WO2007033489A2 - Slurry compositions and methods for making same - Google Patents

Slurry compositions and methods for making same Download PDF

Info

Publication number
WO2007033489A2
WO2007033489A2 PCT/CA2006/001567 CA2006001567W WO2007033489A2 WO 2007033489 A2 WO2007033489 A2 WO 2007033489A2 CA 2006001567 W CA2006001567 W CA 2006001567W WO 2007033489 A2 WO2007033489 A2 WO 2007033489A2
Authority
WO
WIPO (PCT)
Prior art keywords
och
polysiloxane
group
particulates
composition
Prior art date
Application number
PCT/CA2006/001567
Other languages
French (fr)
Other versions
WO2007033489A3 (en
Inventor
Kewei Zhang
Original Assignee
Trican Well Service Ltd.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Trican Well Service Ltd. filed Critical Trican Well Service Ltd.
Priority to BRPI0617261-0A priority Critical patent/BRPI0617261A2/en
Priority to AU2006294332A priority patent/AU2006294332B2/en
Priority to EA200800891A priority patent/EA024720B1/en
Priority to EP06790733A priority patent/EP1934287A4/en
Priority to CN200680034823XA priority patent/CN101268150B/en
Publication of WO2007033489A2 publication Critical patent/WO2007033489A2/en
Publication of WO2007033489A3 publication Critical patent/WO2007033489A3/en
Priority to NO20081926A priority patent/NO20081926L/en

Links

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
    • C09K8/66—Compositions based on water or polar solvents
    • C09K8/68—Compositions based on water or polar solvents containing organic compounds
    • C—CHEMISTRY; METALLURGY
    • C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
    • C08L—COMPOSITIONS OF MACROMOLECULAR COMPOUNDS
    • C08L83/00—Compositions of macromolecular compounds obtained by reactions forming in the main chain of the macromolecule a linkage containing silicon with or without sulfur, nitrogen, oxygen or carbon only; Compositions of derivatives of such polymers
    • C08L83/04—Polysiloxanes
    • 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
    • C09K8/02—Well-drilling compositions
    • C09K8/04—Aqueous well-drilling compositions
    • C09K8/14—Clay-containing compositions
    • C09K8/18—Clay-containing compositions characterised by the organic compounds
    • C09K8/22—Synthetic organic compounds
    • 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
    • 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

