CN118679303A - Thermal expansion sealing element - Google Patents
Thermal expansion sealing element Download PDFInfo
- Publication number
- CN118679303A CN118679303A CN202280091499.4A CN202280091499A CN118679303A CN 118679303 A CN118679303 A CN 118679303A CN 202280091499 A CN202280091499 A CN 202280091499A CN 118679303 A CN118679303 A CN 118679303A
- Authority
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- China
- Prior art keywords
- substance
- sealing element
- well system
- wellbore
- phase transition
- Prior art date
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Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/1208—Packers; Plugs characterised by the construction of the sealing or packing means
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Sealing Material Composition (AREA)
- Gasket Seals (AREA)
Abstract
The present disclosure provides a sealing element that may be used to form a seal in a component of a wellbore or downhole tool. The sealing element may include an elastomeric matrix and a substance embedded in the elastomer that expands at a phase transition temperature. The substance may be an organic based substance such as a polymeric plastic, thermoplastic or wax. The organic-based material is expandable at a temperature greater than or equal to the phase transition temperature. The substance may also be a metal-based substance. The metal-based material is expandable at a temperature less than or equal to the phase transition temperature. After expansion, the substance may fill small gaps or cracks in the elastomeric matrix due to temperature fluctuations. The sealing element may be included on a downhole tool. The sealing element may be an O-ring or gasket, or may be included on a packer assembly, plug, or liner hanger.
Description
Technical Field
A variety of sealing elements may be used to form a seal within a wellbore or within a wellbore tool or apparatus. A thermally expansive material may be included in the sealing element. The thermally expansive material may expand as the temperature increases or decreases. After expansion, the thermally expandable material may form a better seal than a sealing element without the thermally expandable material.
Brief description of the drawings
The features and advantages of the various embodiments will be more readily understood when considered in connection with the accompanying drawings. The drawings should not be construed as limiting any of the embodiments.
FIG. 1 is a schematic illustration of a downhole tool including a sealing element, according to certain embodiments.
Fig. 2 is a schematic illustration of a liner hanger including a sealing element according to some embodiments.
FIG. 3 is a schematic illustration of a packer assembly including a sealing element, in accordance with certain embodiments.
FIG. 4 is a schematic illustration of expansion of two different thermally expansive materials according to some embodiments.
Detailed Description
Oil and gas hydrocarbons naturally occur in some subterranean formations. In the oil and gas industry, subterranean formations containing oil and/or gas are known as reservoirs. The reservoir may be located underground or offshore. Reservoirs are typically located in the range of hundreds of feet (shallow reservoirs) to tens of thousands of feet (ultra-deep reservoirs). To produce oil or gas, a wellbore is drilled into or adjacent to a reservoir. The oil, gas or water produced from a reservoir is referred to as reservoir fluid.
The well may include, but is not limited to, an oil, gas, or water producing well, an injection well, or a geothermal well. As used herein, a "well" includes at least one wellbore. The wellbore may include vertical, inclined, and horizontal sections, and it may be straight, curved, or branched. As used herein, the term "wellbore (wellbore)" includes any cased and any uncased open hole portion of a wellbore. As used herein, "into the wellbore (into a wellbore)" means and is included into any portion of the well.
A portion of the wellbore may be open hole or cased hole. In an open hole wellbore section, a string of tubing may be placed into the wellbore. The tubing string allows fluid to be introduced into or flowed from the distal portion of the wellbore. In a cased hole wellbore section, casing is placed into the wellbore, which may also contain a tubular string. The wellbore may contain an annulus. Examples of annular volumes include, but are not limited to: a space between the wellbore and an exterior of the tubing string in the open hole wellbore; a space between the wellbore and an exterior of the casing in the cased wellbore; and a space between an interior of the casing and an exterior of the tubular string in the cased wellbore. It should be understood that reference to "tubing string" includes casing strings.
A variety of wellbore tools are used for oil and gas operations. Wellbore tools may be run on a string to perform various functions. The wellbore tool may include one or more sealing elements. By way of a first example, a sealing element may be used to seal one or more components of a downhole tool. Non-limiting examples of downhole tools that utilize sealing elements include sleeves, valves (e.g., flapper valves, safety valves, and barrier valves), and seals for tools that include an interior space that needs to be isolated from wellbore fluids, such as sensors, actuators, telemetry tools, and pressure balance seals. The sealing element may seal one or more components of the downhole tool against fluid flow or pressure. Examples of such sealing elements include, but are not limited to, O-rings, gland seals, stack seals, and gaskets.
During completion and production, it is often desirable to seal a portion of the annulus so that fluid will not flow through the annulus but through the tubing string. By sealing off portions of the annulus, oil, gas, water, or a combination thereof can be produced in a controlled manner through the wellhead via the tubing string.
By way of a second example, a sealing element may be used to seal a portion of the annulus. Accordingly, the sealing element may be used in a tool for controlling the flow of fluid in an annulus, the tool comprising a compression set packer, an expansion packer and a liner hanger. Typically, packers are used to anchor and seal a pipe to a wellbore. The packer may be used in a cased hole wellbore section or an open hole wellbore section. The packer may include a sealing element that seals to the wellbore to isolate a portion of the wellbore, and may further include slips that grip the interior of the string or wall of the wellbore to anchor the packer to the string or wall of the wellbore. The Inner Diameter (ID) of the sealing element is positioned around the Outer Diameter (OD) of the inner mandrel, wherein the ID of the sealing element is prevented from disengaging from the OD of the inner mandrel.
The packer sealing element may be mechanically set, hydraulically set, or hydrostatic set. Other types of packer sealing elements swell in the presence of setting fluid. As used herein, the term "set" and all grammatical variations thereof means an action that causes or allows a downhole tool to be permanently or retrievably secured at a desired location within a wellbore—typically by one or more tool components moving radially away from an inner mandrel and into contact with an inner diameter of a tubular string or wellbore wall.
Setting of the packer activates the sealing element to expand away from the exterior of the mandrel to engage the interior of the wall or tubing string of the wellbore. The packer sealing element is constrained at the top and bottom such that during setting the sealing element is forced outwardly in a direction away from the mandrel. Mechanical packers use compression of a tubular string to apply the compressive force required to activate the elements and slips. The hydraulic packer has an internal setting piston that is hydraulically actuated to apply compression to activate the sealing element and slips. The hydrostatic set packer has an atmospheric chamber that collapses under the well hydrostatic pressure to supply the compressive force required to set the packer.
