WO2003089540A1 - Fluides de traitement de puits inhibiteurs d'hydrates - Google Patents

Fluides de traitement de puits inhibiteurs d'hydrates Download PDF

Info

Publication number
WO2003089540A1
WO2003089540A1 PCT/US2003/011675 US0311675W WO03089540A1 WO 2003089540 A1 WO2003089540 A1 WO 2003089540A1 US 0311675 W US0311675 W US 0311675W WO 03089540 A1 WO03089540 A1 WO 03089540A1
Authority
WO
WIPO (PCT)
Prior art keywords
well fluid
well
glycol
glycol compound
fluid
Prior art date
Application number
PCT/US2003/011675
Other languages
English (en)
Inventor
William E. Foxenberg
Michael T. Darring
Kim J. Gobert
David P. Kippie
Robert L. Horton
Original Assignee
M-I L.L.C.
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 M-I L.L.C. filed Critical M-I L.L.C.
Priority to AU2003234110A priority Critical patent/AU2003234110A1/en
Priority to BR0309380-8A priority patent/BR0309380A/pt
Priority to GB0423229A priority patent/GB2403757B/en
Publication of WO2003089540A1 publication Critical patent/WO2003089540A1/fr
Priority to NO20044987A priority patent/NO20044987L/no

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
    • C09K8/34—Organic liquids
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/04—Aqueous well-drilling compositions
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/04—Aqueous well-drilling compositions
    • C09K8/06—Clay-free compositions
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
    • C09K2208/22—Hydrates inhibition by using well treatment fluids containing inhibitors of hydrate formers