Definitions

  • This invention relates to an aqueous slurry composition and to a method of making such a composition. Discussion of the Prior Art
  • Aqueous particulate slurries are commonly used or encountered in many industries including the petroleum, pipeline, construction and cleaning industries. Slurries are mixtures normally comprising particulates and an aqueous medium and play an essential role in many industrial operations. For example, slurries are used for transporting particulates from one location to another at different distances either above ground, or from the surface to a subterranean formation or from a subterranean formation to the surface.
  • the most commonly used particulates include sand, ceramic particulates, carbonate particulates, glass spheres, bauxite (aluminum oxide) particulates, resin coated particulates and coal particulates.
  • the particulate sizes normally range from about 10 to about 100 US mesh, and the particulate densities are significantly higher than the density of water.
  • the density of sand is at about 2.6 g/cm 3 while the density of water is 1 g/cm 3 .
  • Sand is by far the most commonly used particulate.
  • particulates must be suspended in a liquid medium for a lengthy period at static or/and dynamic conditions.
  • Convention wisdom tells us that the viscosity or viscoelasticity of the liquid medium must be sufficiently high to be able to suspend particulates.
  • the most commonly used method for increasing viscosity or viscoelasticity of an aqueous liquid is by adding a viscosifier, for example, a natural or synthetic polymer or a viscoelastic surfactant to the liquid medium. It is not unusual that a polymer is used with a foaming agent in order to take advantage of both viscoelastic and foaming properties.
  • a polymer is used with a foaming agent in order to take advantage of both viscoelastic and foaming properties.
  • the use of polymers in slurries increases cost and results in operational difficulties.
  • Hydraulic fracturing operations are used extensively in the petroleum industry to enhance oil and gas production.
  • a fracturing fluid is injected through a wellbore into a subterranean formation at a pressure sufficient to initiate fractures, which increase oil and gas production.
  • particulates called proppants, are suspended in the fracturing fluid and transported into fractures as slurry.
  • Proppants include sands, ceramic particulates, bauxite particulates, resin coated sands and other particulates known in the industry. Among them sand is by far the most commonly used proppant.
  • Fracturing fluids in common use include water-based as well as hydrocarbon-based fluids.
  • a polymer or viscoelastic surfactant is normally employed to increase the viscoelasticity of the fluid.
  • the viscoelastic property of the fluids is essential for transporting proppants deep into a formation.
  • fracturing fluid flows back to the surface and the proppants are left in the fracture forming a proppant pack to prevent the fracture from closing after pressure is released.
  • a proppant-filled fracture provides a highly conductive channel that allows oil and/or gas to seep through more efficiently to the wellbore.
  • the conductivity of the proppant pack plays a dominant role in production enhancement. Polymer residues from fracturing fluids are known to greatly reduce the conductivity of the proppant pack.
  • viscoelastic surfactants Compared to polymeric viscosifiers, viscoelastic surfactants cause less damage to formations and proppant packs. However, they are much more expensive.
  • aqueous-based drilling fluids When drilling subterranean formations for oil and gas, aqueous-based drilling fluids are normally used. During drilling large amounts of particles, called cuttings are generated. Cuttings have different sizes ranging from fines to pebbles.
  • the drilling fluid is circulated through the wellbore to make slurry with the cuttings in situ and transports them out of wellbore.
  • polymers as well as clays are added to the drilling fluids to increase their viscosity/ viscoelasticity in order to transport the cuttings efficiently.
  • polymers as well as clay fines can easily penetrate into pores or thin fractures in a formation and reduce formation permeability significantly, especially near wellbore. Reduced formation permeability impedes oil and/or gas production. Therefore it is highly desirable to provide a drilling fluid that can make stable slurry in situ with the cuttings and transport them out of the wellbore, while causing little formation damage.
  • one aspect of the present invention relates to an aqueous slurry compositions, which can be used to form a stable, highly conductive proppant pack, for efficiently transporting proppants into a subterranean formation, and for use in transporting drilling cuttings, coal particulates and sands.
  • the invention also relates to an aqueous slurry composition comprising particulates, an aqueous liquid and a chemical compound that renders the surface of the particulates extremely hydrophobic, and the method of making such slurry composition.
  • the invention still further relates to a slurry composition comprising particulates, an aqueous liquid, a chemical compound that renders the surface of the particulates extremely hydrophobic and a gas, and the method of making such slurry composition.
  • the invention also relates to a slurry composition comprising particulates, an aqueous liquid, a chemical compound that renders the surface of the particulates extremely hydrophobic and a surfactant.
  • the invention also relates to a slurry composition comprising particulates, an aqueous liquid, a chemical compound that renders the surface of the particulates extremely hydrophobic, a surfactant and a gas, and the method of making such slurry composition.
  • the invention also relates to a method of making an aqueous slurry composition comprising steps of first rendering the particulate surface extremely hydrophobic and then mixing the treated particulates with an aqueous liquid, or an aqueous liquid containing a gas.
  • the invention in another aspect also relates to methods of making the aqueous slurry compositions, including for various applications including hydraulic fracturing, drilling, gravel-pack, transportation through pipelines, blasting and tunneling.
  • particulates tend to move cohesively instead as individual grains; the bulk volume of settled particulates tend to be significantly greater than in a slurry formed by convention methods under the same conditions; the particulate pack formed tends to have high conductivity and can be easily dewatered, and the slurry tends to be fluid and stable at static or dynamic conditions without using a viscosifier.
  • the larger bulk volume of the particulate pack indicates a larger porosity and therefore higher conductivity.
  • the interfacial interactions between a solid substrate and a liquid mainly depend on the surface properties of the solid and the surface tension of the liquid.
  • the macroscopic properties of a solid surface can be characterized by observing the shape of a liquid droplet on the solid substrate, which is the result of free energy of the surface, as well as the free energy of the liquid.
  • a liquid does not completely wet a surface, it forms an angle ⁇ , which is known as the contact angle.
  • the contact angle is the angle formed between a solid substrate and the tangent line at the point of contact between a liquid droplet and the solid substrate.
  • the contact angle can be measured directly on macroscopic, smooth, nonporous, planar solid substrates by merely placing a droplet of the liquid or solution on the solid substrate and determining the contact angle by any of number of techniques.
  • the values of contact angles between many solids and aqueous liquid are provided in various books and scientific publications, which will be known to those skilled in the art. It is known that the majority of naturally occurring minerals are hydrophilic. It is also known that certain hydrocarbon compounds, for example, some conventional quaternary surfactants, amine surfactants and cationic polyacrylamides can be used to reduce the surface energy of certain particulates and make the particulate surface less hydrophilic or more hydrophobic.
  • extremely hydrophobic means that the contact angle of water on the solid substrate is greater than about 90°. At such high contact angles, water does not wet the surface of the solid and instead contracts on the solid surface and forms beads.
  • the chemical compounds that can render a particulate surface extremely hydrophobic are referred as “extremely hydrophobic rendering compounds” (EHRC) for the sake of simplicity.
  • EHRC normally are those compounds that contain organosilane or organosiloxane groups.
  • EHRC are able to impart hydrophobicity to solid surface to a level that conventional hydrocarbon surfactants or polymers are not able to achieve.
  • These compounds are known to render many inorganic solid surfaces extremely hydrophobic.
  • Slurries according to the invention can be made on the ground or in situ in a subterranean formation. Such slurries have numerous applications in many industries, including for (a) transporting particulates over various distances, either on the surface of the ground, from the surface to a subterranean formation or from a subterranean formation to the surface, and (b) well service operations including stimulation, drilling, completion, gravel-pack, controlling sand production and the like.
  • a gas can be mixed into the slurries of the invention.
  • gases for use in the slurry include air, carbon dioxide, nitrogen, methane and mixtures thereof.
  • the gas can be introduced into the slurries during preparation thereof. For example, when the slurry is pumped through a pipe, gas such as nitrogen can be introduced into the slurry, or gas such as air can be simply mixed into the slurry through a sufficient rate of agitation.
  • aqueous liquids means water, salt solutions, water containing an alcohol or other organic solvents. It should be understood that the additives other than water in the aqueous liquid are used in amounts or in a manner that does not adversely affect the present invention.
  • the size of particulates in compositions according to the invention is about 10-100 US mesh, which is about 150 to 1400 ⁇ m. It should be understood that the size distribution of particulates can be narrow or wide. Suitable particulates include sands, ceramic particulates, glass beads, bauxite particulates, resin coated sands, carbonates and coal particulates.
  • organosilicon compounds including organosiloxane, organosilane, fluoro-organosiloxane and fluoro-organosilane compounds are commonly used to render various surfaces extremely hydrophobic.
  • organosilicon compounds including organosiloxane, organosilane, fluoro-organosiloxane and fluoro-organosilane compounds are commonly used to render various surfaces extremely hydrophobic.
  • organosilicon compounds including organosiloxane, organosilane, fluoro-organosiloxane and fluoro-organosilane compounds are commonly used to render various surfaces extremely hydrophobic.
  • organosilicon compounds including organosiloxane, organosilane, fluoro-organosiloxane and fluoro-organosilane compounds are commonly used to render various surfaces extremely hydrophobic.
  • organosilicon compounds including organosiloxane, organosilane, fluoro-organosiloxan
  • particulates tend to move cohesively instead as individual grains; the bulk volume of settled particulates tend to be significantly greater than in a slurry formed by convention methods under the same conditions; the particulate pack formed tends to have high conductivity and be easily dewatered, and the slurry tends to be fluid and stable at static or dynamic conditions without using a viscosifier.
  • Organosilanes are compounds containing silicon to carbon bonds.
  • Organosiloxanes are compounds containing Si-O-Si bonds.
  • Polysiloxanes are compounds in which the elements silicon and oxygen alternate in the molecular skeleton, i.e., Si-O-Si bonds are repeated.
  • the simplest polysiloxanes are polydimethylsiloxanes.
  • Polysiloxane compounds can be modified by various organic substitutes having different numbers of carbons, which may contain N, S, or P moieties that impart desired characteristics.
  • cationic polysiloxanes are compounds in which one or two organic cationic groups are attached to the polysiloxane chain, either at the middle or the end.
  • the organic cationic group contains at least 10 carbons and may contain a hydroxyl group or other functional groups containing N or O.
  • the most common organic cationic groups are alkyl amine derivatives including secondary, tertiary and quaternary amines (for example, quaternary polysiloxanes including, quaternary polysiloxanes including mono- as well as di-quaternary polysiloxanes, amido quaternary polysiloxanes, imidazoline quaternary polysiloxanes and carboxy quaternary polysiloxanes.
  • the polysiloxane can be modified by organic amphoteric groups, where one or two organic amphoteric groups are attached to the polysiloxane chain, either at the middle or the end, and include betaine polysiloxanes and phosphobetaine polysiloxanes.
  • the polysiloxane can be modified by organic anionic groups, where one or two organic anionic groups are attached to the polysiloxane chain, either at the middle or the end, including sulfate polysiloxanes, phosphate polysiloxanes, carboxylate polysiloxanes, sulfonate polysiloxanes, thiosulfate polysiloxanes.
  • the organosiloxane compounds also include alkylsiloxanes including hexamethylcyclotrisiloxane, octamethylcyclotetrasiloxane, decamethylcyclopentasiloxane, hexamethyldisiloxane, hexaethyldisiloxane, 1 ,3- divinyl-1 ,1 ,3,3-tetramethyldisiloxane, octamethyltrisiloxane, decamethyltetrasiloxane.
  • alkylsiloxanes including hexamethylcyclotrisiloxane, octamethylcyclotetrasiloxane, decamethylcyclopentasiloxane, hexamethyldisiloxane, hexaethyldisiloxane, 1 ,3- divinyl-1 ,1 ,3,3-tetramethyldisiloxane, oc
  • the organosilane compounds include alkylchlorosilane, for example methyltrichlorosilane, dimethyldichlorosilane, trimethylchlorosilane, octadecyltrichlorosilane; alkyl- alkoxysilane compounds, for example methyl-, propyl-, isobutyl- and octyltrialkoxysilanes, and fluoro- organosilane compounds, for example, 2-(n-perfluoro-octyl)-ethyltriethoxysilane, and perfluoro-octyldimethyl chlorosilane.
  • alkylchlorosilane for example methyltrichlorosilane, dimethyldichlorosilane, trimethylchlorosilane, octadecyltrichlorosilane
  • alkyl- alkoxysilane compounds for example methyl-, propyl
  • organosilicon compounds can be found in Silicone Surfactants (Randal M. Hill, 1999) and the references therein, and in United States Patent Nos. 4,046,795; 4,537,595; 4,564,456; 4,689,085; 4,960,845; 5,098,979; 5,149,765; 5,209,775; 5,240,760; 5,256,805; 5,359,104; 6,132,638 and 6,830,811 and Canadian Patent No. 2,213,168.
  • Organosilanes can be represented by the formula
  • suitable organosilanes include:
  • polysiloxanes modified with organic amphoteric or cationic groups including organic betaine polysiloxanes and organic quaternary polysiloxanes are examples.
  • organic betaine polysiloxane or quaternary polysiloxane is represented by the formula
  • each of the groups Ri to R 6 , and R 8 to Ri 0 represents an alkyl containing 1-6 carbon atoms, typically a methyl group
  • R 7 represents an organic betaine group for betaine polysiloxane, or an organic quaternary group for quaternary polysiloxane, and have different numbers of carbon atoms, and may contain a hydroxyl group or other functional groups containing N, P or S
  • m and n are from 1 to 200.
  • one type of quaternary polysiloxanes is when R 7 is represented by the group R 1 R 4 O
  • R 1 , R 2 , R 3 are alkyl groups with 1 to 22 carbon atoms or alkenyl groups with 2 to 22 carbon atoms.
  • R 4 , R 5 , R 7 are alkyl groups with 1 to 22 carbon atoms or alkenyl groups with 2 to 22 carbon atoms;
  • R 6 is -O- or the NR 8 group, R 8 being an alkyl or hydroxyalkyl group with 1 to 4 carbon atoms or a hydrogen group;
  • Z is a bivalent hydrocarbon group with at least 4 carbon atoms, which may have a hydroxyl group and may be interrupted by an oxygen atom, an amino group or an amide group;
  • x is 2 to 4;
  • the R 1 , R 2 , R 3 , R 4 , R 5 , R 7 may be the same or the different, and
  • X " is an inorganic or organic anion including Cl " and CH 3 COO " .
  • organic quaternary groups include [R-N + (CH 3 ) 2 - CH 2 CH(OH)CH 2 -O-(CH 2 )3-] (CH 3 COO " ), wherein R is an alkyl group containing from 1-22 carbons or an benzyl radical and CH 3 COO ' an anion.
  • organic betaine include -(CH 2 ) 3 -O-CH 2 CH(OH)(CH 2 )-N + (CH 3 ) 2 CH 2 COO ' .
  • Betaine polysiloxane copolyol is one of examples. It should be understood that cationic polysiloxanes include compounds represented by formula (II), wherein R 7 represents other organic amine derivatives including organic primary, secondary and tertiary amines.
  • organo-modified polysiloxanes include di-betaine polysiloxanes and di-quatemary polysiloxanes, which can be represented by the formula wherein the groups R 12 to Ri 7 each represents an alkyl containing 1-6 carbon atoms, typically a methyl group, both Rn and R 1 S group represent an organic betaine group for di-betaine polysiloxanes or an organic quaternary group for di- quaternary, and have different numbers of carbon atoms and may contain a hydroxyl group or other functional groups containing N, P or S, and m is from 1 to 200.
  • R 11 and R 1S are represented by the group
  • cationic polysiloxanes include compounds represented by formula (III), wherein Ri 1 and R 18 represents other organic amine derivatives including organic primary, secondary and tertiary amines. It should be apparent to those skilled in the art that there are different mono- and di-quaternary polysiloxanes, mono- and di- betaine polysiloxanes and other organo-modified polysiloxane compounds which can be used to render the solid surfaces extremely hydrophobic and are useful in the present invention. These compounds are widely used in personal care and other products, for example as discussed in United States patent nos.
  • Suitable examples are fluorinated chlorosilanes or fluorinated alkoxysilanes including 2-(n-perfluoro- octyl)ethyltriethoxysilane, perfluoro-octyldimethylchlorosilane,
  • the particulate surfaces can be hydrophobized either by forming covalent bonds between the particulate surfaces and an EHRC or by adsorption of an EHRC on the particulate surfaces.
  • chlorosilanes and alkoxysilanes which usually undergo hydrolysis in aqueous medium under suitable conditions, are used to modify surface through forming covalent bonds.
  • reactive silanol groups are formed, which can condense with other silanol groups, for example, those on the surface of siliceous materials, to form covalent bonds.
  • methyltrichlorosilane, dimethyldichlorosilane, trimethylchlorosilane, their alkoxy derivatives can be used to render glass surface extremely hydrophobic through forming covalent bonds with the glass surfaces. It has been observed that polysiloxanes including various organic modified derivatives tend to have little tendency to hydrolysis under normal conditions. It is believed that they modify the surfaces predominantly by adsorption on the solid surfaces. It is common that solid surfaces, especially inorganic solid surfaces, in an aqueous medium possess charges, either negative or positive, which is influenced significantly by the pH of the aqueous medium.
  • Organic substitutes on polysiloxane molecule enhance significantly the adsorption of polysiloxanes on the solid surfaces.
  • a cationic polysiloxane can readily adsorb on sand surface in an aqueous liquid with neutral pH, at which the sand surface possesses negative charges.
  • an anionic polysiloxane for example, a sulfonate polysiloxane tend to adsorb to a carbonate surface in an aqueous liquid more easily at neutral pH.
  • Slurries according to the present invention can be prepared, for example, by mixing an aqueous liquid with particulates and an EHRC, using conventional mixing method with a sufficient amount of shear.
  • the particulates can be first treated by contacting the particulates with a fluid medium containing an EHRC to render the particulate surfaces extremely hydrophobic and then separating the particulates from the medium.
  • the fluid medium can be a liquid or a gas.
  • the pre-hydrophobized particulates can later be used to make a slurry.
  • a gas including air, nitrogen, carbon dioxide, methane and mixtures thereof, can also be mixed into the slurries under agitation. Water is the most preferred aqueous liquid for making the slurry.
  • Suitable conventional hydrocarbon surfactants into the slurry composition is also useful.
  • the surfactants should be added to the slurry at concentrations and in a manner which would not adversely affect the slurry.
  • a surfactant when added to the slurries, one should try to avoid forming insoluble precipitates with the EHRC, or changing greatly the wettability of the particulate surface, or greatly reducing the surface tension of the aqueous liquid.
  • mixing cationic polysiloxane with an anionic hydrocarbon-surfactant, or vice versa is normally not preferred, due to the tendency of causing undesired precipitations.
  • a cationic polysiloxane when used a cationic or an amphoteric hydrocarbon surfactant is more preferred.
  • an anionic polysiloxane when used, an anionic surfactant or an amphoteric hydrocarbon surfactant is more preferred.
  • Principles about surfactant compatibility are known to those skilled in the art.
  • a very low surface tension of the aqueous liquid is not desirable. When the surface tension of the liquid is too low, more water can be added or some of the aqueous fluid containing surfactants can be replaced with water.
  • the slurries can be prepared on surface (above ground) or in a subterranean formation where the particulates, an aqueous fluid, and an EHRC, for example a di-quaternary polysiloxane, are mixed in situ. Examples of situations where in situ mixing is used include drilling and wellbore cleanout operations.
  • the particulates can be first mixed with a liquid in which an EHRC is dispersed or dissolved and then the particulates separated from the liquid or dried. The thus treated particulates can subsequently be used to make the slurry.
  • Various proppants including sands, ceramic particulates or resin coated sands can be treated according to the present invention during manufacturing process.
  • the thus prepared hydrophobic particulates can be used as proppants in fracturing operations.
  • EHRC concentration can be used to render the particulate surface extremely hydrophobic.
  • the amount of EHRC added is very small and has no apparent effect on the viscosity of the liquid to which it is added.
  • the concentration of EHRC in the slurry can be as low as a few ppm to hundreds of ppm. In most applications, it is unnecessary to add EHRC in an amount larger than 1 percent of the total liquid.
  • Tegopren 6923 a di-quaternary polydimethylsiloxane from Degussa Corp.
  • Tegopren 6923 a di-quaternary polydimethylsiloxane from Degussa Corp.
  • the bottles were vigorously shaken and then let stand to allow sands settle down.
  • the volumes of the settled sands in the two bottles were compared.
  • the volume of the settled sands was about 40 percent greater than the one without, and the sands are more fluid.
  • the volume of settled pre-treated sands is significant larger than that in the control one.
  • the settled sands in the control bottle tended to move as individual grains, while the settled pre-hydrophobized sands tended to move as cohesive masses.
  • Example 10 100 ml of water and 25 grams 30/50 fracturing sands were added into each of two glass bottles (200ml).
  • 0.05 ml of Tegopren 6922 a di-quaternary polydimethylsiloxane from Degussa Corp.
  • a confidential and experimental hydraulic fracturing treatment was carried out in a gas well.
  • the depth of the well was about 2500m and the formation temperature was about 76 0 C.
  • the fracturing fluid used was slick water, where a small amount of polymer was added into water to reduce friction pressure.
  • Two proppants were used, one was 40/70 sands and the other was 30/50 sands.
  • Tegopren 6922 was added into the fracturing fluid by continuous mixing at concentrations of 1 L/m 3 to 3 L/m 3 through the proppant stage, where the slurry was prepared and pumped into the formation through wellbore. Nitrogen gas was mixed with the fluid and the slurry during the operation.
  • the present invention is particularly useful in many applications in the petroleum industry as well as in other industries. Examples include various well service operations including hydraulic fracturing, gravel pack, wellbore cleanout and drilling, particulate transportation through pipe lines, sand blasting, and excavation of a geological formation including tunneling, dredging, digging and the like.
  • An EHRC for example, a di-quaternary polysiloxane can be mixed with an aqueous liquid and proppants on-the-fly to make the slurry and subsequently pumped into the formation during the proppant stage, either with or without a gas, or furthermore, a hydrocarbon surfactant, for example, a betaine surfactant, can be combined into the composition.
  • a hydrocarbon surfactant for example, a betaine surfactant
  • slick- water fracturing treatment It is particularly beneficial to use the slurry in so-called slick- water fracturing treatment.
  • conventional slick-water fracturing operations due to the low viscosity of the fluid, only low concentrations of proppants can be effectively pumped deep into a formation, and moreover the proppants tend to settle down on the bottom of the fracture, resulting in lower conductivity.
  • high concentration of proppants can easily be pumped deep into a formation and the proppants are more evenly distributed in the fracture, leading to improved conductivity of the proppant pack.
  • Other aqueous fracturing fluids including water, brine, cross-linked polymer fluid and viscoelastic surfactant fluid can also be employed in the present invention.
  • An EHRC can be added straightly or premixed with a solvent or added as an emulsion during an operation.
  • Another benefit of the slurries of the present invention is that the aqueous liquid is re-useable after it is separated from the particulates. This has great significance considering there is limited water supply in a number of places.
  • the present invention also provides a new method for preventing proppant flowback after a fracturing treatment.
  • proppants can be pumped into a formation using the composition of the present invention.
  • a fluid medium containing an EHRC can be pumped into the formation following the proppant stage to mix with particulates already in the formation.
  • the particulates in the slurry tend to move cohesively in contrast to conventional slurries under the same conditions. It is worth noting that the cohesiveness among the proppant grains in the present slurry originates from hydrophobic interactions, instead of tackiness as described, for example in US Patent 6,047,772.
  • the slurry of the present invention is particularly useful in gravel-pack operations where sand slurry is normally pumped into a wellbore to prevent excessive amount of sands from flowing into the wellbore from the formation.
  • the present method is cost effective and the sand pack formed has a high conductivity.
  • the slurry can also be used in so-called formation consolidation operations. In such an operation, a fluid containing an EHRC is injected into a formation to increase cohesiveness among sand grains to consolidate the formation and to reduce sand production.
  • an EHRC can be added into a water-based drilling fluid. It is particularly useful when the EHRC is added to water or brine for use as a drilling fluid.
  • the fluid forms slurry in situ with cuttings and transports the cuttings out of the wellbore.
  • a gas such as nitrogen or carbon dioxide can be mixed with the slurry during drilling. Since it is not necessary to use polymers or clays to viscosity the fluid, there is much less formation damage.
  • the cuttings can be easily removed on the surface and the aqueous liquid becomes re-useable. Different formations including sandstone, carbonate, shale and coal seams can be drilled using the slurry of the present invention.
  • water containing an EHRC can circulate in the wellbore and form slurry with debris in situ.
  • the debris is subsequently transported out of the wellbore as slurry.
  • the fluid is re-useable after separation from the debris.
  • slurry For transporting particulates through pipelines slurry can be prepared by mixing the ingredients and then pumping the slurry through the pipeline.