All of these types of packers have a sealing element that is a ring of elastomeric material with the entire inner diameter of the sealing element fitted onto the outside of the mandrel. The sealing elements are typically constrained at the top and bottom such that actuation of the packer axially compresses the sealing elements to cause radial expansion of the sealing elements and seal the annulus. Actuation of the packer expands the slips to grip and anchor the packer to the interior of the wall of the string or wellbore. For swellable seal elements, exposure to the setting fluid will cause the seal element to radially swell or expand away from the inner mandrel to form a seal in the wellbore.
The sealing element may also be used in a tool for controlling fluid flow within a tubular string. By way of a third example, a sealing element may be used to seal a portion of the interior of the tubular string. Plugs, such as bridge plugs, frac plugs, and seals for plugs and abandonment, may be used to seal the interior of the string. The plug is mainly composed of slips, a plug mandrel and a rubber sealing element. A plug may be introduced into the wellbore and when the plug is positioned very similar to the sealing element of the packer, the sealing element may be caused to block fluid flow into the downstream zone.
The packer and plug may be permanent or retrievable. To retrieve the packer or plug, the sealing element may be moved radially rearward toward the inner mandrel. In this way, the sealing element is no longer engaged with the interior of the wellbore wall or tubular string and is allowed to be retrieved from the wellbore, for example with a retrieval tool. For permanent packers or plugs that are not designed to be retrieved from the wellbore, the sealing element need not be moved back toward the inner mandrel.
A liner hanger is a device for attaching or hanging a liner to the inner wall of a previous tubular string. The purpose of the liner hanger is to suspend a section of liner inside the previous string while sealing the annulus between the liner and the string. The liner hanger may be anchored to the interior of the tubular string by contact between a metal ridge located around the exterior of the liner hanger and the interior of the tubular string. By way of a fourth example, a sealing element may be used to seal the annulus of the liner hanger.
The bottom hole temperature of the well varies significantly depending on the subsurface formation and may range from about 100°f to about 600°f (about 37.8 ℃ to about 315.6 ℃). As used herein, the term "bottomhole (bottomhole)" means at the location of the sealing element. Accordingly, the sealing element may experience a wide range of temperatures within the wellbore. For example, the temperature deep in the wellbore will typically be greater than the temperature near the wellhead. Thus, downhole tools that move to different locations within the wellbore (farther from the wellhead, or closer to the wellhead) may experience large temperature fluctuations. In addition, fluids introduced into or produced from the wellbore may affect the temperature of the wellbore. For example, as the produced formation fluid flows uphole through the tubing string, the fluid typically increases the temperature of the wellbore. When production is stopped, the wellbore cools down. Conversely, when fluids introduced into the wellbore, such as fluids used in carbon sequestration, stimulation and secondary recovery operations, flow down the string, the fluids typically reduce the temperature of the wellbore. When fluid injection into the wellbore ceases, the wellbore temperature rises. It is not uncommon for the temperature within a portion of the wellbore to fluctuate by 50 ℃ or more. In gas injection wells, such as for carbon sequestration, localized cooling caused by gas expansion may reduce the downhole ambient temperature to-40 ℃ or less. For example, steam injection for heavy oil formations may inject fluids 400 ℃ higher than the downhole ambient temperature.
Most sealing elements are made of an elastomeric material that is capable of elastic stretching and may impart structural integrity to the formed seal. However, larger temperature fluctuations may reduce the structural integrity of the sealing element by: causing small gaps or cracks to form in the elastomeric material, either by reducing elastic strain in the elastomeric material, or by reducing the tensile strength of the elastomeric material-especially at the interface between the sealing element and the tool component, wellbore wall or tubular string. This may damage the seal such that pressure is no longer maintained and/or the fluid may bypass the seal.
Some attempts to address this problem have involved the use of seal stacks, which are multiple seal elements located adjacent to each other. However, the use of multiple sealing elements is not only expensive, but also the size of the downhole tool must be increased in order to accommodate the multiple sealing elements. Thus, there is a need for a sealing element that can maintain structural integrity in environments with large temperature fluctuations.
It has been found that the sealing element may comprise a substance that expands during or after the phase change. The expanding substance may maintain the structural integrity of the sealing element during temperature fluctuations. The swelling substance included in the sealing element may fill imperfections in the string, increase contact stresses against the string or downhole tool components, and improve sealing and anchoring properties. The additional expansion of the phase change material may also help overcome elastic recoil from the expansion process. As used herein, the term "expansion (expand, expansion)" and all grammatical variations thereof means an increase in the volume of a substance. As used herein, "phase change (PHASE CHANGE)" means any change in a physical property of a substance. As used herein, "phase change" may include, but is not limited to, a change in phase of a substance (i.e., from a solid to a liquid or semi-liquid, from a liquid or semi-liquid to a solid, from a liquid or semi-liquid to a gas, etc.), a glass transition, a change in the amount of crystallinity of a substance, a physical change in the amorphous and/or crystalline portion of a substance, and any combination thereof. The material will undergo a phase change at a "phase transition temperature". As used herein, "phase transition temperature" includes a single temperature as well as a range of temperatures at which a substance undergoes a phase transition. The "phase transition temperature" may be a single temperature or a range of temperatures at which maximum volumetric expansion occurs. Thus, it is not necessary to constantly specify that the phase transition temperature be a single temperature or a range of temperatures throughout. The material may have a plurality of phase transition temperatures corresponding to the phase transitions of different components within the material.
According to any of the embodiments, the well system comprises: a wellbore penetrating a subterranean formation; and a sealing element comprising: an elastomer matrix; and a substance embedded within the elastomeric matrix, wherein the substance expands at a phase transition temperature.
According to any of the embodiments, a method of forming a seal within a wellbore, the method comprising: introducing a downhole tool into the wellbore, wherein the downhole tool comprises a sealing element, wherein the sealing element comprises: an elastomer matrix; and a substance embedded within the elastomeric matrix, wherein the substance expands at a phase transition temperature; and cause or allow the sealing element to form a seal within the wellbore.
The various embodiments disclosed are applicable to systems, methods, and apparatus without the need to repeat the various embodiments in their entirety. As used herein, any reference to the unit "gallons (gallons)" means american gallons.
The well system includes a sealing element. The sealing element may be located on the downhole tool. The downhole tools may be, for example, sleeves, valves (e.g., safety valves and barrier valves), and seals for tools that include an interior space that needs to be separated from wellbore fluids, such as sensors, actuators, telemetry tools, pressure balanced seals, packer assemblies, plugs, or liner hangers.
