WO2005017313A1 - Compositions et procedes permettant de reguler la liberation de substances chimiques situees sur des particules - Google Patents
Compositions et procedes permettant de reguler la liberation de substances chimiques situees sur des particulesInfo
- Publication number
- WO2005017313A1 WO2005017313A1 PCT/GB2004/002715 GB2004002715W WO2005017313A1 WO 2005017313 A1 WO2005017313 A1 WO 2005017313A1 GB 2004002715 W GB2004002715 W GB 2004002715W WO 2005017313 A1 WO2005017313 A1 WO 2005017313A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- poly
- particulate material
- treating agent
- cement slurry
- particulate
- Prior art date
Links
- 238000000034 method Methods 0.000 title claims abstract description 47
- 239000000203 mixture Substances 0.000 title claims abstract description 18
- 239000000126 substance Substances 0.000 title description 8
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 63
- 239000011236 particulate material Substances 0.000 claims abstract description 62
- 239000000463 material Substances 0.000 claims abstract description 48
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 43
- 238000000576 coating method Methods 0.000 claims abstract description 38
- 239000011248 coating agent Substances 0.000 claims abstract description 37
- -1 poly(orthoester) Polymers 0.000 claims description 41
- 239000002002 slurry Substances 0.000 claims description 31
- 239000004568 cement Substances 0.000 claims description 30
- 239000012530 fluid Substances 0.000 claims description 20
- YMWUJEATGCHHMB-UHFFFAOYSA-N Dichloromethane Chemical compound ClCCl YMWUJEATGCHHMB-UHFFFAOYSA-N 0.000 claims description 15
- KFZMGEQAYNKOFK-UHFFFAOYSA-N Isopropanol Chemical compound CC(C)O KFZMGEQAYNKOFK-UHFFFAOYSA-N 0.000 claims description 15
- 239000002904 solvent Substances 0.000 claims description 14
- 239000003112 inhibitor Substances 0.000 claims description 12
- 239000000654 additive Substances 0.000 claims description 11
- 150000002148 esters Chemical class 0.000 claims description 11
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 11
- CSCPPACGZOOCGX-UHFFFAOYSA-N Acetone Chemical compound CC(C)=O CSCPPACGZOOCGX-UHFFFAOYSA-N 0.000 claims description 10
- 239000002253 acid Substances 0.000 claims description 7
- 102000004190 Enzymes Human genes 0.000 claims description 6
- 108090000790 Enzymes Proteins 0.000 claims description 6
- 239000003139 biocide Substances 0.000 claims description 6
- 230000007797 corrosion Effects 0.000 claims description 6
- 238000005260 corrosion Methods 0.000 claims description 6
- 239000012188 paraffin wax Substances 0.000 claims description 6
- 239000002455 scale inhibitor Substances 0.000 claims description 6
- CUDYYMUUJHLCGZ-UHFFFAOYSA-N 2-(2-methoxypropoxy)propan-1-ol Chemical compound COC(C)COC(C)CO CUDYYMUUJHLCGZ-UHFFFAOYSA-N 0.000 claims description 5
- 229920000331 Polyhydroxybutyrate Polymers 0.000 claims description 5
- 229920001710 Polyorthoester Polymers 0.000 claims description 5
- 229920003232 aliphatic polyester Polymers 0.000 claims description 5
- 150000008064 anhydrides Chemical class 0.000 claims description 5
- 239000002270 dispersing agent Substances 0.000 claims description 5
- 239000005015 poly(hydroxybutyrate) Substances 0.000 claims description 5
- 229920000747 poly(lactic acid) Polymers 0.000 claims description 5
- RUOJZAUFBMNUDX-UHFFFAOYSA-N propylene carbonate Chemical compound CC1COC(=O)O1 RUOJZAUFBMNUDX-UHFFFAOYSA-N 0.000 claims description 5
- 239000000375 suspending agent Substances 0.000 claims description 5
- 230000009974 thixotropic effect Effects 0.000 claims description 5
- 150000002905 orthoesters Chemical class 0.000 claims description 4
- 229920001308 poly(aminoacid) Polymers 0.000 claims description 4
- 229920001610 polycaprolactone Polymers 0.000 claims description 4
- 230000000996 additive effect Effects 0.000 claims 8