Definitions

  • the invention relates generally to wellbore fluids. More particularly, the present invention relates to non-aqueous, non-corrosive packer fluids.
  • packer fluid means a fluid that is left in the annular region of a well between tubing and outer casing above a packer.
  • the main functions of a packer fluid are: (1) to provide hydrostatic pressure in order to lower differential pressure across a sealing element, (2) to lower differential pressure on a wellbore and casing to prevent collapse and (3) to protect metals and elastomers from corrosion or deterioration.
  • they should be of sufficient density to control the producing formation, be solids-free and resistant to viscosity changes over long periods of time, and be noncorrosive to the wellbore and completion components.
  • the present invention relates to a method of treating a well including injecting a substantially water- free well-treating fluid into the well, where the well-treating fluid comprises a glycol compound and an organic liquid, the glycol compound and the organic liquid being present in amounts selected to achieve a predetermined density.
  • the present invention relates to a substantially water- free well fluid including a glycol compound and an organic liquid, where the glycol compound and the organic liquid are present in amounts selected to achieve a predetermined density.
  • the present invention relates to a method of treating a well including injecting a well-treating fluid into the well, where the well-treating fluid comprises water, a glycol compound, and other organic liquids in which the combination of fluids meets pre-set performance characteristics such as density, viscosity, hydrate inhibition, and compatibility with other fluids and elements in the annulus.
  • the present invention relates to a well fluid that includes water, a glycol compound, and other organic liquids in which the combination of fluids meets pre-set performance characteristics such as density, viscosity, hydrate inhibition, and compatibility with other fluids and elements in the annulus.
  • the present invention relates to a well fluid that includes a glycol compound, and a quaternary amine salt, where the glycol compound and the quaternary amine salt are present in amounts selected to achieve a predetermined density.
  • Glycols such as ethylene glycol, propylene glycol, and others can be mixed at a very broad range of ratios with water and/or organic liquids such as alcohols, glycol ethers and others to form fluid mixtures having densities ranging from low ( ⁇ 7 lbm/gal) to high (-11 lbm/gal), depending on desired properties.
  • Lbm/gal is a unit of density, which one of ordinary skill in the art would interpret as pound per gallon, or more specifically pound mass per gallon.
  • Such mixtures inhibit hydrates because the mixture is either substantially free of water or the water is made inhibitive by virtue of the glycol and alcohol.
  • the present invention describes the development of non-aqueous, non-solids laden, non-corrosive, hydrate inhibitive well fluids (or packer fluids) for use in oil field production annuli.
  • the well fluids are prepared to desired densities for annular pressure control by proportioning miscible, non-aqueous fluids together.
  • the non-aqueous fluids include glycols, glycol-ethers, alcohols and other organic liquids.
  • the well fluids may contain soluble salts to achieve specific densities.
  • the well fluids may be viscosified with synthetic or biopolymers to reduce convective currents, needed in some cases for annular heat insulation.
  • the present invention describes the development of non-solids laden, non-corrosive, hydrate inhibitive well fluids for use in oil field production annuli.
  • the fluid is prepared to desired densities for annular pressure control by proportioning miscible fluids together with water.
  • These fluids include glycols, glycol-ethers, alcohols and other organic liquids.
  • the fluids may contain soluble salts to achieve specific densities.
  • the fluids may be viscosified with synthetic or biopolymers to reduce convective currents, needed in some cases for annular heat insulation.
  • glycol compound and an organic liquid may be mixed in amounts sufficient to yield a desired density.
  • multiple glycol compounds and multiple organic liquids may be mixed, with or without water, so long as the mixture remains a solution.
  • a well fluid in accordance with one embodiment of the present invention comprises a mixture of 0.2 barrels of methanol, 0.35 barrels of monoethylene glycol (MEG), 0.42 barrels of water, and a sufficient amount of a CaBr 2 solution, having a density of 14.5 ppg, to form a well fluid, referred to as formulation 1 herein, having an overall density of approximately 8.6 ppg.
  • formulation 1 having an overall density of approximately 8.6 ppg.
  • a well fluid in accordance with one embodiment of the present invention comprises a mixture 0.2 barrels of methanol, 0.35 barrels of monoethylene glycol (MEG), 0.42 barrels of water, and a sufficient amount of a CaBr 2 solution, having a density of 15.3 ppg, to form a well fluid, referred to as formulation 2 herein, having an overall density of approximately 8.8 ppg. While particular salts, and particular densities are referenced in the above embodiments, it should be understood that the salt types and concentrations may also vary from zero to saturation, according to density / compatibility requirements.
  • aqueous fluids are susceptible to gas hydrate formation if high-pressure gas is encountered. Typical oilfield pressures exceed 8,000 psi.
  • An additional consideration is that well fluids having a density of 8.6 ppg (achievable with 3.5-4.5 wt% salt) are often used. This salt concentration is not adequate to prevent hydrate formation under the combination of low salinity fluid, low temperature and high gas pressure, should such a combination occur in the wellbore. Therefore, other means of hydrate prevention, while maintaining density control, are desired.
  • the present invention has discovered that advantageously, mixtures of glycol and organic liquids are effective hydrate inhibitors.
  • formulations are produced involving (1) halide brines, formate brines, and acetate brines, such as, for example, those based on tetramethylammonium chloride, tetramethylammonium bromide, tetramethylammonium formate, tetramethylammonium acetate, tetraethylammonium chloride, tetraethylammonium bromide, tetraethylammonium formate, tetraethylammonium acetate, tetrapropylammonium chloride, tetrapropylammonium bromide, tetrapropylammonium formate, tetrapropylammonium acetate, tetrabutylammonium chloride, tetrabutylammonium bromide, tetrabutylammonium formate, tetrabutylammonium formate, tetrabut
  • the present invention relates to well fluids comprising a glycol compound and a quaternary amine salt.
  • the glycol compound and quaternary amine may be mixed with an organic liquid, as described above, or with numerous other compounds.
  • mixtures of any or all of the above compounds may be used in connection with the present invention. The above list is not intended to be a comprehensive list of all suitable mixtures within the scope of the present invention.
  • One of ordinary skill in the art, having reference to this specification, will recognize that other mixtures are within the scope of the present invention.
  • a solution comprising 200 grams of ethylene glycol and 150 grams of tetrabutylammonium bromide was prepared.
  • the solution had a density of 9.0 ppg and a TCT (Thermodynamic Crystallization Temperature) ⁇ 25°F.
  • TCT Thermodynamic Crystallization Temperature
  • This fluid is highly inhibitive of hydrates.
  • salts like CaBr 2 , NaCl, and the like, cause the density of ethylene glycol to increase upon the addition of the salt to the ethylene glycol.
  • salt for example, tetrabutylammonium bromide
  • the density decreases.
  • Other salts that exhibit this surprising behavior include tetramethylammonium chloride, tetramethylammonium acetate, and the like.
  • a solution comprising 200 grams of ethylene glycol and 400 grams of tetrabutylammonium bromide was prepared.
  • the solution had a density of 9.0 ppg, substantially the same as that of the third example, another highly surprising result - that a substantial amount of a salt with density substantially greater than 9.0 ppg could be added to a solution without any appreciable density increase in the solution.
  • This fluid is highly inhibitive of hydrates.
  • a suitable well fluid having a predetermined density may comprise 20% to 50% of methanol and 20% to 50% of monethylene glycol of the total weight percentage. More preferably, in one or more embodiments, a suitable well fluid having a predetermined density may comprise 30% to 45% of methanol and 30% to 45% of monoethylene glycol of the total weight percentage. Still more preferably, in one or more embodiments, a suitable well fluid may comprise 35% to 40% of methanol and 35%o to 40% of monoethylene glycol of the total weight percentage.
  • a suitable well fluid may comprise a density of 5 ppg to 9 ppg. More preferably, in one or more embodiments, a suitable well fluid may comprise a density of 8.2 ppg to 8.8 ppg. Still more preferably, in one or more embodiments, a suitable well fluid may comprise 8.3 ppg to 8.5 ppg.
  • fluids disclosed herein may also be used as fluids in or in connection with drilling, drill-in, displacement, completion, hydraulic fracturing, work-over, well-treating, testing, or abandonment.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Physical Or Chemical Processes And Apparatus (AREA)
  • Agricultural Chemicals And Associated Chemicals (AREA)
  • Lubricants (AREA)
  • Infusion, Injection, And Reservoir Apparatuses (AREA)
  • Feeding, Discharge, Calcimining, Fusing, And Gas-Generation Devices (AREA)

