WO2014134541A1 - Compositions de gel pour applications de fracturation hydraulique - Google Patents

Compositions de gel pour applications de fracturation hydraulique Download PDF

Info

Publication number
WO2014134541A1
WO2014134541A1 PCT/US2014/019599 US2014019599W WO2014134541A1 WO 2014134541 A1 WO2014134541 A1 WO 2014134541A1 US 2014019599 W US2014019599 W US 2014019599W WO 2014134541 A1 WO2014134541 A1 WO 2014134541A1
Authority
WO
WIPO (PCT)
Prior art keywords
copolymer
dialdehyde
acrylamide polymer
wellbore
gel composition
Prior art date
Application number
PCT/US2014/019599
Other languages
English (en)
Inventor
Jiang Li
Roopa TELLAKULA
Original Assignee
Kemira Oyj
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 Kemira Oyj filed Critical Kemira Oyj
Priority to RU2015138480A priority Critical patent/RU2660810C2/ru
Priority to US14/770,668 priority patent/US10081754B2/en
Priority to CA2902801A priority patent/CA2902801C/fr
Priority to AU2014224044A priority patent/AU2014224044B2/en
Priority to CN201480024060.5A priority patent/CN105431609A/zh
Priority to NZ631343A priority patent/NZ631343A/en
Publication of WO2014134541A1 publication Critical patent/WO2014134541A1/fr
Priority to AU2018202757A priority patent/AU2018202757A1/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
    • C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
    • C09K8/504—Compositions based on water or polar solvents
    • C09K8/506—Compositions based on water or polar solvents containing organic compounds
    • C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
    • C09K8/512—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
    • 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
    • C09K8/685—Compositions based on water or polar solvents containing organic compounds containing cross-linking agents