Abstract

An aqueous slurry composition for use in industries such as the petroleum and pipeline industries includes a particulate, an aqueous liquid and a chemical compound that renders the particulate surface extremely hydrophobic. The slurry is produced by rendering the surface of the particulate extremely hydrophobic during or before making the slurry.

Description

Slurry Compositions and the Methods for Making Same
BACKGROUND OF THE INVENTION Field of the Invention
This invention relates to an aqueous slurry composition and to a method of making such a composition. Discussion of the Prior Art
Aqueous particulate slurries are commonly used or encountered in many industries including the petroleum, pipeline, construction and cleaning industries. Slurries are mixtures normally comprising particulates and an aqueous medium and play an essential role in many industrial operations. For example, slurries are used for transporting particulates from one location to another at different distances either above ground, or from the surface to a subterranean formation or from a subterranean formation to the surface. The most commonly used particulates include sand, ceramic particulates, carbonate particulates, glass spheres, bauxite (aluminum oxide) particulates, resin coated particulates and coal particulates. The particulate sizes normally range from about 10 to about 100 US mesh, and the particulate densities are significantly higher than the density of water. For example, the density of sand is at about 2.6 g/cm3 while the density of water is 1 g/cm3. Sand is by far the most commonly used particulate.
To make relatively stable slurry, particulates must be suspended in a liquid medium for a lengthy period at static or/and dynamic conditions. Convention wisdom tells us that the viscosity or viscoelasticity of the liquid medium must be sufficiently high to be able to suspend particulates. The most commonly used method for increasing viscosity or viscoelasticity of an aqueous liquid is by adding a viscosifier, for example, a natural or synthetic polymer or a viscoelastic surfactant to the liquid medium. It is not unusual that a polymer is used with a foaming agent in order to take advantage of both viscoelastic and foaming properties. However, the use of polymers in slurries increases cost and results in operational difficulties. In particular applications, for example, hydraulic fracturing of subterranean formations, the use of polymers in slurry impedes oil and gas production due to large amounts of residue left in the formation. As for viscoelastic surfactants, although they have fewer residues compared to normal polymers, their cost is usually much higher. In many other applications such as gravel-pack, well completion and sand transportation through pipelines, it is highly desirable to make stable particulate slurry without using a viscosifier.
Hydraulic fracturing operations are used extensively in the petroleum industry to enhance oil and gas production. In hydraulic fracturing, a fracturing fluid is injected through a wellbore into a subterranean formation at a pressure sufficient to initiate fractures, which increase oil and gas production. Frequently, particulates, called proppants, are suspended in the fracturing fluid and transported into fractures as slurry. Proppants include sands, ceramic particulates, bauxite particulates, resin coated sands and other particulates known in the industry. Among them sand is by far the most commonly used proppant.
Fracturing fluids in common use include water-based as well as hydrocarbon-based fluids. In water-based fracturing fluids, a polymer or viscoelastic surfactant is normally employed to increase the viscoelasticity of the fluid. In most cases the viscoelastic property of the fluids is essential for transporting proppants deep into a formation. At the last stage of the fracturing treatment, fracturing fluid flows back to the surface and the proppants are left in the fracture forming a proppant pack to prevent the fracture from closing after pressure is released. A proppant-filled fracture provides a highly conductive channel that allows oil and/or gas to seep through more efficiently to the wellbore. The conductivity of the proppant pack plays a dominant role in production enhancement. Polymer residues from fracturing fluids are known to greatly reduce the conductivity of the proppant pack.
Compared to polymeric viscosifiers, viscoelastic surfactants cause less damage to formations and proppant packs. However, they are much more expensive.
Accordingly, a need exists for a composition for efficiently transporting proppants deep into a formation at low cost while at the same time causing little damage to the formation and proppant pack. Grain size, concentration, shape and the packing pattern of proppants are also important factors in determining the conductivity. Despite extensive research in recent years, limited progress has been achieved to maximize the conductivity of a proppant pack in a fracture. Therefore, a need exists for making a composition for use in a proppant pack with improved conductivity.
Proppant flowback after fracturing treatments has long been plaguing the petroleum industry. Flowback reduces the amount of proppants in the formation leading to a less conductive fracture. As disclosed, for example in US Patent 6,047,772, various methods have been tried to solve the flowback problem. In one method, resins are used to coat the proppant and make them very tacky. In doing so, the proppant grains tend to stick together reducing flowback. This method is not only expensive, but the tacky resins introduced in the proppant pack tend to reduce its conductivity. Therefore, there is a need for a composition and method for making slurry, which can form a stable proppant pack resisting proppant flowback, while at the same time has a high conductivity.
When drilling subterranean formations for oil and gas, aqueous-based drilling fluids are normally used. During drilling large amounts of particles, called cuttings are generated. Cuttings have different sizes ranging from fines to pebbles. The drilling fluid is circulated through the wellbore to make slurry with the cuttings in situ and transports them out of wellbore. In most cases, polymers as well as clays are added to the drilling fluids to increase their viscosity/ viscoelasticity in order to transport the cuttings efficiently. However, polymers as well as clay fines, can easily penetrate into pores or thin fractures in a formation and reduce formation permeability significantly, especially near wellbore. Reduced formation permeability impedes oil and/or gas production. Therefore it is highly desirable to provide a drilling fluid that can make stable slurry in situ with the cuttings and transport them out of the wellbore, while causing little formation damage.
The escalating price of oil and its alarming depletion rate have caused people to consider using coal as an oil substitute. Several factors have slowed the substitution of coal for oil. One factor is the difficulty in transporting coal cost- effectively over long distance through pipelines. It is therefore highly desirable to provide a composition for making coal slurry which is stable, highly fluid and cost- effective to transport.
In oil sand operation massive amount of sands are left after oil is stripped from the sand surface. Finding a more cost effective way to transport sands efficiently over distance through pipelines has long been required in the industry. Thus, a composition and a method for making stable and highly fluid sand slurries at low cost would be quite useful.
SUMMARY OF THE INVENTION
Accordingly, one aspect of the present invention relates to an aqueous slurry compositions, which can be used to form a stable, highly conductive proppant pack, for efficiently transporting proppants into a subterranean formation, and for use in transporting drilling cuttings, coal particulates and sands.
The invention also relates to an aqueous slurry composition comprising particulates, an aqueous liquid and a chemical compound that renders the surface of the particulates extremely hydrophobic, and the method of making such slurry composition.
The invention still further relates to a slurry composition comprising particulates, an aqueous liquid, a chemical compound that renders the surface of the particulates extremely hydrophobic and a gas, and the method of making such slurry composition. The invention also relates to a slurry composition comprising particulates, an aqueous liquid, a chemical compound that renders the surface of the particulates extremely hydrophobic and a surfactant.
The invention also relates to a slurry composition comprising particulates, an aqueous liquid, a chemical compound that renders the surface of the particulates extremely hydrophobic, a surfactant and a gas, and the method of making such slurry composition. The invention also relates to a method of making an aqueous slurry composition comprising steps of first rendering the particulate surface extremely hydrophobic and then mixing the treated particulates with an aqueous liquid, or an aqueous liquid containing a gas.
The invention in another aspect also relates to methods of making the aqueous slurry compositions, including for various applications including hydraulic fracturing, drilling, gravel-pack, transportation through pipelines, blasting and tunneling.
DETAILED DESCRIPTION OF THE INVENTION
It is discovered in the present invention that when the surface of particulates according to the invention become extremely hydrophobic, a slurry made with such particulates has several novel properties. For example, particulates tend to move cohesively instead as individual grains; the bulk volume of settled particulates tend to be significantly greater than in a slurry formed by convention methods under the same conditions; the particulate pack formed tends to have high conductivity and can be easily dewatered, and the slurry tends to be fluid and stable at static or dynamic conditions without using a viscosifier. The larger bulk volume of the particulate pack indicates a larger porosity and therefore higher conductivity. This is particularly beneficial for improving fracturing treatment, since, as mentioned above, the conductivity of the proppant pack is the dominant property affecting fracturing treatments. The extremely hydrophobic surface of the particulate further reduces the dragging force exerted by the fluid and makes it more difficult for proppants to be carried away by the fluid once the particulates become completely settled. This is particularly beneficial for minimizing proppant flowback after fracturing treatments, leading to increased proppant conductivity. In conventional slurries, viscosity or viscoelasticity of the liquid plays a dominant role while the interfacial interactions between the particulate surface and the liquid play negligible role. However, it is discovered in the present invention that when the surface of the particulate becomes extremely hydrophobic, the interfacial interactions between the surface and the liquid become increasingly important.
In general, the interfacial interactions between a solid substrate and a liquid mainly depend on the surface properties of the solid and the surface tension of the liquid. Normally the macroscopic properties of a solid surface can be characterized by observing the shape of a liquid droplet on the solid substrate, which is the result of free energy of the surface, as well as the free energy of the liquid. When a liquid does not completely wet a surface, it forms an angle θ, which is known as the contact angle. The contact angle is the angle formed between a solid substrate and the tangent line at the point of contact between a liquid droplet and the solid substrate. The contact angle can be measured directly on macroscopic, smooth, nonporous, planar solid substrates by merely placing a droplet of the liquid or solution on the solid substrate and determining the contact angle by any of number of techniques. The values of contact angles between many solids and aqueous liquid are provided in various books and scientific publications, which will be known to those skilled in the art. It is known that the majority of naturally occurring minerals are hydrophilic. It is also known that certain hydrocarbon compounds, for example, some conventional quaternary surfactants, amine surfactants and cationic polyacrylamides can be used to reduce the surface energy of certain particulates and make the particulate surface less hydrophilic or more hydrophobic. However, the "hydrophobicity" imparted by such compounds is not high enough to be included in the term of "extremely hydrophobic" as in the case of the present invention. In the present invention, "extremely hydrophobic" means that the contact angle of water on the solid substrate is greater than about 90°. At such high contact angles, water does not wet the surface of the solid and instead contracts on the solid surface and forms beads. The chemical compounds that can render a particulate surface extremely hydrophobic are referred as "extremely hydrophobic rendering compounds" (EHRC) for the sake of simplicity. EHRC normally are those compounds that contain organosilane or organosiloxane groups. Because of such groups, EHRC are able to impart hydrophobicity to solid surface to a level that conventional hydrocarbon surfactants or polymers are not able to achieve. These compounds are known to render many inorganic solid surfaces extremely hydrophobic. Slurries according to the invention can be made on the ground or in situ in a subterranean formation. Such slurries have numerous applications in many industries, including for (a) transporting particulates over various distances, either on the surface of the ground, from the surface to a subterranean formation or from a subterranean formation to the surface, and (b) well service operations including stimulation, drilling, completion, gravel-pack, controlling sand production and the like.
Furthermore, a gas can be mixed into the slurries of the invention. Suitable gases for use in the slurry include air, carbon dioxide, nitrogen, methane and mixtures thereof. The gas can be introduced into the slurries during preparation thereof. For example, when the slurry is pumped through a pipe, gas such as nitrogen can be introduced into the slurry, or gas such as air can be simply mixed into the slurry through a sufficient rate of agitation.
In the present invention, "aqueous liquids" means water, salt solutions, water containing an alcohol or other organic solvents. It should be understood that the additives other than water in the aqueous liquid are used in amounts or in a manner that does not adversely affect the present invention. One can also add polymers into the aqueous liquid. For example, in so-called slick-water fracturing operations, a small amount of polymer is normally added into an aqueous liquid to reduce friction pressure during pumping.
The size of particulates in compositions according to the invention is about 10-100 US mesh, which is about 150 to 1400 μm. It should be understood that the size distribution of particulates can be narrow or wide. Suitable particulates include sands, ceramic particulates, glass beads, bauxite particulates, resin coated sands, carbonates and coal particulates.
