• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
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    • 专利摘要:
    The present disclosure relates to methods, compositions and systems that use inflatable glass particles (45) to reduce fluid flow in subterranean formations (50). An exemplary method may include introducing inflatable glass particles (45) into an area (75) of a subterranean formation (50); contacting the inflatable glass particles (45) with a resin composition in the area (75); and allowing the resin composition to cure in the zone (75) to thereby reduce flow through the zone.
    公开号:FR3038646A1
    申请号:FR1655366
    申请日:2016-06-10
    公开日:2017-01-13
    发明作者:Jiten Chatterji；Gregory Robert Hundt；Thomas Singh Sodhi；Darrell Chad Brenneis
    申请人:Halliburton Energy Services Inc；
    IPC主号:
    专利说明:

    CONTEXT
    The present disclosure describes wellbore operations and, more particularly, the use of inflatable glass particles to reduce fluid flow in subterranean formations.
    A natural resource such as oil or gas in an underground formation can be recovered by drilling a wellbore in the formation. A wellbore is generally dug while a drilling fluid is circulated through the wellbore. Among other things, the circulating drilling fluid can lubricate the drill bit, transport drill cuttings to the surface and balance the formation pressure on the wellbore. A problem associated with drilling may be the undesirable loss of drilling fluid in the formation. The lost fluids can generally go into, for example, pre-existing fractures, induced fractures, cracks, cavities, channels or other openings through which the fluid may be lost. This problem may be called "loss of circulation" and sections of the formation in which the drilling fluid (or other fluid) may be lost may be called "areas of loss of circulation". The loss of drilling fluid in the formation is undesirable, inter alia, because of the cost associated with the loss of drilling fluid in the formation, the loss of time, the additional tubing string and, under extreme conditions, abandonment of a well. In addition to drilling fluids, circulation loss problems can be encountered with other fluids, eg, separation fluids, completion fluids (eg, completion brines), fracturing fluids and cement compositions that can be introduced into a wellbore.
    A number of techniques have been developed to combat the loss of traffic, one of which includes the placement of traffic loss materials in the area of loss of circulation. Conventional circulating loss materials may include fibrous, lamellar or granular materials. Circulation loss materials may be placed in the formation, inter alia, mixed with a drilling fluid or in the form of a separate circulation loss pill for the purpose of controlling and / or preventing the loss of circulation. Another technique that has been developed to control the loss of circulation includes placing a curable composition in the wellbore to plug the area of lost circulation. However, for a number of reasons, these techniques may not provide a desirable level of traffic loss control in all circumstances.
    BRIEF DESCRIPTION OF THE DRAWINGS
    These drawings illustrate certain aspects of some of the embodiments of the present method, and should not be used to limit or define the method.
    Figure 1 is a schematic illustration of an exemplary fluid handling system.
    Figures 2 and 3 are schematic illustrations of an example of a well system.
    DETAILED DESCRIPTION
    The present disclosure describes wellbore operations and, more particularly, the use of inflatable glass particles to reduce fluid flow in subterranean formations. Inflatable glass particles may be particularly suitable for solving a number of problems in subterranean formations including, without limitation, the loss of circulation. The inflatable glass particles disclosed herein may be described as "inflatable" because they swell (ie, increase in volume) when in contact with organic fluids, e.g., resins. The extent of swelling that can be induced in the inflatable glass particles is a property determined by the specific inflatable glass particles used, the specific organic liquid that comes into contact with the inflatable glass particles, the amount of organic liquid that enters in contact with the inflatable glass particles and the duration of the contact between the organic liquid and the inflatable glass particles.
    Since the inflatable glass particles are inflatable in organic fluids, the inflatable glass particles can be used in a combination of resin to reduce, or even potentially prevent, a fluid flow (or flow) in the body. underground formations. Advantageously, the inflatable glass particles and the resin composition can be used to create a barrier to fluid flow. The fluid flow barrier may be formed in the subterranean formation to block certain pathways in the subterranean formation thereby reducing the flow of fluid through the subterranean formation. Examples of types of flow paths that may be blocked by the fluid flow barrier include, but are not limited to, perforations, such as those formed by a perforator, cracks, cracks, fractures, ore strips, flow channels, cavities, highly permeable ore belts, annular cavities, or combinations thereof, as well as any other area in the formation through which there may be an undesirable flow of fluid .
    [0009] Inflatable glass particles can be used with the resin composition in a variety of underground operations, in which the formation of deflection barriers (or flow prevention) may be desirable. The sealant may be used before, during, or after a variety of underground operations. As an example, a traffic loss area may be identified during drilling, cementing, or other underground operation, necessitating the cessation of downhole activities for corrective operations. To alleviate the problems of loss of circulation, the inflatable glass additives can be introduced into the subterranean formation and contacted with a resin composition. Inflatable glass additives may swell when contacted with a resin composition while the resin composition may cure to form a solidified mass. Without being limited by theory, it is believed that the inflatable glass particles retain the resin composition near the wellbore, reducing flow of the resin composition to the subterranean formation. The combination of inflatable glass additives and hardened resin can form a flow-blocking barrier, allowing the resumption of drilling, cementing or other operations in the wellbore. For example, inflatable glass particles with the resin composition can be used to prevent fluid loss (eg, drilling fluids, cement compositions, or other well-treatment fluids) in the zones. loss of circulation, which may include fractures (natural or pre-existing), cracks, cavities, channels and other openings in which the fluid may be lost.
    A wide variety of inflatable glass particles may be used which swell following contact with a resin. Inflatable glass particles can be used in the methods disclosed herein to help reduce flow in a subterranean formation. For example, inflatable glass particles, when exposed to a sufficient amount of resin, can swell to a volume several times greater than the volume of the inflatable glass particles prior to such exposure.
    [0011] A nonlimiting example of suitable inflatable glass particles may include a plurality of interconnected organosilicon nanoparticles. In general, these types of inflatable glass particles can be described as a plurality of interconnected organosilicon nanoparticles. More particularly, the inflatable glass particles may comprise bridged organosiloxane sol-gels comprising a plurality of alkylsoloxy substituents. Without being limited by theory, these interconnected organosilicon nanoparticles can generally be produced by a method which comprises the use of a bridged organosiloxane sol-gel comprising residual silanols and then derivatizing the residual sol-gel silanols. with a reagent comprising at least one group which is reactive with the residual silanols and also at least one alkyl group. More specifically, the preparation of the sol-gel may generally comprise the formation of interconnected organosilicon particles from bridged silane precursor molecules by polymerization using an acidic or basic catalyst. After gelation, the sol-gel may be mature enough to undergo syneresis. At this point, the sol-gel may be derivatized as previously described to capper the silanol-terminated polymers present on the sol-gel. Typical derivatization reagents may include, but are not limited to, halosilanes, silazanes, disilazanes, and the like. The derivatized sol-gel can then be dried and / or ground into a fine powder for use as an inflatable glass particle. An example of a commercially available inflatable glass particle is OSORB® inflatable glass, available from ABSMaterials, Inc., Wooster, Ohio.
