. Therefore, the various embodiments are well suited to achieving the aforementioned objectives and advantages, as well as those inherent therein. The particular embodiments described above are merely illustrative, as the various embodiments can be modified and implemented in different but equivalent ways, which will be evident to a person skilled in the art who benefits from the teachings contained herein. Furthermore, no limitations are foreseen for the construction or design details presented in the present invention, other than those described in the claims below. It is therefore evident that the particular illustrative embodiments described above can be changed or modified, and that all such variations are considered within the scope and spirit of the present invention. As used here, the words "include," "have," "include," and all their grammatical variants are each intended to have an open, non-limiting meaning that does not exclude additional elements or steps. Although compositions, systems, and processes are described here as "comprising," "containing," or "including" various components or steps, compositions, systems, and processes can also be "essentially composed of" or "composed of" the various components and steps. It should also be understood that, as used here, "first," "second," and "third" are assigned arbitrarily and are simply intended to differentiate between two or more zones, sealing elements, etc., as appropriate, and do not indicate any sequence.Furthermore, it must be understood that the mere use of the word "first" does not require that there be a "second", and the mere use of the word "second" does not require that there be a "third", etc. Whenever a numeric range with a lower and upper limit is described, every number and every range included within that range are specifically described. In particular, every range of values ​​(of the form, "from about a to about b" or, equivalently, "from about a to b" or, equivalently, "from about ab") described herein is to be understood as describing every number and every range encompassed within the broadest range of values. Furthermore, the terms in the claims have their ordinary and usual meanings unless otherwise explicitly and clearly defined by the patent holder. In the event of a conflict between the uses of a word or term in this description and one or more patents or other documents that may be incorporated herein for reference, the definitions consistent with this description shall prevail.

Claims

Claims

1. A method of capturing carbon in a subterranean formation (12) comprising: installing a sealing element (21) in a wellbore (11) that penetrates the subterranean formation (12), the sealing element swelling in the presence of carbon dioxide; wherein the sealing element (21) comprises a metal-based material, wherein the metal-based material is a compound comprising a framework and metal nodes that are connected together by organic ligand bridges; and contacting the sealing element (21) with the carbon dioxide.

2. The method of claim 1, wherein the sealing element (21) is part of a packer assembly (20), a downhole tool, or a plug (30), and wherein the sealing element (21) creates a seal, forms an anchor, or creates a seal and forms an anchor in the wellbore (11) after contacting the sealing element (21) with carbon dioxide.

3. A method according to claim 1 or 2, wherein the sealing member (21) swells in a range of 20% to 300% by volume.

4. A method according to any preceding claim, wherein the sealing member (21) comprises a carbon-swellable polymer, the carbon-swellable polymer being an elastomer or selected from rubber, an amine-based polymer or an aliphatic-based polymer.

5. The method of claim 4, wherein the carbon swellable polymer is selected from the group consisting of polychloroprene rubber, acrylonitrile butadiene rubber, polyethyleneimine, monoethanolamine, diethanolamine, diisopropylamine, tetraethylenepentamine, dodecylamine, 3-aminopropyltriethoxysilane, tris(2-aminoethyl)amine, aziridine, poly(l-lysine) and combinations thereof.

6. A method according to any preceding claim, wherein a metal of the metal-based material is selected from the group consisting of magnesium, iron, calcium, aluminum, tin, zinc, beryllium, barium, manganese, alloys of any of the foregoing, and combinations thereof, and wherein the metal-based material is selected from metal silicates, metal zirconates, metal aluminates, metal oxides or metal hydroxides.

7. A method according to one of claims 1 to 5, wherein the metal-based material is an organometallic framework material.

8. The method of one of claims 1 to 5, wherein the sealing member (21) further comprises a continuous phase of an elastomeric material and a discrete phase of the particulate metal-based material, and wherein the elastomeric material is a carbon-swellable polymer, a non-carbon-swellable polymer, or combinations thereof.

9. A well system (10), comprising: a wellbore (11) that penetrates a subterranean formation (12); a production string (15) located within the wellbore (11); and a sealing member (21) located adjacent the production string (15), the sealing member (21) swelling in the presence of carbon dioxide, wherein the sealing member (21) comprises a metal-based material, wherein the metal-based material is a compound comprising a framework and metal nodes that are connected together by organic ligand bridges.

10. The well system (10) of claim 9, wherein the sealing member (21) comprises a carbon-swellable polymer, the carbon-swellable polymer being an elastomer or selected from rubber, an amine-based polymer, or an aliphatic-based polymer.

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