- RKDVKSZUMVYZHH-UHFFFAOYSA-N 1,4-dioxane-2,5-dione Chemical compound O=C1COC(=O)CO1 RKDVKSZUMVYZHH-UHFFFAOYSA-N 0.000 claims 4
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 claims 4
- 125000001931 aliphatic group Chemical group 0.000 claims 4
- 230000003115 biocidal effect Effects 0.000 claims 4
- JJTUDXZGHPGLLC-UHFFFAOYSA-N lactide Chemical compound CC1OC(=O)C(C)OC1=O JJTUDXZGHPGLLC-UHFFFAOYSA-N 0.000 claims 4
- 239000007800 oxidant agent Substances 0.000 claims 4
- 229940065514 poly(lactide) Drugs 0.000 claims 4
- 239000002745 poly(ortho ester) Substances 0.000 claims 4
- 229920002627 poly(phosphazenes) Polymers 0.000 claims 4
- 229920000515 polycarbonate Polymers 0.000 claims 4
- 239000004417 polycarbonate Substances 0.000 claims 4
- 150000001413 amino acids Chemical class 0.000 claims 1
- PAPBSGBWRJIAAV-UHFFFAOYSA-N ε-Caprolactone Chemical compound O=C1CCCCCO1 PAPBSGBWRJIAAV-UHFFFAOYSA-N 0.000 claims 1
- 238000005755 formation reaction Methods 0.000 description 38
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 8
- 239000004576 sand Substances 0.000 description 7
- 230000008901 benefit Effects 0.000 description 4
- 238000011282 treatment Methods 0.000 description 4
- 230000015556 catabolic process Effects 0.000 description 3
- 238000006731 degradation reaction Methods 0.000 description 3
- 238000002156 mixing Methods 0.000 description 3
- 238000012856 packing Methods 0.000 description 3
- 239000002245 particle Substances 0.000 description 3
- 229920000642 polymer Polymers 0.000 description 3
- 230000002411 adverse Effects 0.000 description 2
- 230000004888 barrier function Effects 0.000 description 2
- 239000007857 degradation product Substances 0.000 description 2
- 230000007613 environmental effect Effects 0.000 description 2
- JVTAAEKCZFNVCJ-UHFFFAOYSA-N lactic acid Chemical compound CC(O)C(O)=O JVTAAEKCZFNVCJ-UHFFFAOYSA-N 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 239000008188 pellet Substances 0.000 description 2
- 238000005204 segregation Methods 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 238000001179 sorption measurement Methods 0.000 description 2
- 229910011255 B2O3 Inorganic materials 0.000 description 1
- 241000545744 Hirudinea Species 0.000 description 1
- 240000007049 Juglans regia Species 0.000 description 1
- 235000009496 Juglans regia Nutrition 0.000 description 1
- 239000004677 Nylon Substances 0.000 description 1
- 229920002732 Polyanhydride Polymers 0.000 description 1
- 239000006004 Quartz sand Substances 0.000 description 1
- 150000007513 acids Chemical class 0.000 description 1
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 1
- 229910001570 bauxite Inorganic materials 0.000 description 1
- 239000011324 bead Substances 0.000 description 1
- 150000001721 carbon Chemical class 0.000 description 1
- 239000000919 ceramic Substances 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 238000000354 decomposition reaction Methods 0.000 description 1
- 230000006735 deficit Effects 0.000 description 1
- 230000008021 deposition Effects 0.000 description 1
- 238000000151 deposition Methods 0.000 description 1
- 230000000994 depressogenic effect Effects 0.000 description 1
- JKWMSGQKBLHBQQ-UHFFFAOYSA-N diboron trioxide Chemical compound O=BOB=O JKWMSGQKBLHBQQ-UHFFFAOYSA-N 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000000839 emulsion Substances 0.000 description 1
- 230000002255 enzymatic effect Effects 0.000 description 1
- 239000000835 fiber Substances 0.000 description 1
- 239000006260 foam Substances 0.000 description 1
- 239000002223 garnet Substances 0.000 description 1
- 239000000499 gel Substances 0.000 description 1
- 239000011521 glass Substances 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 230000007062 hydrolysis Effects 0.000 description 1
- 238000006460 hydrolysis reaction Methods 0.000 description 1