    Inflatable glass particles are inflatable following contact with organic liquids, such as resins. The extent of swelling that can be induced in the inflatable glass particles is a property determined by the specific inflatable glass particles used, the specific organic liquid that comes into contact with the inflatable glass particles, the amount of organic liquid that enters in contact with the inflatable glass particles and the duration of the contact between the organic liquid and the inflatable glass particles. The inflatable glass particles may swell to a volume greater than about 1.5 times to about 10 times or more of the dried volume of the inflatable glass particles. For example, the inflatable glass particles can swell to a volume of about 2 times, about 3 times, about 5 times, about 7 times, about 10 times or more of the dried volume. inflatable glass particles. As previously described, the inflatable glass particle can swell upon contact with resins.
    Inflatable glass particles can generally be in particulate form for use in dry powder form. As used herein, the term "particulate" describes solid state materials having a well-defined physical form as well as those having irregular geometries, including any particle in the form of platelets, chips, fibers. flakes, ribbons, stems, strips, spheroids, hollow beads, torus, pellets, tablets, any other physical form. The inflatable glass particles can be milled by a process sufficient to obtain an appropriate size. The powdery form of the inflatable glass particles may have a particle size, without limitation, in the range of about 1 micron to about 500 microns, from about 10 microns to about 350 microns or from about 50 microns to about 250 microns . However, particle sizes outside this disclosed range may also be appropriate for particular applications. The inflatable glass particles can be dried to be mixed with a carrier fluid and to facilitate transportation. Without limitation, the inflatable glass particles may be dried by any means sufficient to produce an inflatable glass particle that is easily added to other components of the support fluid. With the benefit of this disclosure, one skilled in the art will be able to choose an appropriate size of the inflatable glass particle.
    Inflatable glass particles may be introduced into an underground formation using any suitable support fluid. The carrier fluid may be any fluid suitable for moving and transporting the inflatable glass particles to the desired location in the subterranean formation. After introduction of the inflatable glass particles into the subterranean formation, the support fluid may be removed (or leaked) from the subterranean formation leaving a deposit of inflatable glass particles in the subterranean formation. The carrier fluid comprising the inflatable glass particles, which are deposited therein, can be pumpable. In specific examples, the support fluid may be selected to be compatible with the subterranean formation and not to damage it.
    Examples of suitable carrier fluids may include, but are not limited to, fresh water, deionized water, brine with different salinities, chloride solutions such as calcium chloride and sodium chloride. potassium, and combinations thereof. To avoid premature swelling, the carrier fluid may be an aqueous fluid in some instances. Specific examples of carrier fluids may include water and optionally may include one or more dissolved salts.
    The support fluid may, at least temporarily, suspend the inflatable glass particles. Since the inflatable glass particles may have a specific gravity different from that of the support fluid (e.g., water), the support fluid may also include a viscosity increasing agent to help suspend the inflatable glass particles. The viscosity increasing agent used for the carrier fluid may comprise any viscosity increasing agent. Without limitation, examples of viscosity increasing agents may include synthetic polymers; polysaccharides (e.g., welan gum); inflatable clays such as bentonite; biopolymers such as cellulose derivatives (eg, hydroxyethyl cellulose, carboxymethyl cellulose, carboxymethyl hydroxyethyl cellulose). An example of commercially available viscosant is SA-1015 ™ suspending agent available from Halliburton Energy Services, Inc., Houston, Texas. If a viscosity increasing agent is added, it would also be useful for the support fluid to additionally comprise an inhibitor of the viscosity increasing agent which is adapted to inhibit the viscosity of the fluid carrier after a period of time. time at the static temperature of the subterranean formation, whereby the support fluid can be used to place the inflatable glass particles in the subterranean formation and then after allowing sufficient time for the viscosity of the support fluid to be inhibited by the Inhibitor, the carrier fluid can be removed from (or leaked) the subterranean formation leaving a deposit of inflatable glass particles in the subterranean formation.
    In specific examples, the carrier fluid for the inflatable glass particles may remain sufficiently non-viscous to be displaced in the permeable zones of the subterranean formation with minimal pressure. Thus, it would not be necessary to apply a higher pressure that could damage the rock structure of the subterranean formation when attempting to force the inflatable glass particles into the permeable zones.
    The inflatable glass particles may be incorporated in the support fluid in an effective amount to seal a permeable zone (later, with the resin) during its placement at the bottom of the well and in the subterranean formation. The effective amount may vary depending on such factors as the type of support fluid, the size of the fracture, crack, etc., the type and amount of resin, etc. The amount of inflatable glass particles that can be mixed with the support fluid depends on a number of factors including the type of carrier fluid. Generally, the carrier fluid may contain, without limitation, from about 0.001 to about 5 pounds of inflatable glass particles per gallon of carrier fluid (ie, from about 1.2 × 10 -4 kg to about 0.6 kg of particles). of inflatable glass per liter of carrier fluid) and, moreover, between about 0.01 to about 2 pounds of inflatable glass particles per gallon of carrier fluid (ie, between about 1.2 × 10 -3 kg / L to about 0 In specific examples, the inflatable glass particles may be present in an amount of about 0.001, about 0.01, about 0.1, about 1, about 2, about 3, about 4 or about 5 pounds of inflatable glass particles per gallon of carrier fluid (about 1.2 × 10 -3, about 1.2 × 10 -3, about 1.2 × 10 -2, about 0.12, about 0.24, about 0.36, about 0.48, or about 0.6 kilograms of inflatable glass particles per liter of fluid support).
    As previously described, the inflatable glass particles may be contacted with a resin to induce swelling in the subterranean formation. The resin may also thicken to develop a compressive force and / or to form a seal when placed in the subterranean formation. Therefore, the resin can act with the inflatable glass particles to create a substantially impermeable barrier to the flow of fluid in the subterranean formation, e.g., to prevent loss of drilling fluid to the subterranean formation and / or to isolating fluids and gases from the formation and, therefore, preventing potential migration of fluid and gas into the ring or into the interior of the casing.
    The resin may be placed in the subterranean formation in a resin composition which may comprise the resin and optionally a diluent. As used herein, the term "resin" describes any one of a number of similar polymerized synthetic resins or chemically modified natural resins including thermoplastic materials and thermosetting materials. Examples of resins which can be used in the resin composition include, but are not limited to, epoxy resins, novolac resins, polyepoxide resins, phenol-aldehyde resins, urea-aldehyde resins, urethane, phenolic resins, furan / furfuryl alcohol resins, phenolic resins / latex, phenol formaldehyde resins, bisphenol A diglycidyl ether resins, butoxymethyl butyl glycidyl ether resins, bisphenol A resins epichlorohydrin, bisphenol F resins, glycidyl ether resins, polyester resins and hybrids and copolymers thereof, polyurethane resins and hybrids and copolymers thereof, acrylate resins, and mixtures thereof. Some suitable resins, such as epoxy resins, can be cured with a curing agent so that, when pumped to the bottom of the well, they can be cured only with time and temperature. Other suitable resins, such as furan resins generally require a time-delayed curing agent to help activate polymerization of the resins if the formation temperature is low (ie, less than 250). ° F (less than about 120 ° C), but it will harden under the effects of time and temperature if the temperature of the formation is greater than about 250 ° F (greater than about 120 ° C). can be used in the embodiments is the WELLLOCK ™ resin system available from Halliburton Energy Services, Inc., Houston, Texas.
