WO2008001112A1 - Swellable elastomers and associated methods - Google Patents

Swellable elastomers and associated methods Download PDF

Info

Publication number
WO2008001112A1
WO2008001112A1 PCT/GB2007/002444 GB2007002444W WO2008001112A1 WO 2008001112 A1 WO2008001112 A1 WO 2008001112A1 GB 2007002444 W GB2007002444 W GB 2007002444W WO 2008001112 A1 WO2008001112 A1 WO 2008001112A1
Authority
WO
WIPO (PCT)
Prior art keywords
rubber
fluid
swellable elastomer
swellable
subterranean formation
Prior art date
Application number
PCT/GB2007/002444
Other languages
French (fr)
Inventor
Anthony M. Badalamenti
John Podowski
Ashok K. Santra
Krishna M. Ravi
Original Assignee
Halliburton Energy Services, Inc.
Curtis, Philip, Anthony
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 Halliburton Energy Services, Inc., Curtis, Philip, Anthony filed Critical Halliburton Energy Services, Inc.
Priority to AU2007263592A priority Critical patent/AU2007263592B2/en
Priority to EP07733422A priority patent/EP2038368A1/en
Priority to BRPI0713979-9A priority patent/BRPI0713979A2/en
Publication of WO2008001112A1 publication Critical patent/WO2008001112A1/en

Links

Classifications

    • CCHEMISTRY; METALLURGY
    • C09DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09KMATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/50Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
    • C09K8/504Compositions based on water or polar solvents
    • C09K8/506Compositions based on water or polar solvents containing organic compounds
    • C09K8/508Compositions based on water or polar solvents containing organic compounds macromolecular compounds
    • CCHEMISTRY; METALLURGY
    • C04CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04BLIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B28/00Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
    • C04B28/02Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
    • CCHEMISTRY; METALLURGY
    • C09DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09KMATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02Well-drilling compositions
    • C09K8/03Specific additives for general use in well-drilling compositions
    • C09K8/035Organic additives
    • CCHEMISTRY; METALLURGY
    • C09DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09KMATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/40Spacer compositions, e.g. compositions used to separate well-drilling from cementing masses
    • CCHEMISTRY; METALLURGY
    • C09DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09KMATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/42Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
    • C09K8/46Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
    • C09K8/467Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
    • C09K8/473Density reducing additives, e.g. for obtaining foamed cement compositions
    • CCHEMISTRY; METALLURGY
    • C09DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09KMATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/42Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
    • C09K8/46Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
    • C09K8/467Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
    • C09K8/487Fluid loss control additives; Additives for reducing or preventing circulation loss
    • CCHEMISTRY; METALLURGY
    • C09DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09KMATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60Compositions for stimulating production by acting on the underground formation
    • C09K8/62Compositions for forming crevices or fractures
    • C09K8/66Compositions based on water or polar solvents
    • C09K8/68Compositions based on water or polar solvents containing organic compounds
    • CCHEMISTRY; METALLURGY
    • C04CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04BLIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B2103/00Function or property of ingredients for mortars, concrete or artificial stone
    • C04B2103/46Water-loss or fluid-loss reducers, hygroscopic or hydrophilic agents, water retention agents
    • YGENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02WCLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO WASTEWATER TREATMENT OR WASTE MANAGEMENT
    • Y02W30/00Technologies for solid waste management
    • Y02W30/50Reuse, recycling or recovery technologies
    • Y02W30/91Use of waste materials as fillers for mortars or concrete