The sealing element may be any type of element that forms a seal between two components. By way of a first example, the sealing element may form a seal between two components of the downhole tool. According to this example, the sealing element may be, but is not limited to, an O-ring, a gland seal, a stack seal, or a gasket. Turning to the drawings, FIG. 1 is a schematic illustration of a downhole tool including a sealing element. It should be understood that the downhole tool shown in fig. 1 is only one example of a downhole tool that may include sealing elements, as may other downhole tools not shown. The downhole tool may include a body 213. The body 213 may be configured to fit within the tubular string 112. The tubular string 112 and downhole tools may be introduced into a wellbore defined by a wellbore wall 120. The annulus may be defined as the space between the wellbore wall 120 and the exterior of the tubular string 112 and the body 213.
Downhole tools may include inner sleeve 130 and housing 160. Inner sleeve 130 may be releasably attached to housing 160 by frangible (frangible) means 147. The downhole tool may further comprise a valve 141. The valve 141 may be, for example, a flapper valve. Inner sleeve 130 and housing 160 may also include one or more locking rings 133. The downhole tool also includes a sealing element 134 that restricts or prevents fluid flow between two or more tool components. By way of example and as shown in fig. 1, the sealing element 134 may restrict or prevent fluid flow between the exterior of the inner sleeve 130 and the interior of the housing 160.
By way of another example, the sealing element may form a seal between an exterior of a mandrel of the downhole tool and an interior of a wall of the wellbore or an interior of the tubular string. According to this example, the downhole tool may be a packer assembly, a liner hanger, or a plug, and the sealing element may be located around an exterior of a mandrel of the packer assembly or plug.
Fig. 2 shows an example of a liner hanger including a sealing element. The pipe system may be used as a conduit for a wellbore penetrating the subterranean formation 102. The tubing system may include a surface casing 20 and a surface cement sheath 25 that anchors the surface casing 20 in the wellbore. The surface casing 20 may extend from the surface 30 down to a desired depth in the well. Intermediate sleeve 35 may be disposed concentrically within surface sleeve 20. The intermediate casing 35 may be held in place within the surface casing 20 with an intermediate cement sheath 40. A multi-layered intermediate sleeve may be used. A liner hanger 45 is deployed within the intermediate casing 35. The liner hanger 45 may hang a liner 55 from its end. The liner hanger 45 may be anchored to the intermediate casing 35 with a series of sealing elements 50. The sealing element 50 may seal an annulus between the exterior of an inner intermediate casing and the interior of an adjacent intermediate casing. The seal may inhibit or prevent wellbore fluids from bypassing the liner 55 and liner hanger 45.
The downhole tool may also be a packer. Fig. 3 illustrates a well during a fracturing operation in a portion of a subterranean formation 102. The subterranean formation 102 may be penetrated by a well. The well includes a wellbore 104. Wellbore 104 extends from surface 106 and fracturing fluid 108 is introduced into a portion of subterranean formation 102. The pump and mixer system 100 may be coupled to a tubing string 112 to pump a fracturing fluid 108 into the wellbore 104 to create one or more fractures 116 in the subterranean formation 102. The wellbore 104 may include a casing 110 cemented or otherwise secured to the wellbore wall. The wellbore 104 may be uncased or include uncased sections. Perforations may be formed in the casing 110 or the tubing string 112 to allow fracturing fluid and/or other materials to flow into the subterranean formation 102. The well system may include one or more sets of packers 114 that form one or more wellbore intervals. The packer 114 includes a sealing element 118 positioned about the exterior of the packer. The sealing element 118 may seal an annulus between the exterior of the tubular string 112 and the wellbore wall 120.
There may also be more than one sealing element located on the downhole tool. For example, the sleeve may include O-rings and washers located at different locations on the downhole tool. More than one downhole tool (e.g., packer assembly and sleeve) may also include at least one sealing element.
The sealing element comprises an elastomeric matrix. As used herein, the term "elastomer" means a natural or synthetic polymer having elastomeric properties. As used herein, the term "matrix" means the surrounding medium or structure. The elastomer of the matrix may be the most concentrated material in the sealing element and may provide the necessary structure in which the substance may be embedded within the matrix.
The polymer generally includes amorphous and crystalline regions. Polymers are macromolecules composed of repeating units, typically linked by covalent chemical bonds. The polymer is formed from monomers. During the formation of the polymer, each monomer may lose some chemical groups. Fragments of monomers incorporated into a polymer are referred to as repeat units or monomer residues. The backbone of the polymer is a continuous linkage between monomer residues. The polymer may also contain functional groups or side chains attached to the backbone at various positions along the backbone. Polymer nomenclature is generally based on the type of monomer residue comprising the polymer. Polymers formed from one type of monomer residue are referred to as homopolymers. Copolymers are formed from two or more different types of monomer residues. The number of repeating units of a polymer is referred to as the chain length of the polymer. The number of repeating units of the polymer may range from about 11 to greater than 10,000. In the copolymer, the repeat units from each of the monomer residues may be arranged along the polymer chain in various ways. For example, the repeating units may be random, alternating, periodic, or block. The polymerization conditions can be adjusted to help control the average number of repeat units (average chain length) of the polymer. As used herein, "polymer" may include crosslinked polymers. As used herein, "cross link" or "cross linking" is a linkage between two or more polymer molecules. The cross-links between two or more polymer molecules may be formed by direct interactions between the polymer molecules, or generally by using cross-linking agents that react with the polymer molecules to link the polymer molecules.
The polymer has an average molecular weight that is directly related to the average chain length of the polymer. For the copolymer, each of the monomers will be repeated a certain number of times (number of repeating units). The average molecular weight for the copolymer can be expressed as follows:
Average molecular weight= (m.w.m 1*RU m1)+(M.W.m2*RU m2).
Wherein m.w.m 1 is the molecular weight of the first monomer; RU m 1 is the number of repeating units of the first monomer; m.w.m 2 is the molecular weight of the second monomer; and RU m 2 is the number of repeating units of the second monomer. Of course, the terpolymer will include three monomers, the tetrapolymer will include four monomers, and so on.
