US20030220202A1 - Hydrate-inhibiting well fluids - Google Patents

Hydrate-inhibiting well fluids Download PDF

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Publication number
US20030220202A1
US20030220202A1 US10/410,611 US41061103A US2003220202A1 US 20030220202 A1 US20030220202 A1 US 20030220202A1 US 41061103 A US41061103 A US 41061103A US 2003220202 A1 US2003220202 A1 US 2003220202A1
Authority
US
United States
Prior art keywords
well fluid
well
glycol
glycol compound
fluid
Prior art date
Legal status (The legal status 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 status listed.)
Abandoned
Application number
US10/410,611
Other languages
English (en)
Inventor
William Foxenberg
Michael Darring
Kim Gobert
David Kippie
Robert Horton
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
MI LLC
Original Assignee
MI LLC
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 MI LLC filed Critical MI LLC
Priority to US10/410,611 priority Critical patent/US20030220202A1/en
Priority to BR0309380-8A priority patent/BR0309380A/pt
Priority to AU2003234110A priority patent/AU2003234110A1/en
Priority to PCT/US2003/011675 priority patent/WO2003089540A1/fr
Priority to GB0423229A priority patent/GB2403757B/en
Assigned to M-I L.L.C. reassignment M-I L.L.C. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: DARRING, MICHAEL T., FOXENBERG, WILLIAM E., HORTON, ROBERT L., KIPPIE, DAVID P., GOBERT, KIM J.
Publication of US20030220202A1 publication Critical patent/US20030220202A1/en
Priority to NO20044987A priority patent/NO20044987L/no
Abandoned legal-status Critical Current

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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.
  • 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
  • blends of the above mentioned brines and methanol solutions (5) blends of the above mentioned brines and ethylene glycol solutions, (6) blends of the above mentioned ethylene glycol solutions, and methanol solutions, and (7) blends of the above mentioned brines, ethylene glycol solutions, and methanol solutions are also within the scope of the present invention.
  • 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% 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.

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  • 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)
  • Lubricants (AREA)
  • Feeding, Discharge, Calcimining, Fusing, And Gas-Generation Devices (AREA)
  • Infusion, Injection, And Reservoir Apparatuses (AREA)
  • Agricultural Chemicals And Associated Chemicals (AREA)
US10/410,611 2002-04-19 2003-04-10 Hydrate-inhibiting well fluids Abandoned US20030220202A1 (en)

Priority Applications (6)

Application Number Priority Date Filing Date Title
US10/410,611 US20030220202A1 (en) 2002-04-19 2003-04-10 Hydrate-inhibiting well fluids
BR0309380-8A BR0309380A (pt) 2002-04-19 2003-04-16 Fluidos de poços inibidores de hidratos
AU2003234110A AU2003234110A1 (en) 2002-04-19 2003-04-16 Hydrate Inhibiting Well Fluids
PCT/US2003/011675 WO2003089540A1 (fr) 2002-04-19 2003-04-16 Fluides de traitement de puits inhibiteurs d'hydrates
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 (3)

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

Publications (1)

Publication Number Publication Date
US20030220202A1 true US20030220202A1 (en) 2003-11-27

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Family Applications (1)

Application Number Title Priority Date Filing Date
US10/410,611 Abandoned US20030220202A1 (en) 2002-04-19 2003-04-10 Hydrate-inhibiting well fluids

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 (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20040214726A1 (en) * 2003-04-28 2004-10-28 Robin Tudor Well stimulation fluid and well stimulation fluid recycling process
US20080032902A1 (en) * 2006-08-03 2008-02-07 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
US8048827B2 (en) 2006-08-03 2011-11-01 Baker Hughes Incorporated Kinetic gas hydrate inhibitors in completion fluids
US8895476B2 (en) 2011-03-08 2014-11-25 Tetra Technologies, Inc. Thermal insulating fluids
US20150076065A1 (en) * 2012-02-17 2015-03-19 Hydrafact Limited Water treatment
US10597574B2 (en) 2014-08-13 2020-03-24 Albemarle Corporation High density aqueous well fluids
US10759985B2 (en) 2015-07-23 2020-09-01 Albemarle Corporation High density aqueous well fluids
US11485893B2 (en) 2017-11-02 2022-11-01 Highland Fluid Technology, Inc. Heavy fluid and method of making it