Abstract

L'invention concerne un procédé de traitement de puits, consistant à injecter dans le puits un fluide de traitement de puits, ce fluide comprenant un glycol et un liquide organique présents dans des quantités permettant d'obtenir une densité désirée. Un autre mode de réalisation concerne un fluide de traitement de puits comprenant un glycol, un liquide organique et un sel, ces composés étant présents dans des quantités permettant d'obtenir une densité prédéterminée.
PCT/US2003/011675 2002-04-19 2003-04-16 Fluides de traitement de puits inhibiteurs d'hydrates WO2003089540A1 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
AU2003234110A AU2003234110A1 (en) 2002-04-19 2003-04-16 Hydrate Inhibiting Well Fluids
BR0309380-8A BR0309380A (pt) 2002-04-19 2003-04-16 Fluidos de poços inibidores de hidratos
GB0423229A GB2403757B (en) 2002-04-19 2003-04-16 Hydrate Inhibiting well fluids
NO20044987A NO20044987L (no) 2002-04-19 2004-11-17 Hydrat-inhiberende bronnfluider

Applications Claiming Priority (6)

Application Number Priority Date Filing Date Title
US37404902P 2002-04-19 2002-04-19
US60/374,049 2002-04-19
US41254302P 2002-09-20 2002-09-20
US60/412,543 2002-09-20
US10/410,611 2003-04-10
US10/410,611 US20030220202A1 (en) 2002-04-19 2003-04-10 Hydrate-inhibiting well fluids

Publications (1)