It is known that many organosilicon compounds including organosiloxane, organosilane, fluoro-organosiloxane and fluoro-organosilane compounds are commonly used to render various surfaces extremely hydrophobic. For example, see United States patent nos. 4,537,595; 5,240,760; 5,798,144; 6,323,268; 6,403,163; 6,524,597 and 6,830,811. It is normally not difficult for those skilled in the art to find suitable organosilicon compounds to render a solid surface extremely hydrophobic. However, it discovered in the present invention that when the surfaces of particulates are rendered extremely hydrophobic in aqueous slurry, the slurry exhibits novel properties which are not seen in conventional aqueous slurry. For example, particulates tend to move cohesively instead as individual grains; the bulk volume of settled particulates tend to be significantly greater than in a slurry formed by convention methods under the same conditions; the particulate pack formed tends to have high conductivity and be easily dewatered, and the slurry tends to be fluid and stable at static or dynamic conditions without using a viscosifier.
Organosilanes are compounds containing silicon to carbon bonds. Organosiloxanes are compounds containing Si-O-Si bonds. Polysiloxanes are compounds in which the elements silicon and oxygen alternate in the molecular skeleton, i.e., Si-O-Si bonds are repeated. The simplest polysiloxanes are polydimethylsiloxanes. Polysiloxane compounds can be modified by various organic substitutes having different numbers of carbons, which may contain N, S, or P moieties that impart desired characteristics. For example, cationic polysiloxanes are compounds in which one or two organic cationic groups are attached to the polysiloxane chain, either at the middle or the end. Normally the organic cationic group contains at least 10 carbons and may contain a hydroxyl group or other functional groups containing N or O. The most common organic cationic groups are alkyl amine derivatives including secondary, tertiary and quaternary amines (for example, quaternary polysiloxanes including, quaternary polysiloxanes including mono- as well as di-quaternary polysiloxanes, amido quaternary polysiloxanes, imidazoline quaternary polysiloxanes and carboxy quaternary polysiloxanes.
Similarly, the polysiloxane can be modified by organic amphoteric groups, where one or two organic amphoteric groups are attached to the polysiloxane chain, either at the middle or the end, and include betaine polysiloxanes and phosphobetaine polysiloxanes.
Similarly, the polysiloxane can be modified by organic anionic groups, where one or two organic anionic groups are attached to the polysiloxane chain, either at the middle or the end, including sulfate polysiloxanes, phosphate polysiloxanes, carboxylate polysiloxanes, sulfonate polysiloxanes, thiosulfate polysiloxanes. The organosiloxane compounds also include alkylsiloxanes including hexamethylcyclotrisiloxane, octamethylcyclotetrasiloxane, decamethylcyclopentasiloxane, hexamethyldisiloxane, hexaethyldisiloxane, 1 ,3- divinyl-1 ,1 ,3,3-tetramethyldisiloxane, octamethyltrisiloxane, decamethyltetrasiloxane. The organosilane compounds include alkylchlorosilane, for example methyltrichlorosilane, dimethyldichlorosilane, trimethylchlorosilane, octadecyltrichlorosilane; alkyl- alkoxysilane compounds, for example methyl-, propyl-, isobutyl- and octyltrialkoxysilanes, and fluoro- organosilane compounds, for example, 2-(n-perfluoro-octyl)-ethyltriethoxysilane, and perfluoro-octyldimethyl chlorosilane.
Other types of chemical compounds, which are not organosilicon compounds, which can be used to render particulate surface extremely hydrophobic are certain fluoro-substituted compounds, for example certain fluoro-organic compounds.
Further information regarding organosilicon compounds can be found in Silicone Surfactants (Randal M. Hill, 1999) and the references therein, and in United States Patent Nos. 4,046,795; 4,537,595; 4,564,456; 4,689,085; 4,960,845; 5,098,979; 5,149,765; 5,209,775; 5,240,760; 5,256,805; 5,359,104; 6,132,638 and 6,830,811 and Canadian Patent No. 2,213,168.
Organosilanes can be represented by the formula
RnSiX(4-n) (I) wherein R is an organic radical having 1-50 carbon atoms that may posses functionality containing N, S, or P moieties that imparts desired characteristics, X is a halogen, alkoxy, acyloxy or amine and n has a value of 0-3. Examples of suitable organosilanes include:
CH3SiCI3, CH3CH2SiCI3, (CHg)2SiCI2, (CH3CH2J2SiCI2, (C6Hs)2SiCI2, (C6H5)SiCI3, (CHa)3SiCI, CH3HSiCI2, (CHa)2HSiCI1 CH3SiBr3, (C6H5)SiBr3, (CHs)2SiBr2, (CH3CH2)2SiBr2) (C6Hs)2SiBr2, (CHa)3SiBr, CH3HSiBr2, (CHs)2HSiBr, Si(OCH3)4, CH3Si(OCH3)3, CH3Si(OCH2CHa)3, CH3Si(OCH2CH2CHs)3, CH3Si[O(CH2)3CH3]3l CH3CH2Si(OCH2CHs)3, C6H5Si(OCH3)S, C6H5CH2Si(OCH3)3, C6H5Si(OCH2CH3)3, CH2=CHCH2Si(OCH3)3, (CHs)2Si(OCHs)2, (CH2=CH)Si(CHs)2CI, (CH3)2Si(OCH2CH3)2, (CHs)2Si(OCH2CH2CHs)2, (CHs)2Si[O(CH2)3CH3]2, (CH3CH2)2Si(OCH2CH3)2, (C6Hs)2Si(OCHs)2, (C6H5CH2)2Si(OCH3)2, (C6H5)2Si(OCH2CH3)2, (CH2=CH2)Si(OCH3)2, (CH2=CHCH2)2Si(OCH3)2, (CHs)3SiOCH3, CH3HSi(OCHs)2, (CHs)2HSi(OCH3), CH3Si(OCH2CH2CHs)3, CH2=CHCH2Si(OCH2CH2OCHs)2, (C6H5)2Si(OCH2CH2OCH3)2, (CH3)2Si(OCH2CH2OCH3)2, (CH2=CH2)2Si(OCH2CH2OCH3)2, (CH2=CHCH2)2Si(OCH2CH2OCH3)2, (C6H5)2Si(OCH2CH2OCH3)2, CH3Si(CH3COO)3, 3-aminotriethoxysilane, methyldiethylchlorosilane, butyltrichlorosilane, diphenyldichlorosilane, vinyltrichlorosilane, methyltrimethoxysilane, vinyltriethoxysilane, vinyltris(methoxyethoxy)silane, methacryloxypropyltrimethoxysilane, glycidoxypropyltrimethoxysilane, aminopropyltriethoxysilane, divinyldi-2- methoxysilane, ethyltributoxysilane, isobutyltrimethoxysilane, hexyltrimethoxysilane, n-octyltriethoxysilane, dihexyldimethoxysilane, octadecyltrichlorosilane, octadecyltrimethoxysilane, octadecyldimethylchlorosilane, octadecyldimethylmethoxysilane and quaternary ammonium silanes including 3-(trimethoxysilyl)propyldimethyloctadecyl ammonium chloride, 3-(trimethoxysilyl)propyldimethyloctadecyl ammonium bromide, 3-(trimethylethoxysilylpropyl)didecylmethyl ammonium chloride, triethoxysilyl soyapropyl dimonium chloride, 3- (trimethylethoxysilylpropyl)didecylmethyl ammonium bromide, 3- (trimethylethoxysilylpropyl)didecylmethyl ammonium bromide, triethoxysilyl soyapropyl dimonium bromide, (CH3O)3Si(CH2)SP+(C6H5)SCI, (CH3O)3Si(CH2)3P+(C6H5)3Br-, (CH3O)3Si(CH2)3P+(CH3)3C|-, (CH3O)3Si(CH2)3P+(C6H13)3Cr, (CH3O)3Si(CH2)3N+(CH3)2C4H9CI, (CH3O)3Si(CH2)3N+(CH3)2CH2C6H5Cr, (CH3O)3Si(CH2)3N+(CH3)2CH2CH2OHCr, (CH3O)3Si(CH2)3N+(C2H5)3C|-, (C2H5O)3Si(CH2)3N+(CH3)2C18H37Cr.
Among different organosiloxane compounds which are useful for the present invention, polysiloxanes modified with organic amphoteric or cationic groups including organic betaine polysiloxanes and organic quaternary polysiloxanes are examples. One type of betaine polysiloxane or quaternary polysiloxane is represented by the formula
Figure imgf000015_0001
wherein each of the groups Ri to R6, and R8 to Ri0 represents an alkyl containing 1-6 carbon atoms, typically a methyl group, R7 represents an organic betaine group for betaine polysiloxane, or an organic quaternary group for quaternary polysiloxane, and have different numbers of carbon atoms, and may contain a hydroxyl group or other functional groups containing N, P or S, and m and n are from 1 to 200. For example, one type of quaternary polysiloxanes is when R7 is represented by the group R1 R4 O
N+- -R2 X" or — Z- -N+- (CH2)XR6 CR7 X"
R3 R5
(III)
wherein R1, R2, R3 are alkyl groups with 1 to 22 carbon atoms or alkenyl groups with 2 to 22 carbon atoms. R4, R5, R7 are alkyl groups with 1 to 22 carbon atoms or alkenyl groups with 2 to 22 carbon atoms; R6 is -O- or the NR8 group, R8 being an alkyl or hydroxyalkyl group with 1 to 4 carbon atoms or a hydrogen group; Z is a bivalent hydrocarbon group with at least 4 carbon atoms, which may have a hydroxyl group and may be interrupted by an oxygen atom, an amino group or an amide group; x is 2 to 4; The R1, R2, R3, R4, R5, R7 may be the same or the different, and X" is an inorganic or organic anion including Cl" and CH3COO". Examples of organic quaternary groups include [R-N+(CH3)2- CH2CH(OH)CH2-O-(CH2)3-] (CH3COO"), wherein R is an alkyl group containing from 1-22 carbons or an benzyl radical and CH3COO' an anion. Examples of organic betaine include -(CH2)3-O-CH2CH(OH)(CH2)-N+(CH3)2CH2COO'. Such compounds are commercial available. Betaine polysiloxane copolyol is one of examples. It should be understood that cationic polysiloxanes include compounds represented by formula (II), wherein R7 represents other organic amine derivatives including organic primary, secondary and tertiary amines.
Other example of organo-modified polysiloxanes include di-betaine polysiloxanes and di-quatemary polysiloxanes, which can be represented by the formula
Figure imgf000017_0001
wherein the groups R12 to Ri7 each represents an alkyl containing 1-6 carbon atoms, typically a methyl group, both Rn and R1S group represent an organic betaine group for di-betaine polysiloxanes or an organic quaternary group for di- quaternary, and have different numbers of carbon atoms and may contain a hydroxyl group or other functional groups containing N, P or S, and m is from 1 to 200. For example, one type of di-quaternary polysiloxanes is when R11 and R1S are represented by the group
R1 R4
— z- -N+- -R2 X- or — Z- -N+- (CH2)XR6 CR' X"
R3 R5
(V)
wherein R1, R2, R3, R4, R5, R6, R7, Z, X" and x are the same as defined above. Such compounds are commercially available. Quaternium 80 (INCI) is one of the commercial examples.
It should be appreciated by those skilled in the art that cationic polysiloxanes include compounds represented by formula (III), wherein Ri1 and R18 represents other organic amine derivatives including organic primary, secondary and tertiary amines. It should be apparent to those skilled in the art that there are different mono- and di-quaternary polysiloxanes, mono- and di- betaine polysiloxanes and other organo-modified polysiloxane compounds which can be used to render the solid surfaces extremely hydrophobic and are useful in the present invention. These compounds are widely used in personal care and other products, for example as discussed in United States patent nos. 4,054,161 ; 4,654,161 ; 4,891 ,166; 4,898,957; 4,933,327; 5,166,297; 5,235,082; 5,306,434; 5,474,835; 5,616,758; 5,798,144; 6,277,361 , 6,482,969, 6,323,268 and 6,696,052.
Another example of organosilicon compounds which can be used in the composition of the present invention are fluoro-organosilane or fluoro- organosiloxane compounds in which at least part of the organic radicals in the silane or siloxane compounds are fluorinated. Suitable examples are fluorinated chlorosilanes or fluorinated alkoxysilanes including 2-(n-perfluoro- octyl)ethyltriethoxysilane, perfluoro-octyldimethylchlorosilane,
(CF3CH2CH2)2Si(OCH3)2, CF3CH2CH2Si(OCH3)3,
(CF3CH2CH2)2Si(OCH2CH2OCH3)2 and CF3CH2CH2Si(OCH2CH2OCH3)3 and (CH3O)3Si(CH2)3N+(CH3)2(CH2)3NHC(O)(CF2)6CF3Cr. Other compounds which can be used, but less preferable, are fluoro-substituted compounds, which are not organic silicon compounds, for example, certain fluoro-organic compounds.
It is understood that the particulate surfaces can be hydrophobized either by forming covalent bonds between the particulate surfaces and an EHRC or by adsorption of an EHRC on the particulate surfaces. For example, it is known that chlorosilanes and alkoxysilanes, which usually undergo hydrolysis in aqueous medium under suitable conditions, are used to modify surface through forming covalent bonds. Following hydrolysis, reactive silanol groups are formed, which can condense with other silanol groups, for example, those on the surface of siliceous materials, to form covalent bonds. For example, methyltrichlorosilane, dimethyldichlorosilane, trimethylchlorosilane, their alkoxy derivatives can be used to render glass surface extremely hydrophobic through forming covalent bonds with the glass surfaces. It has been observed that polysiloxanes including various organic modified derivatives tend to have little tendency to hydrolysis under normal conditions. It is believed that they modify the surfaces predominantly by adsorption on the solid surfaces. It is common that solid surfaces, especially inorganic solid surfaces, in an aqueous medium possess charges, either negative or positive, which is influenced significantly by the pH of the aqueous medium. Organic substitutes on polysiloxane molecule, especially ionic ones having charges opposite to those on the solid surface, enhance significantly the adsorption of polysiloxanes on the solid surfaces. For example, a cationic polysiloxane can readily adsorb on sand surface in an aqueous liquid with neutral pH, at which the sand surface possesses negative charges. Similarly, an anionic polysiloxane, for example, a sulfonate polysiloxane tend to adsorb to a carbonate surface in an aqueous liquid more easily at neutral pH.
Slurries according to the present invention can be prepared, for example, by mixing an aqueous liquid with particulates and an EHRC, using conventional mixing method with a sufficient amount of shear. Alternatively, the particulates can be first treated by contacting the particulates with a fluid medium containing an EHRC to render the particulate surfaces extremely hydrophobic and then separating the particulates from the medium. The fluid medium can be a liquid or a gas. The pre-hydrophobized particulates can later be used to make a slurry. In either case, a gas, including air, nitrogen, carbon dioxide, methane and mixtures thereof, can also be mixed into the slurries under agitation. Water is the most preferred aqueous liquid for making the slurry.
It is found in the present invention that adding suitable conventional hydrocarbon surfactants into the slurry composition is also useful. It should be understood that the surfactants should be added to the slurry at concentrations and in a manner which would not adversely affect the slurry. For example, when a surfactant is added to the slurries, one should try to avoid forming insoluble precipitates with the EHRC, or changing greatly the wettability of the particulate surface, or greatly reducing the surface tension of the aqueous liquid. For example, mixing cationic polysiloxane with an anionic hydrocarbon-surfactant, or vice versa, is normally not preferred, due to the tendency of causing undesired precipitations. Instead, when a cationic polysiloxane is used a cationic or an amphoteric hydrocarbon surfactant is more preferred. Similarly, when an anionic polysiloxane is used, an anionic surfactant or an amphoteric hydrocarbon surfactant is more preferred. Principles about surfactant compatibility are known to those skilled in the art. Also a very low surface tension of the aqueous liquid is not desirable. When the surface tension of the liquid is too low, more water can be added or some of the aqueous fluid containing surfactants can be replaced with water.