The elastomer may be a non-reactive polymer, a degradable polymer or a polymer that swells in the presence of a fluid, such as a water-based fluid or an oil-based fluid. Non-limiting examples of non-reactive polymers include nitrile rubber, hydrogenated nitrile rubber (HNBR), fluorocarbon-based fluoroelastomer rubber containing vinylidene fluoride as a monomer, such as FKM or FFKM rubber, natural rubber, polyetheretherketone rubber (PEEK) and Polytetrafluoroethylene (PTFE), which are under the trade nameSynthetic fluoropolymers of tetrafluoroethylene are sold.
Degradable polymers include polymers that dissolve in wellbore fluids. Non-limiting examples of degradable polymers include urethane, polyurethane rubber, polyether based rubber, polyester based rubber, polylactic acid based polymer, polyglycolic acid based polymer, polyvinyl alcohol based polymer, and thiol based polymer.
Non-limiting examples of swellable polymers include EPDM and rubbers made with Superabsorbent Additives (SAPs). EPDM is a copolymer made from ethylene, propylene and diene co-monomers (such that crosslinking is achieved via sulfur vulcanization). The dienes used to make EPDM rubbers are Ethylidene Norbornene (ENB), dicyclopentadiene (DCPD) and Vinyl Norbornene (VNB). EPDM is derived from polyethylene in which 45-85wt% propylene has been copolymerized to reduce the formation of typical polyethylene crystallinity. EPDM is a semi-crystalline material having an ethylene-type crystalline structure at higher ethylene content, becoming essentially amorphous at ethylene contents approaching 50 wt%.
The elastomeric matrix polymer may also include more than one type of polymer, such as a thermoplastic or a thermoset elastomer. Examples of thermoplastic elastomers include thermoplastic urethanes, block copolymers, thermoplastic olefins, and thermoplastic polyamides. According to a first embodiment, the polymer is a thermoset elastomer, wherein the sealing element is formed from a casting. According to another embodiment, the polymer is a thermoplastic polymer, wherein the sealing element is molded.
The sealing element may be axially constrained on the top and/or bottom such that the sealing element expands only in a radial direction, for example when the sealing element is included in a packer assembly or plug. The sealing element may also be constrained around the outside of the element such that the sealing element expands laterally upwards and downwards, for example when the sealing element is an O-ring or gasket. Upon expansion, the sealing element may form a seal between two or more wellbore components. The elastomeric matrix may be excited by mechanical compression and, according to some of the embodiments, no pressure needs to be applied to form the seal. According to any of the embodiments, the sealing element forms a seal by compressing the sealing element between two skin layers, for example with a compressive load in excess of 500 pounds-force per square inch (psi). The seal formed may form a bi-directional seal in which the sealing element may maintain pressure in both directions, e.g., above and below the seal. According to any of the embodiments, the sealing element is capable of bi-directionally maintaining pressures up to 500psi or greater.
As described above, when an elastomeric sealing element experiences large temperature fluctuations (i.e., +/-50 ℃) small cracks or voids can develop in the sealing element and negatively impact the integrity of the formed seal. By way of example, when the sealing element is tested at high temperature and then placed in a position with a lower temperature, the elastomer appears to "set (take a set)" at high temperature and it is difficult to recover the dimensions when cooled. In contrast, elastomers tested at lower temperatures lose sealing ability when placed in locations with higher temperatures.
The sealing element further comprises a substance embedded within the elastomeric matrix, wherein the substance expands at a phase transition temperature. The volume of the material expands. The expansion of the volume may occur in one or more dimensions. It will be appreciated that unlike swellable elastomers which swell in the presence of a fluid, the material expands in response to temperature and does not expand or swell in the presence of a fluid. The response and subsequent expansion of the substance may be nearly instantaneous, e.g., within seconds or minutes, as the substance passes the phase transition temperature. The expansion of the substance may counteract the negative effects of larger temperature fluctuations. Other advantages of the expansion of the substance embedded within the elastomer matrix include, but are not limited to, overcoming compression set in the seal element or overcoming elastic recoil in the movement of the mandrel supporting the elastomer matrix, such as from an expansion liner hanger.
The phase transition temperature may be greater than or less than the temperature at the wellhead. According to any of the embodiments, the substance expands with increasing temperature at or above the phase transition temperature. As used herein, the phrase "expand with increasing temperature" (expands WITH AN INCREASE IN temperature) means that the volume expands by more than 5% when the material undergoes a phase change from a lower temperature to a higher temperature. The phase transitions according to these embodiments may be solid/liquid, solid/semi-liquid and glass transitions. The substance may be an organic based substance. The organic-based material may be amorphous or semi-crystalline in structure. The organic based material may be a polymeric plastic or a thermoplastic including Acrylonitrile Butadiene Styrene (ABS), polypropylene, nylon 6/6, acetal, polycarbonate or polyester. The semi-crystalline organic based material may be, for example, high Density Polyethylene (HDPE). The organic based material may be a wax. The wax may be, for example, paraffin or animal or vegetable fats, such as stearic acid. The phase transition temperature of the organic-based material may be different. By way of example, the phase transition temperature of the paraffin wax may be in the range of 0 ℃ to 150 ℃ depending on the composition of the paraffin wax and additional components within the wax, while the phase transition temperature of the stearic acid wax may be 70 ℃ and the phase transition temperature of the HDPE may be 125 ℃. The sealing element may also comprise more than one type of organic-based material, each material having a different phase transition temperature, so as to cover a wider range of bottom hole temperatures. By way of example, the organic-based material may include paraffin and stearic acid. Table 1 lists non-limiting examples of the volumetric expansion of different organic-based materials with increasing temperature.
TABLE 1
According to any of the embodiments, the substance expands with decreasing temperature at or below the phase transition temperature. As used herein, the phrase "expand with temperature" means that the volume expands by more than 0.5% when the material undergoes a phase change from a higher temperature to a lower temperature. Fig. 4 is a graphical representation of the volumetric expansion of paraffin wax with increasing temperature and the volumetric expansion of bismuth alloy with decreasing temperature. The phase transition temperature according to these embodiments may be the freezing point of the substance. The phase change according to these embodiments may be liquid/solid or semi-liquid/solid. The substance may be a metal-based substance, such as a pure metal or a metal alloy. As used herein, the term "metal alloy" means a mixture of two or more elements, wherein at least one of the elements is a metal. The other elements may be nonmetallic or a different metal. Examples of metallic and non-metallic alloys are steels, which contain the metallic element iron and the non-metallic element carbon. Examples of metals and metal alloys are bronze, which contains the metallic elements copper and tin. Examples of suitable metals for the metal-based species include, but are not limited to, any pure metal or metal alloy of bismuth, gallium, germanium, and combinations thereof. The metal-based material may be alloyed with other elements to improve mechanical properties or to adjust the phase transition temperature. Alloying elements include silicon, antimony, tin, lead, cadmium, indium, magnesium, manganese, zinc, thallium, mercury, lithium, sodium, and potassium. The properties of the different metals and metal alloys are shown in table 2, where the volume expands as the temperature decreases.