Definitions

  • the present disclosure generally relates to gel compositions and wellbore treatment fluids for use in hydraulic fracturing applications.
  • hydraulic fracturing also referred to as fracing (or fracking)
  • fracing or fracking
  • a fluid composition is injected into the well at pressures effective to cause fractures in the surrounding rock formation. Fracing is used both to open up fractures already present in the formation and create new fractures.
  • Proppants such as sand and ceramics, are used to keep induced fractures open both during and after fracturing treatment.
  • the proppant particles are suspended in a fluid that is pumped into the subterranean formation.
  • this fluid has a viscosity sufficient to maintain suspension of the particles.
  • a hydraulic fracturing fluid should be sufficiently viscous to create a fracture of adequate width and be able to transport large quantities of proppants into the fracture.
  • the viscosity of the fluid can be enhanced or modified by addition of synthetic and/or natural polymers, or other rheology modifiers.
  • polymer-enhanced fluids used to increase the viscosity of hydraulic fracturing fluids include slickwater systems, linear gel systems, and crosslinked gel systems. Of these, crosslinked gel systems are the most viscous.
  • a linear polymer or gel for example, a fluid based on guar or modified guar
  • reagents such as borate, zirconate, and titanate in the presence of alkali.
  • the most common version of crosslinked gel is known in the art as guar-borate gel.
  • the crosslinked gel fluid increases the viscosity of the fracturing fluid, such that proppants can be effectively suspended.
  • Synthetic polymers for example polyacrylamide (PAM) polymers, can form permanent gels under acidic conditions with metal crosslinking agents, such as aluminum-, chromium-, zirconium- and titianium-based complexes.
  • metal crosslinking agents such as aluminum-, chromium-, zirconium- and titianium-based complexes.
  • EOR enhanced oil recovery
  • the acidity of the formation in hydraulic fracturing is usually not high, and breaking of the crosslinked gel improves fluid recovery.
  • gel compositions comprising an acrylamide polymer or copolymer having a charge between about 5% to about 35%, or more specifically about 15% to about 20%), and dialdehyde.
  • the gel composition is formed by combining the acrylamide polymer or copolymer and dialdehyde in an aqueous solution at a pH in the range of about 7.5 to about 11, wherein the molar ratio of dialdehyde to monomers of the acrylamide polymer or copolymer is in the range of about greater than about 0.2 to about 2.0.
  • Methods to produce the gel composition comprising injecting the gel composition into a wellbore, and well treatment fluids comprising the gel composition are also disclosed herein.
  • methods of treating a wellbore comprising injecting a composition comprising an acrylamide polymer or copolymer having a charge between 15% to 20% into a wellbore; injecting a composition comprising dialdehyde into the wellbore, and injecting a pH modifying agent into the wellbore in an amount sufficient to produce a downhole solution pH in the range of about 7.5 to about 11, to produce an in-situ gel composition comprising an acrylamide polymer or copolymer crosslinked with dialdehyde.
  • Wellbore treatment fluids comprising an acrylamide polymer or copolymer and dialdehyde are also disclosed herein.
  • the wellbore treatment fluid may be formed (in whole or in part) prior to injection into the wellbore or in situ, where the acrylamide polymer/copolymer and the crosslinker are added to the wellbore separately.
  • the wellbore treatment fluid may optionally comprise one or more additional components, such as proppants and pH control agents.
  • Figure 1 provides a graph showing the results of the viscosity analyses for exemplary gels according to the embodiments and a guar gel.
  • Figure 2 provides a graph showing the relationship between charge and viscosity for anionic copolymers at various charges.
  • the present disclosure provides cross-linked gel compositions which comprise an acrylamide polymer or copolymer and dialdehyde.
  • the gel compositions are useful for increasing the viscosity of hydraulic fracturing fluids.
  • the gel compositions have a charge (mole percent) within a specific range that is especially useful for viscosifying wellbore treatment fluids, enhancing delivery of proppants into fractures.
  • the exemplary gel compositions may break under certain conditions, which can increase fluid recovery in hydraulic fracturing applications.
  • the exemplary gel compositions can be used as a synthetic replacement for crosslinked guar compositions in hydraulic fracturing applications, with comparable performance.
  • the exemplary gel compositions provide high viscosity with a relatively low amount of active polymer in the composition.
  • Exemplary gel compositions may be easier to manufacture, and of a more reliable quality, than guar gels.
  • the present invention is a gel composition comprising an acrylamide polymer or copolymer crosslinked with dialdehyde.
  • acrylamide polymer refers to a homopolymer of acrylamide and encompasses acrylamide polymers chemically modified (e.g., hydrolyzed) following polymerization.
  • acrylamide copolymer refers to a polymer comprising an acrylamide monomer and one or more comonomers.
  • the comonomer may be anionic, cationic or non-ionic. In certain embodiments, the comonomer is hydrophobic.
  • the acrylamide copolymer may be unmodified or chemically modified.
  • Representative, non-limiting co-monomers include acrylic acid, vinyl acetate, vinyl alcohol and/or other unsaturated vinyl monomers.
  • the acrylamide copolymer comprises an anionic comonomer.
  • the anionic monomer is selected from the group consisting of (meth)acrylic acid, alkali/alkaline/ammonium salts of (meth)acrylic acid, 2- acrylamido-2-methylpropanesulfonic acid, alkali/alkaline/ammonium salts of 2-acrylamido- 2-methylpropanesulfonic acid, maleic acid, alkali/alkaline/ammonium salts of maleic acid and the like.