    The choice of a suitable resin may be influenced by the temperature of the subterranean formation in which the composition will be introduced. As an example, for subterranean formations having a bottomhole static temperature ("BHST") ranging from about 60 ° F to about 250 ° F (ie, from about 16 ° C to about 120 ° C), the two epoxy-based components comprising a resin component and a curing agent component may be preferred. For subterranean formations having a BHST of from about 300 ° F to about 600 ° F (ie, from about 150 ° C to about 320 ° C), a furan resin may be preferred. For subterranean formations having a BHST of from about 200 ° F to about 400 ° F (ie, from about 93 ° C to about 200 ° C), a phenol-based resin or a single-component epoxy resin may be appropriate. For subterranean formations having a BHST of at least 175 ° F (ie, at least about 79 ° C), a phenol / phenol formaldehyde / furfuryl alcohol resin may also be suitable. With the benefit of the present disclosure, a person skilled in the art must be able to choose a resin for a given application.
    Generally, the resin may be added to the resin composition in an amount, without limitation, in the range of about 5 to about 100% by volume of the resin composition. In particular examples, the resin may be added to the resin composition in an amount of from about 60 to about 100% by volume of the resin composition. In specific examples, the resin may be present in an amount of about 5%, about 10%, about 20%, about 30%, about 40%, about 50%, the like. about 60%, about 70%, about 80%, about 90%, or about 100% by weight of the resin composition. Factors that could affect this determination include the type of resin and the potential curing agent desired for the given application. With the benefit of the present disclosure, a person skilled in the art must be able to choose a quantity of resin for a given application.
    The resin composition should generally have a density suitable for a given application as desired by those skilled in the art. Without being limited by the theory, the density of the resin composition can be adjusted to achieve the proper density hierarchy for the placement of the resin. Without limitation, the resin composition may have a density in the range of about 5 pounds per gallon ("ppg") to about 17 ppg (ie, from about 0.6 kg / L to about 2.0 kg / L) , on the other hand, from about 8 ppg to about 14 ppg (or about 1.0 kg / L to about 1.7 kg / L), or otherwise, from about 10 ppg to about 12 ppg (or about 1.2 kg / L to about 1.4 kg / L). In addition, filler particles may be selected which alter the mechanical properties of the cured resin composition or the fluid properties of the liquid resin composition (uncured). Such filler particles may have the same density as the resin composition so that the density density is not changed. Examples of suitable filler particles may include, but are not limited to, aluminum oxide, awaruite, barium carbonate, barium oxide, barite, calcium carbonate, calcium oxide, cenospheres, chromite, chromium oxide, copper, copper oxide, dolomite, galena, hematite, hollow glass microspheres, ilmenite, iron oxide, siderite, magnetite, magnesium oxide, manganese carbonate, manganese dioxide, manganese oxide (IV), manganese oxide, manganese tetroxide, manganese oxide (Π), oxide manganese (ΙΠ), molybdenum oxide (IV), molybdenum oxide, molybdenum trioxide, Portland cement, pumice, pyrite, spherelite, silica, silver, tenorite , titanate, titanium (II) oxide, titanium dioxide (ΙΠ), titanium dioxide (IV), zirconium oxide, zirconium silicate, zinc oxide, dust Cement kiln era, expanded and unexpanded perlite, attapulgite, bentonite, zeolite, elastomers, sand, micronized polymers, waxes, polymer fibers, inorganic fibers, and any combination of these. It should be noted that the foregoing list encompasses all crystalline forms of any material. With the benefit of the present disclosure, one skilled in the art will recognize the appropriate density of the resin composition for a given application.
    Optionally, a diluent may be added to the resin composition to reduce the viscosity of the resin composition to facilitate handling, mixing, and transfer. However, in some cases it may be desirable not to use a diluent (eg for environmental or safety reasons). Factors that could affect this decision include the geographic location of the well, the surrounding weather conditions and the desired long-term stability of the wellbore maintenance fluid. With the benefit of the present disclosure, a person skilled in the art must be able to determine the use or not of a diluent for a given application.
    [0025] Generally, any diluent that is compatible with the resin and that provides the desired viscosity effect may be suitable for use in the resin composition. Some diluents may be reactive in that they are incorporated in the resin. Diluents that are reactive may comprise a functional group of amine or epoxide. Suitable diluents may include, but are not limited to, butyl glycidyl ether, cyclohexane dimethanol diglycidyl ether, polyethylene glycol, butyl lactate, dipropylene glycol methyl ether, dimethyl dipropylene glycol ether, dimethyl formamide, diethylene glycol methyl ether, ethylene glycol butyl ether, diethylene glycol butyl ether, propylene carbonate, limonene, methyl esters of fatty acid, or any combination of these. The choice of a suitable diluent depends on the chosen resin. Without limitation, the amount of diluent used in the resin composition may be in the range of about 0.1 to about 30% by weight of the resin composition. In specific examples, the diluent may be present in an amount of about 0.1%, about 1%, about 5%, about 10%, about 25% or about 30% by weight of the resin composition. Optionally, the resin composition may be heated to reduce its viscosity, instead of or in addition to the addition of a diluent. With the benefit of the present disclosure, a person skilled in the art must be able to choose a type of diluent and an amount of diluent for a given application.
    [0026] Optionally, the resin composition may also include a curing agent. As used herein, the term "curing agent" describes any substance capable of converting the liquid resin into a hardened and solidified mass, e.g. by crosslinking the resin. Examples of suitable curing agents include, but are not limited to, aliphatic amines, aliphatic tertiary amines, aromatic amines, cycloaliphatic amines, heterocyclic amines, amido amines, polyamides, polyethyl amines, polyether amines, polyoxyalkylene amines, carboxylic anhydrides, triethylenetetraamine, diamine ethylene, N-cocoalkyltrimethylene, isophorone diamine, N-aminophenyl piperazine, imidazoline, 1,2-diaminocyclohexane, polytheramine, diethyltoluenediamine, 4,4 diaminodiphenyl methane, methyltetrahydrophthalic anhydride, hexahydrophthalic anhydride, maleic anhydride, polyazelaic polyanhydride, phthalic anhydride, and combinations thereof. Commercial curing agent examples may include, but are not limited to, the ETHACURE® 100 curing agent available from Albemarle Corp. of Baton Rouge, Louisiana, and JEFFAMINE® D-230 Polyetheramine, available from Huntsman Corp. from The Woodlands, Texas. The curing agent may be added to the resin composition in an amount sufficient to at least partially cure the resin composition. Without limitation, the curing agent may be added in the resin composition in the range of about 5 to about 50% by volume of the resin composition and, in addition, about 20 to about 50%. In specific examples, the curing agent may be present in an amount of about 5%, about 10%, about 20%, about 30%, about 40% or about 50%. % by volume of the resin composition. With the benefit of the present disclosure, one skilled in the art must be able to choose a type of curing agent and a quantity of curing agent for a given application.