TABLE 2
The material may be selected based on its phase transition temperature and an expected increase or decrease in the bottom hole temperature. By way of example, if formation fluids are to be produced and it is desired to raise the bottom hole temperature to 200 ℃ during production, an organic-based material, such as HDPE, may be selected that has a phase transition temperature of at least 100 ℃. In this way, when the bottom hole temperature increases to the phase transition temperature of the material, the material will undergo a phase transition and expand. By way of another example, if a fluid is injected into the wellbore and the bottom hole temperature is expected to be reduced to 30 ℃, a metal-based species, such as pure metallic gallium, having a phase transition temperature of less than or equal to 30 ℃ may be selected.
According to certain embodiments, one or more substances, each of which has a phase change above or below its phase change temperature, may be used to cover a wide range of downhole temperature variations. For example, one or more metal-based substances may be selected, wherein each substance undergoes a phase change at or below the freezing point, and each substance has a different phase change temperature. By way of another example, one or more organic-based materials may be selected, where each material undergoes a phase change at or above the melting point, and each material has a different phase transition temperature. These embodiments may be useful when the sealing element is included on a downhole tool (e.g., a packer or plug) retrieved from the wellbore after use. In this way, as the bottom hole temperature increases or decreases (e.g., during production or injection), the material may expand and provide a better seal. Then, when the bottom hole temperature is restored (e.g., after production or injection is stopped), the material will shrink and no longer sealingly engage the tool components, walls of the wellbore, or the interior of the tubing string. In this way, the downhole tool may be retrieved.
According to certain other embodiments, two or more substances, one substance having a phase change above its phase transition temperature and the other substance having a phase change below its phase transition temperature, may be used to cover a wide range of downhole temperature variations. For example, at least one metal-based substance may be selected, and at least one organic-based substance may be selected. These embodiments may be useful when the sealing element is included on a downhole tool (e.g., a permanent packer or plug) that remains permanently in the wellbore after use. These embodiments may also be useful when a seal is formed between components of the downhole tool and the downhole tool is retrievable (e.g., an O-ring or gasket). In this way, the organic-based material may expand and provide a better seal as the bottom hole temperature increases (e.g., during production). Then, when the bottom hole temperature cools down (e.g., during injection), the metal-based material may expand and still provide a better seal.
The volumetric expansion of a substance may be different for different substances. According to any of the embodiments, the substance is selected such that the volume of the substance expands by at least 1%, 3% or 15%. As shown in tables 1 and 2, the volume expansion of the organic-based material is generally greater than that of the metal-based material.
The sealing ability of the sealing element may be reduced prior to the phase transition, for example, due to temperature fluctuations during wellbore operations, which create small gaps around and/or throughout the sealing element. According to any of the embodiments, the substance expands in a sufficient volume such that any small gaps formed on the sealing element due to temperature fluctuations are filled with the substance. Accordingly, the sealing capability of the sealing element may be restored after the phase change expansion. The sealing capability may be restored such that the sealing element is able to withstand the desired pressure differential. The pressure differential may be a bottom hole pressure of the subsurface formation across the sealing element. After the substance undergoes a phase change, the strength of the sealing element increases. By way of example, the bulk modulus of paraffin wax is approximately 240,000psi, which indicates that the expanding organic-based material can exert significant forces on the component and thus strengthen the sealing element.
The substance may be in the form of particles. The particles may have a variety of geometries, such as generally spherical, needle-like, or cuboid, and may have a generally smooth or serrated perimeter. The size of the particles may vary and may be in the range of 10 millimeters (mm) to 1,000 nanometers (nm). The particle size may be in the range of 1mm to 10 nm. The particles are embedded within the elastomeric matrix. The particles may be dispersed throughout the elastomer matrix. The particles may also be embedded at one or more selected areas of the elastomeric matrix, for example, only around the outer perimeter of the elastomeric matrix, with small gaps or cracks most likely to form due to temperature fluctuations.
The sealing element may be located on the downhole tool adjacent to a second sealing element that does not include the substance. This embodiment may be useful if the substance reduces the overall strength of the sealing element. In this way, the use of a second sealing element may ensure that an adequate seal is formed.
In addition to the phase change material, the material particles may also comprise other materials. For example, a non-reactive enhancer may be added to the organic-based material. Fibers or other particles may be used to increase the stiffness of the metal matrix material. The concentration of the other material may be selected such that the sealing capability of the sealing element is maintained after the phase change. For example, including higher concentrations of other materials may reduce the amount of phase change material available for expansion.
Some waxes may bleed out of the elastomeric matrix at high temperatures. If the wax bleeds out of the elastomeric matrix, the wax will no longer provide a long term expansion seal enhancement. According to any of the embodiments, the organic-based material particles are encapsulated in a shell. The shell can be used to hold the wax as a distinct phase within the elastomeric matrix. The material used for the shell may be oil-incompatible so that the shell material does not exude from the elastomeric matrix. The shell material may be stretched. In this way, when the substance expands during the phase transition, the shell will not crack and provide a path for the substance to exude from the elastomeric matrix. The shell material may be selected from polymeric materials including: acrylic, epoxy, silver, polystyrene, carbon nanotubes, silica, fluorocarbon-based Fluoroelastomers (FKM) or Polytetrafluoroethylene (PTFE), which are under the trade nameSynthetic fluoropolymers of tetrafluoroethylene are sold.
The method includes introducing a downhole tool into a wellbore. The well may be, but is not limited to, an oil, gas or water producing well, an injection well or a geothermal well. The well may also be an offshore well. The method may include causing or allowing a bottom hole temperature of the wellbore to decrease. The temperature reduction may be performed after the downhole tool is introduced into the wellbore. The step of lowering may include introducing a fluid into the wellbore or stopping production of formation fluids. The fluid may be a variety of types of fluids used in oil or gas operations, such as drilling fluids, injection fluids, fracturing fluids, workover fluids, acidizing fluids, gravel packing fluids, completion fluids, and stimulation fluids. According to this embodiment, the fluid introduced into the wellbore has a surface temperature that is less than the phase transition temperature of the substance. By way of example, the fracturing fluid may cool the bottom hole temperature of the wellbore beyond 100°f (37.8 ℃). The temperature of the portion of the wellbore may be reduced to a temperature less than or equal to the phase transition temperature of the metal-based material.