  • the acrylamide copolymer comprises a cationic comonomer.
  • the cationic monomer is selected from the group consisting of (meth)acrylamidoethyltrimethylammonium chloride, (meth) acrylamido propyltrimethylammonium chloride and the like.
  • the acrylamide copolymer comprises a non-ionic comonomer.
  • the non-ionic monomer is selected from the group consisting (meth)acrylamide, maleic anhydride.
  • the acrylamide copolymer comprises an acrylamide monomer and an anionic comonomer, but does not include a cationic comonomer.
  • the acrylamide polymer or copolymer is characterized by a charge of about 0% to about 40%, about 5% to about 35%, about 15% to about 30%, about 15% to about 20% or about 20% to about 30%. In one embodiment, the charge is in the range of about 5% to about 35% and provides a particularly high viscosity that provides substantial suspending power. In another embodiment, the charge is in the range of about 15%) to about 20%) and provides a particularly high viscosity that provides substantial suspending power. [0024] In another embodiment, the acrylamide polymer or copolymer is characterized by a charge of about 10%, about 15%, about 20%, about 25%, about 30%, about 35% or about 40%.
  • the range of charge for the gel composition disclosed herein is a function of the charge of the polyacrylamide copolymer comprising charged monomers or the chemically modified polyacrylamide polymer or copolymer.
  • the acrylamide copolymer comprises from about 30 to about 90 , about 40 to about 80, about 50 to about 70 or about 60 mole % acrylamide.
  • the weight ratio of the acrylamide monomer to the one or more comonomers is about 10:90 to 90: 10.
  • the acrylamide polymer or copolymer is characterized by a degree of hydrolysis of about 5 to about 10%, about 10 to about 15%, about 15 to about 20%, about 20 to about 25%, about 25 to about 30% or greater than about 30%. In a more particular embodiment, the acrylamide polymer or copolymer is characterized by a degree of hydrolysis of about 15, about 16, about 17, about 18, about 19 or about 20%.
  • acrylamide polymers or copolymers are water dispersible.
  • the acrylamide polymer or copolymer has a weight average molecular weight of greater than or equal to about 0.5 million g/mol. In another embodiment, the acrylamide polymer or copolymer has a weight average molecular weight of in the range of about 0.5 million g/mol to about 30 million g/mol.
  • the liquid used to form the gel composition any suitable aqueous liquid that does not adversely react with the acrylamide polymer or copolymer, such as fresh water, salt water, brine, or any other aqueous liquid.
  • the dialdehyde used to cross-link the acrylamide polymer or copolymer may be any suitable dialdehyde.
  • dialdehydes include glyoxal, malondialdehyde, succindialdehyde, glutaraldehyde, adipaldehyde, o-phthaldehyde, m-phthaldehyde, p-phthaldehyde, and combinations and mixtures thereof.
  • the dialdehyde is a glyoxal.
  • the gel composition comprises an acrylamide polymer, crosslinked with glyoxal.
  • the gel composition comprises an acrylamide polymer crosslinked with glyoxal, wherein the acrylamide polymer is characterized by a charge in range of about 5% to about 40% and provides a particularly high viscosity that provides substantial suspending power.
  • the charge is in the range of about 15% to about 20% and provides a particularly high viscosity that provides substantial suspending power.
  • the charge is about 10%, about 15%, about 20%, about 25%, about 30%, about 35% or about 40%.
  • the gel composition comprises an acrylamide copolymer crosslinked with glyoxal.
  • the gel composition comprises an acrylamide copolymer crosslinked with glyoxal, wherein the acrylamide copolymer is characterized by a charge in range of about 5% to about 40% and provides a particularly high viscosity that provides substantial suspending power.
  • the charge is in the range of about 15% to about 20% and provides a particularly high viscosity that provides substantial suspending power.
  • the charge is about 10%, about 15%, about 20%, about 25%, about 30%, about 35% or about 40%.
  • the amount of the acrylamide polymer or copolymer in the gel composition may depend, for example, on the particular polymer/copolymer used, the purity of the polymer/copolymer, and properties desired in the final composition.
  • the gel composition comprises from about 0.05 to about 5% by weight polymer or copolymer, from about 0.1 to about 1% or from about 0.2 to about 5% by weight polymer or copolymer, based on the total weight of the composition.
  • the gel composition comprises about 5, about 0.1 to about 3, about 0.2 to about 2, or about 0.3 to about 1% by weight percent polymer or copolymer based on the total weight of the composition.
  • the gel composition comprises from about 0.1% to about 25% of acrylamide polymer or copolymer, by weight of the composition. In certain embodiments, the gel composition comprises from about 0.01% to about 25% acrylamide polymer or copolymer, by weight of the composition.
  • the gel composition comprises an acrylamide polymer or copolymer crosslinked with glyoxal wherein the polymer or copolymer (i) comprises about 0.05 to about 5% by weight polymer/copolymer and (ii) is characterized by a charge in range of about 5% to about 40%, and more particularly about 15 to about 20%.
  • the gel composition has a dialdehyde to monomer ratio of from about 0.2 to about 2.0.
  • the molar ratio of dialdehyde to monomers of the acrylamide polymer or copolymer is greater than about 0.2, about 0.3, about 0.4, about 0.5, about 0.6, about 0.7, about 0.8, about 0.9, about 1.0, about 1.1, about 1.2, about 1.3, about 1.4, about 1.5, about 1.6, about 1.7, about 1.8, about 1.9, about 2.0.
  • the molar ratio of dialdehyde to monomers of the acrylamide polymer or copolymer is in the range of about greater than about 0.2 to about 2.0, about 0.5 to about 2.0, about 0.7 to about 2.0, about 0.8 to about 2.0, about 1.0 to about 2.0, about 1.1 to about 2.0, or about 1.0 to about 1.5. In a particular embodiment, the molar ratio of dialdehyde to monomers of the acrylamide polymer or copolymer is greater than about 1.0.