    The amount of curing agent may be chosen to impart desired elasticity or compressibility. Without limitation, generally, the lower the amount of curing agent in the resin composition, the better the elasticity or compressibility. With the benefit of this disclosure, one skilled in the art would be able to choose an appropriate amount of curing agent to achieve the desired elasticity or compressibility for a given application.
    Curing agent mixtures may be used in some examples to impart particular qualities to the resin composition. For example, the curing agent may comprise a fast set curing agent and a slow setting curing agent. As used herein, the terms "quick set curing agent" and "slow setting curing agent" do not imply any specific rate at which the agents cure a resin; instead, the terms only indicate the relative rates at which the curing agents initiate curing of the resin. Whether a given curing agent is considered to be fast setting or slow setting may depend on the other curing agent (s) with which it is used. In specific examples, ETHACURE® 100 can be used as a slow setting agent, and JEFFAMINE® D-230 can be used as a rapid setting agent. In specific examples, the ratio of the fast setting curing agent to the curing agent may be selected to achieve a desired behavior of the curing agent. For example, the fast setting curing agent can be added in a ratio of about 1: 5 by volume to the slow setting curing agent. With the benefit of the present disclosure, one skilled in the art must be able to choose a mixture of curing agents for a given application.
    The curing agent may also comprise an optional silane coupling agent. The silane coupling agent can be used inter alia to act as a mediator to assist in bonding the resin to the surface of the subterranean formation and / or the surface of the wellbore. Examples of silane coupling agents include, but are not limited to, N-2- (aminoethyl) -3-aminopropyltrimethoxysilane; 3-glycidoxypropyltrimethoxysilane; gamma-aminopropyltriethoxysilane; N-beta- (aminoethyl) -gamma-aminopropyltrimethoxysilanes; aminoethyl-N-beta- (aminoethyl) -amma-aminopropyl-trimethoxysilanes; gamma-ureidopropyl triethoxysilanes; beta- (3-4 epoxy-cyclohexyl) -ethyl-trimethoxysilane; gamma-glycidoxypropyltrimethoxysilanes; vinyltrichlorosilane; vinyltris (beta-methoxyethoxy) silane; vinyltriethoxysilane; vinyltrimethoxysilane; 3-methacryloxypropyltrimethoxysilane; beta- (3,4-epoxycyclohexyl) ethyltrimethoxysilane; r-glycidoxypropyltrimethoxysilane; r-glycidoxypropylmethylidiethoxysilane; N-beta- (aminoethyl) -r-aminopropyltrimethoxysilane; N-beta- (aminoethyl) -r-aminopropylmethyldimethoxysilane; 3-aminopropyltriethoxysilane; N-phenyl-r-aminopropyltrimethoxysilane; r-mercaptopropyltrimethoxysilane; r-chloropropyltrimethoxysilane; vinyltrichlorosilane; vinyltris (beta-methoxyethoxy) silane; vinyltrimethoxysilane; r-methacryloxypropyltrimethoxysilane; beta- (3,4-epoxycyclohexyl) ethyltrimethoxysilane; r-glycidoxypropyltrimethoxysilane; r-glycidoxypropylmethylidiethoxysilane; N-beta- (aminoethyl) -r-aminopropyltrimethoxysilane; N-beta- (aminoethyl) -r-aminopropylmethyldimethoxysilane; r-aminopropyltriethoxysilane; N-phenyl-r-aminopropyltrimethoxysilane; r-mercaptopropyltrimethoxysilane; r-chloropropyltrimethoxysilane; N [3- (trimethoxysilyl) propyl] ethylenediamine; substituted silanes wherein one or more substitutions contain a different functional group; or any combination thereof. Generally, the silane coupling agent can be added to the curing agent in an amount that allows sufficient bonding of the resin. Without limitation, the silane coupling agent may be added to the curing agent in the range of about 0.1 to about 95% by volume of the curing agent. In specific examples, the silane curing agent may be present in an amount of about 5%, about 10%, about 20%, about 30%, about 40%, about 50%, about 60%, about 70%, about 80%, about 90%, or about 95% by volume of the curing agent. With the benefit of the present disclosure, one skilled in the art must be able to choose a silane curing agent for a given application.
    As will be understood by those skilled in the art, the resin composition may be prepared in accordance with any suitable technique. For example, the desired amount of resin can be introduced into a mixer (eg, a batch mixer) before adding or monitoring by the addition of any optional curing agent and / or diluent. Additional additives, if any, may be added to the mixer as desired before, or after, adding the resin to the mixer. This mixture can be stirred for a sufficient period of time. As an example, pumps can be used to introduce the resin composition into the wellbore. As will be understood by one skilled in the art, with the benefit of this disclosure, other suitable techniques for the preparation of the resin composition may be used in accordance with the embodiments.
    A method of treating a well according to the present disclosure may include any or all of the components disclosed herein. The method may comprise any or all of the components and / or steps illustrated in Figures 1-3. The method may include introducing inflatable glass particles into an area of an underground formation. The method may include contacting the inflatable glass particles with a resin composition in the area. The method may include allowing the resin composition to cure in the area to reduce flow through the area. The method may also include pumping a carrier fluid comprising the inflatable glass particles through a well conduit and into the zone. The method may also include pumping the resin composition through a well conduit and into the area to contact the inflatable glass particles. At least a portion of the inflatable glass particles may swell upon contact with the resin composition to plug openings in the area. The portion of the inflatable glass particles may swell to a volume greater than about 1.5 times or more of the dry volume of the inflatable glass particles. The inflatable glass particles may each comprise a plurality of interconnected organosilicon nanoparticles. The inflatable glass particles may each comprise bridged organosiloxane sol-gels comprising a plurality of alkylsoloxy substituents. The inflatable glass particles may be introduced into the subterranean formation in a carrier fluid, wherein the carrier fluid is an aqueous fluid and comprises the inflatable glass particles in an amount of about 0.001 to about 5 pounds per gallon (either from about 1.2 × 10 -4 Kg / L to about 0.6 Kg / L) of the carrier fluid The resin composition may comprise a resin and a curing agent The resin may comprise at least one resin selected from epoxy-based resin, novolac resin, polyepoxide resin, phenol-aldehyde resin, urea-aldehyde resin, urethane resin, phenolic resin, furan / furfuryl alcohol resin, phenolic resin / latex, a phenol formaldehyde resin, a bisphenol A diglycidyl ether resin, a butoxymethyl butyl glycidyl ether resin, a bisphenol A-epichlorohydrin resin, a bisphenol F resin, a glyci resin dyl ether, a polyester resin and hybrids and copolymers thereof, a polyurethane resin and copolymers thereof, an acrylate resin, and combinations thereof. The curing agents may comprise at least one curing agent selected from an aliphatic amine, an aliphatic tertiary amine, an aromatic amine, a cycloaliphatic amine, a heterocyclic amine, an amido amido, polyamides, a polyethyl amine, a polyether amine, a polyoxyalkylene amine, carboxylic anhydrides, triethylenetetraamine, diamine ethylene, N-cocoalkyltrimethylene, isophorone diamine, N-aminophenyl piperazine, imidazoline, 1,2-diaminocyclohexane, polytheramine, diethyltoluenediamine, 4, 4'-diaminodiphenyl methane, methyltetrahydrophthalic anhydride, hexahydrophthalic anhydride, maleic anhydride, polyazelaic polyanhydride, phthalic anhydride, and combinations thereof. The resin composition may also comprise a diluent selected from a butyl glycidyl ether, a cyclohexane dimethanol diglycidyl ether, polyethylene glycol, butyl lactate, dipropylene glycol methyl ether, dimethyl dipropylene glycol ether, dimethylformamide, diethyleneglycol methyl ether, ethylene glycol butyl ether, diethylene glycol butyl ether, propylene carbonate, iimonene, methyl esters of fatty acid, or any combination of these. The method may also include identifying a traffic loss area, wherein the area of lost traffic is the area.