The method includes causing or allowing a downhole temperature of the wellbore to rise. The bottom hole temperature may be raised by introducing fluid into the wellbore, producing fluid from the wellbore, or stopping pumping cooler fluid into the wellbore. The fluid may have a temperature greater than or equal to the phase transition temperature of the substance. According to any of the embodiments, the phase change of the substance occurs within normal operating bottom hole temperatures experienced during oil or gas operation. Depending on the oil or gas operation performed, the normal operating bottom hole temperature experienced may be in the range of-40 ℃ to 550 ℃ or 4 ℃ to 200 ℃.
The following are two non-limiting examples of the use of a sealing element with a metal-based substance that expands when the temperature drops below the phase transition temperature. According to a first example, the sealing element is placed outside the sleeve. The heat of the setting cement in the annulus between the casing and the wall of the wellbore causes a phase change of the metal from solid to liquid, which causes shrinkage of the metal-based material and thus reduces the volume of the elastomer matrix, which allows more cement to fill the annular gap. After curing is complete and the bottom hole temperature is reduced, the metal-based phase change material expands and helps seal any possible annular gap between the casing and cement. According to a second example, the sealing element is part of a frac plug. The wellbore is warm when the plug is installed and the metal-based material is liquid, which allows for lower setting forces. During the fracturing operation, the injected water cools the fracturing plug and solidifies the metal-based material. The metal expands upon solidification and enhances sealability. The solidified metal also increases the stiffness of the elastomeric matrix, which increases the pressure retention capability of the plug.
The following are two non-limiting examples of the use of a sealing element with an organic-based substance that expands when the temperature rises above the phase transition temperature. According to a first example, a packer comprising a sealing element is introduced into a geothermal well. The organic-based material is solid when solidified. As hot water is produced from the geothermal wellbore, the organic-based material expands and improves the integrity of the seal and pressure retention capability. According to a second example, the liner hanger includes an organic-based material in at least one of the seal elements. The liner hanger is expanded into position and is arranged to seal between the exterior of the string and the interior of another string. As the subsurface formation heats the sealing element, the organic-based material expands and helps overcome any elastic recoil that may occur during setting of the liner hanger.
An embodiment of the present disclosure is a well system comprising: a wellbore penetrating a subterranean formation; and a downhole tool comprising a sealing element, wherein the sealing element comprises: an elastomer matrix; and a substance embedded within the elastomeric matrix, wherein the substance expands at a phase transition temperature. Optionally, the well system further comprises: wherein the downhole tool is selected from the group consisting of a sleeve, a valve, a sensor, an actuator, a telemetry tool, a pressure balanced seal, a packer assembly, a plug, and a liner hanger. Optionally, the well system further comprises: wherein the sealing element forms a seal between components of the downhole tool, and wherein the sealing element is an O-ring, gland seal, stack seal, or gasket. optionally, the well system further comprises: wherein the sealing element forms a seal between an exterior of a mandrel of the downhole tool and an interior of a wall of the wellbore or an interior of the tubular string, and wherein the downhole tool is a packer assembly, a liner hanger, or a plug. Optionally, the well system further comprises: wherein the elastomer of the elastomer matrix is a non-reactive polymer, a degradable polymer or a polymer that swells in the presence of a fluid. Optionally, the well system further comprises: wherein the substance expands with increasing temperature at or above the phase transition temperature. Optionally, the well system further comprises: wherein the substance is an organic based substance. Optionally, the well system further comprises: wherein the organic-based material is selected from the group consisting of: a polymer plastic; thermoplastics including acrylonitrile butadiene styrene, polypropylene, nylon 6/6, acetal, polycarbonate or polyester; a semi-crystalline organic based material; or a wax including paraffin or stearic acid. Optionally, the well system further comprises: wherein the sealing element further comprises a second organic-based material, wherein the second organic-based material has a different phase transition temperature than the organic-based material. Optionally, the well system further comprises: wherein the organic-based material is in the form of particles, and wherein the particles are encapsulated in a shell. optionally, the well system further comprises: wherein the substance expands with decreasing temperature at or below the phase transition temperature. Optionally, the well system further comprises: wherein the substance is a metal-based substance. Optionally, the well system further comprises: wherein the metal-based material comprises a pure metal or metal alloy comprising bismuth, gallium, germanium, silicon, antimony, tin, lead, cadmium, indium, magnesium, manganese, zinc, thallium, mercury, lithium, sodium, potassium, and combinations thereof. Optionally, the well system further comprises: wherein the sealing element further comprises a second metal-based material, wherein the second metal-based material has a different phase transition temperature than the metal-based material. Optionally, the well system further comprises: wherein the substance expands at or above the phase transition temperature with an increase in temperature, and wherein the sealing element further comprises a second substance, wherein the second substance expands at or below the phase transition temperature with a decrease in temperature. Optionally, the well system further comprises: wherein the substance is selected such that the volume of the substance expands by at least 1%. Optionally, the well system further comprises: wherein the substance is in the form of particles having a particle size in the range of 10 millimeters to 1,000 nanometers. Optionally, the well system further comprises: wherein the particles are dispersed throughout the elastomer matrix.