  • the gel composition comprises an acrylamide polymer or copolymer crosslinked with glyoxal wherein (i) the polymer or copolymer comprises about 0.05 to about 5% by weight polymer/copolymer and is characterized by a charge in range of about 5% to about 40%, and more particularly about 15 to about 20% and (ii) the molar ratio of dialdehyde to monomers of the acrylamide polymer or copolymer is about 0.2 to about 2.0.
  • the gel compositions according to the embodiments have a viscosity of greater than or equal to about 100 cP at about 100 sec-1.
  • the viscosity of the gel may composition may be controlled by varying the concentrations of the
  • the gel composition has a viscosity greater than about 150, or greater than about 200, or greater than about 250 cP, or greater than about 400 cP at about 100 sec-1.
  • the gel composition comprises an acrylamide polymer or copolymer crosslinked with glyoxal, wherein (i) the polymer/copolymer comprises about 0.05 to about 5% by weight polymer/copolymer and is characterized by a charge in range of about 5% to about 40%, and more particularly about 15 to about 20% and (ii) the molar ratio of dialdehyde to monomers of the acrylamide polymer or copolymer is about 0.2 to about 2.0; and (iii) the gel composition has a viscosity of greater than or equal to about 100 cP at about 100 sec-1.
  • the present invention is a wellbore fluid composition
  • a wellbore fluid composition comprising an acrylamide polymer or copolymer crosslinked with dialdehyde.
  • the acrylamide polymer or copolymer may be any suitable acrylamide polymer or copolymer, such as those described above.
  • the necessary or desired amounts of the acrylamide polymer or copolymer and dialdehyde may be determined based on various factors, including, for example, assumptions about the downhole conditions.
  • the presence of a gel down hole may be determined by other indicators other than rheo logical measurements.
  • a wellbore fluid composition may contain from about 0.05 to about 5%, from about 0.1 to about 1%, or from about 0.2 to about 5% by weight acrylamide polymer or copolymer, based on the total weight of the composition.
  • the dialdehyde to monomer ratio is from about 0.2 to about 2.0.
  • the molar ratio of dialdehyde to monomers of the acrylamide polymer or copolymer is greater than about 0.2, about 0.3, about 0.4, about 0.5, about 0.6, about 0.7, about 0.8, about 0.9, about 1.0, about 1.1, about 1.2, about 1.3, about 1.4, about 1.5, about 1.6, about 1.7, about 1.8, about 1.9, about 2.0.
  • the molar ratio of dialdehyde to monomers of the acrylamide polymer or copolymer is in the range of about greater than about 0.2 to about 2.0, about 0.5 to about 2.0, about 0.7 to about 2.0, about 0.8 to about 2.0, about 1.0 to about 2.0, about 1.1 to about 2.0, or about 1.0 to about 1.5. In a particular embodiment, the molar ratio of dialdehyde to monomers of the acrylamide polymer or copolymer is greater than about 1.0.
  • the wellbore fluid composition comprises an acrylamide polymer or copolymer crosslinked by dialdehyde and a pH modifying agent.
  • the wellbore fluid composition is formed (in whole or in part) prior to injection into the wellbore.
  • the wellbore fluid composition is formed (in whole or in part) in situ (i.e., in the wellbore). Where the wellbore fluid composition is formed in situ, the components of the well fluid composition may be injected into the wellbore simultaneously or sequentially, in any order.
  • the wellbore fluid composition is formed in situ by injecting (i) a composition comprising an acrylamide polymer or copolymer and a pH modifying agent and (ii) a composition comprising dialdehyde, where the injection of (i) and (ii) occurs simultaneously or sequentially, in any order.
  • the wellbore fluid composition is formed in situ by injecting (i) a composition comprising dialdehyde and a pH modifying agent and (ii) a composition comprising an acrylamide polymer or copolymer, where the injection of (i) and (ii) occurs simultaneously or sequentially, in any order. .
  • the wellbore fluid composition is formed in situ by injecting (i) a composition comprising an acrylamide polymer or copolymer; (ii) a composition comprising dialdehyde may be combined; and (iii) a composition comprising a pH modifying agents, wherein the injection of (i)-(iii) occurs simultaneously or sequentially, in any order.
  • the pH modifying agent is any suitable pH modifying agent and may be in the form of an aqueous solution, for example an aqueous solution comprising a base, an acid, a pH buffer, or any combination thereof.
  • the pH modifying agent is a potassium carbonate and potassium hydroxide mixture or a sodium bicarbonate and sodium carbonate mixture.
  • a wellbore treatment fluid comprises a gel composition as described herein.
  • the wellbore treatment fluid optionally comprises a proppant, for example natural or synthetic proppants, including but not limited to glass beads, ceramic beads, sand, gravel, and bauxite and combinations thereof.
  • a proppant for example natural or synthetic proppants, including but not limited to glass beads, ceramic beads, sand, gravel, and bauxite and combinations thereof.
  • Exemplary proppants may be coated or contain chemicals; more than one can be used sequentially or in mixtures of different sizes or different materials.
  • the proppant may be resin coated (curable), or pre-cured resin coated.
  • the proppant may be any suitable shape, including substantially spherical materials, fibrous materials, polygonal materials (such as cubic materials), and combinations thereof.
  • the proppant is a reduced density proppant.
  • the wellbore treatment fluids comprising the gel compositions, or dialdehyde and acrylamide polymer or copolymer compositions for forming the gel compositions, can be used in any well treatment fluid where viscosification is desired including but not limited to stimulation and completion operations.