Definitions

  • the present invention relates to the treatment of subterranean formations. More particularly, the present invention relates to compositions and methods utilizing swellable elastomers in subterranean operations.
  • one type of remedial cementing is commonly referred to as "squeeze cementing,” and usually involves a method of preventing undesirable movement of oil, gas, or water through small holes or cracks in pipes disposed in the well bore; or annular spaces between the cement sheath and the pipe or walls of the well bore in permeable zones or fractures in subterranean formations by squeezing hydraulic sealant compositions, such as cement, therein which harden and form impermeable plugs.
  • spacer fluids have been utilized to, inter alia, enhance drilling fluid and filter cake removal from the walls of a well bore. It is thought that inadequate removal of a filter cake from the walls of a well bore may result in a lack of a competent seal between the cement sheath and the well bore.
  • Spacer fluids may be used to displace one fluid, such as a drilling fluid, in a well bore before entry into the well bore of another fluid, such as a cement composition.
  • a spacer fluid may be used not only to enhance drilling fluid and filter cake removal from the walls of well bores, but also to enhance solids removal during drilling operations, enhance displacement efficiency, and/or to physically separate chemically incompatible fluids.
  • the cement composition may be separated from the drilling fluid and partially dehydrated drilling fluid may be removed from the walls of the well bore by placing a spacer fluid into the well bore between the drilling fluid and the cement composition.
  • additives commonly may be included in the treatment fluids.
  • additives include, but are not limited to, gelling agents, such as hydroxyethylcellulose and xanthan.
  • RPMs relative permeability modifiers
  • One example of a commonly used RPM includes polyacrylamide.
  • Swellable elastomers have heretofore been utilized in some subterranean operations, for example, zonal isolation methods.
  • Swellable elastomers usually include materials that swell upon contact with a particular fluid, hi some methods, these swellable elastomers are used in conjunction with packers that are placed in the annulus of a well bore. The packer is contacted with a specific fluid so that the swellable elastomer present in the packer expands to seal the annular space. While this method of sealing an annular space has generally been effective, a need still exists for other methods directed to preventing the undesirable passage of fluids.
  • the present invention relates to the treatment of subterranean formations. More particularly, the present invention relates to compositions and methods utilizing swellable elastomers in subterranean operations.
  • the present invention provides treatment fluids, cement compositions, spacer fluids, fracturing fluids, gravel pack fluids, or other subterranean treatment fluids that comprise swellable elastomers and that may be used in any suitable subterranean application. Although certain specific embodiments are disclosed herein, these do not define the entire scope of the disclosure herein.
  • the present invention provides a method comprising placing a fluid comprising a swellable elastomer into a subterranean formation.
  • the present invention provides a method of cementing comprising: providing a cement composition comprising a cement, water and a swellable elastomer; and placing the cement composition into a subterranean formation.
  • the present invention provides a method comprising: providing a spacer fluid comprising an aqueous fluid and a swellable elastomer; and placing the fluid into a subterranean formation.
  • the present invention provides a method of controlling fluid loss in a subterranean formation comprising: providing a treatment fluid comprising a base fluid and a swellable elastomer; and introducing the treatment fluid into the subterranean formation.
  • the present invention provides a method comprising: providing a viscosified treatment fluid comprising a swellable elastomer and a viscosifying agent, the viscosified treatment fluid having a viscosity; placing the viscosified treatment fluid into a subterranean formation; allowing the viscosity of the viscosified fluid to be reduced to a second viscosity; and allowing the swellable elastomers to be placed in the subterranean formation.
  • the present invention provides a method comprising: providing a treatment fluid comprising a base fluid and a swellable elastomer material; and introducing the treatment fluid into the subterranean formation.
  • the present invention provides a spacer fluid comprising a base fluid and a swellable elastomer.
  • the present invention provides a cement composition comprising a cement, an aqueous fluid and a swellable elastomer.
  • the present invention provides a treatment fluid comprising a base fluid and a swellable elastomer.
  • the present invention relates to the treatment of subterranean formations. More particularly, the present invention relates to compositions and methods utilizing swellable elastomers in subterranean operations. These compositions and methods may be useful to prevent the undesirable passage of fluids in a variety of applications.
  • compositions and methods of the present invention may be useful in a variety of applications, they may be particularly useful in a variety of well completion and remedial operations in subterranean formations and well bores penetrating such formations.
  • well completion methods or “well completion operations” are used herein to mean any of the operations utilized for completing the preparation of a well for hydrocarbon production, e.g., after it has been drilled, including the primary cementing of casing and liners in the well bore, consolidating gravel packs, or incompetent sands and formations and the like.
  • compositions of the present invention may be useful in proactive methods to selectively place a swellable elastomer in a desired portion of a well bore or subterranean formation in preparation for a subsequent treatment, such as cementing, etc.
  • compositions and methods of the present invention may be useful to prevent voids, cracks, fractures, holes and/or channels from forming in the annular cement sheath; seal voids, cracks, fractures, holes and/or channels in the annular cement sheath; seal voids, cracks, fractures, holes and/or channels in the subterranean formation; prevent fluid loss; reduce the production of undesired water and/or gas from the subterranean formation; and/or in remedial cementing applications.
  • compositions of the Present Invention Comprising Swellable Elastomers
  • the swellable elastomers suitable for use in the compositions of the present invention generally include any elastomer that swells upon contact with a selected fluid.
  • a variety of swellable elastomers may be utilized in accordance with the present invention, including, but not limited to, those that swell upon contact with an oleaginous fluid and/or an aqueous fluid, such as water.
  • Swellable elastomers suitable for use in the present invention may generally swell by up to approximately 500% of their original size at the surface. Under downhole conditions, this swelling may be more or less depending on the conditions presented. In some embodiments, the swelling may be up to about 200% under downhole conditions.
  • Suitable elastomers that swell upon contact with an oleaginous fluid and/or an aqueous fluid include, but are not limited to, natural rubber, acrylate butadiene rubber, polyacrylate rubber, isoprene rubber, choloroprene rubber, butyl rubber (HR) 5 brominated butyl rubber (BIIR), chlorinated butyl rubber (CIIR), chlorinated polyethylene (CM/CPE), neoprene rubber (CR), styrene butadiene copolymer rubber (SBR), sulphonated polyethylene (CSM), ethylene acrylate rubber (EAM/AEM), epichlorohydrin ethylene oxide copolymer (CO, ECO), ethylene-propylene rubber (EPM and EDPM), ethylene-propylene-diene terpolymer rubber (EPT), ethylene vinyl acetate copolymer, fluorosilicone rubbers (FVMQ), silicone rubbers (VMQ), silicone rubbers (VMQ
  • Suitable elastomers that swell when in contact with aqueous fluid include, but are not limited to, nitrile rubber (NBR), hydrogenated nitrile rubber (HNBR, HNS), fluoro rubbers (FKM), perfluoro rubbers (FFKM), tetrafluorethylene/propylene (TFE/P), starch-polyacrylate acid graft copolymer, polyvinyl alcoholcyclic acid anhydride graft copolymer, isobutylene maleic anhydride, acrylic acid type polymers, vinylacetate-acrylate copolymer, polyethylene oxide polymers, carboxymethyl cellulose type polymers, starch-polyacrylonitrile graft copolymers and the like, polymethacrylate, polyacrylamide, non-soluble acrylic polymers, and highly swelling clay minerals such as sodium bentonite (having as main ingredient montmorillonite).
  • NBR nitrile rubber
  • HNBR hydrogenated nitrile rubber
  • FKM fluor
  • swellable materials that behave in a similar fashion with respect to oleaginous fluids or aqueous fluids also may be suitable.
  • Those of ordinary skill in the art, with the benefit of this disclosure, will be able to select an appropriate swellable elastomer for use in the compositions of the present invention based on a variety of factors, including the application in which the composition will be used and the desired swelling characteristics.
  • the swellable elastomers may be any shape or size, including, but not limited to, spherical, fiber-like, ovoid, ribbons, etc. In some embodiments, the swellable elastomers may be particles ranging in size from about O.l ⁇ to about 2000 ⁇ . Other examples of suitable swellable elastomers that may be used in the methods of the present invention are disclosed in U.S. Application No. 2004/261990, the relevant disclosure of which is herein incorporated by reference. [0025] Depending on the application to which the compositions may be put, the swellable elastomers may comprise from about 0.01% to about 50% by weight of the composition. In other embodiments, the swellable elastomer may comprise from about 0.01% to about 25% by weight of the composition. While these ranges may be suitable in certain embodiments, any amount within the disclosed range may also be suitable.
  • compositions that are contemplated in the present invention are discussed below.
  • a composition of the present invention comprises a spacer fluid comprising a base fluid and a swellable elastomer.
  • spacer fluid is defined herein to include any fluid (e.g., a liquid, a gel, a gas, or combination thereof) that may be introduced into a subterranean formation prior to or after some other process or occurrence in the subterranean formation, and does not require any particular action by the spacer fluid.
  • the base fluids suitable for use in these embodiments may be non-aqueous fluids or aqueous fluids.
  • Suitable non-aqueous fluids may include one or more organic liquids, such as hydrocarbons (e.g., kerosene, xylene, toluene, or diesel), oils (e.g., mineral oils or synthetic oils), esters, and the like.
  • Aqueous fluids suitable for use in the spacer fluids may comprise fresh water, saltwater, brine, seawater, and/or any other aqueous fluid that does not adversely react with the other components used in accordance with this invention or with the subterranean formation.
  • the base fluid may be present in the spacer fluids in an amount in the range of from about 1% to about 99.9% by weight of the spacer fluid. In some embodiments, the base fluid is present in the spacer fluids in an amount in the range of from about 65% to about 75% by weight of the fluid. While these ranges may be suitable in certain embodiments, any amount within the disclosed range may also be suitable.
  • the swellable elastomer may be present in the spacer fluids in an amount believed to be sufficient to seal a void, crack, hole, and/or channel, or to perform another desired function.
  • the swellable elastomer may be present in an amount in the range of from about 0.1% to about 50% by weight of the spacer fluid.
  • the swellable elastomer may be present in an amount in the range of from about 0.1% to about 10% by weight of the spacer fluid.
  • the swellable elastomer may be present in an amount in the range of from about 3% to about 8% by weight of the spacer fluid.
  • any amount within the disclosed range may also be suitable.
  • Those of ordinary skill in the art, with the benefit of this disclosure, will be able to select an appropriate amount of the swellable elastomer to include in the spacer fluids of the present invention based on a variety of factors, including the application in which the composition will be used, compatibility with other treatment fluids, and the desired swelling characteristics.
  • Additional additives may be added to the spacer fluids as deemed appropriate by one skilled in the art.
  • suitable additives include, but are not limited to, viscosifying agents, fluid loss additives, salts, shale swelling inhibitors, weighting agents, dispersing agents, foaming and stabilizing surfactants, well bore scouring materials, friction reducers, and numerous other additives suitable for use in spacer fluids.
  • Spacer fluids like these may be useful in any subterranean operation where it may be desirable, among other purposes, to have a buffer between two fluids during subterranean operations, to clean out undesirable substances (e.g., oil, residue, or debris) from the pore spaces in the matrix of the subterranean formation, and/or to prepare the subterranean formation for later placement of a consolidation treatment.
  • undesirable substances e.g., oil, residue, or debris
  • a composition of the present invention comprises a cement, an aqueous fluid, and a swellable elastomer. Any cement suitable for use in the desired application may be suitable for use in these cement compositions. While a variety of cements may be suitable, in some embodiments, the cement compositions may comprise a suitable cementitious material such as a hydraulic cement, although others may be suitable. A variety of hydraulic cements may be utilized in accordance with the present invention, including, but not limited to, those that comprise calcium, aluminum, silicon, oxygen, and/or sulfur, which set and harden by reaction with water.
  • Suitable hydraulic cements include, but are not limited to, Portland cements, pozzolana cements, gypsum cements, high alumina content cements, slag cements, and silica cements, and combinations thereof.
  • the hydraulic cement may comprise a Portland cement.
  • the Portland cements may be classified as Class A, C, G and H according to American Petroleum Institute, API Specification for Materials and Testing for Well Cements, API Specification 10. 5 th Edition, July 1, 1990.
  • the aqueous fluid suitable for use in the cement compositions of the present invention may be from any source, provided that it does not contain an excess of compounds that adversely affect other compounds in the cement compositions.
  • a cement composition suitable for use in the present invention may comprise freshwater, saltwater (e.g., water containing one or more salts dissolved therein), brine (e.g., saturated saltwater), seawater, or combinations thereof.
  • the water may be present in an amount sufficient to form a pumpable slurry.
  • the water is present in the cement compositions of the present invention in an amount in the range of from about 20% to about 180% by weight of cement.
  • the swellable elastomer may be present in the cement compositions in an amount believed to be sufficient to seal a void, crack, hole, and/or channel, or to perform another desired function.
  • the swellable elastomer may be present in an amount in the range of from about 0.1% to about 50% by weight of cement.
  • the swellable elastomer may be present in an amount in the range of from about 0.1% to about 10% by weight of cement.
  • the swellable elastomer may be present in an amount in the range of from about 3% to about 8% by weight of cement. While these ranges may be suitable in certain embodiments, any amount within the disclosed range may also be suitable.
  • a cement composition of the present invention may comprise a cement, water, and a swellable elastomer in an amount of up to about 10%.
  • the swellable elastomer may swell upon contact with an oleaginous fluid, e.g., diesel, synthetic base mud, etc., and thus, the cement composition may expand in an amount in the range of from about 0.5% to about 5%.
  • the cement composition may expand more as time elapses.
  • the cement compositions of the present invention may expand in an amount in the range of from about 0.6% to about 0.9% after 5 days, from about 0.7% to about 1. % after 9 days, from about 0.9% to about 1.3% after 20 days, from about 1.2% to about 1.5% after 41 days, from about 1.4% to about 1.6% after 56 days, and from about 1.7% to about 1.8% after 79 days.
  • the cement compositions of the present invention may expand in an amount in the range of from about 1.2% to about 1.6% after 5 days, from about 1.7% to about 2.2% after 9 days, from about 2.2% to about 3% after 20 days, from about 2.2% to about 3.8% after 41 days, from about 3.2% to about 4.1% after 56 days, and from about 3.5% to about 4.6 after 79 days.