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CN101821305A (zh) 2007-03-23 2010-09-01 德克萨斯州立大学董事会 用溶剂处理地层的方法
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
AU2008331558A1 (en) 2007-11-30 2009-06-11 3M Innovative Properties Company Methods for improving the productivity of oil producing wells
US8678090B2 (en) 2007-12-21 2014-03-25 3M Innovative Properties Company Methods for treating hydrocarbon-bearing formations with fluorinated polymer compositions
WO2009085936A1 (fr) 2007-12-21 2009-07-09 3M Innovative Properties Company Compositions de polymères fluorés et procédés de traitement de formulations renferment des hydrocarbures à l'aide de celles-ci
WO2009137285A1 (fr) 2008-05-05 2009-11-12 3M Innovative Properties Company Procédés de traitement de formations contenant des hydrocarbures ayant de la saumure
CA2730971A1 (fr) 2008-07-18 2010-01-21 3M Innovative Properties Company Compositions a base de polymeres fluores cationiques et procedes de traitement de formations contenant du petrole a l'aide de ces compositions
US9057012B2 (en) 2008-12-18 2015-06-16 3M Innovative Properties Company Method of contacting hydrocarbon-bearing formations with fluorinated phosphate and phosphonate compositions
EP2451891B1 (fr) 2009-07-09 2015-08-19 3M Innovative Properties Company Procédés de traitement de formations de carbonate contenant des hydrocarbures par des composés amphotères fluorés
CN103261361B (zh) 2010-12-20 2016-06-15 3M创新有限公司 用于用氟化胺氧化物处理碳酸盐含烃地层的方法
EP2655544A4 (fr) 2010-12-21 2015-01-14 3M Innovative Properties Co Procédé pour traiter des formations contenant des hydrocarbures avec une amine fluorée
CN103328603B (zh) 2011-01-13 2016-11-16 3M创新有限公司 用于用氟化胺氧化物处理硅质碎屑含烃地层的方法
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
EP2920271A4 (fr) 2012-11-19 2016-05-25 3M Innovative Properties Co Procédé de mise en contact de formations portant des hydrocarbures avec des polymères ioniques fluorés
GB2552198A (en) * 2016-07-13 2018-01-17 Statoil Petroleum As Fluids

Citations (14)

* 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
US4477360A (en) * 1983-06-13 1984-10-16 Halliburton Company Method and compositions for fracturing subterranean formations
US4494610A (en) * 1983-04-11 1985-01-22 Texaco Inc. Method for releasing stuck drill pipe
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
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
US6784140B2 (en) * 2001-08-15 2004-08-31 M-I L.L.C. Thermally stable, substantially water-free well fluid

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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
GB2363148B (en) * 1997-03-11 2002-02-13 Baker Hughes Inc Glycol derivatives and blends thereof as gas hydrate inhibitors in water base drilling, drill-in, and completion fluids

Patent Citations (14)

* 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
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
US6784140B2 (en) * 2001-08-15 2004-08-31 M-I L.L.C. Thermally stable, substantially water-free well fluid

Cited By (16)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20040214726A1 (en) * 2003-04-28 2004-10-28 Robin Tudor Well stimulation fluid and well stimulation fluid recycling process
US20080032902A1 (en) * 2006-08-03 2008-02-07 Baker Hughes Incorporated Kinetic gas hydrate inhibitors in completion fluids
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
US9523028B2 (en) 2011-03-08 2016-12-20 Tetra Technologies, Inc. Thermal insulating fluids
US20150076065A1 (en) * 2012-02-17 2015-03-19 Hydrafact Limited Water treatment
US9790104B2 (en) * 2012-02-17 2017-10-17 Hydrafact Limited Water treatment
US10597574B2 (en) 2014-08-13 2020-03-24 Albemarle Corporation High density aqueous well fluids
US11268005B2 (en) 2014-08-13 2022-03-08 Albemarle Corporation High density aqueous well fluids
US10759985B2 (en) 2015-07-23 2020-09-01 Albemarle Corporation High density aqueous well fluids
US11485893B2 (en) 2017-11-02 2022-11-01 Highland Fluid Technology, Inc. Heavy fluid and method of making it

Also Published As

Publication number Publication date
NO20044987L (no) 2005-01-19
BR0309380A (pt) 2005-02-22
AU2003234110A1 (en) 2003-11-03
GB2403757B (en) 2006-03-29
GB2403757A (en) 2005-01-12
WO2003089540A1 (fr) 2003-10-30
GB0423229D0 (en) 2004-11-24

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