    A loss of circulation composition according to the present disclosure may include one or all components disclosed herein or illustrated in FIGS. 1-3. The circulation loss composition may comprise a resin composition and inflatable glass particles. The inflatable glass particles may be dispersed in the resin composition. At least a portion of the inflatable glass particles may swell to a volume greater than about 1.5 times or more of the dry volume of the inflatable glass particles. The resin composition can be cured to form a solidified mass. The inflatable glass particles may each comprise a plurality of interconnected organosilicon nanoparticles. The inflatable glass particles may each comprise bridged organosiloxane sol-gels comprising a plurality of alkylsoloxy substituents. The resin composition may also include a resin and a curing agent. The resin may comprise at least one resin selected from an epoxy resin, a novolac resin, a polyepoxide resin, a phenol-aldehyde resin, a urea-aldehyde resin, a urethane resin, a phenolic resin, a furan / furfuryl alcohol resin, phenolic resin / latex, phenol formaldehyde resin, bisphenol A diglycidyl ether resin, butoxymethyl butyl glycidyl ether resin, bisphenol A-epichlorohydrin resin, bisphenol F resin, a glycidyl ether resin, a polyester resin and hybrids and copolymers thereof, a polyurethane resin and hybrids and copolymers thereof, an acrylate resin, and mixtures thereof. The curing agents may comprise at least one curing agent selected from an aliphatic amine, an aliphatic tertiary amine, an aromatic amine, a cycloaliphatic amine, a heterocyclic amine, an amido amido, polyamides, a polyethyl amine, a polyether amine, a polyoxyalkylene amine, carboxylic anhydrides, triethylenetetraamine, diamine ethylene, N-cocoalkyltrimethylene, isophorone diamine, N-aminophenyl piperazine, imidazoline, 1,2-diaminocyclohexane, polytheramine, diethyltoluenediamine, 4, 4'-diaminodiphenyl methane, methyltetrahydrophthalic anhydride, hexahydrophthalic anhydride, maleic anhydride, polyazelaic polyanhydride, phthalic anhydride, and combinations thereof. The resin composition may also comprise a diluent selected from a butyl glycidyl ether, a cyclohexane dimethanol diglycidyl ether, polyethylene glycol, butyl lactate, dipropylene glycol methyl ether, dimethyl dipropylene glycol ether, dimethyl formamide, diethylene glycol methyl ether, ethylene glycol butyl ether, diethylene glycol butyl ether, propylene carbonate, iimonene, methyl esters of fatty acid, or any combination of these.
    A well system according to the present disclosure may include any or all of the components disclosed herein. The well system may comprise any or all of the compounds and / or steps illustrated in Figures 1-3. The well system may comprise a fluid supply comprising: a support fluid comprising inflatable glass particles; and a resin composition, wherein the inflatable glass particles are not in contact with the resin composition in the fluid supply. The well system may also include pumping equipment for pumping the support fluid and / or the resin composition into a wellbore. The support fluid and the resin composition may be contained in separate containers. The well system may also include a well supply conduit in fluid communication with a wellbore. At least a portion of the inflatable glass particles may swell upon contact with the resin composition to plug openings in the area. The portion of the inflatable glass particles may swell to a volume greater than about 1.5 times or more of the dry volume of the inflatable glass particles. The inflatable glass particles may each comprise a plurality of interconnected organosilicon nanoparticles. The inflatable glass particles may each comprise bridged organosiloxane sol-gel comprising a plurality of alkylsoloxy substituents. The carrier fluid may be an aqueous fluid and comprise the inflatable glass particles in an amount of from about 0.001 to about 5 pounds per gallon (about 1.2x10 -4 kg / L to about 0.6 kg / L). ) of the support fluid. The resin composition may comprise a resin and a curing agent. The resin may comprise at least one resin selected from an epoxy resin, a novolac resin, a polyepoxide resin, a phenol-aldehyde resin, a urea-aldehyde resin, a urethane resin, a phenolic resin, a furan / furfuryl alcohol resin, phenolic resin / latex, phenol formaldehyde resin, bisphenol A diglycidyl ether resin, butoxymethyl butyl glycidyl ether resin, bisphenol A-epichlorohydrin resin, bisphenol F resin, a glycidyl ether resin, a polyester resin and hybrids and copolymers thereof, a polyurethane resin and copolymers thereof, an acrylate resin, and combinations thereof. The curing agents may comprise at least one curing agent selected from an aliphatic amine, an aliphatic tertiary amine, an aromatic amine, a cycloaliphatic amine, a heterocyclic amine, an amido amido, polyamides, a polyethyl amine, a polyether amine, a polyoxyalkylene amine, carboxylic anhydrides, triethylenetetraamine, diamine ethylene, N-cocoalkyltrimethylene, isophorone diamine, N-aminophenyl piperazine, imidazoline, 1,2-diaminocyclohexane, polytheramine, diethyltoluenediamine, 4, 4'-diaminodiphenyl methane, methyltetrahydrophthalic anhydride, hexahydrophthalic anhydride, maleic anhydride, polyazelaic polyanhydride, phthalic anhydride, and combinations thereof. The resin composition may also comprise a diluent selected from a butyl glycidyl ether, a cyclohexane dimethanol diglycidyl ether, polyethylene glycol, butyl lactate, dipropylene glycol methyl ether, dimethyl dipropylene glycol ether, dimethylformamide, diethyleneglycol methyl ether, ethylene glycol butyl ether, diethylene glycol butyl ether, propylene carbonate, iimonene, methyl esters of fatty acid, or any combination of these.