  • the cement compositions of present invention may optionally comprise a dispersant.
  • the dispersant acts, inter alia, to control the rheology of the cement composition and to stabilize the cement composition over a broad density range.
  • one suitable dispersant comprises a graft copolymer having a backbone of a condensation product of formaldehyde, acetone and sodium bisulfite, commercially available under the trade name CFR-8TM cement dispersant from Halliburton Energy Services, Inc., Duncan, Oklahoma.
  • Another example of a suitable dispersant is a condensation product of ketone, aldehyde, and compound introducing acid groups.
  • condensation products examples include condensation products of acetone, formaldehyde, and sodium bisulfite, and those in U.S. Patent No. 4,818,288, the disclosure of which is incorporated herein by reference.
  • a suitable dispersant is a polyamide graft copolymer containing at least one side chain formed from aldehydes and sulfur- containing acids or their salts.
  • condensation products of sodium naphthalene sulfonic acid and formaldehyde examples of U.S. Patent No. 6,681,856, the disclosure of which is incorporated herein by reference.
  • Combinations of suitable dispersants also may be used, hi some embodiments, the dispersant is present in the cement compositions in an amount in the range of from about 0 to about 5 pounds per barrel of water.
  • additives may be added to the cement compositions as deemed appropriate by one skilled in the art, with the benefit of this disclosure.
  • additives include, but are not limited to, accelerators, set retarders, weight reducing additives, heavyweight additives, lost circulation materials, filtration control additives, foaming agents, defoamers, salts, vitrified shale, fly ash, fiber, strength retrogression additives, expanding additives, yield stress reducing agents, and combinations thereof.
  • a strength retrogression additive such as crystalline silica, may be used to prevent high-temperature strength retrogression that occurs to set cement compositions in high-temperature wells.
  • Suitable crystalline silica are SSA-I and SSA-2 strength stabilization agents, from Halliburton Energy Services, Inc., Duncan, Oklahoma.
  • SSA-I and SSA-2 strength stabilization agents from Halliburton Energy Services, Inc., Duncan, Oklahoma.
  • Halliburton Energy Services, Inc. Duncan, Oklahoma.
  • One of ordinary skill in the art, with the benefit of this disclosure, will be able to recognize where a particular additive is suitable for a particular application.
  • cementing compositions may be useful in primary and remedial cementing operations.
  • the swellable elastomers may migrate to the edges of the cement composition as it sets, e.g., towards the microannuli created by the casing and/or the subterranean formation.
  • the swellable elastomers may then swell due to the presence of fluids present in those microannuli, which may lead to better sealing. This migration may be due to chemical potential or hydrophobicity.
  • the swellable elastomers may also float or sink to a given location within the cement composition, and then congeal to form a mass.
  • the swellable elastomers of the present invention also may be used in subterranean treatment fluids.
  • the swellable elastomers may, among other things, expand to seal any voids, cracks, fractures, holes and/or channels present in their vicinity. It is believed that this may reduce the subsequent problems associated with undesirable fluids flowing into the well bore from the subterranean formation and/or from one portion of a subterranean formation to another portion.
  • the treatment fluids of the present invention may be used in a variety of subterranean treatments. Such treatments include, but are not limited to, drilling operations, stimulation operations, well completion operations and remedial operations.
  • treatment refers to any subterranean operation that uses a fluid in conjunction with a desired function and/or for a desired purpose.
  • treatment does not imply any particular action by the fluid or any component thereof.
  • the treatment fluids of the present invention generally comprise a base fluid and a swellable elastomer.
  • a variety of additional additives suitable for use in the chosen treatment may be included in the treatment fluids as desired.
  • the base fluids suitable for use in these embodiments may be non-aqueous fluids or aqueous fluids.
  • Suitable non-aqueous fluids for use in the treatment fluids may include one or more organic liquids, such as hydrocarbons (e.g., kerosene, xylene, toluene, or diesel), oils (e.g., mineral oils or synthetic oils), esters, and the like.
  • aqueous fluids suitable for use in the treatment fluids may include freshwater, saltwater, brine (e.g., saturated saltwater), or seawater.
  • the aqueous fluid may be from any source, provided that it does not contain components that may adversely affect other components in the treatment fluid.
  • the base fluid may be present in the treatment fluids in an amount in the range of from about 1% to about 99.9% by weight of the treatment fluid. In some embodiments, the base fluid is present in the treatment fluids in an amount in the range of from about 65% to about 75% by weight of the fluid. While these ranges may be suitable in certain embodiments, any amount within the disclosed range may also be suitable.
  • the amount of the swellable elastomer material to include in the treatment fluids is dependent on a variety of factors, including, but not limited to, the application in which the treatment fluid is to be utilized.
  • the swellable elastomer should be present in the treatment fluids in an amount in the range of from about 0.01% to about 50% by weight of the treatment fluid.
  • the swellable elastomer should be present in the treatment fluids in an amount in the range of from about 0.5% to about 20% by weight of the treatment fluid. While these ranges may be suitable in certain embodiments, any amount within the disclosed range may also be suitable.
  • Additional additives may be added to the treatment fluids as deemed appropriate for a particular application by one skilled in the art with the benefit of this disclosure.
  • additives include, but are not limited to, weighting agents, surfactants, scale inhibitors, antifoaming agents, bactericides, salts, foaming agents, acids, conventional fluid loss control additives, viscosifying agents, cross linking agents, gel breakers, shale swelling inhibitors, combinations thereof, and the like.
  • the treatment fluid may be a drilling fluid, a fracturing fluid, a work over fluid, a well bore cleanup fluid, a gravel packing fluid, or any other suitable fluids used in subterranean treatments.
  • the treatment fluid may be a preflush that is introduced into the well bore prior to the subterranean treatment.
  • the swellable elastomers may also float or sink to a given location within the treatment fluid composition, and then congeal to form a mass.
  • the methods of the present invention may be utilized in any portion of a subterranean formation including, but not limited to, those penetrated by a horizontal, vertical, inclined, or otherwise formed portion of a well bore. In addition, these methods can be performed at any time during the life of the well formed therein.
  • the methods of the present invention involve introducing a spacer fluid comprising a base fluid and a swellable elastomer into a subterranean formation.
  • the spacer fluids may be introduced into the subterranean formation, among other purposes, to be a buffer between two fluids during subterranean operations, to clean out undesirable substances (e.g., oil, residue, or debris) from the pore spaces in the matrix of the subterranean formation, and/or to prepare the subterranean formation for later placement of a consolidation treatment.
  • an acidic spacer fluid may be introduced into at least a portion of the subterranean formation that may, inter alia, dissolve undesirable substances in the subterranean formation.
  • spacer fluids of the present invention may be used in any application where a spacer fluid is appropriate. For instance, one may be used between a drilling fluid and a cement composition. Another example is between different drilling fluids during drilling fluid change-outs. Another example is between drilling fluids and completion brines.
  • the spacer fluids may be introduced into the subterranean formation using any means suitable for introducing fluids into the subterranean formation. For instance, the spacer fluid may be introduced into the subterranean formation by the methods disclosed in U.S. Patent Nos. 6,668,927, 4,588,032, and 6,852,676, the relevant disclosures of which are herein incorporated by reference.
  • One example of such a method comprises introducing a spacer fluid comprising a base fluid and a swellable elastomer into a subterranean formation; and allowing the swellable elastomer to swell to do at least one of the following: seal voids, cracks, fractures, holes and/or channels.
  • the method comprises introducing a spacer fluid comprising a base fluid and a swellable elastomer into a subterranean formation; and allowing a fluid to come into contact with the swellable elastomer so that it swells to do at least one of the following: seal a void, a crack, a fracture, a hole, a channel, and/or a combination thereof.
  • the methods of the present invention involve introducing a cement composition comprising cement, an aqueous fluid and a swellable elastomer into a subterranean formation.
  • the cement compositions may be introduced into the subterranean formation, among other purposes, to provide bonding between casing and/or liners disposed in well bores and the walls of the well bores. They also may be used for primary and remedial cementing operations. Additionally, the methods of the present invention are particularly suitable for performing squeeze remedial operations wherein the sealant is forced into cracks and/or voids to provide a seal therein.
  • the methods of the present invention for forming temporary or permanent plugs or seals in a well bore or in one or more subterranean formations penetrated by the well bore generally comprise the steps of placing a cement composition of the present invention in the subterranean formation or in the well bore penetrating the formation at a desired location therein; allowing the swellable elastomer to swell; and allowing the cement composition to set.
  • Permanent plugs may be useful when abandoning a well.
  • a method of the present invention comprises: providing a cement composition comprising a cement, an aqueous fluid and a swellable elastomer material; placing the cement composition into a location to be cemented; and allowing the cement composition to set therein.
  • the location to be cemented may be above ground or in a subterranean formation.
  • the cement composition may be placed into an annulus between a pipe string located in a well bore and a subterranean formation penetrated by the well bore.
  • the cement compositions may be introduced into the subterranean formation using any means suitable for introducing cements into the subterranean formation.
  • the swellable elastomers in the cement compositions of the present invention may counteract pressure losses in the cement compositions that may be due to shrinkage factors and the like.
  • the methods of the present invention involve introducing a treatment fluid comprising a base fluid and a swellable elastomer material into a subterranean formation.
  • the treatment fluids may be introduced into the subterranean formation, among other purposes, to at least partially reduce fluid loss, at least partially seal a perforation, and/or at least partially inhibit the production of undesirable water and/or gas from the subterranean formation.
  • Operations in which the methods are particularly suitable include, but are not limited to, consolidated gravel packs or incompetent formations exposed to high temperatures and pressures, forming temporary or permanent plugs or packers in well bores including horizontal well bores, forming lightweight floatation barriers above liquid hydrocarbons in caverns and the like.
  • a method of the present invention comprises providing a treatment fluid comprising a base fluid and a swellable elastomer material; introducing the treatment fluid into the subterranean formation; and allowing the swellable elastomer to swell and at least partially reduce fluid loss.
  • a method of the present invention comprises providing a treatment fluid comprising a base fluid and a swellable elastomer material; introducing the treatment fluid into the subterranean formation; and allowing the swellable elastomer to swell and at least partially seal a perforation.
  • a method of the present invention comprises providing a treatment fluid comprising a base fluid and a swellable elastomer material; introducing the treatment fluid into the subterranean formation; and allowing the swellable elastomer to swell and at least partially inhibit the production of undesirable water or gas from the subterranean formation.
  • the present invention provides a method comprising: providing a viscosified treatment fluid comprising swellable elastomers and a viscosifying agent, the viscosified treatment fluid having a viscosity; placing the viscosified treatment fluid into a subterranean formation; allowing the viscosity of the viscosified fluid to be reduced to a second viscosity; and allowing the swellable elastomers to be placed in the subterranean formation.
  • the swellable elastomers may be placed toward the top of the treatment fluid. In others, the swellable elastomers may be placed toward the bottom of the treatment fluid.
  • a breaker may be incorporated into the viscosified treatment fluid or added to the fluid, if desired.
  • suitable breakers for viscosified treatment fluids of the present invention include, but are not limited to, sodium chlorite, hypochlorite, perborate, persulfates, peroxides, including organic peroxides.
  • Other suitable breakers include suitable acids.
  • Preferred examples of suitable breakers for viscosified treatment fluids of the present invention that include a gelling agent that comprises diutan include peroxide breakers. Preferred examples include tert-butyl hydroperoxide and tert-amyl hydroperoxide.
  • a breaker may be included in a viscosified treatment fluid of the present invention in an amount and form sufficient to achieve the desired viscosity reduction at a desired time.
  • the breaker may be formulated to provide a delayed break, if desired.
  • a suitable breaker may be encapsulated if desired. Suitable encapsulation methods are known to those skilled in the art. One suitable encapsulation method that may be used involves coating the chosen breakers with a material that will degrade when downhole so as to release the breaker when desired. Resins that may be suitable include, but are not limited to, polymeric materials that will degrade when downhole.
  • degrade refers to both the two relatively extreme cases of hydrolytic degradation that the degradable material may undergo, i.e., heterogeneous (or bulk erosion) and homogeneous (or surface erosion), and any stage of degradation in between these two.
  • This degradation can be a result of, inter alia, a chemical or thermal reaction or a reaction induced by radiation.
  • Suitable examples include polysaccharides such as dextran or cellulose; chitins; chitosans; proteins; aliphatic polyesters; poly(lactides); poly(glycolides); poly(y-caprolactones); ⁇ oly(hydroxybutyrates); poly(anhydrides); aliphatic polycarbonates; orthoesters, poly(orthoesters); poly(amino acids); poly(ethylene oxides); and polyphosphazenes.
  • a breaker should be included in a composition of the present invention in an amount sufficient to facilitate the desired reduction in viscosity in a viscosifier treatment fluid.
  • peroxide concentrations that may be used vary from about 0.1 to about 10 gallons of peroxide per 1000 gallons of the viscosified treatment fluid.
  • the viscosified treatment fluid may contain an activator or a retarder, inter alia, to optimize the break rate provided by the breaker.
  • Any known activator or retarder that is compatible with the particular breaker used is suitable for use in the present invention.
  • suitable activators include, but are not limited to, chelated iron, copper, cobalt, and reducing sugars.
  • An example of a suitable retarder includes sodium thiosulfate diethylene triamine. In some embodiments, the sodium thiosulfate may be used in a range of from about 5 to about 2000 lbs. per 1000 gallons of viscosified treatment fluid.
  • An artisan of ordinary skill with the benefit of this disclosure will be able to identify a suitable activator or retarder and the proper concentration of such activator or retarder for a given application.
  • every range of values (of the form, "from about a to about b,” or, equivalently, “from approximately a to b,” or, equivalently, “from approximately a-b") disclosed herein is to be understood as referring to the power set (the set of all subsets) of the respective range of values, and set forth every range encompassed within the broader range of values.
  • the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee.