- 238000005470 impregnation Methods 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 230000001788 irregular Effects 0.000 description 1
- 230000002427 irreversible effect Effects 0.000 description 1
- 235000014655 lactic acid Nutrition 0.000 description 1
- 239000004310 lactic acid Substances 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- 244000005700 microbiome Species 0.000 description 1
- 230000005012 migration Effects 0.000 description 1
- 238000013508 migration Methods 0.000 description 1
- 229920005615 natural polymer Polymers 0.000 description 1
- 230000007935 neutral effect Effects 0.000 description 1
- 229920001778 nylon Polymers 0.000 description 1
- 230000003647 oxidation Effects 0.000 description 1
- 238000007254 oxidation reaction Methods 0.000 description 1
- 229910052760 oxygen Inorganic materials 0.000 description 1
- 239000001301 oxygen Substances 0.000 description 1
- 230000002028 premature Effects 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 239000000047 product Substances 0.000 description 1
- 230000003252 repetitive effect Effects 0.000 description 1
- 239000012508 resin bead Substances 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 239000011343 solid material Substances 0.000 description 1
- 238000005507 spraying Methods 0.000 description 1
- 229920001059 synthetic polymer Polymers 0.000 description 1
- 235000020234 walnut Nutrition 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/70—Compositions for forming crevices or fractures characterised by their form or by the form of their components, e.g. foams
- C09K8/706—Encapsulated breakers
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/516—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
- C09K8/536—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/80—Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/04—Gravelling of wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
- Y10T428/00—Stock material or miscellaneous articles
- Y10T428/29—Coated or structually defined flake, particle, cell, strand, strand portion, rod, filament, macroscopic fiber or mass thereof
- Y10T428/2982—Particulate matter [e.g., sphere, flake, etc.]
- Y10T428/2991—Coated
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
- Y10T428/00—Stock material or miscellaneous articles
- Y10T428/29—Coated or structually defined flake, particle, cell, strand, strand portion, rod, filament, macroscopic fiber or mass thereof
- Y10T428/2982—Particulate matter [e.g., sphere, flake, etc.]
- Y10T428/2991—Coated
- Y10T428/2998—Coated including synthetic resin or polymer
Definitions
- the present invention relates to methods and compositions for treating subterranean formations, and more specifically, to improved methods for creating and using particulate materials having treating agents absorbed thereon and coated with a degradable coating material.
- a subterranean formation may be treated to increase its conductivity by hydraulically fracturing the formation to create one or more cracks or "fractures.”
- Such hydraulic fracturing is usually accomplished by injecting a viscous fracturing fluid into a subterranean formation at a rate and pressure sufficient to cause the formation to break down and produce one or more fractures.
- the fracture or fractures may be horizontal or vertical, with the latter usually predominating, and with the tendency toward vertical fractures increasing with the depth of the formation being fractured.
- the fracturing fluid is generally a gel, emulsion, or foam that may comprise a particulate material often referred to as a proppant.
- the proppant When used, the proppant is deposited in the fracture to prevent the fracture from fully closing and to maintain conductive channels through which produced fluids can flow upon completion of the fracturing treatment and release of the attendant hydraulic pressure.