The slurries can be prepared on surface (above ground) or in a subterranean formation where the particulates, an aqueous fluid, and an EHRC, for example a di-quaternary polysiloxane, are mixed in situ. Examples of situations where in situ mixing is used include drilling and wellbore cleanout operations. Alternatively, the particulates can be first mixed with a liquid in which an EHRC is dispersed or dissolved and then the particulates separated from the liquid or dried. The thus treated particulates can subsequently be used to make the slurry. Various proppants including sands, ceramic particulates or resin coated sands can be treated according to the present invention during manufacturing process. The thus prepared hydrophobic particulates can be used as proppants in fracturing operations. Depending on the amount and size of the particulates in the slurry, a wide range of EHRC concentration can be used to render the particulate surface extremely hydrophobic. Usually the amount of EHRC added is very small and has no apparent effect on the viscosity of the liquid to which it is added. For example, the concentration of EHRC in the slurry can be as low as a few ppm to hundreds of ppm. In most applications, it is unnecessary to add EHRC in an amount larger than 1 percent of the total liquid.
The following examples serve to illustrate the concepts of the present invention. Example 1
50 ml of water and 50 grams of 20/40 mesh fracturing sands were added into each of two glass bottles (200ml). 0.5 ml of Tegopren 6923, a di-quaternary polydimethylsiloxane from Degussa Corp., was added into one of the bottles and the other bottle was used as control. The bottles were vigorously shaken and then let stand to allow sands settle down. The volumes of the settled sands in the two bottles were compared. In the bottle containing Tegopren 6923, the volume of the settled sands was about 40 percent greater than the one without, and the sands are more fluid. When the bottles were tilted slowly, the settled sands in the control tended to move as individual sand grains, while the settled sands containing Tegopren 6923 tended to move as cohesive masses. Example 2
50 ml water, 50 grams of 20/40 mesh fracturing sands, 0.5 ml of Tegopren 6923 and 0.1 ml of Aquard 18-50, C18-trimethylammonium chloride, a cationic hydrocarbon surfactant from Akzo Nobel Corp., was mixed into a glass bottle (200ml). The bottles were vigorously shaken and then let stand to allow sands settle down. All sands settled down to the bottom immediately in the control bottle. In the bottle containing Tegopren 6923, the sands immediately following agitation were fully distributed in the water making a stable slurry. After one hour, about half amount of sands settled on the bottom while the other half was floating on the top. Example 3
100 ml of water and 50 grams of 20/40 mesh ceramic proppants were added into each of two glass bottles (200ml). 0.5 ml of TEGO Betaine 810, capryl/capramidopropyl betaine, an amphoteric hydrocarbon surfactant from Degussa Corp., and 1 ml of a solution containing 20% Tegopren 6924, a di- quaternary polydimethylsiloxane from Degussa Corp., and 80% of ethylene glycol mono-butyl ether were added into one of the bottles, and the other bottle was used as control. The bottles were vigorously shaken and then let stand to allow proppants settle down. All proppants settled down to the bottom immediately in the control bottle. In the one containing Tegopren 6924 about 25% of proppants was floating on the top and the remaining 75% settled on the bottom, while the volume of the 75% settled proppants was still significantly larger than that in the control one. When the bottles were tilted slowly, the settled proppants in the bottle with straight water tended to move as individual grains, while the settled proppants in the one containing Tegopren 6924 tended to move as cohesive masses. Example 4
100 ml of water and 50 grams of 40/70 mesh fracturing sand were added into each of two glass bottles (200ml). 0.1 ml of Tegopren 6924 and 0.1 ml of TEGO Betaine 810, were added and further added 2 wt% KCI. The other bottle was used as control. The bottles were vigorously shaken and then let stand to allow sands settle down. The volumes of the settled sands in the two bottles were compared. All sands settled down to the bottom immediately in the control bottle. In the bottle containing Tegopren 6924, about 15% of sands was floating on the top and the remaining 85% settled on the bottom, while the volume of the 85% settled sand was still significantly larger than that in the control one. When the bottles were tilted slowly, the settled sands in the bottle with straight water tended to move as individual grains, while the settled sands in the one containing Tegopren 6924 tended to move as cohesive masses. Example 5 100 ml of water and 50 grams of 40/70 mesh fracturing sand were added into each of two glass bottles (200ml). 0.5 ml of TEGO Betaine 810 and 1 ml of a solution containing 20% Tegopren 6924 and 80% of ethylene glycol mono-butyl ether were added into one of the bottles. After thoroughly mixing the sands were separated from the liquid and dried at room temperature. The pre-hydrophobized sands were mixed with 100ml water and shaken vigorously. All sands settled down to the bottom immediately in the control bottle. In the bottle containing pre- hydrophobized sands, about 40% of sands was floating on the top and the remaining 60% settled on the bottom, while the volume of the 60% settled sand was still significantly larger than that in the control one. When the bottles were tilted slowly, the settled sands in the bottle with straight water tended to move as individual grains, while the settled pre-hydrophobized sands tended to move as cohesive masses. Example 6
100 ml of water and 50 grams of coal particulates were added into each of two glass bottles (200ml). 0.5 ml of TEGO Betaine 810 and 1 ml of a solution containing 20% Tegopren 6924 and 80% of ethylene glycol mono-butyl ether were added into one of the bottles. The other bottle was used as control. The bottles were vigorously shaken and then let stand to allow coal particulates settle down. The coal particulates in the control bottle settled down immediately. In the bottle containing Tegopren 6924, about 45% of coal particulates was floating on the top and the remaining 55% settled on the bottom, while the volume of the 55% settled coal particulates was about only 15% smaller than the volume of 100% of the coal particles in the control one. Example 7
100 ml of water and 50 grams of 40/70 mesh fracturing sand were added into each of two glass bottles (200ml). 0.03 ml of Maquat QSX, a quaternary silane compound characterized as triethoxysilyl soyapropyl dimonium chloride in butylene glycol, was added into one of the bottles. The other bottle was used as control. After being thoroughly mixed the liquid above the settled sand in the one containing Maquat QSX was discarded and replaced with same amount of water. The bottles were vigorously shaken and then let stand to allow sands settle down. The volumes of the settled sands in the two bottles were compared. All sands settled down to the bottom immediately in the control bottle. In the bottle containing Maquat QSX, about 5% of sands was floating on the top and remaining 95% settled on the bottom, while the volume of the 95% settled sand was still significantly larger than the control one. When the bottles were tilted slowly, the settled sands in the control bottle tended to move as individual grains, while the settled sands in the one containing Maquat QSX tended to move as cohesive masses. Example 8
100 ml of water and 50 grams of 20/40 mesh resin coated sands were added into each of two glass bottles (200ml). 1 ml of a solution containing 20% Tegopren 6924 and 80% of ethylene glycol mono-butyl ether were added into one of the bottles, and the other bottle was used as control. The bottles were vigorously shaken and then let stand to allow resin coated sands settle down. All resin coated sands settled down to the bottom immediately in the control bottle. In the bottle containing Tegopren 6924, about 15% of the resin coated sands was floating on the top and the remaining 85% settled on the bottom, while the volume of the 85% settled sand was still significantly larger than that in the control one. When the bottles were tilted slowly, the settled sands in the bottle with straight water tended to move as individual grains, while the settled sands in the one containing Tegopren 6924 tended to move as cohesive masses. Example 9
50 gram of 30/50 mesh fracturing sands were mixed with 10 ml of silicone oil (polydimethylsiloxane) of viscosity of 20 cp and left on filter paper at room temperature for 24 hours. 10 gram of the pre-hydrophobized sands and 50 ml of water is mixed into glass bottle (200 ml). 10 gram of untreated sands into 50 ml of water was used as control. The bottles were vigorously shaken and then let stand to allow resin sands settle down. All sands in the control bottle settled down to the bottom immediately. In the bottle containing pre-hydrophobized sands, a small amount of sands was floating on the top of water. The volume of settled pre-treated sands is significant larger than that in the control one. When the bottles were tilted slowly, the settled sands in the control bottle tended to move as individual grains, while the settled pre-hydrophobized sands tended to move as cohesive masses. Example 10 100 ml of water and 25 grams 30/50 fracturing sands were added into each of two glass bottles (200ml). 0.05 ml of Tegopren 6922, a di-quaternary polydimethylsiloxane from Degussa Corp., was added into one of the bottles. The other bottle was used as control. The bottles were vigorously shaken and then let stand to allow coal particulates settle down. The sands in the control bottle settled down immediately. In the bottle containing Tegopren 6922, sands settled down slower and a layer of sands was floating on the top and furthermore the sands were more fluid than those in the control one. The volume of settled sands in the one containing Tegopren 6922 was about twice of that in the control. Example 11
A confidential and experimental hydraulic fracturing treatment was carried out in a gas well. The depth of the well was about 2500m and the formation temperature was about 76 0C. The fracturing fluid used was slick water, where a small amount of polymer was added into water to reduce friction pressure. Two proppants were used, one was 40/70 sands and the other was 30/50 sands. During the proppant stage, Tegopren 6922 was added into the fracturing fluid by continuous mixing at concentrations of 1 L/m3 to 3 L/m3 through the proppant stage, where the slurry was prepared and pumped into the formation through wellbore. Nitrogen gas was mixed with the fluid and the slurry during the operation. The samples taken during the operation showed that compared to sands in conventional slick water fracturing, the sands settled down slower and were more fluid. As mentioned above, the present invention is particularly useful in many applications in the petroleum industry as well as in other industries. Examples include various well service operations including hydraulic fracturing, gravel pack, wellbore cleanout and drilling, particulate transportation through pipe lines, sand blasting, and excavation of a geological formation including tunneling, dredging, digging and the like.
When used in a hydraulic fracturing operation, a large amount of proppants can effectively be transported into a subterranean formation without using a viscosifier. It is not only cost-effective but also eliminates damage to the formation and proppant pack caused by polymer residues. An EHRC, for example, a di-quaternary polysiloxane can be mixed with an aqueous liquid and proppants on-the-fly to make the slurry and subsequently pumped into the formation during the proppant stage, either with or without a gas, or furthermore, a hydrocarbon surfactant, for example, a betaine surfactant, can be combined into the composition. It is particularly beneficial to use the slurry in so-called slick- water fracturing treatment. In conventional slick-water fracturing operations, due to the low viscosity of the fluid, only low concentrations of proppants can be effectively pumped deep into a formation, and moreover the proppants tend to settle down on the bottom of the fracture, resulting in lower conductivity. With the composition of the present invention, high concentration of proppants can easily be pumped deep into a formation and the proppants are more evenly distributed in the fracture, leading to improved conductivity of the proppant pack. Other aqueous fracturing fluids including water, brine, cross-linked polymer fluid and viscoelastic surfactant fluid can also be employed in the present invention. An EHRC can be added straightly or premixed with a solvent or added as an emulsion during an operation. Similarly, one can use pre-hydrophobised proppants to make the slurries in the fracturing operations. Another benefit of the slurries of the present invention is that the aqueous liquid is re-useable after it is separated from the particulates. This has great significance considering there is limited water supply in a number of places.
The present invention also provides a new method for preventing proppant flowback after a fracturing treatment. In field operations, proppants can be pumped into a formation using the composition of the present invention. Alternatively, a fluid medium containing an EHRC can be pumped into the formation following the proppant stage to mix with particulates already in the formation. The particulates in the slurry tend to move cohesively in contrast to conventional slurries under the same conditions. It is worth noting that the cohesiveness among the proppant grains in the present slurry originates from hydrophobic interactions, instead of tackiness as described, for example in US Patent 6,047,772.
The slurry of the present invention is particularly useful in gravel-pack operations where sand slurry is normally pumped into a wellbore to prevent excessive amount of sands from flowing into the wellbore from the formation. The present method is cost effective and the sand pack formed has a high conductivity. Similarly, the slurry can also be used in so-called formation consolidation operations. In such an operation, a fluid containing an EHRC is injected into a formation to increase cohesiveness among sand grains to consolidate the formation and to reduce sand production.
In drilling operations, an EHRC can be added into a water-based drilling fluid. It is particularly useful when the EHRC is added to water or brine for use as a drilling fluid. During a drilling operation, the fluid forms slurry in situ with cuttings and transports the cuttings out of the wellbore. A gas such as nitrogen or carbon dioxide can be mixed with the slurry during drilling. Since it is not necessary to use polymers or clays to viscosity the fluid, there is much less formation damage. Moreover, the cuttings can be easily removed on the surface and the aqueous liquid becomes re-useable. Different formations including sandstone, carbonate, shale and coal seams can be drilled using the slurry of the present invention.
Similarly in wellbore cleanout operations, for example, water containing an EHRC can circulate in the wellbore and form slurry with debris in situ. The debris is subsequently transported out of the wellbore as slurry. The fluid is re-useable after separation from the debris.
For transporting particulates through pipelines slurry can be prepared by mixing the ingredients and then pumping the slurry through the pipeline.