Abstract

Methods are provided that include a method of reducing fluid loss in a subterranean formation comprising placing a lost circulation composition comprising a base fluid and a swellable elastomer in at least a portion of a subterranean formation comprising a lost circulation zone; allowing the swellable elastomer to at least partially swell upon contact with a fluid; and allowing the lost circulation composition to at least partially reduce the loss of fluid to the subterranean formation. Additional methods are also provided.

Description

SWELLABLE ELASTOMERS AND ASSOCIATED METHODS
BACKGROUND
[0001] The present invention relates to the treatment of subterranean formations. More particularly, the present invention relates to compositions and methods utilizing swellable elastomers in subterranean operations.
[0002] In subterranean operations, there may be several instances where it may be desirable to control or prevent the passage of fluid through a portion of a subterranean formation, control or prevent the production of an undesirable fluid through a well bore, and/or isolate specific areas in a well bore or zones in a subterranean formation. However, in many instances, it may be problematic to do these things for a variety of reasons.
[0003] A variety of methods have been employed in an attempt to address the above mentioned problems. For example, improved cement compositions have been used in cementing operations in an effort to prevent, inter alia, the failure of the cement and/or the formation of voids, cracks, fractures, holes and/or channels that may form in the cement. In addition, several remedial cementing methods have been developed. For example, one type of remedial cementing is commonly referred to as "squeeze cementing," and usually involves a method of preventing undesirable movement of oil, gas, or water through small holes or cracks in pipes disposed in the well bore; or annular spaces between the cement sheath and the pipe or walls of the well bore in permeable zones or fractures in subterranean formations by squeezing hydraulic sealant compositions, such as cement, therein which harden and form impermeable plugs.
[0004] Additionally, spacer fluids have been utilized to, inter alia, enhance drilling fluid and filter cake removal from the walls of a well bore. It is thought that inadequate removal of a filter cake from the walls of a well bore may result in a lack of a competent seal between the cement sheath and the well bore. Spacer fluids may be used to displace one fluid, such as a drilling fluid, in a well bore before entry into the well bore of another fluid, such as a cement composition. Among other things, a spacer fluid may be used not only to enhance drilling fluid and filter cake removal from the walls of well bores, but also to enhance solids removal during drilling operations, enhance displacement efficiency, and/or to physically separate chemically incompatible fluids. For example, in primary cementing, the cement composition may be separated from the drilling fluid and partially dehydrated drilling fluid may be removed from the walls of the well bore by placing a spacer fluid into the well bore between the drilling fluid and the cement composition.
[0005] Also, several methods have been utilized in an effort to prevent fluid loss and/or the undesirable production of water. For example, to prevent fluid loss and/or the undesirable production of water, additives commonly may be included in the treatment fluids. Examples of commonly used additives include, but are not limited to, gelling agents, such as hydroxyethylcellulose and xanthan. hi addition, compounds referred to as relative permeability modifiers ("RPMs") have been utilized to decrease the production of undesirable water. One example of a commonly used RPM includes polyacrylamide. These conventional methods commonly work at the well bore and/or formation face, however, in some instances formation damage may occur. Additionally, the use of crosslinked fluids may impact fracture geometry, for example, creating wider, shorter fractures.
[0006] Swellable elastomers have heretofore been utilized in some subterranean operations, for example, zonal isolation methods. Swellable elastomers usually include materials that swell upon contact with a particular fluid, hi some methods, these swellable elastomers are used in conjunction with packers that are placed in the annulus of a well bore. The packer is contacted with a specific fluid so that the swellable elastomer present in the packer expands to seal the annular space. While this method of sealing an annular space has generally been effective, a need still exists for other methods directed to preventing the undesirable passage of fluids.
SUMMARY
[0007] The present invention relates to the treatment of subterranean formations. More particularly, the present invention relates to compositions and methods utilizing swellable elastomers in subterranean operations.
[0008] In some embodiments, the present invention provides treatment fluids, cement compositions, spacer fluids, fracturing fluids, gravel pack fluids, or other subterranean treatment fluids that comprise swellable elastomers and that may be used in any suitable subterranean application. Although certain specific embodiments are disclosed herein, these do not define the entire scope of the disclosure herein.
[0009] hi one embodiment, the present invention provides a method comprising placing a fluid comprising a swellable elastomer into a subterranean formation. [0010] In another embodiment, the present invention provides a method of cementing comprising: providing a cement composition comprising a cement, water and a swellable elastomer; and placing the cement composition into a subterranean formation.
[001I] In yet another embodiment, the present invention provides a method comprising: providing a spacer fluid comprising an aqueous fluid and a swellable elastomer; and placing the fluid into a subterranean formation.
[0012] In yet another embodiment, the present invention provides a method of controlling fluid loss in a subterranean formation comprising: providing a treatment fluid comprising a base fluid and a swellable elastomer; and introducing the treatment fluid into the subterranean formation.
[0013] hi yet another embodiment, the present invention provides a method comprising: providing a viscosified treatment fluid comprising a swellable elastomer and a viscosifying agent, the viscosified treatment fluid having a viscosity; placing the viscosified treatment fluid into a subterranean formation; allowing the viscosity of the viscosified fluid to be reduced to a second viscosity; and allowing the swellable elastomers to be placed in the subterranean formation.
[0014] In yet another embodiment, the present invention provides a method comprising: providing a treatment fluid comprising a base fluid and a swellable elastomer material; and introducing the treatment fluid into the subterranean formation.
[0015] In yet another embodiment, the present invention provides a spacer fluid comprising a base fluid and a swellable elastomer.
[0016] In yet another embodiment, the present invention provides a cement composition comprising a cement, an aqueous fluid and a swellable elastomer.
[0017] hi yet another embodiment, the present invention provides a treatment fluid comprising a base fluid and a swellable elastomer.
[0018] The features and advantages of the present invention will be readily apparent to those skilled in the art. While numerous changes may be made by those skilled in the art, such changes are within the spirit of the invention.
DESCRIPTION OF PREFERRED EMBODIMENTS
[0019] The present invention relates to the treatment of subterranean formations. More particularly, the present invention relates to compositions and methods utilizing swellable elastomers in subterranean operations. These compositions and methods may be useful to prevent the undesirable passage of fluids in a variety of applications.
[0020] Although the compositions and methods of the present invention may be useful in a variety of applications, they may be particularly useful in a variety of well completion and remedial operations in subterranean formations and well bores penetrating such formations. The terms "well completion methods" or "well completion operations" are used herein to mean any of the operations utilized for completing the preparation of a well for hydrocarbon production, e.g., after it has been drilled, including the primary cementing of casing and liners in the well bore, consolidating gravel packs, or incompetent sands and formations and the like. The terms "remedial methods" or "remedial operations" are used herein to mean procedures carried out in subterranean formations or in well bores penetrating the formations to correct problems such as sealing cracks or voids, placing plugs in the well bore or in zones or formations containing undesirable fluids, placing temporary and/or permanent plugs {e.g. , kick-off plugs, abandonment plugs, etc.) in lieu of packers to isolate zones or formations, filling external casing packers and the like. Additionally, the compositions of the present invention may be useful in proactive methods to selectively place a swellable elastomer in a desired portion of a well bore or subterranean formation in preparation for a subsequent treatment, such as cementing, etc.
[0021] In addition, the compositions and methods of the present invention may be useful to prevent voids, cracks, fractures, holes and/or channels from forming in the annular cement sheath; seal voids, cracks, fractures, holes and/or channels in the annular cement sheath; seal voids, cracks, fractures, holes and/or channels in the subterranean formation; prevent fluid loss; reduce the production of undesired water and/or gas from the subterranean formation; and/or in remedial cementing applications.
I. Compositions of the Present Invention Comprising Swellable Elastomers
[0022] The swellable elastomers suitable for use in the compositions of the present invention generally include any elastomer that swells upon contact with a selected fluid. A variety of swellable elastomers may be utilized in accordance with the present invention, including, but not limited to, those that swell upon contact with an oleaginous fluid and/or an aqueous fluid, such as water. Swellable elastomers suitable for use in the present invention may generally swell by up to approximately 500% of their original size at the surface. Under downhole conditions, this swelling may be more or less depending on the conditions presented. In some embodiments, the swelling may be up to about 200% under downhole conditions.
[0023] Some specific examples of suitable elastomers that swell upon contact with an oleaginous fluid and/or an aqueous fluid include, but are not limited to, natural rubber, acrylate butadiene rubber, polyacrylate rubber, isoprene rubber, choloroprene rubber, butyl rubber (HR)5 brominated butyl rubber (BIIR), chlorinated butyl rubber (CIIR), chlorinated polyethylene (CM/CPE), neoprene rubber (CR), styrene butadiene copolymer rubber (SBR), sulphonated polyethylene (CSM), ethylene acrylate rubber (EAM/AEM), epichlorohydrin ethylene oxide copolymer (CO, ECO), ethylene-propylene rubber (EPM and EDPM), ethylene-propylene-diene terpolymer rubber (EPT), ethylene vinyl acetate copolymer, fluorosilicone rubbers (FVMQ), silicone rubbers (VMQ), poly 2,2,1-bicyclo heptene (polynorborneane), alkylstyrene, crosslinked substituted vinyl acrylate copolymers and diatomaceous earth. Examples of suitable elastomers that swell when in contact with aqueous fluid include, but are not limited to, nitrile rubber (NBR), hydrogenated nitrile rubber (HNBR, HNS), fluoro rubbers (FKM), perfluoro rubbers (FFKM), tetrafluorethylene/propylene (TFE/P), starch-polyacrylate acid graft copolymer, polyvinyl alcoholcyclic acid anhydride graft copolymer, isobutylene maleic anhydride, acrylic acid type polymers, vinylacetate-acrylate copolymer, polyethylene oxide polymers, carboxymethyl cellulose type polymers, starch-polyacrylonitrile graft copolymers and the like, polymethacrylate, polyacrylamide, non-soluble acrylic polymers, and highly swelling clay minerals such as sodium bentonite (having as main ingredient montmorillonite). Other swellable materials that behave in a similar fashion with respect to oleaginous fluids or aqueous fluids also may be suitable. Those of ordinary skill in the art, with the benefit of this disclosure, will be able to select an appropriate swellable elastomer for use in the compositions of the present invention based on a variety of factors, including the application in which the composition will be used and the desired swelling characteristics.
[0024] The swellable elastomers may be any shape or size, including, but not limited to, spherical, fiber-like, ovoid, ribbons, etc. In some embodiments, the swellable elastomers may be particles ranging in size from about O.lμ to about 2000μ. Other examples of suitable swellable elastomers that may be used in the methods of the present invention are disclosed in U.S. Application No. 2004/261990, the relevant disclosure of which is herein incorporated by reference. [0025] Depending on the application to which the compositions may be put, the swellable elastomers may comprise from about 0.01% to about 50% by weight of the composition. In other embodiments, the swellable elastomer may comprise from about 0.01% to about 25% by weight of the composition. While these ranges may be suitable in certain embodiments, any amount within the disclosed range may also be suitable.
[0026] Some examples of the compositions that are contemplated in the present invention are discussed below.
A. Spacer Fluid Compositions Comprising A Swellable Elastomer
[0027] In one embodiment, a composition of the present invention comprises a spacer fluid comprising a base fluid and a swellable elastomer. The term "spacer fluid" is defined herein to include any fluid (e.g., a liquid, a gel, a gas, or combination thereof) that may be introduced into a subterranean formation prior to or after some other process or occurrence in the subterranean formation, and does not require any particular action by the spacer fluid.
[0028] The base fluids suitable for use in these embodiments may be non-aqueous fluids or aqueous fluids. Suitable non-aqueous fluids may include one or more organic liquids, such as hydrocarbons (e.g., kerosene, xylene, toluene, or diesel), oils (e.g., mineral oils or synthetic oils), esters, and the like. Aqueous fluids suitable for use in the spacer fluids may comprise fresh water, saltwater, brine, seawater, and/or any other aqueous fluid that does not adversely react with the other components used in accordance with this invention or with the subterranean formation. Generally, the base fluid may be present in the spacer fluids in an amount in the range of from about 1% to about 99.9% by weight of the spacer fluid. In some embodiments, the base fluid is present in the spacer fluids in an amount in the range of from about 65% to about 75% by weight of the fluid. While these ranges may be suitable in certain embodiments, any amount within the disclosed range may also be suitable.
[0029] Generally, the swellable elastomer may be present in the spacer fluids in an amount believed to be sufficient to seal a void, crack, hole, and/or channel, or to perform another desired function. In some embodiments, the swellable elastomer may be present in an amount in the range of from about 0.1% to about 50% by weight of the spacer fluid. In other embodiments, the swellable elastomer may be present in an amount in the range of from about 0.1% to about 10% by weight of the spacer fluid. In other embodiments, the swellable elastomer may be present in an amount in the range of from about 3% to about 8% by weight of the spacer fluid. While these ranges may be suitable in certain embodiments, any amount within the disclosed range may also be suitable. Those of ordinary skill in the art, with the benefit of this disclosure, will be able to select an appropriate amount of the swellable elastomer to include in the spacer fluids of the present invention based on a variety of factors, including the application in which the composition will be used, compatibility with other treatment fluids, and the desired swelling characteristics.
[0030] Additional additives may be added to the spacer fluids as deemed appropriate by one skilled in the art. Examples of suitable additives include, but are not limited to, viscosifying agents, fluid loss additives, salts, shale swelling inhibitors, weighting agents, dispersing agents, foaming and stabilizing surfactants, well bore scouring materials, friction reducers, and numerous other additives suitable for use in spacer fluids.
[0031] Spacer fluids like these may be useful in any subterranean operation where it may be desirable, among other purposes, to have a buffer between two fluids during subterranean operations, to clean out undesirable substances (e.g., oil, residue, or debris) from the pore spaces in the matrix of the subterranean formation, and/or to prepare the subterranean formation for later placement of a consolidation treatment.
B. Cement Compositions Comprising A Swellable Elastomer
[0032] In some embodiments, a composition of the present invention comprises a cement, an aqueous fluid, and a swellable elastomer. Any cement suitable for use in the desired application may be suitable for use in these cement compositions. While a variety of cements may be suitable, in some embodiments, the cement compositions may comprise a suitable cementitious material such as a hydraulic cement, although others may be suitable. A variety of hydraulic cements may be utilized in accordance with the present invention, including, but not limited to, those that comprise calcium, aluminum, silicon, oxygen, and/or sulfur, which set and harden by reaction with water. Suitable hydraulic cements, include, but are not limited to, Portland cements, pozzolana cements, gypsum cements, high alumina content cements, slag cements, and silica cements, and combinations thereof. In certain embodiments, the hydraulic cement may comprise a Portland cement. In some embodiments, the Portland cements may be classified as Class A, C, G and H according to American Petroleum Institute, API Specification for Materials and Testing for Well Cements, API Specification 10. 5th Edition, July 1, 1990.
[0033] The aqueous fluid suitable for use in the cement compositions of the present invention may be from any source, provided that it does not contain an excess of compounds that adversely affect other compounds in the cement compositions. For example, a cement composition suitable for use in the present invention may comprise freshwater, saltwater (e.g., water containing one or more salts dissolved therein), brine (e.g., saturated saltwater), seawater, or combinations thereof. The water may be present in an amount sufficient to form a pumpable slurry. Generally, the water is present in the cement compositions of the present invention in an amount in the range of from about 20% to about 180% by weight of cement.
[0034] Generally, the swellable elastomer may be present in the cement compositions in an amount believed to be sufficient to seal a void, crack, hole, and/or channel, or to perform another desired function. In some embodiments, the swellable elastomer may be present in an amount in the range of from about 0.1% to about 50% by weight of cement. In other embodiments, the swellable elastomer may be present in an amount in the range of from about 0.1% to about 10% by weight of cement. In other embodiments, the swellable elastomer may be present in an amount in the range of from about 3% to about 8% by weight of cement. While these ranges may be suitable in certain embodiments, any amount within the disclosed range may also be suitable. Those of ordinary skill in the art, with the benefit of this disclosure, will be able to select an appropriate amount of the swellable elastomer to include in the cement compositions of the present invention based on a variety of factors, including the application in which the cement composition will be used and the desired swelling characteristics.