- Sand control treatments may be used to reduce the migration of unconsolidated formation particulates into the wellbore.
- One such sand control treatment involves the use of a "gravel pack.”
- One common type of gravel packing operation involves placing a gravel pack screen in the well bore and packing the surrounding annulus between the screen and the well bore with gravel of a specific size designed to prevent the passage of formation sand.
- the gravel pack screen is generally a filter assembly used to retain the gravel placed during gravel pack operation.
- a wide range of sizes and screen configurations are available to suit the characteristics of the gravel used.
- a wide range of sizes of gravel is available to suit the characteristics of the unconsolidated or poorly consolidated particulates in the subterranean formation.
- the resulting structure presents a barrier to migrating sand from the formation while still permitting fluid flow.
- the gravel pack When installing the gravel pack, the gravel is carried to the formation in the form of a slurry by mixing the gravel with a transport fluid. Gravel packs act, inter alia, to stabilize the formation while causing minimal impairment to well productivity.
- particulates also may be used to carry a variety of treating agents that may be useful in the subterranean zone. Treating agents may be placed onto particulate material by, for example, impregnation, deposition, or adsorption thereon. Examples of such treating agents include, but are not limited to, gel breakers, scale inhibitors, biocides, corrosion inhibitors, paraffin inhibitors, and other any other treating agent that does not adversely impact the formation or the proppant pack.
- treating agents placed on particulate material and introduced into a subterranean zone often dissolve into the fluids present in the subterranean zone too rapidly.
- the treating agents dissolve too rapidly, they may not remain in the subterranean formation for a long enough period of time or may not be delivered to the desired location in the subterranean formation.
- High sheer rates in the subterranean zone, high temperature, and solubility and interaction with delivery and formation fluids are factors known to increase the rate at which the treating agents dissolve off of the particulate material.
- the present invention relates to methods and compositions for treating subterranean formations, and more specifically, to improved methods for creating and using particulate materials having treating agents absorbed thereon and coated with a degradable coating material.
- One embodiment of a method of the present invention provides a method of treating to a subterranean foraiation comprising placing a coated, treated particulate into a subterranean formation wherein the coated, treated particulate comprises a particulate material having a treating agent placed thereon and a substantially complete layer of a degradable coating material placed thereon over the treating agent.
- Another embodiment of the present invention provides a chemically treated, coated particulate material comprising a particulate material having a treating agent placed thereon and a substantially complete layer of a degradable coating material coated placed thereon over the treating agent.
- treating agents are adsorbed onto a particulate material, such as proppant or gravel, for introduction into a subterranean formation.
- a particulate material such as proppant or gravel
- the particulate material is coated with a degradable coating material that temporarily shields the chemical from the fluids present in the subterranean formation until at least a portion of the coating degrades away, at which point the treating agent is exposed to the fluids in the subterranean formation and begins to be released.
- a coated and treated particulate is mixed with a liquid such as a servicing fluid, the treating agent is gradually released into the servicing fluid as the degradable coating gradually degrades or dissolves.
- any particulate material suitable for use in conjunction with subterranean applications is suitable for use as the particulate material in the compositions and methods of the present invention.
- natural sand, quartz sand, garnet, glass, walnut hulls, nylon pellets, bauxite, ceramics, polymeric materials, carbon composites, natural or synthetic polymers, resin beads, and mixtures thereof are suitable.
- Suitable sizes range from 4 to 100 U.S. mesh, in certain preferred embodiments the sizes range from 10 to 60 US mesh.
- the proppant particles may be in any form, including that of regular or irregular pellets, fibers, flakes, ribbons, beads, shavings, platelets and the like.
- the particulate material it is preferable for the particulate material to exhibit a surface geometry such that at least one recessed or depressed area exists along the surface of the particulate.
- a particulate surface geometry is referred to herein as porous, or partially hollow.