Publication Number Publication Date
WO2003089540A1 true WO2003089540A1 (fr) 2003-10-30

Family

ID=29255351

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2003/011675 WO2003089540A1 (fr) 2002-04-19 2003-04-16 Fluides de traitement de puits inhibiteurs d'hydrates

Country Status (6)

Country Link
US (1) US20030220202A1 (fr)
AU (1) AU2003234110A1 (fr)
BR (1) BR0309380A (fr)
GB (1) GB2403757B (fr)
NO (1) NO20044987L (fr)
WO (1) WO2003089540A1 (fr)

Cited By (15)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2139933A1 (fr) * 2007-03-23 2010-01-06 Board of Regents, The University of Texas System Procédé de traitement de formation avec un solvant
US8261825B2 (en) 2007-11-30 2012-09-11 Board Of Regents, The University Of Texas System Methods for improving the productivity of oil producing wells
US8403050B2 (en) 2007-03-23 2013-03-26 3M Innovative Properties Company Method for treating a hydrocarbon-bearing formation with a fluid followed by a nonionic fluorinated polymeric surfactant
US8418759B2 (en) 2007-12-21 2013-04-16 3M Innovative Properties Company Fluorinated polymer compositions and methods for treating hydrocarbon-bearing formations using the same
US8678090B2 (en) 2007-12-21 2014-03-25 3M Innovative Properties Company Methods for treating hydrocarbon-bearing formations with fluorinated polymer compositions
US8701763B2 (en) 2008-05-05 2014-04-22 3M Innovative Properties Company Methods for treating hydrocarbon-bearing formations having brine
US8833449B2 (en) 2009-07-09 2014-09-16 3M Innovative Properties Company Methods for treating carbonate hydrocarbon-bearing formations with fluorinated amphoteric compounds
US9057012B2 (en) 2008-12-18 2015-06-16 3M Innovative Properties Company Method of contacting hydrocarbon-bearing formations with fluorinated phosphate and phosphonate compositions
US9200102B2 (en) 2008-07-18 2015-12-01 3M Innovative Properties Company Cationic fluorinated polymer compositions and methods for treating hydrocarbon-bearing formations using the same
US9499737B2 (en) 2010-12-21 2016-11-22 3M Innovative Properties Company Method for treating hydrocarbon-bearing formations with fluorinated amine
US9624422B2 (en) 2010-12-20 2017-04-18 3M Innovative Properties Company Methods for treating carbonate hydrocarbon-bearing formations with fluorinated amine oxides
US9701889B2 (en) 2011-01-13 2017-07-11 3M Innovative Properties Company Methods for treating siliciclastic hydrocarbon-bearing formations with fluorinated amine oxides
GB2552198A (en) * 2016-07-13 2018-01-17 Statoil Petroleum As Fluids
US9890294B2 (en) 2012-11-19 2018-02-13 3M Innovative Properties Company Composition including a fluorinated polymer and a non-fluorinated polymer and methods of making and using the same
US10106724B2 (en) 2012-11-19 2018-10-23 3M Innovative Properties Company Method of contacting hydrocarbon-bearing formations with fluorinated ionic polymers