Claims

CLAIMS:
1. An aqueous slurry composition, comprising
(a) an aqueous liquid;
(b) particulates; and
(c) a chemical compound for rendering the surface of the particulates extremely hydrophobic.
2. The aqueous slurry composition of claim 1 wherein the size of the particulates is in the range of 10-100 US mesh.
3. The aqueous slurry composition of claim 1 or 2 wherein the particulates are selected from a group consisting of sands, resin coated sands, ceramic, carbonate, bauxite, shale and coal particulates.
4. The composition of any one of claims 1 to 4, wherein the particulates are subterranean formation particulates.
5. The composition of any one of claims 1 to 4, wherein the chemical compound is selected from a group consisting of organosilanes, organosiloxanes, fluoro-organosilanes, fluoro-organosiloxanes and fluoro-organic compounds.
6. The composition of any one of claims 1 to 4, wherein the chemical compound is an organosilane having the formula
RnSiX(4-n) wherein R is an organic radical having 1-50 carbon atoms that may posses a functionality containing N, S, or P moieties that imparts desired characteristics, X is a halogen, alkoxy, acyloxy or amine and n has a value of 0-3.
7. The composition of any one of claims 1 to 4, wherein the chemical compound is selected from a group consisting of: CH3SiCI3, CH3CH2SiCI3, (CHs)2SiCI2, (CH3CH2)2SiCI2) (C6Hs)2SiCI2, (C6H5)SiCI3, (CH3)3SiCI, CH3HSiCI2, (CH3)2HSiCI, CH3SiBr3, (C6H5)SiBr3, (CHa)2SiBr2, (CH3CH2)2SiBr2, (C6Hs)2SiBr2, (CH3)3SiBr, CH3HSiBr2, (CHs)2HSiBr, Si(OCH3)4, CH3Si(OCH3)3, CH3Si(OCH2CHs)3, CH3Si(OCH2CH2CH3)3, CH3Si[O(CH2)3CH3]3, CH3CH2Si(OCH2CH3)3, C6H5Si(OCH3)3, C6H5CH2Si(OCH3)3, C6H5Si(OCH2CH3)S, CH2=CHCH2Si(OCHs)3, (CH3)2Si(OCH3)2, (CH2=CH)Si(CHs)2CI, (CH3)2Si(OCH2CH3)2> (CHa)2Si(OCH2CH2CHs)2, (CHs)2Si[O(CH2)sCHs]2, (CHsCH2)2Si(OCH2CH3)2, (C6Hs)2Si(OCHs)2, (C6H5CH2)2Si(OCH3)2, (C6H5)2Si(OCH2CH3)2, (CH2=CH2)Si(OCHs)2, (CH2=CHCH2)2Si(OCH3)2, (CH3)3SiOCH3, CH3HSi(OCH3)2, (CH3)2HSi(OCH3), CH3Si(OCH2CH2CHs)3, CH2=CHCH2Si(OCH2CH2OCH3)2, (C6H5)2Si(OCH2CH2OCH3)2, (CHs)2Si(OCH2CH2OCH3)2, (CH2=CH2)2Si(OCH2CH2OCH3)2, (CH2=CHCH2)2Si(OCH2CH2OCH3)2, (C6H5)2Si(OCH2CH2OCH3)2, CH3Si(CH3COO)3, 3-aminotriethoxysilane, methyldiethylchlorosilane, butyltrichlorosilane, diphenyldichlorosilane, vinyltrichlorosilane, methyltrimethoxysilane, vinyltriethoxysilane, vinyltris(methoxyethoxy)silane, methacryloxypropyltrimethoxysilane, glycidoxypropyltrimethoxysilane, aminopropyltriethoxysilane, divinyldi-2- methoxysilane, ethyltributoxysilane, isobutyltrimethoxysilane, hexyltrimethoxysilane, n-octyltriethoxysilane, dihexyldimethoxysilane, octadecyltrichlorosilane, octadecyltrimethoxysilane, octadecyldimethylchlorosilane, octadecyldimethylmethoxysilane and quaternary ammonium silanes including S-^rimethoxysilyOpropyldimethyloctadecyl ammonium chloride, 3-(trimethoxysilyl)propyldimethyloctadecyl ammonium bromide, 3-(trimethylethoxysilylpropyl)didecylmethyl ammonium chloride, triethoxysilyl soyapropyl dimonium chloride, 3- (trimethylethoxysilylpropyl)didecylmethyl ammonium bromide, 3- (trimethylethoxysilylpropyl)didecylmethyl ammonium bromide, triethoxysilyl soyapropyl dimonium bromide, (CH3O)3Si(CH2)SP+(CeH5)SCI, (CH3O)3Si(CH2)3P+(C6H5)3Br-, (CH3O)3Si(CH2)3P+(CH3)3C|-, (CH3O)3Si(CH2)3P+(C6H13)3Cr) (CH3O)3Si(CH2)3N+(CH3)2C4H9CI) (CH3O)3Si(CH2)3N+(CH3)2CH2C6H5Cri (CH3O)3Si(CH2)3N+(CH3)2CH2CH2OHCr, (CH3O)3Si(CH2)SN+(C2Hs)3Cr, (C2H5O)3Si(CH2)3N+(CH3)2C18H37C|-.
8. The composition of any one of claims 1 to 4, wherein the chemical compound is an organosiloxane.
9. The composition of claim 8, wherein the organosiloxane is selected from a group consisting of polyalkylsiloxanes, cationic polysiloxane, amphoteric polysiloxanes, sulfate polysiloxanes, phosphate polysiloxanes, carboxylate polysiloxanes, sulfonate polysiloxanes, thiosulfate polysiloxanes, hexamethylcyclotrisiloxane, octamethylcyclotetrasiloxane, decamethylcyclopentasiloxane, hexamethyldisiloxane, hexaethyldisiloxane, 1 ,3- divinyl-1 ,1 ,3,3-tetramethyldisiloxane, octamethyltrisiloxane and decamethyltetrasiloxane.
10. The composition of claim 8, wherein the organosiloxane is selected from a group consisting of hexamethylcyclotrisiloxane, octamethylcyclotetrasiloxane, decamethylcyclopentasiloxane, hexamethyldisiloxane, hexaethyldisiloxane, 1 ,3- divinyl-1 ,1 ,3,3-tetramethyldisiloxane, octamethyltrisiloxane, decamethyltetrasiloxane.
11. The composition of claim 8, wherein the organosiloxane is a polyalkylsiloxane.
12. The composition of claim 8, wherein the organosiloxane is a cationic polysiloxane.
13. The composition of claim 8, wherein the organosiloxane is a quaternary polysiloxane.
14. The composition of claim 8, wherein the organosiloxane is an amophoteric polysiloxane.
15. The composition of claim 8, wherein the organosiloxane is a betaine polysiloxane.
16. The composition of claim 8 wherein the organosiloxane is selected from a group consisting of sulfate polysiloxane, sulfonate polysiloxane, phosphate polysiloxane, carboxylate polysiloxane and thiosulfate polysiloxane.
17. The composition of claim 8, wherein the organosiloxane is a cationic polysiloxane having the formula
Figure imgf000034_0001
wherein each of Ri to RQ and R8 to R10, represents alkyl containing 1-6 carbon atoms, typically a methyl group, R7 represents a quaternary group and is associated with an anionic ion and may have a hydroxyl group and may be interrupted by an oxygen atom, an amino group or an amide group, and m and n are from 1 to 200.
18. The composition of claim 8, wherein the organosiloxane is a betaine polysiloxane having the formula
Figure imgf000035_0001
wherein each of Ri to R6 and R8 to R-io, represents alkyl containing 1-6 carbon atoms, typically a methyl group, R7 represents an organic betaine group and may have a hydroxyl group and may be interrupted by an oxygen atom, an amino group or an amide group, and m and n are from 1 to 200.
19. The composition of claim 8, wherein the organosiloxane is according to the formula
R 18
Figure imgf000035_0002
where Ri2 to Ri7 each represents alkyl containing 1-6 carbon atoms, typically a methyl group, Rn and Ri8 each represents an organic betaine group and may have a hydroxyl group and may be interrupted by an oxygen atom, an amino group or an amide group and m is 1 to 200.
20. The composition of claim 8, wherein the organosiloxane is according to the formula
Figure imgf000036_0001
where R12 to R17 each represents alkyl containing 1-6 carbon atoms, typically a methyl group, Rn and Ri8 each independently represents an organic quaternary group and is associated with an anionic ion and may have a hydroxyl group and may be interrupted by an oxygen atom, an amino group or an amide group and m is 1 to 200.
21. The composition of any one of claims 1 to 20 further including a gas.
22. A fracturing fluid including the slurry composition according to any one of claims 1 to 21.
23. A gravel-pack fluid including the slurry composition according to any one of claims 1 to 21.
24. A drilling fluid including the slurry composition according to any one of claims 1 to 21.
25. The use of the slurry composition according to any one of claims 1 to 21 for transporting particulates through a pipeline.
26. The use of the slurry composition according to any one of claims 1 to 21 in a well service operation.
27. A method of making an aqueous slurry composition comprising the steps (a) treating particulates with a chemical compound to render the particulate surface extremely hydrophobic, and then
(b) mixing the treated particulates with an aqueous liquid to make an aqueous slurry.
28. A method for making an aqueous slurry composition comprising steps of mixing
(a) an aqueous liquid;
(b) particulates; and
(c) a chemical compound for rendering the surface of the particulates extremely hydrophobic.
29. The method of claim 27 or 28 wherein the size of particulates is in the range of 10-100 US mesh.
30. The method of any one of claims 27 to 29 wherein the particulates are selected from a group consisting of sands, resin coated sands, ceramic, carbonate, bauxite, shale and coal particulates.
31. The method of any one of claims 27 to 30, further including the step of mixing the slurry with a gas.
32. The method of any one of claims 27 to 31 wherein the chemical compound is selected from a group consisting of organosilanes, organosiloxanes, fluoro-organosilanes, fluoro-organosiloxanes and fluoro-organic compounds.
33. The method of any one of claims 27 to 31 wherein the chemical compound is an organosilane having the formula RnSiX(4-n) wherein R is an organic radical having 1-50 carbon atoms that may posses a functionality containing N, S, or P moieties that imparts desired characteristics, X is a halogen, alkoxy, acyloxy or amine and n has a value of 0-3.
34. The method of any one of claims 27 to 31 wherein the chemical compound in claim 21 is an organosiloxane selected from a group consisting of polyalkylsiloxanes, cationic polysiloxane, amphoteric polysiloxanes, sulfate polysiloxanes, phosphate polysiloxanes, carboxylate polysiloxanes, sulfonate polysiloxanes, thiosulfate polysiloxanes, hexamethylcyclotrisiloxane, octamethylcyclotetrasiloxane, decamethylcyclopentasiloxane, hexamethyldisiloxane, hexaethyldisiloxane, 1 ,3-divinyM , 1 ,3,3- tetramethyldisiloxane, octamethyltrisiloxane and decamethyltetrasiloxane.
35. The method of any one of claims 27 to 31 wherein the chemical compound is a polyalkylsiloxane.
36. The method of any one of claims 27 to 31 wherein the chemical compound is a cationic polysiloxane.
37. The method of any one of claims 27 to 31 wherein the chemical compound is a quaternary polysiloxane.
38. The method of any one of claims 27 to 31 wherein the chemical compound is an amophoteric polysiloxane.
39. The method of any one of claims 27 to 31 wherein the chemical compound is a betaine polysiloxane.
40. The method of any one of claims 27 to 31 wherein the chemical compound is selected from a group consisting of sulfate polysiloxane, sulfonate polysiloxane, phosphate polysiloxane, carboxylate polysiloxane and thiosulfate polysiloxane.
41. The method of any one of claims 27 to 40 further including the step of mixing a surfactant with the slurry composition.
42. The slurry composition of any one of claims 1 to 21 further including a surfactant.
43. The fracturing fluid of claim 22 further including a surfactant.
44. The gravel-pack fluid of claim 23 further including a surfactant.
45. The drilling fluid of claim 24 further including a surfactant.
46. A wellbore cleanout fluid including the slurry composition according to any one of claims 1 to 21.
PCT/CA2006/001567 2005-09-23 2006-09-25 Slurry compositions and methods for making same WO2007033489A2 (en)