- the methods of the present invention can be used to deliver almost any treating agent, including but not limited to gel breakers, acids, oxidizers, enzymes, hydrolyzable esters, scale inhibitors, biocides, corrosion inhibitors, paraffin inhibitors, cement slurry set accelerators, cement slurry set retarders, cement slurry dispersants, cement slurry fluid loss control additives, cement slurry thixotropic additives, cement slurry suspending agents, or substantially any other chemical that is soluble in the formation fluids under the environmental conditions of the formation within which it is placed.
- the degradable coating material of the present invention protects the treating agent from exposure to the formation fluids and environmental conditions until that degradable coating degrades away.
- the treating agent may be impregnated, deposited, coated, permeated, or saturated onto the particulate material.
- the term "adsorbed” will be used to refer to any method known in the art to incorporate a chemical with a solid particulate. Any such method known in the art that allows a treating agent to be physically incorporated with a particulate material in a manner in which it is later able to leech off of the particulate material is suitable for use in the present invention.
- a liquid treating agent is adsorbed onto a particulate material by simply spraying the treating agent onto the particulate material in an amount such that the particulate material surface is substantially dry after the adsorption is substantially complete.
- Another method involves mixing the treating agent with a solvent, adsorbing the solvent/agent mixture onto the particulate material, and then allowing the solvent to substantially evaporate from the surface of the particulate over time or under vacuum conditions. This method may be used where the treating agent is solid at room temperature to facilitate the coating process.
- the amount of treating agent absorbed onto the particulate material ranged from about 0.1% to about 50% by weight of the particulate material.
- the amounts of treating agent adsorbed onto the particulate can be several times the weight of the particulate depending on the agent chosen and the desired effect.
- the degradable coating materials suitable for use in the present invention are those compounds that degrade over time in the subterranean formation. Any material capable of acting as a temporary barrier between the fluids in the subterranean formation and the chemical carried on the particulate material and that does not undesirably interfere with the subterranean formation, the particulate, or the treating agent is suitable for use as a coating material in the present invention. It is not necessary for the degradable coating material to cover 100% of the surface area of the impregnated particulate.
- the degradable coating material need only cover enough of the particulate's surface area to delay the release of the adsorbed treating agent in the formation to a desired extent.
- the surface area is coated to a sufficient extent as to allow the particulates to be placed in a desirable location in the subterranean formation before the majority of the treating agent is released.
- Degradable materials that may be used in conjunction with the present invention are those materials than can be coated onto a particulate and, in preferred embodiments, are substantially water insoluble such that they degrade over time, rather than instantaneously.
- suitable degradable materials include substantially water insoluble esters such as ortho esters; poly(orthoesters); aliphatic polyesters; lactides, poly(lactides); glycolides; poly(glycolides); poly( ⁇ -caprolactone); poly(hydroxybutyrate); substantially water insoluble anhydrides; poly(anhydrides); and poly(amino acids).
- Polymers suitable for use as a degradable material of the present invention may be considered degradable if the degradation is due, inter alia, to chemical and/or radical process such as hydrolysis, oxidation, or enzymatic decomposition.
- the degradability of a polymer depends at least in part on its backbone structure, type of repetitive unit, composition, sequence, length, molecular geometry, molecular weight, morphology (e.g., crystallinity, size of spherulites, and orientation), hydrophilicity, hydrophobicity, surface area, and additives. Also, the environment to which the polymer is subjected may affect how it degrades, e.g., temperature, presence of moisture, oxygen, microorganisms, enzymes, pH, and the like. Blends of certain degradable materials may also be suitable as the degradable coating materials of the present invention.
- a suitable blend of materials is a mixture of ⁇ oly(lactic acid) and a poly(anhydride) where the mixing of an acid and base could result in a neutral solution where this is desirable.
- Another example would include a blend of polyQactic acid) and boric oxide.