    [0034] Examples of methods of using the inflatable glass particles to reduce the flow in a subterranean formation will now be described in more detail with reference to FIGS. 1-3. Any of the foregoing embodiments of the inflatable glass particles and / or the resin composition may be applied in the context of FIGS. 1-3. Referring now to Figure 1, a fluid handling system 10 is illustrated. The fluid handling system 10 may be used to prepare a carrier fluid comprising the inflatable glass particles placed therein and the introduction of the carrier fluid into a wellbore. On the other hand, the fluid handling system 10 may be used to prepare a resin composition comprising a resin, optional diluent and optional curing agent and introducing the resin composition into a wellbore. The fluid handling system 10 may comprise moving vehicles, stationary installations, frames, pipes, tubes, tanks or fluid reservoirs, pumps, valves and / or other suitable structures and equipment. For example, the fluid handling system 10 may comprise a fluid supply 15 and a pump equipment 20, both of which may be fluidly coupled to a wellbore supply conduit 25. The feed in fluid 15 may contain the support fluid or the resin composition. The pumping equipment 20 may be used to deliver the carrier fluid or resin composition from a fluid supply 15, which may include a tray, a reservoir, connections to external fluid sources and / or other appropriate structures and equipment. Even if not illustrated, the fluid supply 15 may contain the carrier fluid and the inflatable glass particles (or one or more components of the resin composition) in separate bins or other containers which may be mixed at any desired time. The pumping equipment 20 may be fluidly coupled to the wellbore supply conduit 25 for conveying the carrier fluid and / or the resin composition into the wellbore. The fluid handling system 10 may also include surface and bottom well sensors (not shown) to measure pressure, velocity, temperature, and / or other processing parameters. The fluid handling system 2 may also include pump controls and / or other types of controls for starting, stopping and / or otherwise controlling the pumping as well as controls for selecting and / or otherwise controlling the pumped fluids. during injection treatment. An injection control system can communicate with such equipment to monitor and control the injection treatment. The fluid handling system 10 may be configured as illustrated in Figure 1 or in a different manner, and may include additional or different features as appropriate. The fluid handling system 10 may be deployed through a chassis system, may be deployed on a marine vessel or may be part of equipment deployed under the sea.
    Referring now to Figure 2, an exemplary well system 30 is illustrated. As illustrated, the well system 30 may include a fluid handling system 10, which may include a fluid supply 15, a pumping equipment 20 and a wellbore supply conduit 25. As it has been previously described in connection with FIG. 1, the pumping equipment 20 may be fluidly coupled with the wellbore supply conduit 25 for conveying the support fluid into the wellbore 40. As shown in FIG. the fluid supply 15 and the pumping equipment 20 may be above the surface 35 while the wellbore 40 is below the surface. The well system 30 may be configured as illustrated in Figure 2 or in a different manner, and may include additional or different features as appropriate.
    As illustrated in FIG. 2, the well system 30 can be used for the introduction of the inflatable glass particles 45, described here, into an underground formation 50 surrounded by a wellbore 40. In general the wellbore 40 may include vertical, bent, curved, and other geometry or orientation borehole geometries and orientations, and the inflatable glass particles 45 may generally be applied to the subterranean formation 50 Surrounding any portion of the wellbore 14. As illustrated, the wellbore 40 may include casing 55 (eg, surface casing) that may be cemented (or otherwise attached) to the wall of the wellbore. A well duct 65 such as coiled casing, production casing, any suitable duct may be placed inside the casing 55 in the wellbore 40. Well 65 may be the same conduit or conduit different from the wellbore supply conduit 25. For example, a well conduit 65 may be an extension of the wellbore supply conduit into the wellbore 25. 40 or may be a casing or other duct which is coupled to the supply conduit of the wellbore 25.
    A carrier fluid comprising the inflatable glass particles 45 may be pumped from the fluid supply 15 into the well conduit 65 into the wellbore 40. flow down the interior of the well conduit 65, exit the well conduit 65 and finally enter the subterranean formation 50 surrounding the wellbore 40, as shown in FIG. 2 by arrows 70. As illustrated, the carrier fluid comprising the inflatable glass particles 45 can be introduced into the zone 75 of the subterranean formation 50. The zone 75 can be any part of the subterranean formation 50 containing flow paths through which the fluid can flow undesirably. As an example, zone 75 may include, but is not limited to, cracks, cracks, fractures, ore belts, flow channels, cavities, highly permeable ore belts, annular cavities, or combinations of those as well as any other area in the subterranean formation 50 through which there may be an undesirable flow of fluid. The support fluid may leak into the subterranean formation 50 or may be recovered at the surface 35, depositing the inflatable glass particles 45 in the zone 75 of the subterranean formation 50.
    Referring now to FIG. 3, a resin composition is then pumped from the fluid supply 15 down into the interior of the well conduit 65 into the wellbore 40. the resin composition flows down the interior of the well conduit 65, out of the well conduit 65 and ultimately into the subterranean formation 50 surrounding the wellbore 40 as it is illustrated in Figure 3 by arrows 80. As illustrated, the resin composition can be introduced into the zone 75 of the subterranean formation 50 in which the inflatable glass particles 45 have been placed. The resin composition may contact the inflatable glass particles 45, resulting in swelling of the inflatable glass particles 45. In the area 45, the resin composition may cure to form a solidified mass, which is illustrated in FIG. As the cured resin 85. The cured resin 85 with the inflatable particles 45 can reduce the flow of fluid in the zone 75 of the subterranean formation 50, thereby potentially restricting and preventing the flow of fluid in the wellbore 40 through the area. 75. The cured resin 85 with the inflatable particles 45 can also restrict and potentially prevent the flow of fluid from the wellbore 40 to the zone 75, thereby relieving potential problems of loss of circulation in the wellbore 40. since drilling and other operations in the wellbore 40 had to be stopped for the introduction of the resin composition and For example, in order to control the loss of circulation, such drilling or other operations may recommence once the resin has cured and the inflatable glass particles 45 placed in the zone 75.
    Examples of inflatable glass particles and / or resin disclosed herein can directly or indirectly affect one or more components or pieces of equipment associated with the preparation, introduction, recapture, recycling, reuse and / or or removing the compositions of inflatable glass particles and resin. For example, the inflatable glass particles and / or the resins may directly or indirectly affect the one or more mixers, related mixing equipment, settling ponds, storage facilities or units, composition separators, exchangers heat exchangers, sensors, gauges, pumps, compressors and similar apparatuses used to produce, store, track, regulate and / or recondition examples of inflatable glass particles and / or resins. The inflatable glass particles and / or resins may also directly or indirectly affect any transport or delivery equipment used to transport the inflatable glass particles and / or resins to a well site or the bottom of a well such as for example, transport containers, pipes, pipelines, trucks, tubes and / or pipes used to move the particles of the inflatable glass and / or the resins from one location to another, pumps, compressors or motors (eg, upper or lower-sided) used to put the inflatable glass particles and / or resins in motion, any valves or related joints used to regulate the pressure or flow of the inflatable glass particles and or the resins, and any sensor (ie, pressure and temperature), gauges and / or combinations thereof, etc. The inflatable glass particles and / or resins can also directly or indirectly affect the various downhole equipment and tools that could come into contact with the inflatable glass particles and / or resins such as, without limitation, casing. wellbore, a wellbore liner, a completion train, an insert train, a drill pipe, a coiled casing, a smooth cable, a cable line, a drill pipe, rod weights, motors sludge, downhole motors and / or pumps, cement pumps, surface mounted motors and / or pumps, centralizers, turboliters, scrapers, floats (eg, hooves , collars, valves, etc.), logging tools and related telemetry equipment, actuators (eg, electromechanical devices, hydromechanical devices, etc.), sliding sleeves, production sleeves, of the plugs, screens, filters, flow control devices (eg, influx control devices, autonomous impulse control devices, output flow control devices, etc.) , couplings (eg electrohydraulic wet couplings, dry couplings, inductive couplings, etc.), control lines (eg, electrical, fiber optic, hydraulic, etc.), drill bit monitoring lines, drilling and reamers, sensors or network of sensors, downhole heat exchangers, valves and corresponding actuators, tool seals, packers, cement plugs, support plugs , and other wellbore isolation devices, or components, etc.