[0035] In some embodiments, a cement composition of the present invention may comprise a cement, water, and a swellable elastomer in an amount of up to about 10%. In those embodiments where the swellable elastomer is included in the cement composition in the amount of about 10%, the swellable elastomer may swell upon contact with an oleaginous fluid, e.g., diesel, synthetic base mud, etc., and thus, the cement composition may expand in an amount in the range of from about 0.5% to about 5%. Generally, the cement composition may expand more as time elapses. For example, in some embodiments, where a cement composition of the present invention is in contact with a synthetic drilling mud, the cement compositions of the present invention may expand in an amount in the range of from about 0.6% to about 0.9% after 5 days, from about 0.7% to about 1. % after 9 days, from about 0.9% to about 1.3% after 20 days, from about 1.2% to about 1.5% after 41 days, from about 1.4% to about 1.6% after 56 days, and from about 1.7% to about 1.8% after 79 days. Similarly, in some embodiments, where a cement composition of the present invention is in contact with diesel, the cement compositions of the present invention may expand in an amount in the range of from about 1.2% to about 1.6% after 5 days, from about 1.7% to about 2.2% after 9 days, from about 2.2% to about 3% after 20 days, from about 2.2% to about 3.8% after 41 days, from about 3.2% to about 4.1% after 56 days, and from about 3.5% to about 4.6 after 79 days.
[0036] The cement compositions of present invention may optionally comprise a dispersant. Where present, the dispersant acts, inter alia, to control the rheology of the cement composition and to stabilize the cement composition over a broad density range. While a variety of dispersants known to those skilled in the art may be used in accordance with the present invention, one suitable dispersant comprises a graft copolymer having a backbone of a condensation product of formaldehyde, acetone and sodium bisulfite, commercially available under the trade name CFR-8™ cement dispersant from Halliburton Energy Services, Inc., Duncan, Oklahoma. Another example of a suitable dispersant is a condensation product of ketone, aldehyde, and compound introducing acid groups. Examples of these types of condensation products are condensation products of acetone, formaldehyde, and sodium bisulfite, and those in U.S. Patent No. 4,818,288, the disclosure of which is incorporated herein by reference. Another example of a suitable dispersant is a polyamide graft copolymer containing at least one side chain formed from aldehydes and sulfur- containing acids or their salts. Examples of these types of copolymers are condensation products of sodium naphthalene sulfonic acid and formaldehyde, and those in U.S. Patent No. 6,681,856, the disclosure of which is incorporated herein by reference. Combinations of suitable dispersants also may be used, hi some embodiments, the dispersant is present in the cement compositions in an amount in the range of from about 0 to about 5 pounds per barrel of water.
[0037] Optionally, other additional additives may be added to the cement compositions as deemed appropriate by one skilled in the art, with the benefit of this disclosure. Examples of such additives include, but are not limited to, accelerators, set retarders, weight reducing additives, heavyweight additives, lost circulation materials, filtration control additives, foaming agents, defoamers, salts, vitrified shale, fly ash, fiber, strength retrogression additives, expanding additives, yield stress reducing agents, and combinations thereof. For example, a strength retrogression additive, such as crystalline silica, may be used to prevent high-temperature strength retrogression that occurs to set cement compositions in high-temperature wells. Examples of suitable crystalline silica are SSA-I and SSA-2 strength stabilization agents, from Halliburton Energy Services, Inc., Duncan, Oklahoma. One of ordinary skill in the art, with the benefit of this disclosure, will be able to recognize where a particular additive is suitable for a particular application.
[0038] These cementing compositions may be useful in primary and remedial cementing operations.
[0039] In some embodiments, the swellable elastomers may migrate to the edges of the cement composition as it sets, e.g., towards the microannuli created by the casing and/or the subterranean formation. The swellable elastomers may then swell due to the presence of fluids present in those microannuli, which may lead to better sealing. This migration may be due to chemical potential or hydrophobicity.
[0040] In some embodiments, the swellable elastomers may also float or sink to a given location within the cement composition, and then congeal to form a mass.
C. Treatment Fluids Comprising A Swellable Elastomer
[0041] In some embodiments, the swellable elastomers of the present invention also may be used in subterranean treatment fluids. In such treatment fluids, it is contemplated that the swellable elastomers may, among other things, expand to seal any voids, cracks, fractures, holes and/or channels present in their vicinity. It is believed that this may reduce the subsequent problems associated with undesirable fluids flowing into the well bore from the subterranean formation and/or from one portion of a subterranean formation to another portion. The treatment fluids of the present invention may be used in a variety of subterranean treatments. Such treatments include, but are not limited to, drilling operations, stimulation operations, well completion operations and remedial operations. As used herein, the term "treatment," or "treating," refers to any subterranean operation that uses a fluid in conjunction with a desired function and/or for a desired purpose. The term "treatment," or "treating," does not imply any particular action by the fluid or any component thereof.
[0042] The treatment fluids of the present invention generally comprise a base fluid and a swellable elastomer. A variety of additional additives suitable for use in the chosen treatment may be included in the treatment fluids as desired. The base fluids suitable for use in these embodiments may be non-aqueous fluids or aqueous fluids. Suitable non-aqueous fluids for use in the treatment fluids may include one or more organic liquids, such as hydrocarbons (e.g., kerosene, xylene, toluene, or diesel), oils (e.g., mineral oils or synthetic oils), esters, and the like. Examples of aqueous fluids suitable for use in the treatment fluids may include freshwater, saltwater, brine (e.g., saturated saltwater), or seawater. The aqueous fluid may be from any source, provided that it does not contain components that may adversely affect other components in the treatment fluid. Generally, the base fluid may be present in the treatment fluids in an amount in the range of from about 1% to about 99.9% by weight of the treatment fluid. In some embodiments, the base fluid is present in the treatment fluids in an amount in the range of from about 65% to about 75% by weight of the fluid. While these ranges may be suitable in certain embodiments, any amount within the disclosed range may also be suitable.
[0043] The amount of the swellable elastomer material to include in the treatment fluids is dependent on a variety of factors, including, but not limited to, the application in which the treatment fluid is to be utilized. In some embodiments, the swellable elastomer should be present in the treatment fluids in an amount in the range of from about 0.01% to about 50% by weight of the treatment fluid. In other embodiments, the swellable elastomer should be present in the treatment fluids in an amount in the range of from about 0.5% to about 20% by weight of the treatment fluid. While these ranges may be suitable in certain embodiments, any amount within the disclosed range may also be suitable. Those of ordinary skill in the art, with the benefit of this disclosure, will be able to select an appropriate amount of the swellable elastomer to include in the treatment fluids of the present invention based on a variety of factors, including the application in which the fluid will be used, compatibility with other treatment fluids, and the desired swelling characteristics.
[0044] Additional additives may be added to the treatment fluids as deemed appropriate for a particular application by one skilled in the art with the benefit of this disclosure. Examples of such additives include, but are not limited to, weighting agents, surfactants, scale inhibitors, antifoaming agents, bactericides, salts, foaming agents, acids, conventional fluid loss control additives, viscosifying agents, cross linking agents, gel breakers, shale swelling inhibitors, combinations thereof, and the like.
[0045] In certain embodiments, the treatment fluid may be a drilling fluid, a fracturing fluid, a work over fluid, a well bore cleanup fluid, a gravel packing fluid, or any other suitable fluids used in subterranean treatments. In another embodiment, the treatment fluid may be a preflush that is introduced into the well bore prior to the subterranean treatment. [0046] In some embodiments, the swellable elastomers may also float or sink to a given location within the treatment fluid composition, and then congeal to form a mass.
II. Methods of the Present Invention
[0047] The methods of the present invention may be utilized in any portion of a subterranean formation including, but not limited to, those penetrated by a horizontal, vertical, inclined, or otherwise formed portion of a well bore. In addition, these methods can be performed at any time during the life of the well formed therein.
A. Methods Involving Spacer Fluids
[0048] In some embodiments, the methods of the present invention involve introducing a spacer fluid comprising a base fluid and a swellable elastomer into a subterranean formation. The spacer fluids may be introduced into the subterranean formation, among other purposes, to be a buffer between two fluids during subterranean operations, to clean out undesirable substances (e.g., oil, residue, or debris) from the pore spaces in the matrix of the subterranean formation, and/or to prepare the subterranean formation for later placement of a consolidation treatment.
[0049] It is believed that during normal leak off of the spacer fluids into the subterranean formation, the swellable elastomers, among other things, may expand to seal any voids, cracks, fractures, holes and/or channels present therein. It is believed that this may reduce the subsequent problems associated with undesirable fluids flowing into the well bore from the subterranean formation. Additionally, in some embodiments, an acidic spacer fluid may be introduced into at least a portion of the subterranean formation that may, inter alia, dissolve undesirable substances in the subterranean formation.
[0050] Such spacer fluids of the present invention may be used in any application where a spacer fluid is appropriate. For instance, one may be used between a drilling fluid and a cement composition. Another example is between different drilling fluids during drilling fluid change-outs. Another example is between drilling fluids and completion brines. The spacer fluids may be introduced into the subterranean formation using any means suitable for introducing fluids into the subterranean formation. For instance, the spacer fluid may be introduced into the subterranean formation by the methods disclosed in U.S. Patent Nos. 6,668,927, 4,588,032, and 6,852,676, the relevant disclosures of which are herein incorporated by reference. [0051] One example of such a method comprises introducing a spacer fluid comprising a base fluid and a swellable elastomer into a subterranean formation; and allowing the swellable elastomer to swell to do at least one of the following: seal voids, cracks, fractures, holes and/or channels.
[0052] In another embodiment, the method comprises introducing a spacer fluid comprising a base fluid and a swellable elastomer into a subterranean formation; and allowing a fluid to come into contact with the swellable elastomer so that it swells to do at least one of the following: seal a void, a crack, a fracture, a hole, a channel, and/or a combination thereof.
B. Methods Involving Cement Compositions
[0053] In some embodiments, the methods of the present invention involve introducing a cement composition comprising cement, an aqueous fluid and a swellable elastomer into a subterranean formation. The cement compositions may be introduced into the subterranean formation, among other purposes, to provide bonding between casing and/or liners disposed in well bores and the walls of the well bores. They also may be used for primary and remedial cementing operations. Additionally, the methods of the present invention are particularly suitable for performing squeeze remedial operations wherein the sealant is forced into cracks and/or voids to provide a seal therein.
[0054] Other operations in which the methods are particularly suitable include, but are not limited to, consolidated gravel packs or incompetent formations exposed to high temperatures and pressures, forming temporary or permanent plugs or packers in well bores including horizontal well bores, forming lightweight floatation barriers above liquid hydrocarbons in caverns and the like.
[0055] In one embodiment, the methods of the present invention for forming temporary or permanent plugs or seals in a well bore or in one or more subterranean formations penetrated by the well bore generally comprise the steps of placing a cement composition of the present invention in the subterranean formation or in the well bore penetrating the formation at a desired location therein; allowing the swellable elastomer to swell; and allowing the cement composition to set. Permanent plugs may be useful when abandoning a well.
[0056] In another embodiment, a method of the present invention comprises: providing a cement composition comprising a cement, an aqueous fluid and a swellable elastomer material; placing the cement composition into a location to be cemented; and allowing the cement composition to set therein. The location to be cemented may be above ground or in a subterranean formation. For example, the cement composition may be placed into an annulus between a pipe string located in a well bore and a subterranean formation penetrated by the well bore. The cement compositions may be introduced into the subterranean formation using any means suitable for introducing cements into the subterranean formation.
[0057] In some embodiments, the swellable elastomers in the cement compositions of the present invention may counteract pressure losses in the cement compositions that may be due to shrinkage factors and the like.
C. Methods Involving Treatment Fluid Compositions
[0058] In some embodiments, the methods of the present invention involve introducing a treatment fluid comprising a base fluid and a swellable elastomer material into a subterranean formation. The treatment fluids may be introduced into the subterranean formation, among other purposes, to at least partially reduce fluid loss, at least partially seal a perforation, and/or at least partially inhibit the production of undesirable water and/or gas from the subterranean formation. Operations in which the methods are particularly suitable include, but are not limited to, consolidated gravel packs or incompetent formations exposed to high temperatures and pressures, forming temporary or permanent plugs or packers in well bores including horizontal well bores, forming lightweight floatation barriers above liquid hydrocarbons in caverns and the like.
[0059] In one embodiment, a method of the present invention comprises providing a treatment fluid comprising a base fluid and a swellable elastomer material; introducing the treatment fluid into the subterranean formation; and allowing the swellable elastomer to swell and at least partially reduce fluid loss.
[0060] In another embodiment, a method of the present invention comprises providing a treatment fluid comprising a base fluid and a swellable elastomer material; introducing the treatment fluid into the subterranean formation; and allowing the swellable elastomer to swell and at least partially seal a perforation.
[0061] In yet another embodiment, a method of the present invention comprises providing a treatment fluid comprising a base fluid and a swellable elastomer material; introducing the treatment fluid into the subterranean formation; and allowing the swellable elastomer to swell and at least partially inhibit the production of undesirable water or gas from the subterranean formation.
[0062] In yet another embodiment, the present invention provides a method comprising: providing a viscosified treatment fluid comprising swellable elastomers and a viscosifying agent, the viscosified treatment fluid having a viscosity; placing the viscosified treatment fluid into a subterranean formation; allowing the viscosity of the viscosified fluid to be reduced to a second viscosity; and allowing the swellable elastomers to be placed in the subterranean formation. In some embodiments, the swellable elastomers may be placed toward the top of the treatment fluid. In others, the swellable elastomers may be placed toward the bottom of the treatment fluid. Optionally, a breaker may be incorporated into the viscosified treatment fluid or added to the fluid, if desired. Examples of such suitable breakers for viscosified treatment fluids of the present invention include, but are not limited to, sodium chlorite, hypochlorite, perborate, persulfates, peroxides, including organic peroxides. Other suitable breakers include suitable acids. Preferred examples of suitable breakers for viscosified treatment fluids of the present invention that include a gelling agent that comprises diutan include peroxide breakers. Preferred examples include tert-butyl hydroperoxide and tert-amyl hydroperoxide. A breaker may be included in a viscosified treatment fluid of the present invention in an amount and form sufficient to achieve the desired viscosity reduction at a desired time. The breaker may be formulated to provide a delayed break, if desired. For example, a suitable breaker may be encapsulated if desired. Suitable encapsulation methods are known to those skilled in the art. One suitable encapsulation method that may be used involves coating the chosen breakers with a material that will degrade when downhole so as to release the breaker when desired. Resins that may be suitable include, but are not limited to, polymeric materials that will degrade when downhole. The terms "degrade," "degradation," or "degradable" refer to both the two relatively extreme cases of hydrolytic degradation that the degradable material may undergo, i.e., heterogeneous (or bulk erosion) and homogeneous (or surface erosion), and any stage of degradation in between these two. This degradation can be a result of, inter alia, a chemical or thermal reaction or a reaction induced by radiation. Suitable examples include polysaccharides such as dextran or cellulose; chitins; chitosans; proteins; aliphatic polyesters; poly(lactides); poly(glycolides); poly(y-caprolactones); ρoly(hydroxybutyrates); poly(anhydrides); aliphatic polycarbonates; orthoesters, poly(orthoesters); poly(amino acids); poly(ethylene oxides); and polyphosphazenes. If used, a breaker should be included in a composition of the present invention in an amount sufficient to facilitate the desired reduction in viscosity in a viscosifier treatment fluid. For instance, peroxide concentrations that may be used vary from about 0.1 to about 10 gallons of peroxide per 1000 gallons of the viscosified treatment fluid. Optionally, the viscosified treatment fluid may contain an activator or a retarder, inter alia, to optimize the break rate provided by the breaker. Any known activator or retarder that is compatible with the particular breaker used is suitable for use in the present invention. Examples of such suitable activators include, but are not limited to, chelated iron, copper, cobalt, and reducing sugars. An example of a suitable retarder includes sodium thiosulfate diethylene triamine. In some embodiments, the sodium thiosulfate may be used in a range of from about 5 to about 2000 lbs. per 1000 gallons of viscosified treatment fluid. An artisan of ordinary skill with the benefit of this disclosure will be able to identify a suitable activator or retarder and the proper concentration of such activator or retarder for a given application.
[0063] Therefore, the present invention is well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. The particular embodiments disclosed above are illustrative only, as the present invention may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular illustrative embodiments disclosed above may be altered or modified and all such variations are considered within the scope and spirit of the present invention. In particular, every range of values (of the form, "from about a to about b," or, equivalently, "from approximately a to b," or, equivalently, "from approximately a-b") disclosed herein is to be understood as referring to the power set (the set of all subsets) of the respective range of values, and set forth every range encompassed within the broader range of values. Also, the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee.