- Other materials that undergo an irreversible degradation may also be suitable, if the products of the degradation do not undesirably interfere with either the conductivity of the proppant matrix or with the production of any of the fluids from the subterranean formation. In choosing the appropriate degradable material, one should consider the degradation products that will result. The degradation products should not adversely affect other operations or components.
- degradable material also can depend, at least in part, on the conditions of the well, e.g., wellbore temperature. For instance, lactides have been found to be suitable for lower temperature wells, including those within the range of 60°F to 150°F, and polylactides have been found to be suitable for well bore temperatures above this range.
- a preferable result is achieved if the degradable material degrades slowly over time as opposed to instantaneously. Even more preferable results have been obtained when the degradable material does not substantially degrade until after the particulate impregnated with a treating agent has been placed in a desired location in the subterranean formation.
- the coating material does not substantially degrade until after the operation delivering the particulate, such as a fracturing operation or gravel packing operation, is substantially complete.
- the chosen degradable coating material is a solid material at ambient temperatures it may be advantageous to mix it with a solvent to facilitate the coating of the degradable coating material onto the particulate material.
- solvents include, but are not limited to acetone, propylene carbonate, dipropylene glycol methyl ether, methylene chloride, isopropyl alcohol, and combinations thereof.
- the particle material is coated with from about 0.1% to about 30% degradable coating material by weight of the particulate material. In some embodiments of the present invention, all of the treated particle material used in the subterranean operation is coated with a degradable coating material while in other embodiments, only a portion of the particulate material is coated. It is within the ability of one skilled in the art, with the benefit of this disclosure, to determine the thickness of degradable coating that should be applied to the treated particulate material and the percentage of the treated particulate material that should be coated.
- a treating agent is absorbed onto a particulate material after which the absorbed particulate material is coated with a degradable coating material and the absorbed, coated particulate material is placed into a subterranean formation. Once in the formation, the coating material degrades off of the particulate material, exposing the treating agent, which is then released into the subterranean formation. Therefore, the present invention is well adapted to carry out the objects and attain the ends and advantages mentioned as well as those that are inherent therein. While numerous changes may be made by those skilled in the art, such changes are encompassed within the spirit and scope of this invention as defined by the appended claims.
Abstract
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/634,705 US20050028976A1 (en) | 2003-08-05 | 2003-08-05 | Compositions and methods for controlling the release of chemicals placed on particulates |
US10/634,705 | 2003-08-05 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2005017313A1 true WO2005017313A1 (fr) | 2005-02-24 |
Family
ID=34116092
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/GB2004/002715 WO2005017313A1 (fr) | 2003-08-05 | 2004-06-24 | Compositions et procedes permettant de reguler la liberation de substances chimiques situees sur des particules |
Country Status (2)
Country | Link |
---|---|
US (1) | US20050028976A1 (fr) |
WO (1) | WO2005017313A1 (fr) |
Cited By (20)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB2448442A (en) * | 2004-12-15 | 2008-10-15 | Bj Services Co | Treatment agent adsorbed on a water-insoluble adsorbent |
WO2009016549A2 (fr) * | 2007-07-27 | 2009-02-05 | Schlumberger Canada Limited | Système, procédé et appareil pour la fracturation acide avec la protection par un inhibiteur de tartre |
WO2009016545A2 (fr) * | 2007-07-27 | 2009-02-05 | Schlumberger Canada Limited | Système, procédé et appareil pour une combinaison d'un traitement de fracturation et d'une inhibition de tartre |
US7491682B2 (en) | 2004-12-15 | 2009-02-17 | Bj Services Company | Method of inhibiting or controlling formation of inorganic scales |
US7598209B2 (en) | 2006-01-26 | 2009-10-06 | Bj Services Company | Porous composites containing hydrocarbon-soluble well treatment agents and methods for using the same |
US7886822B2 (en) | 2007-07-27 | 2011-02-15 | Schlumberger Technology Corporation | System, method, and apparatus for acid fracturing with scale inhibitor protection |
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