  • the wellbore treatment fluid can be used for hydraulic fracturing applications.
  • the fracturing fluid i.e. wellbore treatment fluid
  • the fracturing fluid can be configured as a gelled fluid, a foamed gel fluid, acidic fluids, water and potassium chloride treatments, and the like.
  • the fluid is injected at a pressure effective to create one or more fractures in the subterranean formation.
  • additives may also be added to the wellbore fluid to change the physical properties of the fluid or to serve a certain beneficial function.
  • a propping agent such as sand or other hard material is added which serves to keep the fractures open after the fracturing operation.
  • fluid loss agents may be added to partially seal off the more porous sections of the formation so that the fracturing occurs in the less porous strata.
  • oilfield additives that may also be added to the wellbore treatment fluid include antifoams, scale inhibitors, H 2 S and or 0 2 scavengers, biocides, surface tension reducers, breakers, buffers, surfactants and non-emulsifiers, fluorocarbon surfactants, clay stabilizers, fluid loss additives, foamers, friction reducers, temperature stabilizers, diverting agents, shale and clay stabilizers, paraffin/asphaltene inhibitors, corrosion inhibitors.
  • the wellbore treatment fluid may optionally further comprise additional additives, including, but not limited to, acids, fluid loss control additives, gas, corrosion inhibitors, scale inhibitors, catalysts, clay control agents, biocides, friction reducers, combinations thereof and the like.
  • additional additives including, but not limited to, acids, fluid loss control additives, gas, corrosion inhibitors, scale inhibitors, catalysts, clay control agents, biocides, friction reducers, combinations thereof and the like.
  • a gas such as air, nitrogen, or carbon dioxide.
  • the present invention is a method of making a gel composition comprising an acrylamide polymer or copolymer crosslinked by dialdehyde.
  • a method of making a gel composition comprises combining or contacting an acrylamide polymer or copolymer with a dialdehyde in an aqueous medium, wherein the molar ratio of dialdehyde to monomers of the acrylamide polymer or copolymer is in the range of about greater than about 0.2 to about 2.0, or from about 1 to 1.5, at a temperature and for a period of time sufficient to produce the gel composition.
  • the pH of the aqueous medium may vary.
  • the pH of the aqueous solution is greater than about 7.5, about 8.0, about 8.5, about 9.0, about 10.0, about 10.2, about 10.5, about 10.7, or about 11.
  • the pH is in the range of about 7.5 to about 11, about 8.5 to about 11, about 9.0 to about 1 1, about 10 to about 11, or about 10.2 to about 10.7.
  • the pH is greater than about 9.0.
  • the pH modifying agents which may be used to modify the pH of the gel or the composition in which the gel is formed are any pH modifying agents suitable, for example basic compounds, which are inert relatively to the polymer and the dialdehyde, for example inorganic compounds, such as alkaline and alkaline-earth hydroxides or salts, including but not limited to alkaline carbonate or phosphate.
  • acrylamide polymer or copolymer is provided in the form of a fine aqueous dispersion or emulsion of the acrylamide polymer or copolymer.
  • the acrylamide polymer or copolymer component is about 0.1 to 1 wt. % of the acrylamide polymer or copolymer in the solution, dispersion or emulsion.
  • the dialdehyde is in the form of a dialdehyde in an aqueous solution.
  • the acrylamide polymer or copolymer component and/or the dialdehyde component are each adjusted to a pH in the range of about 7.5 to about 11 prior the step of combining or contacting the components.
  • the acrylamide polymer or copolymer component is prepared by shearing, agitating or stirring the acrylamide polymer or copolymer in an aqueous medium until a fine dispersion or emulsion is obtained.
  • the pH of the fine aqueous dispersion or emulsion of the acrylamide polymer or copolymer is adjusted as desired, for example, adjusted to a pH in the range of about 7.5 to about 11.0.
  • the step of combining or contacting the acrylamide polymer or copolymer with dialdehyde in an aqueous solution includes shearing, agitating or stirring the components to form a thoroughly blended mixture or a gel composition.
  • the final pH of the mixture or gel composition is recorded, and then the gel is tested for viscosity in a rheometer (e.g. a Grace Instrument M5600 HPHT Rheometer).
  • the aqueous solution may be in the form of an aqueous liquid, an aqueous emulsion, an aqueous dispersion or an aqueous slurry.
  • the period of time sufficient to produce the gel composition may vary.
  • the formation of the gel composition or the crosslinking of the acrylamide polymer or copolymer and dialdehyde occurs in less than about 1 hour, about 40 minutes, about 30 minutes, or about 20 minutes or less than about 10 minutes, or less than about 5 minutes.
  • the temperature to produce the gel composition may vary.
  • the gel composition is produced at a temperature of greater than or equal to about 20° C, about 30° C, about 40° C, about 50° C, about 60° C, about 70° C, about 80° C, or about 90° C.
  • the gel composition is produced in a period of time of about 1 minute to about 24 hours, about 5 minutes to about 2 hours, or about 10 minutes to about 1 hour.
  • a method to produce a gel composition comprises combining or contacting an acrylamide polymer or copolymer, or a fine aqueous dispersion or emulsion of the acrylamide polymer or copolymer, with dialdehyde in an aqueous solution at a pH in the range of about 7.5 to about 11, wherein the molar ratio of dialdehyde to monomers of the acrylamide polymer or copolymer is in the range of about greater than about 0.2 to about 2.0, at a temperature and for a period of time sufficient to produce the gel composition.