Claims

What is claimed is:
1. A method of reducing fluid loss in a subterranean formation comprising: placing a lost circulation composition comprising a base fluid and a swellable elastomer in at least a portion of a subterranean formation comprising a lost circulation zone; allowing the swellable elastomer to at least partially swell upon contact with a fluid; and allowing the lost circulation composition to at least partially reduce the loss of fluid to the subterranean formation.
2. The method of claim 1 wherein the swellable elastomer comprises at least one swellable elastomer selected from the group consisting of: an acrylate butadiene rubber, a polyacrylate rubber, an isoprene rubber, a choloroprene rubber, a butyl rubber, a brominated butyl rubber, a chlorinated butyl rubber, a chlorinated polyethylene, a neoprene rubber, a styrene butadiene copolymer rubber, a sulphonated polyethylene, an ethylene acrylate rubber, an epichlorohydrin ethylene oxide copolymer, an ethylene-propylene rubber, an ethylene- propylene-diene terpolymer rubber, an ethylene vinyl acetate copolymer, a fluorosilicone rubber, a silicone rubber, a poly 2,2,1-bicyclo heptene, an alkylstyrene, a crosslinked substituted vinyl acrylate copolymer, and diatomaceous earth.
3. The method of claim 1 wherein the swellable elastomer comprises at least one swellable elastomer selected from the group consisting of: a nitrile rubber, a hydrogenated nitrile rubber, a fluoro rubber, a perfiuoro rubber, a tetrafiuorethylene/propylene, a starch- polyacrylate acid graft copolymer, a polyvinyl alcoholcyclic acid anhydride graft copolymer, an isobutylene maleic anhydride, an acrylic acid type polymer, a vinylacetate-acrylate copolymer, a polyethylene oxide polymer, a carboxymethyl cellulose type polymer, and a starch- polyacrylonitrile graft copolymer.
4. The method of claim 1 wherein the swellable elastomer is a particle having a particle size in the range of from about 0.1 microns to about 2000 microns.
5. The method of claim 1 wherein the swellable elastomer is present in an amount of about 0.01% to about 50% by weight of the lost circulation composition.
6. The method of claim 1 wherein the fluid is an aqueous fluid.
7. A method comprising: providing a viscosified treatment fluid comprising a base fluid, a swellable elastomer and a viscosifying agent, the viscosified treatment fluid having a viscosity; placing the viscosified treatment fluid into a least a portion of a subterranean formation; allowing the swellable elastomer to swell to form a swelled elastomer; allowing the viscosity of the viscosified fluid to be reduced to a second viscosity; and allowing the swelled elastomer to placed in the subterranean formation.
8. The method of claim 7 wherein the swellable elastomer comprises at least one swellable elastomer selected from the group consisting of: an acrylate butadiene rubber, a polyacrylate rubber, an isoprene rubber, a choloroprene rubber, a butyl rubber, a brominated butyl rubber, a chlorinated butyl rubber, a chlorinated polyethylene, a neoprene rubber, a styrene butadiene copolymer rubber, a sulphonated polyethylene, an ethylene acrylate rubber, an epichlorohydrin ethylene oxide copolymer, an ethylene-propylene rubber, an ethylene- propylene-diene terpolymer rubber, an ethylene vinyl acetate copolymer, ,a fluorosilicone rubber, a silicone rubber, a poly 2,2,1-bicyclo heptene, an alkylstyrene, a crosslinked substituted vinyl acrylate copolymer, and diatomaceous earth.
9. The method of claim 7 wherein the swellable elastomer comprises at least one swellable elastomer selected from the group consisting of: a nitrile rubber, a hydrogenated nitrile rubber, a fluoro rubber, a perfluoro rubber, a tetrafluorethylene/propylene, a starch- polyacrylate acid graft copolymer, a polyvinyl alcoholcyclic acid anhydride graft copolymer, an isobutylene maleic anhydride, an acrylic acid type polymer, a vinylacetate-acrylate copolymer, a polyethylene oxide polymer, a carboxymethyl cellulose type polymer, and a starch- polyacrylonitrile graft copolymer.
10. The method of claim 7 wherein the swellable elastomer is a particle having a particle size in the range of from about 0.1 microns to about 2000 microns.
11. The method of claim 7 wherein the swellable elastomer is present in an amount of about 0.01% to about 50% by weight of the viscosified treatment fluid.
12. The method of claim 7 wherein the viscosified treatment fluid further comprises a breaker that comprises at least one selected from the group consisting of: sodium chlorite, hypochlorite, a perborate, a persulfate, and a peroxide.
13. The method of claim 7 wherein the base fluid is an aqueous fluid.
14. A method comprising: providing a spacer fluid comprising a base fluid and a swellable elastomer comprising at least one swellable elastomer selected from the group consisting of an acrylate butadiene rubber, a polyacrylate rubber, an isoprene rubber, a poly 2,2,1 - bicyclo heptene, and an allcylstyrene; and introducing the spacer fluid into a least a portion of a subterranean formation between a first fluid and a second fluid in a subterranean operation.
15. The method of claim 14 wherein the first fluid is a drilling fluid, and the second fluid is a cement composition.
16. The method of claim 14 wherein the first fluid is a drilling fluid.
17. The method of claim 14 wherein the second fluid is a brine.
18. The method of claim 14 further comprising allowing the swellable elastomer to at least partially swell.
19. The method of claim 14 wherein the swellable elastomer at least partially seals a void, a fracture, a hole, a channel or a combination thereof.
20. The method of claim 14 wherein the swellable elastomer is a particle having a particle size in the range of from about 0.1 microns to about 2000 microns.
PCT/GB2007/002444 2006-06-29 2007-06-29 Swellable elastomers and associated methods WO2008001112A1 (en)

Priority Applications (3)

Application Number Priority Date Filing Date Title
AU2007263592A AU2007263592B2 (en) 2006-06-29 2007-06-29 Swellable elastomers and associated methods
EP07733422A EP2038368A1 (en) 2006-06-29 2007-06-29 Swellable elastomers and associated methods
BRPI0713979-9A BRPI0713979A2 (en) 2006-06-29 2007-06-29 Method for reducing fluid loss in an underground formation and for treating underground formations

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US80613706P 2006-06-29 2006-06-29
US60/806,137 2006-06-29

Publications (1)

Publication Number Publication Date
WO2008001112A1 true WO2008001112A1 (en) 2008-01-03

Family

ID=38462362

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB2007/002444 WO2008001112A1 (en) 2006-06-29 2007-06-29 Swellable elastomers and associated methods

Country Status (5)

Country Link
US (2) US7717180B2 (en)
EP (3) EP2038368A1 (en)
AU (1) AU2007263592B2 (en)
BR (1) BRPI0713979A2 (en)
WO (1) WO2008001112A1 (en)

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2009047496A2 (en) * 2007-10-10 2009-04-16 Halliburton Energy Services, Inc. Cement compositions comprising a high-density particulate elastomer and associated methods
GB2458215A (en) * 2008-03-12 2009-09-16 Brinker Technology Ltd Method of sealing a leak
WO2010058224A1 (en) * 2008-11-20 2010-05-27 Brinker Technology Ltd Sealing method and apparatus
WO2010119296A1 (en) * 2009-04-16 2010-10-21 Brinker Technology Ltd Delivery method and compositions
US7878245B2 (en) 2007-10-10 2011-02-01 Halliburton Energy Services Inc. Cement compositions comprising a high-density particulate elastomer and associated methods
EP2356193A2 (en) * 2008-10-13 2011-08-17 M.I L.L, C. Chrome free water-based wellbore fluid
AU2011225933B2 (en) * 2010-03-10 2014-02-06 Halliburton Energy Services, Inc Methods relating to modifying flow patterns using in-situ barriers