Priority Applications (6)

Application Number Priority Date Filing Date Title
BRPI0617261-0A BRPI0617261A2 (en) 2005-09-23 2006-09-25 muddy compositions and methods for producing the same
AU2006294332A AU2006294332B2 (en) 2005-09-23 2006-09-25 Slurry compositions and methods for making same
EA200800891A EA024720B1 (en) 2005-09-23 2006-09-25 Aqueous slurry composition for hydraulic fracturing and method for making same
EP06790733A EP1934287A4 (en) 2005-09-23 2006-09-25 Slurry compositions and methods for making same
CN200680034823XA CN101268150B (en) 2005-09-23 2006-09-25 Slurry compositions and methods for making same
NO20081926A NO20081926L (en) 2005-09-23 2008-04-22 Slurry mixture and methods for its preparation

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US71959705P 2005-09-23 2005-09-23
US60/719,597 2005-09-23

Publications (2)

Publication Number Publication Date
WO2007033489A2 true WO2007033489A2 (en) 2007-03-29
WO2007033489A3 WO2007033489A3 (en) 2007-05-18

Family

ID=37889158

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/CA2006/001567 WO2007033489A2 (en) 2005-09-23 2006-09-25 Slurry compositions and methods for making same

Country Status (8)

Country Link
EP (1) EP1934287A4 (en)
CN (2) CN103382387A (en)
AU (1) AU2006294332B2 (en)
BR (1) BRPI0617261A2 (en)
EA (1) EA024720B1 (en)
MY (1) MY153414A (en)
NO (1) NO20081926L (en)
WO (1) WO2007033489A2 (en)

Cited By (29)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2008087444A1 (en) * 2007-01-19 2008-07-24 Halliburton Energy Services, Inc. Compositions for increasing gas production from a subterranean formation
WO2008131540A1 (en) * 2007-04-26 2008-11-06 Trican Well Service Ltd Control of particulate entrainment by fluids
WO2009027680A1 (en) * 2007-08-29 2009-03-05 Statoilhydro Asa Well treatment
US7723274B2 (en) 2005-05-02 2010-05-25 Trican Well Service Ltd. Method for making particulate slurries and particulate slurry compositions
US8053395B2 (en) 2007-01-19 2011-11-08 Halliburton Energy Services, Inc. Compositions for increasing gas production from a subterranean formation
US8236737B2 (en) 2006-12-07 2012-08-07 3M Innovative Properties Company Particles comprising a fluorinated siloxane and methods of making and using the same
US8302691B2 (en) 2007-01-19 2012-11-06 Halliburton Energy Services, Inc. Methods for increasing gas production from a subterranean formation
EP2526161A1 (en) * 2010-01-21 2012-11-28 Trican Well Services Ltd. Compositions and methods for enhancing fluid recovery for hydraulic fracturing treatments
RU2470145C2 (en) * 2007-12-27 2012-12-20 Шлюмбергер Текнолоджи Б.В. Method of retarding damage of formation exposed surface in gas and oil wells (versions) and system to this end
US8360149B2 (en) 2008-12-16 2013-01-29 Schlumberger Technology Corporation Surface modification for cross-linking or breaking interactions with injected fluid
US8678090B2 (en) 2007-12-21 2014-03-25 3M Innovative Properties Company Methods for treating hydrocarbon-bearing formations with fluorinated polymer compositions
US8701763B2 (en) 2008-05-05 2014-04-22 3M Innovative Properties Company Methods for treating hydrocarbon-bearing formations having brine
US8833449B2 (en) 2009-07-09 2014-09-16 3M Innovative Properties Company Methods for treating carbonate hydrocarbon-bearing formations with fluorinated amphoteric compounds
US9057012B2 (en) 2008-12-18 2015-06-16 3M Innovative Properties Company Method of contacting hydrocarbon-bearing formations with fluorinated phosphate and phosphonate compositions
WO2015071750A3 (en) * 2013-11-18 2015-07-23 Clearwater International, Llc Methods and compositions for creating high conductivity fractures
US9315719B2 (en) 2011-07-13 2016-04-19 Halliburton Energy Services, Inc. Low surface friction proppants
WO2016140591A1 (en) * 2015-03-03 2016-09-09 Schlumberger Canada Limited Stabilized pillars for hydraulic fracturing field of the disclosure
US9499737B2 (en) 2010-12-21 2016-11-22 3M Innovative Properties Company Method for treating hydrocarbon-bearing formations with fluorinated amine
US9624422B2 (en) 2010-12-20 2017-04-18 3M Innovative Properties Company Methods for treating carbonate hydrocarbon-bearing formations with fluorinated amine oxides
US9701889B2 (en) 2011-01-13 2017-07-11 3M Innovative Properties Company Methods for treating siliciclastic hydrocarbon-bearing formations with fluorinated amine oxides
US9714371B2 (en) 2005-05-02 2017-07-25 Trican Well Service Ltd. Method for making particulate slurries and particulate slurry compositions
US9850423B2 (en) 2011-11-11 2017-12-26 Schlumberger Technology Corporation Hydrolyzable particle compositions, treatment fluids and methods
US9890294B2 (en) 2012-11-19 2018-02-13 3M Innovative Properties Company Composition including a fluorinated polymer and a non-fluorinated polymer and methods of making and using the same
US9932514B2 (en) 2014-04-25 2018-04-03 Trican Well Service Ltd. Compositions and methods for making aqueous slurry
US10011763B2 (en) 2007-07-25 2018-07-03 Schlumberger Technology Corporation Methods to deliver fluids on a well site with variable solids concentration from solid slurries
US10106724B2 (en) 2012-11-19 2018-10-23 3M Innovative Properties Company Method of contacting hydrocarbon-bearing formations with fluorinated ionic polymers
US10196560B2 (en) 2015-01-30 2019-02-05 Trican Well Service Ltd. Proppant treatment with polymerizable natural oils
US10202542B2 (en) 2014-07-16 2019-02-12 Trican Well Service Ltd. Aqueous slurry for particulates transportation
US10240082B2 (en) 2014-06-30 2019-03-26 Schlumberger Technology Corporation Method for design of production wells and injection wells