  • the method of producing the gel composition comprises combining or contacting an acrylamide polymer or copolymer with dialdehyde in an aqueous solution at a pH in the range of about 7.5 to about 11, at a temperature and for a period of time sufficient to produce a gel composition, wherein the gel composition is partially cross-linked before it is added to the wellbore and then becomes fully-crosslinked in situ.
  • the present invention is a method of treating a wellbore using a gel composition.
  • a method of treating a wellbore comprises injecting a gel composition described herein into a wellbore.
  • the gel composition is at least partially pre-formed and subsequently injected into the wellbore.
  • the gel composition is formed in situ.
  • a method of treating a wellbore comprises injecting a composition comprising an acrylamide polymer or copolymer into a wellbore; injecting a composition comprising dialdehyde into the wellbore, and injecting a pH modifying agent into the wellbore in an amount sufficient (or calculated to be sufficient) to produce a downhole solution pH in the range of about 7.5 to about 11, to produce an in-situ gel composition comprising an acrylamide polymer or copolymer crosslinked with dialdehyde.
  • the wellbore treatment fluid or gel composition may be used for carrying out a variety of subterranean treatments, including, but not limited to, drilling operations, fracturing treatments, and completion operations (e.g., gravel packing).
  • the wellbore treatment fluid or gel composition may be used in treating a portion of a subterranean formation.
  • the wellbore treatment fluid or gel composition may be introduced into a well bore that penetrates the subterranean formation.
  • the wellbore treatment fluid or gel composition may be used in fracturing treatments.
  • the wellbore treatment fluids and gel compositions of the present embodiments may be used in any subterranean treatment as desired.
  • Such subterranean treatments include, but are not limited to, drilling operations, stimulation treatments, and completion operations.
  • Those of ordinary skill in the art, with the benefit of this disclosure, will be able to recognize a suitable subterranean treatment where friction reduction may be desired.
  • the wellbore treatment fluid, gel compositions and methods can be used in or injected into fresh water, salt water or brines.
  • wellbore treatment fluid, gel compositions and methods can be used within a temperature range of about 20°C to about 205°C, about 50°C to about 200°C, or about 70°C to about 200°C.
  • a method of fracturing a subterranean formation comprises: providing a wellbore treatment fluid or gel composition according to the present embodiments; and placing the wellbore treatment fluid or gel composition into a subterranean formation so as to create or enhance a fracture in the subterranean formation.
  • a method of fracturing a subterranean formation comprises: providing a wellbore treatment fluid or gel composition according to the present embodiments; and pumping the wellbore treatment fluid or gel composition so as to form or extend a fracture in the subterranean formation and deposit the wellbore treatment fluid or gel composition in the fracture.
  • the method further comprises allowing the gel composition in the fracture to break.
  • the gel composition breaks without the addition of breaking agents or breakers.
  • the method further comprises the addition of breaking agents or breakers.
  • breakers include persulfates of ammonium, sodium and potassium, sodium perborate, hydrogen peroxide, organic peroxides, percarbonates, perphosphates, organic acids, perphosphate esters, amides, ammonium sulfate, enzymes, copper compounds, ethylene glycol, glycol ethers, and combinations thereof
  • Example 1 Preparation and Viscosity Analysis of Exemplary Glyoxal- Crosslinked-Polymer Gels
  • Exemplary gels were prepared by the following protocol. About 0.4 wt% of active acrylamide polymer in water was stirred for about 10 minutes to about 20 minutes at room temperature. Once the solution was thoroughly blended, the pH of the solution was measured and adjusted using a pH buffer solution to about 9.8 to about 10.3. 0.33, 0.49 or 0.65 wt. % of glyoxal was added to the solution. The mixture was stirred until the glyoxal was well incorporated. The viscosity of each of the resulting gels was measured on a Grace Instrument M5600 HPHT Rheometer at 180°F.
  • the Grace Instrument M5600 HPHT Rheometer which is a true Couette, coaxial cylinder, rotational, high pressure and temperature rheometer.
  • the instrument is fully automated and all data acquisition is under computer control.
  • the temperature of the sample is maintained with an oil bath which runs from ambient to 500°F.
  • the gel is also subjected to pressure with nitrogen gas to prevent boiling off the solvent. After 20 minutes of shear conditioning, the gel is subjected to a shear sweep which can be programmed in the software that accompanies the Rheometer.
  • the data acquired from the computer is processed and plotted as desired.
  • Figure 1 shows the viscosity analyses of three exemplary gels and, for comparison, a guar gel.
  • Example 2 Charge- Viscosity Analysis of Exemplary Dry and Emulsion Glyoxal-Crosslinked-Polymer Gels
  • the compositions were prepared by adding 200 mL of 2% KC1 to a Waring blender jar. 0.3% of active acrylamide copolymer was added along with the pH buffer and mixed for a few minutes. 0.33% glyoxal was added (to provide a molar ratio of glyoxal to monomer of about 1.35) and blended for a few seconds.
  • the obtained crosslinked gel was evaluated on an Anton Paar Physica Rheometer setup with concentric cylinder geometry. The gel was sheared at a constant shear rate of 100 s "1 and at a temperature of 180 °F. The viscosity reported in the table is an average reading measured over 30 minutes.
  • the Static Proppant Settling Column test was used to evaluate settling time of proppants in PAM. This test used a 250mL graduated cylinder with a proppant loading of 4 lb/gal with a 20/40 mesh. Proppant was blended with the crosslinked PAM using a blender for 10-30 seconds until well mixed. The downward mobility was measured as a function of time. Sample Type Time Initial Final Sand Fluid