Families Citing this family (91)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7607482B2 (en) * 2005-09-09 2009-10-27 Halliburton Energy Services, Inc. Settable compositions comprising cement kiln dust and swellable particles
US7607484B2 (en) * 2005-09-09 2009-10-27 Halliburton Energy Services, Inc. Foamed cement compositions comprising oil-swellable particles and methods of use
US8316936B2 (en) 2007-04-02 2012-11-27 Halliburton Energy Services Inc. Use of micro-electro-mechanical systems (MEMS) in well treatments
US8297353B2 (en) 2007-04-02 2012-10-30 Halliburton Energy Services, Inc. Use of micro-electro-mechanical systems (MEMS) in well treatments
US8302686B2 (en) 2007-04-02 2012-11-06 Halliburton Energy Services Inc. Use of micro-electro-mechanical systems (MEMS) in well treatments
US9494032B2 (en) 2007-04-02 2016-11-15 Halliburton Energy Services, Inc. Methods and apparatus for evaluating downhole conditions with RFID MEMS sensors
US9200500B2 (en) 2007-04-02 2015-12-01 Halliburton Energy Services, Inc. Use of sensors coated with elastomer for subterranean operations
US9822631B2 (en) 2007-04-02 2017-11-21 Halliburton Energy Services, Inc. Monitoring downhole parameters using MEMS
US9194207B2 (en) 2007-04-02 2015-11-24 Halliburton Energy Services, Inc. Surface wellbore operating equipment utilizing MEMS sensors
US8162050B2 (en) 2007-04-02 2012-04-24 Halliburton Energy Services Inc. Use of micro-electro-mechanical systems (MEMS) in well treatments
US9732584B2 (en) 2007-04-02 2017-08-15 Halliburton Energy Services, Inc. Use of micro-electro-mechanical systems (MEMS) in well treatments
US10358914B2 (en) 2007-04-02 2019-07-23 Halliburton Energy Services, Inc. Methods and systems for detecting RFID tags in a borehole environment
US8291975B2 (en) 2007-04-02 2012-10-23 Halliburton Energy Services Inc. Use of micro-electro-mechanical systems (MEMS) in well treatments
US8297352B2 (en) 2007-04-02 2012-10-30 Halliburton Energy Services, Inc. Use of micro-electro-mechanical systems (MEMS) in well treatments
US9879519B2 (en) 2007-04-02 2018-01-30 Halliburton Energy Services, Inc. Methods and apparatus for evaluating downhole conditions through fluid sensing
US8342242B2 (en) 2007-04-02 2013-01-01 Halliburton Energy Services, Inc. Use of micro-electro-mechanical systems MEMS in well treatments
US8876437B2 (en) * 2007-04-27 2014-11-04 M-I L.L.C. Use of elastomers to produce gels for treating a wellbore
AU2008245793B2 (en) * 2007-04-27 2012-06-21 M-I Llc Use of curable liquid elastomers to produce gels for treating a wellbore
US9512351B2 (en) 2007-05-10 2016-12-06 Halliburton Energy Services, Inc. Well treatment fluids and methods utilizing nano-particles
US9206344B2 (en) 2007-05-10 2015-12-08 Halliburton Energy Services, Inc. Sealant compositions and methods utilizing nano-particles
US9199879B2 (en) 2007-05-10 2015-12-01 Halliburton Energy Serives, Inc. Well treatment compositions and methods utilizing nano-particles
US8586512B2 (en) 2007-05-10 2013-11-19 Halliburton Energy Services, Inc. Cement compositions and methods utilizing nano-clay
US8685903B2 (en) * 2007-05-10 2014-04-01 Halliburton Energy Services, Inc. Lost circulation compositions and associated methods
US8476203B2 (en) 2007-05-10 2013-07-02 Halliburton Energy Services, Inc. Cement compositions comprising sub-micron alumina and associated methods
US8276666B2 (en) * 2007-08-08 2012-10-02 Halliburton Energy Services Inc. Sealant compositions and methods of use
US20090038801A1 (en) * 2007-08-08 2009-02-12 Ravi Krishna M Sealant Compositions and Methods of Use
US8181708B2 (en) * 2007-10-01 2012-05-22 Baker Hughes Incorporated Water swelling rubber compound for use in reactive packers and other downhole tools
US8240377B2 (en) * 2007-11-09 2012-08-14 Halliburton Energy Services Inc. Methods of integrating analysis, auto-sealing, and swellable-packer elements for a reliable annular seal
MX2010007771A (en) * 2008-01-18 2010-11-30 Mi Llc Degradable non-aqueous gel systems.
MX2010012058A (en) * 2008-05-05 2010-12-17 Mi Llc Methods and aqueous based wellbore fluids for reducing wellbore fluid loss and filtrate loss.
US9303502B2 (en) * 2009-10-27 2016-04-05 Baker Hughes Incorporated Method of controlling water production through treating particles with RPMS
US7866406B2 (en) * 2008-09-22 2011-01-11 Baker Hughes Incorporated System and method for plugging a downhole wellbore
WO2010065485A1 (en) * 2008-12-02 2010-06-10 Schlumberger Canada Limited Method and system for zonal isolation
US20110160096A1 (en) * 2008-12-31 2011-06-30 Halliburton Energy Services, Inc. Methods and Compositions Comprising a Dual Oil/Water-Swellable Particle
US7934554B2 (en) * 2009-02-03 2011-05-03 Halliburton Energy Services, Inc. Methods and compositions comprising a dual oil/water-swellable particle
US7923413B2 (en) * 2009-05-19 2011-04-12 Schlumberger Technology Corporation Lost circulation material for oilfield use
GB0909621D0 (en) * 2009-06-05 2009-07-15 3M Innovative Properties Co Fluorinated polymeric microparticles and uses thereof as fluid reducing additives
US8807216B2 (en) * 2009-06-15 2014-08-19 Halliburton Energy Services, Inc. Cement compositions comprising particulate foamed elastomers and associated methods
US8450391B2 (en) 2009-07-29 2013-05-28 Halliburton Energy Services, Inc. Weighted elastomers, cement compositions comprising weighted elastomers, and methods of use
US8623936B2 (en) 2009-07-29 2014-01-07 Halliburton Energy Services, Inc. Weighted elastomers, cement compositions comprising weighted elastomers, and methods of use
US20110086942A1 (en) * 2009-10-09 2011-04-14 Schlumberger Technology Corporation Reinforced elastomers
US9708523B2 (en) * 2009-10-27 2017-07-18 Halliburton Energy Services, Inc. Swellable spacer fluids and associated methods
US20110277996A1 (en) * 2010-05-11 2011-11-17 Halliburton Energy Services, Inc. Subterranean flow barriers containing tracers
US20120031612A1 (en) * 2010-08-09 2012-02-09 Weatherford/Lamb, Inc. Swellable Elastomer for Water Shut Off in Gravel Pack
US10280358B2 (en) * 2011-03-01 2019-05-07 Bottom Line Industries, Inc. Non-invasive cement spacer fluid compositions, spacer fluid products, methods of well operation and well apparatus
US9546314B2 (en) 2011-04-07 2017-01-17 Halliburton Energy Services, Inc. Treatment fluids containing a relative permeability modifier and a companion polymer interacting synergistically therewith and methods for use thereof
US8883695B2 (en) 2011-05-03 2014-11-11 Halliburton Energy Services, Inc. Particulate materials coated with a relative permeability modifier and methods for treating subterranean formations using treatment fluids containing the same
WO2012162117A1 (en) * 2011-05-20 2012-11-29 M-I L.L.C. Wellbore fluid used with swellable elements
US8967276B2 (en) 2012-01-18 2015-03-03 Baker Hughes Incorporated Non-ballistic tubular perforating system and method
US9540501B2 (en) * 2012-04-16 2017-01-10 Zeon Chemicals L.P. Water swellable rubber composition having stable swelling property at high temperatures
US9701881B2 (en) * 2012-06-20 2017-07-11 Halliburton Energy Services, Inc. Oil absorbent oilfield materials as additives in oil-based drilling fluid applications
US9080419B2 (en) * 2012-07-05 2015-07-14 Craig H. Benson Bentonite collars for wellbore casings
US10000984B2 (en) 2012-07-09 2018-06-19 M-I L.L.C. Wellbore fluid used with oil-swellable elements
EP2885371B1 (en) 2012-08-20 2017-03-15 Tucc Technology, Llc Solubilized polymer concentrates, methods of preparation thereof, and well drilling and servicing fluids containing the same
US9540561B2 (en) 2012-08-29 2017-01-10 Halliburton Energy Services, Inc. Methods for forming highly conductive propped fractures
US20140060836A1 (en) * 2012-09-03 2014-03-06 Fatma Daou Methods for Maintaining Zonal Isolation in A Subterranean Well
US9169433B2 (en) 2012-09-27 2015-10-27 Halliburton Energy Services, Inc. Methods for enhancing well productivity and minimizing water production using swellable polymers
US20140102726A1 (en) 2012-10-16 2014-04-17 Halliburton Energy Services, Inc. Controlled Swell-Rate Swellable Packer and Method
US9598927B2 (en) 2012-11-15 2017-03-21 Halliburton Energy Services, Inc. Expandable coating for solid particles and associated methods of use in subterranean treatments
US20150308221A1 (en) 2012-11-30 2015-10-29 Maersk Olie Og Gas A/S Method of providing a barrier in a fracture-containing system
US9587163B2 (en) * 2013-01-07 2017-03-07 Baker Hughes Incorporated Shape-change particle plug system
US9175529B2 (en) 2013-02-19 2015-11-03 Halliburton Energy Services, Inc. Methods and compositions for treating subterranean formations with interlocking lost circulation materials
US9284798B2 (en) 2013-02-19 2016-03-15 Halliburton Energy Services, Inc. Methods and compositions for treating subterranean formations with swellable lost circulation materials
US9416306B2 (en) 2013-02-28 2016-08-16 Halliburton Energy Services, Inc. Clean fluid loss control additives
WO2014158192A1 (en) * 2013-03-29 2014-10-02 Halliburton Energy Services, Inc. Accelerated swelling of oil-swellable elastomers in a well
US9688901B2 (en) * 2013-07-05 2017-06-27 James Blair Fontenot Lost circulation drilling fluids comprising elastomeric rubber particles and a method for decreasing whole mud loss using such composition
US9605519B2 (en) 2013-07-24 2017-03-28 Baker Hughes Incorporated Non-ballistic tubular perforating system and method
WO2015034601A1 (en) * 2013-09-06 2015-03-12 Isp Investments Inc. Fluid composition comprising crosslinked polyvinylpyrrolidone for oil field applications
US9441455B2 (en) 2013-09-27 2016-09-13 Baker Hughes Incorporated Cement masking system and method thereof
US9410398B2 (en) 2013-09-27 2016-08-09 Baker Hughes Incorporated Downhole system having compressable and expandable member to cover port and method of displacing cement using member
WO2015060815A1 (en) * 2013-10-22 2015-04-30 Halliburton Energy Services, Inc. Wellbore fluids comprising hydrated inorganic oxide materials and associated methods
CA2926076C (en) * 2013-11-22 2018-05-01 Halliburton Energy Services, Inc. Traceable polymeric additives for use in subterranean formations
US9725635B2 (en) * 2014-01-17 2017-08-08 Halliburton Energy Services, Inc. Methods and compositions to use shape changing polymers in subterranean formations
US9334337B2 (en) 2014-01-24 2016-05-10 Baker Hughes Incorporated Enhanced water swellable compositions
WO2015126419A1 (en) 2014-02-24 2015-08-27 Halliburton Energy Services, Inc. Propping subterranean formation fractures using memory particulates
CN104449655B (en) * 2014-11-05 2017-04-12 中国石油化工股份有限公司 Fracture-cavern type oil reservoir filtrate reducer composition and fracture-cavern type oil reservoir filtrate reducing method
WO2016085458A1 (en) * 2014-11-25 2016-06-02 Halliburton Energy Services, Inc. Self-degradation swelling diverter system
US9869154B2 (en) * 2014-11-25 2018-01-16 Baker Hughes, A Ge Company, Llc Apparatus and methods for closing flow paths in wellbores
US9783727B2 (en) 2015-10-22 2017-10-10 Halliburton Energy Services, Inc. Fluid loss control package for use in subterranean formation operations
CN105331342B (en) * 2015-12-04 2018-07-06 中国石油集团西部钻探工程有限公司 Gu completion tamponade liquid and preparation method thereof
US11053770B2 (en) * 2016-03-01 2021-07-06 Baker Hughes, A Ge Company, Llc Coiled tubing deployed ESP with seal stack that is slidable relative to packer bore
US10787880B2 (en) 2017-06-26 2020-09-29 Steve Wehrenberg Method for sealing perforation tunnels with swelling elastomer material
US10557074B2 (en) * 2018-06-29 2020-02-11 Baker Hughes, A Ge Company, Llc Methods of cementing a wellbore with the use of an oil swellable elastomer
US11898415B2 (en) * 2018-07-02 2024-02-13 Schlumberger Technology Corporation Cement compositions and methods
CN109762542A (en) * 2018-12-28 2019-05-17 青岛科凯达橡塑有限公司 A kind of oil-soluble lotion sealing agent and preparation method thereof
MX2021011392A (en) * 2019-04-08 2021-10-13 Halliburton Energy Services Inc Stable suspension of elastomer particles for use in a cement slurry.
CA3143230A1 (en) * 2019-06-28 2020-12-30 Schlumberger Canada Limited Cement compositions and methods
US20210355366A1 (en) 2020-05-15 2021-11-18 Halliburton Energy Services, Inc. Wellbore Servicing Fluid and Methods of Making and Using Same
CN111978020A (en) * 2020-08-19 2020-11-24 辽宁昆成实业有限公司 Cement paste system for plugging leakage of coupling gap of casing for oil well workover
CN114437684A (en) * 2020-10-16 2022-05-06 中国石油化工股份有限公司 Shielding temporary plugging agent for shallow casing leakage plugging and construction process thereof
US11680199B2 (en) 2021-05-14 2023-06-20 Halliburton Energy Services, Inc. Wellbore servicing fluid and methods of making and using same

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4588032A (en) 1984-08-09 1986-05-13 Halliburton Company Fluid spacer composition for use in well cementing
WO2002059452A1 (en) * 2001-01-26 2002-08-01 E2 Tech Limited Device and method to seal boreholes
US6668927B1 (en) 2003-03-21 2003-12-30 Halliburton Energy Services, Inc. Well completion foamed spacer fluids and methods
US20040180794A1 (en) * 2003-03-11 2004-09-16 Reddy B. Raghava Methods and compositions for sealing oil containing subterranean zones
US20040244978A1 (en) * 2003-06-04 2004-12-09 Sun Drilling Products Corporation Lost circulation material blend offering high fluid loss with minimum solids