Families Citing this family (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CA2426607A1 (fr) * 2003-04-28 2004-10-28 Robin Tudor Fluide pour le traitement de puits et procede pour son recyclage
US7638465B2 (en) * 2006-08-03 2009-12-29 Baker Hughes Incorporated Kinetic gas hydrate inhibitors in completion fluids
US8048827B2 (en) 2006-08-03 2011-11-01 Baker Hughes Incorporated Kinetic gas hydrate inhibitors in completion fluids
US20100200237A1 (en) * 2009-02-12 2010-08-12 Colgate Sam O Methods for controlling temperatures in the environments of gas and oil wells
US20100236784A1 (en) * 2009-03-20 2010-09-23 Horton Robert L Miscible stimulation and flooding of petroliferous formations utilizing viscosified oil-based fluids
US20100252259A1 (en) * 2009-04-01 2010-10-07 Horton Robert L Oil-based hydraulic fracturing fluids and breakers and methods of preparation and use
US20100263867A1 (en) * 2009-04-21 2010-10-21 Horton Amy C Utilizing electromagnetic radiation to activate filtercake breakers downhole
US8895476B2 (en) 2011-03-08 2014-11-25 Tetra Technologies, Inc. Thermal insulating fluids
US9790104B2 (en) * 2012-02-17 2017-10-17 Hydrafact Limited Water treatment
EP3180408B1 (fr) 2014-08-13 2018-12-12 Albemarle Corporation Fluides aqueux de puits à densité élevée
MY188299A (en) 2016-11-17 2021-11-25 Albemarle Corp High density aqueous well fluids
US20190127623A1 (en) 2017-11-02 2019-05-02 Highland Fluid Technology, Ltd. Heavy Fluid and Method of Making It

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1994024413A1 (fr) * 1993-04-08 1994-10-27 Bp Chemicals Limited Procede d'inhibition de la formation de solides et melanges utilises dans ce procede
US6080704A (en) * 1997-03-11 2000-06-27 Halliday; William S. Glycols as gas hydrate inhibitors in drilling, drill-in, and completion fluids
US20010001991A1 (en) * 1998-01-08 2001-05-31 M-I Llc Conductive medium for openhold logging and logging while drilling
GB2363148A (en) * 1997-03-11 2001-12-12 Baker Hughes Inc Glycol derivatives and blends thereof as gas hydrate inhibitors

Family Cites Families (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2636050A (en) * 1951-05-03 1953-04-21 Union Carbide & Carbon Corp Separation of methanol from methyl acetate by extractive distillation with ethylene glycol
US3575855A (en) * 1968-05-01 1971-04-20 Pan American Petroleum Corp Drilling fluid system
US4360600A (en) * 1981-06-29 1982-11-23 Union Carbide Corporation Process for producing ethylene glycol and methanol
US4362820A (en) * 1981-06-29 1982-12-07 Union Carbide Corporation Process for producing ethylene glycol and methanol
US4494610A (en) * 1983-04-11 1985-01-22 Texaco Inc. Method for releasing stuck drill pipe
US4477360A (en) * 1983-06-13 1984-10-16 Halliburton Company Method and compositions for fracturing subterranean formations
US4981601A (en) * 1988-07-22 1991-01-01 Halliburton Company Reducing sludging during oil well acidizing
US5008026A (en) * 1989-01-30 1991-04-16 Halliburton Company Well treatment compositions and method
US5084192A (en) * 1990-09-28 1992-01-28 Halliburton Company Method and composition for preventing the formation of sludge in crude oil
US5290768A (en) * 1991-01-18 1994-03-01 Merck & Co., Inc. Welan gum-ethylene glycol insulating compositions
US5622921A (en) * 1993-01-21 1997-04-22 Nowsco Well Service, Inc. Anionic compositions for sludge prevention and control during acid stimulation of hydrocarbon wells
US6784140B2 (en) * 2001-08-15 2004-08-31 M-I L.L.C. Thermally stable, substantially water-free well fluid

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1994024413A1 (fr) * 1993-04-08 1994-10-27 Bp Chemicals Limited Procede d'inhibition de la formation de solides et melanges utilises dans ce procede
US6080704A (en) * 1997-03-11 2000-06-27 Halliday; William S. Glycols as gas hydrate inhibitors in drilling, drill-in, and completion fluids
GB2363148A (en) * 1997-03-11 2001-12-12 Baker Hughes Inc Glycol derivatives and blends thereof as gas hydrate inhibitors
US20010001991A1 (en) * 1998-01-08 2001-05-31 M-I Llc Conductive medium for openhold logging and logging while drilling

Non-Patent Citations (2)