Landscapes

  • Chemical & Material Sciences (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Compositions Of Macromolecular Compounds (AREA)
  • Addition Polymer Or Copolymer, Post-Treatments, Or Chemical Modifications (AREA)
  • Processes Of Treating Macromolecular Substances (AREA)

Abstract

L'invention concerne des compositions de gel comprenant un polymère ou un copolymère à base d'acrylamide réticulé avec un dialdéhyde, des procédés pour produire ces compositions de gel, des fluides de traitement de trous de forage comprenant ces compositions de gel, et des procédés de traitement d'un trou de forage consistant à injecter ces compositions de gel. Lors du forage, de la complétion et de la stimulation de puits de pétrole et de gaz, des fluides de traitement de puits sont souvent introduits par pompage dans des trous de forage sous haute pression et à des débits élevés, provoquant la fracturation de la formation rocheuse entourant le trou de forage.
PCT/US2014/019599 2013-02-28 2014-02-28 Compositions de gel pour applications de fracturation hydraulique WO2014134541A1 (fr)

Priority Applications (7)

Application Number Priority Date Filing Date Title
RU2015138480A RU2660810C2 (ru) 2013-02-28 2014-02-28 Гелевые композиции для применения в гидроразрыве пластов
US14/770,668 US10081754B2 (en) 2013-02-28 2014-02-28 Gel compositions for hydraulic fracturing applications
CA2902801A CA2902801C (fr) 2013-02-28 2014-02-28 Compositions de gel pour applications de fracturation hydraulique
AU2014224044A AU2014224044B2 (en) 2013-02-28 2014-02-28 Gel compositions for hydraulic fracturing applications
CN201480024060.5A CN105431609A (zh) 2013-02-28 2014-02-28 用于水力压裂应用的凝胶组合物
NZ631343A NZ631343A (en) 2013-02-28 2014-02-28 Gel compositions for hydraulic fracturing applications
AU2018202757A AU2018202757A1 (en) 2013-02-28 2018-04-19 Gel compositions for hydraulic fracturing applications

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201361770620P 2013-02-28 2013-02-28
US61/770,620 2013-02-28

Publications (1)

Publication Number Publication Date
WO2014134541A1 true WO2014134541A1 (fr) 2014-09-04

Family

ID=51428866

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2014/019599 WO2014134541A1 (fr) 2013-02-28 2014-02-28 Compositions de gel pour applications de fracturation hydraulique

Country Status (4)

Country Link
CN (1) CN105431609A (fr)
AU (2) AU2014224044B2 (fr)
NZ (1) NZ631343A (fr)
WO (1) WO2014134541A1 (fr)

Families Citing this family (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN111961452B (zh) * 2020-08-04 2021-05-07 中国石油大学(华东) 耐高温高强度触变型凝胶堵漏剂及其制备方法与应用
CN112608729A (zh) * 2020-12-15 2021-04-06 陕西科技大学 一种可分相存储酸触发的压裂液及其制备方法和应用
CN112521639A (zh) * 2020-12-15 2021-03-19 陕西科技大学 一种可分相存储高温触发的压裂液及方法和应用
CN112592497A (zh) * 2020-12-15 2021-04-02 陕西科技大学 一种可分相存储高温触发的压裂液及其制备方法和应用