Family Cites Families (56)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE2705046A1 (en) 1977-02-08 1978-08-10 Schenk Filterbau Gmbh METHOD AND DEVICE FOR FILTRATING LIQUIDS
DE3344291A1 (en) 1983-12-07 1985-06-13 Skw Trostberg Ag, 8223 Trostberg DISPERSING AGENT FOR SALTY SYSTEMS
US4704213A (en) * 1985-05-28 1987-11-03 Texaco Inc. Encapsulated oil absorbent polymers as lost circulation additives for oil based drilling fluids
GB2197363B (en) 1986-11-14 1990-09-12 Univ Waterloo Packing seal for boreholes
US4919989A (en) 1989-04-10 1990-04-24 American Colloid Company Article for sealing well castings in the earth
GB2248255B (en) 1990-09-27 1994-11-16 Solinst Canada Ltd Borehole packer
US5657822A (en) 1995-05-03 1997-08-19 James; Melvyn C. Drill hole plugging method utilizing layered sodium bentonite and liquid retaining particles
JPH09165995A (en) * 1995-12-15 1997-06-24 Denki Kagaku Kogyo Kk Slurry excavation method
US6017854A (en) 1997-05-28 2000-01-25 Union Oil Company Of California Simplified mud systems
US7121352B2 (en) 1998-11-16 2006-10-17 Enventure Global Technology Isolation of subterranean zones
OA11859A (en) 1999-04-09 2006-03-02 Shell Int Research Method for annular sealing.
AU2001231075A1 (en) 2000-01-24 2001-07-31 Robert R. Wood Improved drilling fluids
NO312478B1 (en) 2000-09-08 2002-05-13 Freyer Rune Procedure for sealing annulus in oil production
NO313895B1 (en) 2001-05-08 2002-12-16 Freyer Rune Apparatus and method for limiting the flow of formation water into a well
US6806232B1 (en) * 2001-05-31 2004-10-19 Steve Cart Composition of drilling fluids comprising ground elastomeric crumb rubber material and a method of decreasing seepage and whole mud loss using such composition
MY135121A (en) 2001-07-18 2008-02-29 Shell Int Research Wellbore system with annular seal member
US7644773B2 (en) 2002-08-23 2010-01-12 Baker Hughes Incorporated Self-conforming screen
US6832651B2 (en) 2002-08-29 2004-12-21 Halliburton Energy Services, Inc. Cement composition exhibiting improved resilience/toughness and method for using same
GB2409480B (en) 2002-09-06 2006-06-28 Shell Int Research Wellbore device for selective transfer of fluid
US20040055748A1 (en) 2002-09-19 2004-03-25 Reddy B. Raghava Elastomeric admixtures for improving cement elasticity
US6935432B2 (en) 2002-09-20 2005-08-30 Halliburton Energy Services, Inc. Method and apparatus for forming an annular barrier in a wellbore
US6854522B2 (en) 2002-09-23 2005-02-15 Halliburton Energy Services, Inc. Annular isolators for expandable tubulars in wellbores
US6840325B2 (en) 2002-09-26 2005-01-11 Weatherford/Lamb, Inc. Expandable connection for use with a swelling elastomer
NO318358B1 (en) 2002-12-10 2005-03-07 Rune Freyer Device for cable entry in a swelling gasket
US6834725B2 (en) 2002-12-12 2004-12-28 Weatherford/Lamb, Inc. Reinforced swelling elastomer seal element on expandable tubular
US6907937B2 (en) 2002-12-23 2005-06-21 Weatherford/Lamb, Inc. Expandable sealing apparatus
US7482309B2 (en) 2003-11-24 2009-01-27 Halliburton Energy Services, Inc. Methods of drilling wellbores using variable density fluids comprising coated elastic particles
US7543642B2 (en) 2003-01-24 2009-06-09 Halliburton Energy Services, Inc. Cement compositions containing flexible, compressible beads and methods of cementing in subterranean formations
US6848505B2 (en) 2003-01-29 2005-02-01 Baker Hughes Incorporated Alternative method to cementing casing and liners
NO319620B1 (en) 2003-02-17 2005-09-05 Rune Freyer Device and method for selectively being able to shut off a portion of a well
GB0412131D0 (en) 2004-05-29 2004-06-30 Weatherford Lamb Coupling and seating tubulars in a bore
DE602004015098D1 (en) 2003-05-14 2008-08-28 Schlumberger Technology Bv SELF-ADAPTIVE CEMENT SYSTEMS
US6681856B1 (en) 2003-05-16 2004-01-27 Halliburton Energy Services, Inc. Methods of cementing in subterranean zones penetrated by well bores using biodegradable dispersants
WO2005012686A1 (en) 2003-07-29 2005-02-10 Shell Internationale Research Maatschappij B.V. System for sealing a space in a wellbore
US7243732B2 (en) 2003-09-26 2007-07-17 Baker Hughes Incorporated Zonal isolation using elastic memory foam
US7234533B2 (en) 2003-10-03 2007-06-26 Schlumberger Technology Corporation Well packer having an energized sealing element and associated method
US6976542B2 (en) 2003-10-03 2005-12-20 Baker Hughes Incorporated Mud flow back valve
US20050113260A1 (en) 2003-11-21 2005-05-26 Wood Robert R. Drilling fluids
WO2005052308A1 (en) 2003-11-25 2005-06-09 Baker Hughes Incorporated Swelling layer inflatable
US7527095B2 (en) 2003-12-11 2009-05-05 Shell Oil Company Method of creating a zonal isolation in an underground wellbore
US7213652B2 (en) 2004-01-29 2007-05-08 Halliburton Energy Services, Inc. Sealed branch wellbore transition joint
GB2427887B (en) 2004-03-12 2008-07-30 Schlumberger Holdings Sealing system and method for use in a well
US7172022B2 (en) 2004-03-17 2007-02-06 Halliburton Energy Services, Inc. Cement compositions containing degradable materials and methods of cementing in subterranean formations
NO320173B1 (en) 2004-04-22 2005-11-07 Rune Freyer Method and apparatus for controlling a fluid flow between the outside and inside of a source tube
US20050241831A1 (en) 2004-05-03 2005-11-03 Steele David J Anchor for branch wellbore liner
US7275595B2 (en) 2004-05-13 2007-10-02 Schlumberger Technology Corporation Method and apparatus to isolate fluids during gravel pack operations
NO325434B1 (en) 2004-05-25 2008-05-05 Easy Well Solutions As Method and apparatus for expanding a body under overpressure
MY143661A (en) 2004-11-18 2011-06-30 Shell Int Research Method of sealing an annular space in a wellbore
NO322718B1 (en) 2004-12-16 2006-12-04 Easy Well Solutions As Method and apparatus for sealing an incompletely filled compartment with stop pulp
NO325912B1 (en) 2005-03-15 2008-08-18 Easy Well Solutions As Device and method for inserting a bottom seal into a borehole
NO324087B1 (en) 2005-05-02 2007-08-13 Easy Well Solutions As Device for annulus gasket
NO327157B1 (en) 2005-05-09 2009-05-04 Easy Well Solutions As Anchoring device for an annulus gasket having a first second end region and mounted on a tubular element
NO323791B1 (en) 2005-05-09 2007-07-09 Easy Well Solutions As Filter method and arrangement
US7341106B2 (en) 2005-07-21 2008-03-11 Halliburton Energy Services, Inc. Methods for wellbore strengthening and controlling fluid circulation loss
US7543640B2 (en) 2005-09-01 2009-06-09 Schlumberger Technology Corporation System and method for controlling undesirable fluid incursion during hydrocarbon production
US7650940B2 (en) 2005-12-29 2010-01-26 Halliburton Energy Services Inc. Cement compositions comprising particulate carboxylated elastomers and associated methods

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4588032A (en) 1984-08-09 1986-05-13 Halliburton Company Fluid spacer composition for use in well cementing
WO2002059452A1 (en) * 2001-01-26 2002-08-01 E2 Tech Limited Device and method to seal boreholes
US20040180794A1 (en) * 2003-03-11 2004-09-16 Reddy B. Raghava Methods and compositions for sealing oil containing subterranean zones
US6668927B1 (en) 2003-03-21 2003-12-30 Halliburton Energy Services, Inc. Well completion foamed spacer fluids and methods
US6852676B1 (en) 2003-03-21 2005-02-08 Halliburton Energy Services, Inc. Well completion foamed spacer fluids and methods
US20040244978A1 (en) * 2003-06-04 2004-12-09 Sun Drilling Products Corporation Lost circulation material blend offering high fluid loss with minimum solids

Cited By (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2009047496A2 (en) * 2007-10-10 2009-04-16 Halliburton Energy Services, Inc. Cement compositions comprising a high-density particulate elastomer and associated methods
WO2009047496A3 (en) * 2007-10-10 2009-05-28 Halliburton Energy Serv Inc Cement compositions comprising a high-density particulate elastomer and associated methods
US7878245B2 (en) 2007-10-10 2011-02-01 Halliburton Energy Services Inc. Cement compositions comprising a high-density particulate elastomer and associated methods
GB2458215A (en) * 2008-03-12 2009-09-16 Brinker Technology Ltd Method of sealing a leak
GB2458215B (en) * 2008-03-12 2012-09-05 Brinker Technology Ltd Method of sealing a leak
EP2356193A2 (en) * 2008-10-13 2011-08-17 M.I L.L, C. Chrome free water-based wellbore fluid
EP2356193A4 (en) * 2008-10-13 2012-05-02 Mi Llc Chrome free water-based wellbore fluid
WO2010058224A1 (en) * 2008-11-20 2010-05-27 Brinker Technology Ltd Sealing method and apparatus
WO2010119296A1 (en) * 2009-04-16 2010-10-21 Brinker Technology Ltd Delivery method and compositions
US8950438B2 (en) 2009-04-16 2015-02-10 Brinker Technology Ltd Method and compositions for delivery of a concentrated quantity of sealing elements to a leak site in a vessel
AU2011225933B2 (en) * 2010-03-10 2014-02-06 Halliburton Energy Services, Inc Methods relating to modifying flow patterns using in-situ barriers

Also Published As

Publication number Publication date
AU2007263592B2 (en) 2012-02-23
EP2514796A1 (en) 2012-10-24
US20080017376A1 (en) 2008-01-24
US20100218949A1 (en) 2010-09-02
EP2038368A1 (en) 2009-03-25
US7866393B2 (en) 2011-01-11
BRPI0713979A2 (en) 2012-11-20
EP2511359A1 (en) 2012-10-17
AU2007263592A1 (en) 2008-01-03
US7717180B2 (en) 2010-05-18

Similar Documents

Publication Publication Date Title
US7717180B2 (en) Swellable elastomers and associated methods
US9976383B2 (en) Traceable polymeric additives for use in subterranean formations
AU2010212167B2 (en) Methods and compositions comprising a dual oil/water-swellable particle
US7549474B2 (en) Servicing a wellbore with an aqueous based fluid comprising a clay inhibitor
EP2710088B1 (en) Wellbore fluid used with swellable elements
CA3001854C (en) Rare earth-containing compounds to enhance performance of downhole treatment compositions
US20110160096A1 (en) Methods and Compositions Comprising a Dual Oil/Water-Swellable Particle
AU2011218707B2 (en) Swellable elastomers and associated methods
WO2021061168A1 (en) Combination of fluid loss control additive and lost circulation materials to control losses in formation
AU2015202446B2 (en) Wellbore fluid used with swellable elements
AU2012259128A1 (en) Wellbore fluid used with swellable elements

Legal Events

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

Ref document number: 07733422

Country of ref document: EP

Kind code of ref document: A1

WWE Wipo information: entry into national phase

Ref document number: 2007263592

Country of ref document: AU

REEP Request for entry into the european phase

Ref document number: 2007733422

Country of ref document: EP

WWE Wipo information: entry into national phase

Ref document number: 2007733422

Country of ref document: EP

NENP Non-entry into the national phase

Ref country code: DE

ENP Entry into the national phase

Ref document number: 2007263592

Country of ref document: AU

Date of ref document: 20070629

Kind code of ref document: A

NENP Non-entry into the national phase

Ref country code: RU

ENP Entry into the national phase

Ref document number: PI0713979

Country of ref document: BR

Kind code of ref document: A2

Effective date: 20081226