    In order to facilitate a better understanding of the present disclosure, the following examples of certain aspects of certain embodiments are given. The following examples should in no way be interpreted as limiting or defining the overall scope of the embodiments.
    EXAMPLES
    The following example was made to demonstrate the ability of inflatable glass particles, with a resin composition, to reduce the flow of fluid. For this example, the 330 micron medium particle size (D50) inflatable glass particles were obtained from ABSMaterials, Inc., Wooster, Ohio, under the tradename OSORB® inflatable glass. An aqueous suspension was prepared comprising:
    Table 1: Composition of the suspension
    The aqueous suspension was poured into a static fluid loss cell with a 325 mesh screen and a differential pressure of 1000 psi (about 69 bar) was applied. All fluid drained from the fluid loss cell in 8 minutes and 47 seconds. A filter cake containing the inflatable glass particles was retained on the mesh screen. This aqueous suspension had poor fluid loss control because the inflatable glass particles did not block the flow of fluid.
    Then, the pressure was slowly released into the fluid loss cell, and the upper part of the cell was opened to reveal the filter cake of the inflatable glass particles. Then, a resin composition was slowly added to the fluid loss cell so as not to disturb the filter cake. The resin composition comprised:
    Table 2: Composition of the resin
    The epoxy resin was ARALDITE® 506 epoxy resin from Sigma-Aldrich Corp., St. Louis, Missouri. After adding the resin composition, the fluid loss cell was plugged and a differential pressure of 1000 psi (about 69 bar) was applied. The resin composition begins to flow slowly from the bottom of the fluid loss cell as it permeates through the filter cake the inflatable glass particles. The flow velocity dramatically slowed down and stopped 2 minutes and 35 seconds after pressurizing the cell. This is believed to represent the time required for inflatable glass particles to swell upon exposure to the resin composition. The fluid loss cell then maintained the differential pressure of 1000 pounds per square inch (about 69 bar) for the remaining 27 minutes and 25 seconds (total test time of 30 minutes) and no other fluid flowed of the cell during this time. It is believed that the unique performance in this fluid loss test can be attributed to the swelling of the glass particles with the resin composition, since the inflatable glass particles swell in a small space to plug any cavity or any channel for the fluid flow.
    After 30 minutes, the test was stopped and the pressure on the fluid loss cell was slowly removed. Upon examination of the fluid loss cell, it was observed that the inflatable glass particles inflated to occlude almost the entire interior of the fluid loss cell. No liquid resin composition remained above the filter cake, indicating that curing of the resin composition was not hindered by the inflatable glass particles. The resin composition has hardened to form a hard and resistant barrier.
    The same test was repeated except that the inflatable glass particles were not added to the composition of the suspension of Table 1. In this test, the entire volume of the resin composition (125 ml) is passed through the fluid loss cell in 3 minutes. In comparison, the resin composition had only 8 ml of fluid loss over a period of 30 minutes when used with the inflatable glass particles. This indicates that the inflatable glass particles have retained the resin composition preventing it from flowing through the fluid loss cell.
    For the sake of brevity, only certain intervals are explicitly described here. However, intervals from any lower limit may be combined with any upper limit to cover an interval not explicitly indicated, and intervals from any lower limit may be combined with any other lower limit to cover a non-explicitly indicated range of similarly, intervals from any upper limit may be combined with any other upper limit to indicate an interval not explicitly stated. In addition, whenever a numerical range with a lower bound and an upper bound is specified, any inclusive number or range within the range is specifically included. In particular, each range of values (of the form, "from about a to about b" or, equivalently, "from about a to b", or, equivalently, "from about ab") indicated here should be understood as describing each number and interval within the widest range of values if it is not explicitly stated. Thus, each individual point or value may serve its own lower or upper limit combined with any other point or individual value or other lower or upper limit to indicate an interval not explicitly stated.
    Therefore, the exemplary embodiments are well adapted to achieve the objectives and advantages mentioned and also those that are inherent in the present disclosure. The given embodiments disclosed above are illustrative only, since the disclosed embodiments may be modified and practiced in a different but equivalent manner by those skilled in the art who benefit from the teachings of the present disclosure. Although only individual embodiments are described, the disclosure covers any combination of all of these embodiments. In addition, no limitation is provided to the construction or design details described herein, other than those described in the claims below. In addition, the terms in the claims have their clear and ordinary meaning, except in the case of explicit and clear indication other defined by the applicant. It is therefore obvious that the particular illustrative embodiments described above may be altered or modified and any such variations are considered to be within the scope of the present disclosure.
    权利要求:
    Claims (24)
    [1" id="c-fr-0001]
    A well treatment method, characterized by comprising: introducing inflatable glass particles (45) into a zone (75) of a subterranean formation (50); contacting the inflatable glass particles (45) with a resin composition in the area (75); and allowing the resin composition to cure in the area (75) to reduce flow through the area (75).
    [2" id="c-fr-0002]
    The method of claim 1, further comprising pumping a carrier fluid comprising the inflatable glass particles (45) through a well conduit (65) and into the region (75).
    [3" id="c-fr-0003]
    The method of claim 1 or 2, further comprising pumping the resin composition through a well conduit (65) and into the zone (75) to contact the inflatable glass particles (45).
    [4" id="c-fr-0004]
    A method according to any one of claims 1 to 3, wherein at least a portion of the inflatable glass particles (45) swells upon contact with the resin composition to plug openings in the zone (75).
    [5" id="c-fr-0005]
    The method of claim 4, wherein the portion of the inflatable glass particles (45) inflates to a volume greater than about 1.5 times or more of the dry volume of the inflatable glass particles (45).
    [6" id="c-fr-0006]
    The method of any one of claims 1 to 5, wherein the inflatable glass particles (45) each comprise a plurality of interconnected organosilicon nanoparticles.
    [7" id="c-fr-0007]
    The method of any one of claims 1 to 6, wherein the inflatable glass particles (45) each comprise bridged organosiloxane sol-gels comprising a plurality of alkylsoloxy substituents.
    [8" id="c-fr-0008]
    The process according to any one of claims 1 to 7, wherein the inflatable glass particles (45) are introduced into the subterranean formation (50) in a carrier fluid, wherein the carrier fluid is an aqueous fluid and comprises the inflatable glass particles (45) in an amount of about 1.2x10 -3 to about 0.6 kg / L of the support fluid.
    [9" id="c-fr-0009]
    The method of any one of claims 1 to 8, wherein the resin composition comprises a resin and a curing agent.