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4782900A (en) * 1987-04-24 1988-11-08 Pfizer Inc. Aminoalkylated polyacrylamide aldehyde gels, their preparation and use in oil recovery
US5246073A (en) * 1992-08-31 1993-09-21 Union Oil Company Of California High temperature stable gels
US20060116296A1 (en) * 2004-11-29 2006-06-01 Clearwater International, L.L.C. Shale Inhibition additive for oil/gas down hole fluids and methods for making and using same
US20060142535A1 (en) * 2004-12-21 2006-06-29 Shane Cyr Reactive cationic resins for use as dry and wet strength agents in sulfite ion-containing papermaking systems

Family Cites Families (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6908888B2 (en) * 2001-04-04 2005-06-21 Schlumberger Technology Corporation Viscosity reduction of viscoelastic surfactant based fluids
US7084095B2 (en) * 2001-04-04 2006-08-01 Schlumberger Technology Corporation Methods for controlling the rheological properties of viscoelastic surfactants based fluids
US7897545B2 (en) * 2008-08-08 2011-03-01 Halliburton Energy Services, Inc. Fluid loss compositions and methods of use for subterranean operations
WO2013188413A1 (fr) * 2012-06-12 2013-12-19 Soane Energy, Llc Systèmes de gel polymère synthétique réticulé pour fracturation hydraulique

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4782900A (en) * 1987-04-24 1988-11-08 Pfizer Inc. Aminoalkylated polyacrylamide aldehyde gels, their preparation and use in oil recovery
US5246073A (en) * 1992-08-31 1993-09-21 Union Oil Company Of California High temperature stable gels
US20060116296A1 (en) * 2004-11-29 2006-06-01 Clearwater International, L.L.C. Shale Inhibition additive for oil/gas down hole fluids and methods for making and using same
US20060142535A1 (en) * 2004-12-21 2006-06-29 Shane Cyr Reactive cationic resins for use as dry and wet strength agents in sulfite ion-containing papermaking systems

Also Published As

Publication number Publication date
NZ631343A (en) 2017-06-30
CN105431609A (zh) 2016-03-23
AU2018202757A1 (en) 2018-05-10
AU2014224044A1 (en) 2015-09-24
AU2014224044B2 (en) 2018-05-10

Similar Documents

Publication Publication Date Title
US20220251440A1 (en) Cross-linked acrylamide polymer or copolymer gel and breaker compositions and methods of use
US8450252B2 (en) High temperature fracturing fluids and methods
US8003577B2 (en) Method of treating subterranean formation with crosslinked polymer fluid
CA2618394C (fr) Compositions pour traitement de puits de forage contenant un epaississant de mousse et procedes d'utilisation correspondants
US7044224B2 (en) Permeable cement and methods of fracturing utilizing permeable cement in subterranean well bores
US7897545B2 (en) Fluid loss compositions and methods of use for subterranean operations
AU5793600A (en) Hydraulic fracturing using non-ionic surfactant gelling agent
EA027700B1 (ru) Повышающий вязкость агент для регулирования потерь жидкости с использованием хелатов
AU2018202757A1 (en) Gel compositions for hydraulic fracturing applications
US8813843B2 (en) Hydrophobically modified polymer for thermally stabilizing fracturing fluids
US9803132B2 (en) Methods for altering fluid rheology
WO2011123249A2 (fr) Procédé de traitement de formation souterraine
US8426346B2 (en) Polycarboxylic acid gelling agents
US7325615B2 (en) Viscosified treatment fluids comprising polycarboxylic acid gelling agents and associated methods
CA2902801C (fr) Compositions de gel pour applications de fracturation hydraulique
US20240067867A1 (en) Friction Reducers, Fluid Compositions and Uses Thereof
US20140262276A1 (en) Viscosity enhancement of polysaccharide fluids
Edy Rheological characterization of borate crosslinked fluids using oscillatory measurements

Legal Events

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

Ref document number: 201480024060.5

Country of ref document: CN

121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 14757714

Country of ref document: EP

Kind code of ref document: A1

ENP Entry into the national phase

Ref document number: 2902801

Country of ref document: CA

WWE Wipo information: entry into national phase

Ref document number: 14770668

Country of ref document: US

NENP Non-entry into the national phase

Ref country code: DE

ENP Entry into the national phase

Ref document number: 2014224044

Country of ref document: AU

Date of ref document: 20140228

Kind code of ref document: A

ENP Entry into the national phase

Ref document number: 2015138480

Country of ref document: RU

Kind code of ref document: A

122 Ep: pct application non-entry in european phase

Ref document number: 14757714

Country of ref document: EP

Kind code of ref document: A1