Families Citing this family (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2450502B (en) 2007-06-26 2012-03-07 Statoil Asa Microbial enhanced oil recovery
US8119574B2 (en) * 2007-07-25 2012-02-21 Schlumberger Technology Corporation High solids content slurries and methods
EA022566B1 (en) 2008-07-18 2016-01-29 3М Инновейтив Пропертиз Компани Cationic fluorinated polymer and method for treating a hydrocarbon-bearing formation using the same
CN102071873A (en) * 2010-12-21 2011-05-25 山西晋城无烟煤矿业集团有限责任公司 Clean water drilling process of coal bed gas well
CN107129797A (en) * 2017-05-11 2017-09-05 孙东光 A kind of drilling construction retaining wall construction material and preparation method thereof
CN109021958A (en) * 2017-06-12 2018-12-18 中国石油化工股份有限公司 A kind of steady sand load fluid and preparation method thereof with suppression sand function
CN109052539A (en) * 2018-08-31 2018-12-21 王召惠 A kind of preparation method of swimming pool material for water treatment
CN112377127A (en) * 2020-11-30 2021-02-19 西华大学 Drilling tool with well cleaning function
CN115612480A (en) * 2021-07-16 2023-01-17 中国石油化工股份有限公司 Carbon nano tube/perfluorosilane composite sol material and synthesis method and application thereof
CN116425979A (en) * 2023-05-24 2023-07-14 西南石油大学 Betaine polysiloxane, preparation method and application thereof

Family Cites Families (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
ZA756203B (en) * 1974-10-11 1976-09-29 Dresser Ind Silane coated silicate minerals and method for preparing same
US4074536A (en) * 1976-08-02 1978-02-21 Halliburton Company Oil well consolidation treating
US4183814A (en) * 1978-01-03 1980-01-15 Union Carbide Corporation Asbestos composition having organo-silane coating
US4231428A (en) * 1978-12-04 1980-11-04 Phillips Petroleum Company Well treatment method
JPS58146434A (en) * 1982-02-26 1983-09-01 Neos Co Ltd Additive used for aqueous slurry of coal
DE3208598A1 (en) * 1982-03-10 1983-09-22 Degussa Ag, 6000 Frankfurt METHOD FOR THE PRODUCTION OF ZEOLITES MODIFIED WITH ORGANOSILANES
US4554056A (en) * 1985-04-18 1985-11-19 Eagle-Picher Industries, Inc. Impregnation of nickel electrodes using electric pH control circuits
FR2695558B1 (en) * 1992-09-11 1994-10-21 Oreal Cosmetic composition containing solid particles coated with an amphoteric polymer.
US6772838B2 (en) * 1996-11-27 2004-08-10 Bj Services Company Lightweight particulate materials and uses therefor
US5908708A (en) * 1997-03-05 1999-06-01 Engelhard Corporation Aqueous dispersion of a particulate solid having a hydrophobic outer surface and films produced thereby
JP2003506549A (en) * 1999-08-10 2003-02-18 バイエル インコーポレイテッド Method for producing rubber silica masterbatch based on the use of polymer latex
US6736891B1 (en) * 1999-08-19 2004-05-18 Ppg Industries Ohio, Inc. Process for producing hydrophobic particulate inorganic oxides
CA2329600A1 (en) * 2000-12-22 2002-06-22 Kewei Zhang Fracturing fluid
CA2408052A1 (en) * 2000-05-03 2001-11-08 Trican Well Service Ltd. Fracturing fluid
US20040023818A1 (en) * 2002-08-05 2004-02-05 Nguyen Philip D. Method and product for enhancing the clean-up of hydrocarbon-producing well
BRPI0509899A (en) * 2004-04-12 2007-10-09 Carbo Ceramics Inc coating and / or treatment of hydraulic fracturing bearing materials to improve wetting, lubrication of the bearing material, and / or to reduce damage by fracturing fluids and reservoir fluids.
BRPI0610614A2 (en) * 2005-05-02 2010-07-13 Trican Well Services Ltd method for transporting aqueous sludge by particulate hydrophobization

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See references of EP1934287A4 *

Cited By (44)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9976075B2 (en) 2005-05-02 2018-05-22 Trican Well Service Ltd. Method for making particulate slurries and particulate slurry compositions
US9714371B2 (en) 2005-05-02 2017-07-25 Trican Well Service Ltd. Method for making particulate slurries and particulate slurry compositions
US10023786B2 (en) 2005-05-02 2018-07-17 Trican Well Service Ltd. Method for making particulate slurries and particulate slurry compositions
US7723274B2 (en) 2005-05-02 2010-05-25 Trican Well Service Ltd. Method for making particulate slurries and particulate slurry compositions
US8236737B2 (en) 2006-12-07 2012-08-07 3M Innovative Properties Company Particles comprising a fluorinated siloxane and methods of making and using the same
WO2008087444A1 (en) * 2007-01-19 2008-07-24 Halliburton Energy Services, Inc. Compositions for increasing gas production from a subterranean formation
US8302691B2 (en) 2007-01-19 2012-11-06 Halliburton Energy Services, Inc. Methods for increasing gas production from a subterranean formation
US8053395B2 (en) 2007-01-19 2011-11-08 Halliburton Energy Services, Inc. Compositions for increasing gas production from a subterranean formation
AU2008243667B2 (en) * 2007-04-26 2013-11-07 Trican Well Service Ltd Control of particulate entrainment by fluids
CN101675143B (en) * 2007-04-26 2013-07-31 川汉油田服务有限公司 Control of particulate entrainment by fluids
EP2147077A4 (en) * 2007-04-26 2011-04-06 Trican Well Service Ltd Control of particulate entrainment by fluids
CN101675143A (en) * 2007-04-26 2010-03-17 川汉油田服务有限公司 Control of particulate entrainment by fluids
WO2008131540A1 (en) * 2007-04-26 2008-11-06 Trican Well Service Ltd Control of particulate entrainment by fluids
US10138416B2 (en) 2007-04-26 2018-11-27 Trican Well Service, Ltd Control of particulate entrainment by fluids
US8800658B2 (en) 2007-04-26 2014-08-12 Trican Well Service Ltd. Control of particulate entrainment by fluids
US8236738B2 (en) 2007-04-26 2012-08-07 Trican Well Service Ltd Control of particulate entrainment by fluids
EP2147077A1 (en) * 2007-04-26 2010-01-27 Trican Well Service Ltd. Control of particulate entrainment by fluids
US10011763B2 (en) 2007-07-25 2018-07-03 Schlumberger Technology Corporation Methods to deliver fluids on a well site with variable solids concentration from solid slurries
WO2009027680A1 (en) * 2007-08-29 2009-03-05 Statoilhydro Asa Well treatment
GB2453317B (en) * 2007-08-29 2012-12-19 Champion Technologies Ltd Retaining a proppant by use of an organosilane
US8678090B2 (en) 2007-12-21 2014-03-25 3M Innovative Properties Company Methods for treating hydrocarbon-bearing formations with fluorinated polymer compositions
RU2470145C2 (en) * 2007-12-27 2012-12-20 Шлюмбергер Текнолоджи Б.В. Method of retarding damage of formation exposed surface in gas and oil wells (versions) and system to this end
US8701763B2 (en) 2008-05-05 2014-04-22 3M Innovative Properties Company Methods for treating hydrocarbon-bearing formations having brine
US8360149B2 (en) 2008-12-16 2013-01-29 Schlumberger Technology Corporation Surface modification for cross-linking or breaking interactions with injected fluid
US9057012B2 (en) 2008-12-18 2015-06-16 3M Innovative Properties Company Method of contacting hydrocarbon-bearing formations with fluorinated phosphate and phosphonate compositions
US8833449B2 (en) 2009-07-09 2014-09-16 3M Innovative Properties Company Methods for treating carbonate hydrocarbon-bearing formations with fluorinated amphoteric compounds
EP2526161A1 (en) * 2010-01-21 2012-11-28 Trican Well Services Ltd. Compositions and methods for enhancing fluid recovery for hydraulic fracturing treatments
US20120322697A1 (en) * 2010-01-21 2012-12-20 Trican Well Service Ltd Compositions and methods for enhancing fluid recovery for hydraulic fracturing treatments
EP2526161A4 (en) * 2010-01-21 2013-07-03 Trican Well Service Ltd Compositions and methods for enhancing fluid recovery for hydraulic fracturing treatments
US9624422B2 (en) 2010-12-20 2017-04-18 3M Innovative Properties Company Methods for treating carbonate hydrocarbon-bearing formations with fluorinated amine oxides
US9499737B2 (en) 2010-12-21 2016-11-22 3M Innovative Properties Company Method for treating hydrocarbon-bearing formations with fluorinated amine
US9701889B2 (en) 2011-01-13 2017-07-11 3M Innovative Properties Company Methods for treating siliciclastic hydrocarbon-bearing formations with fluorinated amine oxides
US9315719B2 (en) 2011-07-13 2016-04-19 Halliburton Energy Services, Inc. Low surface friction proppants
US10351762B2 (en) 2011-11-11 2019-07-16 Schlumberger Technology Corporation Hydrolyzable particle compositions, treatment fluids and methods
US9850423B2 (en) 2011-11-11 2017-12-26 Schlumberger Technology Corporation Hydrolyzable particle compositions, treatment fluids and methods
US10106724B2 (en) 2012-11-19 2018-10-23 3M Innovative Properties Company Method of contacting hydrocarbon-bearing formations with fluorinated ionic polymers
US9890294B2 (en) 2012-11-19 2018-02-13 3M Innovative Properties Company Composition including a fluorinated polymer and a non-fluorinated polymer and methods of making and using the same
WO2015071750A3 (en) * 2013-11-18 2015-07-23 Clearwater International, Llc Methods and compositions for creating high conductivity fractures
US9932514B2 (en) 2014-04-25 2018-04-03 Trican Well Service Ltd. Compositions and methods for making aqueous slurry
US10240082B2 (en) 2014-06-30 2019-03-26 Schlumberger Technology Corporation Method for design of production wells and injection wells
US10202542B2 (en) 2014-07-16 2019-02-12 Trican Well Service Ltd. Aqueous slurry for particulates transportation
US10196560B2 (en) 2015-01-30 2019-02-05 Trican Well Service Ltd. Proppant treatment with polymerizable natural oils
RU2687722C2 (en) * 2015-03-03 2019-05-15 Шлюмберже Текнолоджи Б.В. Reinforced proppant clusters for formation hydraulic fracturing
WO2016140591A1 (en) * 2015-03-03 2016-09-09 Schlumberger Canada Limited Stabilized pillars for hydraulic fracturing field of the disclosure

Also Published As

Publication number Publication date
EP1934287A4 (en) 2012-04-11
AU2006294332B2 (en) 2013-01-31
MY153414A (en) 2015-02-13
CN103382387A (en) 2013-11-06
NO20081926L (en) 2008-04-22
EA200800891A1 (en) 2008-10-30
CN101268150A (en) 2008-09-17
EA024720B1 (en) 2016-10-31
EP1934287A2 (en) 2008-06-25
WO2007033489A3 (en) 2007-05-18
BRPI0617261A2 (en) 2011-07-19
AU2006294332A1 (en) 2007-03-29
CN101268150B (en) 2013-05-08

Similar Documents

Publication Publication Date Title
AU2006294332B2 (en) Slurry compositions and methods for making same
US7723274B2 (en) Method for making particulate slurries and particulate slurry compositions
US10023786B2 (en) Method for making particulate slurries and particulate slurry compositions
US10138416B2 (en) Control of particulate entrainment by fluids
EP2526161B1 (en) Compositions and methods for enhancing fluid recovery for hydraulic fracturing treatments
US20150252254A1 (en) Fracturing slurry compositions and methods for making same

Legal Events

Date Code Title Description
WWE Wipo information: entry into national phase

Ref document number: MX/a/2008/003446

Country of ref document: MX

WWE Wipo information: entry into national phase

Ref document number: 200680034823.X

Country of ref document: CN

WWE Wipo information: entry into national phase

Ref document number: 2464/DELNP/2008

Country of ref document: IN

WWE Wipo information: entry into national phase

Ref document number: 2006294332

Country of ref document: AU

NENP Non-entry into the national phase in:

Ref country code: DE

REEP Request for entry into the european phase

Ref document number: 2006790733

Country of ref document: EP

WWE Wipo information: entry into national phase

Ref document number: 2006790733

Country of ref document: EP

WWE Wipo information: entry into national phase

Ref document number: DZP2008000212

Country of ref document: DZ

ENP Entry into the national phase in:

Ref document number: 2006294332

Country of ref document: AU

Date of ref document: 20060925

Kind code of ref document: A

WWP Wipo information: published in national office

Ref document number: 2006294332

Country of ref document: AU

WWE Wipo information: entry into national phase

Ref document number: 200800891

Country of ref document: EA

WWP Wipo information: published in national office

Ref document number: 2006790733

Country of ref document: EP

ENP Entry into the national phase in:

Ref document number: PI0617261

Country of ref document: BR

Kind code of ref document: A2

Effective date: 20080324