* Cited by examiner, † Cited by third party
Title
DATABASE COMPENDEX [online] ENGINEERING INFORMATION, INC., NEW YORK, NY, US; NG HENG-JOO ET AL: "HYDRATE FORMATION AND INHIBITION IN GAS CONDENSATE AND HYDROCARBON LIQUID SYSTEMS", XP002248530, Database accession no. EIX88010013897 *
PAPERS PRESENTED AT THE AICHE 1987 SPRING NATIONAL MEETING.;HOUSTON, TX, USA, 1987, Amer Inst Chem Eng Natl Eng Natl Meet 1987 AIChE, New York, NY, USA *

Cited By (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2139933A4 (fr) * 2007-03-23 2012-01-11 Univ Texas Procédé de traitement de formation avec un solvant
US8403050B2 (en) 2007-03-23 2013-03-26 3M Innovative Properties Company Method for treating a hydrocarbon-bearing formation with a fluid followed by a nonionic fluorinated polymeric surfactant
US9353309B2 (en) 2007-03-23 2016-05-31 Board Of Regents, The University Of Texas System Method for treating a formation with a solvent
EP2139933A1 (fr) * 2007-03-23 2010-01-06 Board of Regents, The University of Texas System Procédé de traitement de formation avec un solvant
US8261825B2 (en) 2007-11-30 2012-09-11 Board Of Regents, The University Of Texas System Methods for improving the productivity of oil producing wells
US8418759B2 (en) 2007-12-21 2013-04-16 3M Innovative Properties Company Fluorinated polymer compositions and methods for treating hydrocarbon-bearing formations using the same
US8678090B2 (en) 2007-12-21 2014-03-25 3M Innovative Properties Company Methods for treating hydrocarbon-bearing formations with fluorinated polymer compositions
US8701763B2 (en) 2008-05-05 2014-04-22 3M Innovative Properties Company Methods for treating hydrocarbon-bearing formations having brine
US9200102B2 (en) 2008-07-18 2015-12-01 3M Innovative Properties Company Cationic fluorinated polymer compositions and methods for treating hydrocarbon-bearing formations using the same
US9057012B2 (en) 2008-12-18 2015-06-16 3M Innovative Properties Company Method of contacting hydrocarbon-bearing formations with fluorinated phosphate and phosphonate compositions
US8833449B2 (en) 2009-07-09 2014-09-16 3M Innovative Properties Company Methods for treating carbonate hydrocarbon-bearing formations with fluorinated amphoteric compounds
US9624422B2 (en) 2010-12-20 2017-04-18 3M Innovative Properties Company Methods for treating carbonate hydrocarbon-bearing formations with fluorinated amine oxides
US9499737B2 (en) 2010-12-21 2016-11-22 3M Innovative Properties Company Method for treating hydrocarbon-bearing formations with fluorinated amine
US9701889B2 (en) 2011-01-13 2017-07-11 3M Innovative Properties Company Methods for treating siliciclastic hydrocarbon-bearing formations with fluorinated amine oxides
US9890294B2 (en) 2012-11-19 2018-02-13 3M Innovative Properties Company Composition including a fluorinated polymer and a non-fluorinated polymer and methods of making and using the same
US10106724B2 (en) 2012-11-19 2018-10-23 3M Innovative Properties Company Method of contacting hydrocarbon-bearing formations with fluorinated ionic polymers
GB2552198A (en) * 2016-07-13 2018-01-17 Statoil Petroleum As Fluids

Also Published As

Publication number Publication date
NO20044987L (no) 2005-01-19
US20030220202A1 (en) 2003-11-27
BR0309380A (pt) 2005-02-22
GB2403757B (en) 2006-03-29
AU2003234110A1 (en) 2003-11-03
GB2403757A (en) 2005-01-12
GB0423229D0 (en) 2004-11-24