    [10" id="c-fr-0010]
    The method of claim 9, wherein the resin comprises at least one resin selected from an epoxy resin, a novolac resin, a polyepoxide resin, a phenol aldehyde resin, a urea-aldehyde resin, a resin of urethane, phenolic resin, furan / furfuryl alcohol resin, phenolic resin / latex, phenol formaldehyde resin, bisphenol A diglycidyl ether resin, butoxymethyl butyl glycidyl ether resin, bisphenol A resin epichlorohydrin, a bisphenol F resin, a glycidyl ether resin, a polyester resin and the hybrids and copolymers thereof, a polyurethane resin and the hybrids and copolymers thereof, an acrylate resin and mixtures thereof, and wherein the curing agent comprises at least one curing agent selected from an aliphatic amine, an aliphatic tertiary amine, an aromatic amine, a cycloaliphatic mine, heterocyclic amine, amido amine, polyamides, polyethyl amine, polyether amine, polyoxyalkylene amine, carboxylic anhydrides, triethylenetraamine, diamine ethylene, N-cocoalkyltrimethylene, isophorone diamine, N-aminophenyl piperazine, imidazoline, 1,2-diaminocyclohexane, polytheramine, diethyltoluenediamine, 4,4'-diaminodiphenylmethane, methyltetrahydrophthalic anhydride, hexahydrophthalic anhydride, maleic anhydride, polyazelaic polyanhydride , phthalic anhydride, and combinations thereof.
    [11" id="c-fr-0011]
    The process according to claim 9 or 10, wherein the resin composition further comprises a diluent selected from butyl glycidyl ether, cyclohexane dimethanol diglycidyl ether, polyethylene glycol, butyl lactate, methyl ether, and the like. dipropylene glycol, dimethyl ether dipropylene glycol, dimethyl formamide, diethylene glycol methyl ether, ethylene glycol butyl ether, diethylene glycol butyl ether, propylene carbonate, iimonene, the methyl esters of the fatty acid, or any combination thereof.
    [12" id="c-fr-0012]
    The method of any one of claims 1 to 11, further comprising identifying a traffic loss area, wherein the area of loss of circulation is the area (75).
    [13" id="c-fr-0013]
    13. Loss of circulation composition, characterized in that it comprises: a resin composition; and inflatable glass particles (45).
    [14" id="c-fr-0014]
    The circulation loss composition of claim 13, wherein the inflatable glass particles (45) are dispersed in the resin composition and wherein at least a portion of the inflatable glass particles (45) are inflated to a volume about 1.5 times or more of the dry volume of the inflatable glass particles (45).
    [15" id="c-fr-0015]
    The circulation loss composition of claim 13 or 14, wherein the resin composition is cured to form a solidified mass.
    [16" id="c-fr-0016]
    16. A circulation loss composition according to any one of claims 13 to 15, wherein the inflatable glass particles each comprise a plurality of interconnected organosilicon nanoparticles.
    [17" id="c-fr-0017]
    Well system (30), characterized in that it comprises: a fluid supply (15) comprising: a support fluid comprising inflatable glass particles (45); and a resin composition, wherein the inflatable glass particles (45) are not in contact with the resin composition in the fluid supply (15); and pumping equipment (20) configured to pump the carrier fluid and / or the resin composition into a wellbore (40).
    [18" id="c-fr-0018]
    The well system (30) of claim 17, wherein the support fluid and the resin composition are contained in separate containers.
    [19" id="c-fr-0019]
    The well system (30) of claim 17 or 18, further comprising a well supply conduit (25) in fluid communication with a wellbore (40).
    [20" id="c-fr-0020]
    The well system (30) according to any one of claims 17 to 19, wherein the inflatable glass particles (45) each comprise a plurality of interconnected organosilicon nanoparticles.
    [21" id="c-fr-0021]
    The well system (30) according to any one of claims 17 to 20, wherein the support fluid is an aqueous fluid and comprises the inflatable glass particles (45) in an amount of about 1.2x10 " 4 to about 0.6 kg / L of the support fluid.
    [22" id="c-fr-0022]
    The well system (30) of any one of claims 17 to 21, wherein the resin composition comprises a resin and a curing agent.
    [23" id="c-fr-0023]
    The well system (30) of claim 22, wherein the resin comprises at least one resin selected from an epoxy resin, a novolac resin, a polyepoxide resin, a phenol aldehyde resin, a urea resin aldehyde, a urethane resin, a phenolic resin, a furan / furfuryl alcohol resin, a phenolic resin / latex, a phenol formaldehyde resin, a bisphenol A diglycidyl ether resin, a butoxymethyl butyl glycidyl ether resin, a bisphenol A-epichlorohydrin resin, a bisphenol F resin, a glycidyl ether resin, a polyester resin and the hybrids and copolymers thereof, a polyurethane resin and the hybrids and copolymers thereof, an acrylate resin, and mixtures thereof, and wherein the curing agent comprises at least one curing agent selected from an aliphatic amine, an aliphatic tertiary amine, an arine amine, and a cycloaliphatic amine, a heterocyclic amine, an amido amido, polyamides, a polyethyl amine, a polyether amine, a polyoxyalkylene amine, carboxylic anhydrides, triethylenetraamine, diamine ethylene, N-cocoalkyltrimethylene, isophorone diamine, N-aminophenyl piperazine, imidazoline, 1,2-diaminocyclohexane, polytheramine, diethyltoluenediamine, 4,4'-diaminodiphenyl methane, methyltetrahydrophthalic anhydride, hexahydrophthalic anhydride, maleic anhydride, polyanhydride polyazelaic, phthalic anhydride, and combinations thereof
    [24" id="c-fr-0024]
    A well system (30) according to claim 22 or 23, wherein the resin composition further comprises a diluent selected from butyl glycidyl ether, cyclohexane dimethanol diglycidyl ether, polyethylene glycol, butyl lactate, methyl dipropylene glycol ether, dimethyl dipropylene glycol ether, dimethyl formamide, diethylene glycol methyl ether, ethylene glycol butyl ether, diethylene glycol butyl ether, propylene carbonate , iimonene, the methyl esters of the fatty acid, or any combination thereof.
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    WO2015183319A1|2015-12-03|Resin compositions used with alkali metal salts
    同族专利:
    公开号 | 公开日
    AU2015401505A1|2017-12-07|
    CA2987542A1|2017-01-12|
    US20180155605A1|2018-06-07|
    WO2017007472A1|2017-01-12|
    GB2555301B|2021-10-20|
    MX2017016282A|2018-04-20|
    GB2555301A|2018-04-25|
    GB201719812D0|2018-01-10|
    US10907085B2|2021-02-02|
    NO20171898A1|2017-11-28|
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    法律状态:
    2017-04-12| PLFP| Fee payment|Year of fee payment: 2 |
    2018-04-25| PLFP| Fee payment|Year of fee payment: 3 |
    2020-03-13| ST| Notification of lapse|Effective date: 20200206 |
    优先权:
    申请号 | 申请日 | 专利标题
    PCT/US2015/039591|WO2017007472A1|2015-07-08|2015-07-08|Swellable glass particles for reducing fluid flow in subterranean formations|
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