Another embodiment of the present disclosure is a method of forming a seal within a wellbore, the method comprising: introducing a downhole tool into the wellbore, wherein the downhole tool comprises a sealing element, wherein the sealing element comprises: an elastomer matrix; and a substance embedded within the elastomeric matrix, wherein the substance expands at a phase transition temperature; and cause or allow the sealing element to form a seal within the wellbore. Optionally, the method further comprises: wherein the downhole tool is selected from the group consisting of a sleeve, a valve, a sensor, an actuator, a telemetry tool, a pressure balanced seal, a packer assembly, a plug, and a liner hanger. Optionally, the method further comprises: wherein the sealing element forms a seal between components of the downhole tool, and wherein the sealing element is an O-ring, gland seal, stack seal, or gasket. Optionally, the method further comprises: wherein the sealing element forms a seal between an exterior of a mandrel of the downhole tool and an interior of a wall of the wellbore or an interior of the tubular string, and wherein the downhole tool is a packer assembly, a liner hanger, or a plug. Optionally, the method further comprises: wherein the elastomer of the elastomer matrix is a non-reactive polymer, a degradable polymer or a polymer that swells in the presence of a fluid. Optionally, the method further comprises: wherein the substance expands with increasing temperature at or above the phase transition temperature. Optionally, the method further comprises: wherein the substance is an organic based substance. Optionally, the method further comprises: wherein the organic-based material is selected from the group consisting of: a polymer plastic; thermoplastics including acrylonitrile butadiene styrene, polypropylene, nylon 6/6, acetal, polycarbonate or polyester; a semi-crystalline organic based material; or a wax including paraffin or stearic acid. Optionally, the method further comprises: wherein the sealing element further comprises a second organic-based material, wherein the second organic-based material has a different phase transition temperature than the organic-based material. Optionally, the method further comprises: wherein the organic-based material is in the form of particles, and wherein the particles are encapsulated in a shell. Optionally, the method further comprises: wherein the substance expands with decreasing temperature at or below the phase transition temperature. Optionally, the method further comprises: wherein the substance is a metal-based substance. Optionally, the method further comprises: wherein the metal-based material comprises a pure metal or metal alloy comprising bismuth, gallium, germanium, silicon, antimony, tin, lead, cadmium, indium, magnesium, manganese, zinc, thallium, mercury, lithium, sodium, potassium, and combinations thereof. Optionally, the method further comprises: wherein the sealing element further comprises a second metal-based material, wherein the second metal-based material has a different phase transition temperature than the metal-based material. Optionally, the method further comprises: wherein the substance expands at or above the phase transition temperature with an increase in temperature, and wherein the sealing element further comprises a second substance, wherein the second substance expands at or below the phase transition temperature with a decrease in temperature. Optionally, the method further comprises: wherein the substance is selected such that the volume of the substance expands by at least 1%. Optionally, the method further comprises: wherein the substance is in the form of particles having a particle size in the range of 10 millimeters to 1,000 nanometers. Optionally, the method further comprises: wherein the particles are dispersed throughout the elastomer matrix.
Another embodiment of the present disclosure is a downhole tool comprising: a mandrel; and a sealing element located adjacent to the mandrel, wherein the sealing element comprises: an elastomer matrix; and a substance embedded within the elastomeric matrix, wherein the substance expands at a phase transition temperature. Optionally, the downhole tool further comprises: wherein the downhole tool is selected from the group consisting of a sleeve, a valve, a sensor, an actuator, a telemetry tool, a pressure balanced seal, a packer assembly, a plug, and a liner hanger. Optionally, the downhole tool further comprises: wherein the sealing element forms a seal between components of the downhole tool, and wherein the sealing element is an O-ring, gland seal, stack seal, or gasket. Optionally, the downhole tool further comprises: wherein the sealing element forms a seal between an exterior of a mandrel of the downhole tool and an interior of a wall of the wellbore or an interior of the tubular string, and wherein the downhole tool is a packer assembly, a liner hanger, or a plug. Optionally, the downhole tool further comprises: wherein the elastomer of the elastomer matrix is a non-reactive polymer, a degradable polymer or a polymer that swells in the presence of a fluid. Optionally, the downhole tool further comprises: wherein the substance expands with increasing temperature at or above the phase transition temperature. Optionally, the downhole tool further comprises: wherein the substance is an organic based substance. Optionally, the downhole tool further comprises: wherein the organic-based material is selected from the group consisting of: a polymer plastic; thermoplastics including acrylonitrile butadiene styrene, polypropylene, nylon 6/6, acetal, polycarbonate or polyester; a semi-crystalline organic based material; or a wax including paraffin or stearic acid. Optionally, the downhole tool further comprises: wherein the sealing element further comprises a second organic-based material, wherein the second organic-based material has a different phase transition temperature than the organic-based material. Optionally, the downhole tool further comprises: wherein the organic-based material is in the form of particles, and wherein the particles are encapsulated in a shell. Optionally, the downhole tool further comprises: wherein the substance expands with decreasing temperature at or below the phase transition temperature. Optionally, the downhole tool further comprises: wherein the substance is a metal-based substance. Optionally, the downhole tool further comprises: wherein the metal-based material comprises a pure metal or metal alloy comprising bismuth, gallium, germanium, silicon, antimony, tin, lead, cadmium, indium, magnesium, manganese, zinc, thallium, mercury, lithium, sodium, potassium, and combinations thereof. Optionally, the downhole tool further comprises: wherein the sealing element further comprises a second metal-based material, wherein the second metal-based material has a different phase transition temperature than the metal-based material. Optionally, the downhole tool further comprises: wherein the substance expands at or above the phase transition temperature with an increase in temperature, and wherein the sealing element further comprises a second substance, wherein the second substance expands at or below the phase transition temperature with a decrease in temperature. Optionally, the downhole tool further comprises: wherein the substance is selected such that the volume of the substance expands by at least 1%. Optionally, the downhole tool further comprises: wherein the substance is in the form of particles having a particle size in the range of 10 millimeters to 1,000 nanometers. Optionally, the downhole tool further comprises: wherein the particles are dispersed throughout the elastomer matrix.
Thus, the various embodiments are well adapted to carry out the objects and advantages mentioned, as well as those inherent therein. The particular embodiments disclosed above are illustrative only, as the various embodiments may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular illustrative embodiments disclosed above may be altered or modified and all such variations are considered within the scope and spirit of the invention.
As used herein, the words "comprise", "have", "include" and all grammatical variants thereof are each intended to have an open, non-limiting meaning that does not exclude additional elements or steps. While the compositions, systems, and methods are described in terms of "comprising," "containing," or "including" various components or steps, the compositions, systems, and methods may also "consist essentially of" or "consist of" the various components or steps. It should also be understood that as used herein, "first," "second," and "third" are arbitrarily designated and are merely intended to distinguish between two or more zones, sealing elements, etc., as appropriate, and do not indicate any order. Furthermore, it should be understood that the use of the word "first" alone does not require the presence of any "second", and the use of the word "second" alone does not require the presence of any "third", etc.
Whenever a numerical range with a lower limit and an upper limit is disclosed, in particular any number and any included range falling within the range is disclosed. In particular, each range of values (in the form of "about a to about b," or, equivalently, "about a to b," or, equivalently, "about a-b") disclosed herein is to be understood as setting each quantity and range within the range including the broader range of values. Furthermore, unless the patentee otherwise explicitly and clearly defines the term in the claims, the term in the claims has its plain, ordinary meaning. Furthermore, the indefinite articles "a" or "an" as used in the claims are defined herein to mean one or more than one of the element to which they are introduced. If the use of a word or term in this specification conflicts with one or more patents or other documents possibly incorporated by reference herein, the definition consistent with this specification shall govern.