Similar Documents

Publication Publication Date Title
US20030220202A1 (en) Hydrate-inhibiting well fluids
EP0850287B1 (fr) Fluide de forage a base de glycol
EP2325277B1 (fr) Saumures haute densite employees dans des fluides de forages
AU702689B2 (en) Use of sized salts as bridging agent for oil based fluids
US20050113264A1 (en) Well treatment fluid
US20090082230A1 (en) Well Treatment Fluids Containing Nanoparticles and Methods of Using Same
US6194355B1 (en) Use of alkoxylated surfactants and aluminum chlorohydrate to improve brine-based drilling fluids
US20030236174A1 (en) Viscoelastic Surfactant Fluids Stable at High Brine Concentration and Methods of Using Same
CA2564566C (fr) Systeme de fluide de forage aqueux inhibiteur et procede de forage de sables et d'autres formations sensibles a l'eau
US7833946B2 (en) Water-based drilling fluid
EP3426748A1 (fr) Procédé d'augmentation de la masse volumique d'une saumure de traitement de puits
WO2005035931A2 (fr) Agent de stabilite thermique destine a maintenir des proprietes de viscosite et de perte de fluide dans des fluides de forage
CA2737445C (fr) Systeme de fluide de forage inhibiteur a base d'eau et procede de forage de sables et autres formations sensibles a l'eau
WO1996004348A1 (fr) Additifs de fluide de forage pour environnements enclins aux formations hydriques comportant des materiaux sensibles a l'eau, fluides de forage contenant lesdits additifs et procede de forage dans lesdits environnements
WO2009067362A2 (fr) Fluides de traitement dont la viscosité augmente à une température de seuil ou au-dessus et procédés de formulation et d'utilisation de tels fluides
CA2538771C (fr) Agents lubrifiants a base de phospholipides dans des fluides de forage aqueux
CA1244236A (fr) Polymeres liquide a teneur de compositions pour epaissir des melanges aqueux
WO2019222095A1 (fr) Procédé et composition pour sceller une formation souterraine
US20030075331A1 (en) Thermally stable, substantially water-free well fluid
US20170298270A1 (en) Environmental gelling agent for gravel packing fluids
CN111971365B (zh) 用于高密度澄清盐水流体的结晶抑制剂组合
WO2021026262A1 (fr) Phosphates de chlorure de sodium alkyle pg-dimonium en tant qu'agents lubrifiants dans des fluides de forage à base aqueuse
US20030078169A1 (en) Thermal extenders for well fluid applications
GB2367315A (en) Well treatment fluid
WO2003097995A1 (fr) Liquides tensioactifs viscoelastiques stables a des concentrations elevees de saumure et procedes d'utilisation associes

Legal Events

Date Code Title Description
AK Designated states

Kind code of ref document: A1

Designated state(s): AE AG AL AM AT AU AZ BA BB BG BR BY BZ CA CH CN CO CR CU CZ DE DK DM DZ EC EE ES FI GB GD GE GH GM HR HU ID IL IN IS JP KE KG KP KR KZ LC LK LR LS LT LU LV MA MD MG MK MN MW MX MZ NO NZ OM PH PL PT RO RU SC SD SE SG SK SL TJ TM TN TR TT TZ UA UG UZ VC VN YU ZA ZM ZW

AL Designated countries for regional patents

Kind code of ref document: A1

Designated state(s): GH GM KE LS MW MZ SD SL SZ TZ UG ZM ZW AM AZ BY KG KZ MD RU TJ TM AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IT LU MC NL PT RO SE SI SK TR BF BJ CF CG CI CM GA GN GQ GW ML MR NE SN TD TG

ENP Entry into the national phase

Ref document number: 0423229

Country of ref document: GB

Kind code of ref document: A

Free format text: PCT FILING DATE = 20030416

121 Ep: the epo has been informed by wipo that ep was designated in this application
122 Ep: pct application non-entry in european phase
NENP Non-entry into the national phase

Ref country code: JP

WWW Wipo information: withdrawn in national office

Country of ref document: JP