Claims (20)
1. A well system, the well system comprising:
A wellbore penetrating a subterranean formation; and
A downhole tool comprising a sealing element, wherein the sealing element comprises:
an elastomer matrix; and
A substance embedded within the elastomeric matrix, wherein the substance expands at a phase transition temperature.
2. The well system of claim 1, wherein the downhole tool is selected from a sleeve, a valve, a sensor, an actuator, a telemetry tool, a pressure balanced seal, a packer assembly, a plug, or a liner hanger.
3. The well system of claim 1 or 2, wherein the sealing element forms a seal between components of the downhole tool, and wherein the sealing element is an O-ring, gland seal, stack seal, or gasket.
4. A well system according to any preceding claim, wherein the sealing element forms a seal between an exterior of a mandrel of the downhole tool and an interior of a wall of the wellbore or an interior of a tubular string, and wherein the downhole tool is a packer assembly, a liner hanger or a plug.
5. The well system of any of the preceding claims, wherein the elastomer of the elastomer matrix is a non-reactive polymer, a degradable polymer, or a polymer that swells in the presence of a fluid.
6. A well system as claimed in any preceding claim, wherein the substance expands with increasing temperature at or above the phase transition temperature.
7. The well system of claim 6, wherein the substance is an organic-based substance.
8. The well system of claim 7, wherein the organic-based material is selected from the group consisting of: a polymer plastic; thermoplastics including acrylonitrile butadiene styrene, polypropylene, nylon 6/6, acetal, polycarbonate or polyester; a semi-crystalline organic based material; or a wax including paraffin or stearic acid.
9. The well system of claim 7, wherein the sealing element further comprises a second organic-based material, wherein the second organic-based material has a different phase transition temperature than the organic-based material.
10. The well system of claim 7, wherein the organic-based material is in the form of particles, and wherein the particles are encapsulated in a shell.
11. The well system of any one of claims 1 to 6, wherein the substance expands with decreasing temperature at or below the phase transition temperature.
12. The well system of claim 11, wherein the substance is a metal-based substance.
13. The well system of claim 12, wherein the metal-based substance comprises a pure metal or metal alloy comprising bismuth, gallium, germanium, silicon, antimony, tin, lead, cadmium, indium, magnesium, manganese, zinc, thallium, mercury, lithium, sodium, potassium, and combinations thereof.
14. The well system of claim 12, wherein the sealing element further comprises a second metal-based substance, wherein the second metal-based substance has a different phase transition temperature than the metal-based substance.
15. The well system of any one of claims 1 to 6 or 11, wherein the substance expands with increasing temperature at or above the phase transition temperature, and wherein the sealing element further comprises a second substance, wherein the second substance expands with decreasing temperature at or below the phase transition temperature.
16. The well system of any one of claims 1 to 6, 11 or 15, wherein the substance is selected such that the volume of the substance expands by at least 1%.
17. The well system of any one of claims 1 to 6, 11, 15 or 16, wherein the substance is in the form of particles having a particle size in the range of 10 millimeters to 1,000 nanometers.
18. The well system of claim 17, wherein the particles are dispersed throughout the elastomer matrix.
19. A method of forming a seal within a wellbore, the method comprising:
introducing a downhole tool into the wellbore, wherein the downhole tool comprises a sealing element, wherein the sealing element comprises:
an elastomer matrix; and
A substance embedded within the elastomeric matrix, wherein the substance expands at a phase transition temperature; and
Causing or allowing the sealing element to form the seal within the wellbore.
20. A downhole tool, the downhole tool comprising:
A mandrel; and
A sealing element located adjacent to the mandrel, wherein the sealing element comprises:
an elastomer matrix; and
A substance embedded within the elastomeric matrix, wherein the substance expands at a phase transition temperature.
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| US17/659,884 | 2022-04-20 | ||
| US17/659,884 US20230340854A1 (en) | 2022-04-20 | 2022-04-20 | Thermally expanding sealing elements |
| PCT/US2022/071851 WO2023204869A1 (en) | 2022-04-20 | 2022-04-22 | Thermally expanding sealing elements |
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| CN118679303A true CN118679303A (en) | 2024-09-20 |
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| EP (1) | EP4453375A1 (en) |
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| US7455104B2 (en) * | 2000-06-01 | 2008-11-25 | Schlumberger Technology Corporation | Expandable elements |
| EP2113546A1 (en) * | 2008-04-28 | 2009-11-04 | Schlumberger Holdings Limited | Swellable compositions for borehole applications |
| US8286701B2 (en) * | 2008-12-31 | 2012-10-16 | Halliburton Energy Services, Inc. | Recovering heated fluid using well equipment |
| US9587459B2 (en) * | 2011-12-23 | 2017-03-07 | Weatherford Technology Holdings, Llc | Downhole isolation methods and apparatus therefor |
| US9534701B2 (en) * | 2012-02-01 | 2017-01-03 | Halliburton Energy Services, Inc. | Opening or closing a fluid flow path using a material that expands or contracts via a change in temperature |
| EP2999763B1 (en) * | 2013-05-22 | 2018-10-31 | FMC Kongsberg Subsea AS | Seal element |
| US10502017B2 (en) * | 2013-06-28 | 2019-12-10 | Schlumberger Technology Corporation | Smart cellular structures for composite packer and mill-free bridgeplug seals having enhanced pressure rating |
| US9228420B2 (en) * | 2013-08-19 | 2016-01-05 | Baker Hughes Incorporated | Conformable materials containing heat transfer nanoparticles and devices made using same |
| US10584564B2 (en) * | 2014-11-17 | 2020-03-10 | Terves, Llc | In situ expandable tubulars |
| CA2966530A1 (en) * | 2014-11-17 | 2016-05-26 | Powdermet, Inc. | Structural expandable materials |
| US11585188B2 (en) * | 2014-11-17 | 2023-02-21 | Terves, Llc | In situ expandable tubulars |
| AU2018442812A1 (en) * | 2018-09-24 | 2021-01-28 | Halliburton Energy Services, Inc. | Swellable metal packer with porous external sleeve |
| WO2020123786A1 (en) * | 2018-12-13 | 2020-06-18 | Schlumberger Technology Corporation | Expandable metal alloy plugs for abandoned wells |
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| EP4453375A1 (en) | 2024-10-30 |
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