WO2000043465A1 - Fluide de forage en eaux profondes a base d'eau - Google Patents

Fluide de forage en eaux profondes a base d'eau Download PDF

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Publication number
WO2000043465A1
WO2000043465A1 PCT/US1999/008212 US9908212W WO0043465A1 WO 2000043465 A1 WO2000043465 A1 WO 2000043465A1 US 9908212 W US9908212 W US 9908212W WO 0043465 A1 WO0043465 A1 WO 0043465A1
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WO
WIPO (PCT)
Prior art keywords
glucoside
glucorine
component
glycerine
mud
Prior art date
Application number
PCT/US1999/008212
Other languages
English (en)
Inventor
Norman P. Kenney
James A. Sampey
Mack Smithey
Jose J. Perez
Thomas S. Carter
Original Assignee
Kenney Norman P
Sampey James A
Mack Smithey
Perez Jose J
Carter Thomas S
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 Kenney Norman P, Sampey James A, Mack Smithey, Perez Jose J, Carter Thomas S filed Critical Kenney Norman P
Priority to AU35615/99A priority Critical patent/AU3561599A/en
Publication of WO2000043465A1 publication Critical patent/WO2000043465A1/fr

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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
    • C09K8/36—Water-in-oil emulsions
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/04—Aqueous well-drilling compositions
    • C09K8/14—Clay-containing compositions
    • C09K8/18—Clay-containing compositions characterised by the organic compounds
    • C09K8/20—Natural organic compounds or derivatives thereof, e.g. polysaccharides or lignin derivatives
    • C09K8/206—Derivatives of other natural products, e.g. cellulose, starch, sugars

Definitions

  • the present invention is based in part on the discovery that by combining a biodegradable
  • a water base drilling fluid may be used in place of an oil base drilling fluid, it may be used in the internal
  • phase of an oil base mud to more closely exhibit the oil base mud rheological properties it may be used as a completion fluid and it may be used as a drill-in fluid.
  • a drill-in fluid is a fluid used to drill through the pay zone of a reservoir.
  • permeability testing suspend particular materials introduced into the mud system, without being effected by or not affecting the water or interact with the drilling mud depending upon the concentration of the alkyl glucoside and glycerine component incorporated into the fluid.
  • Exemplary of the present invention is the recognition that it is desirable to formulate drilling drill-in and completion fluids for a particular application.
  • embodiments of the present invention comprise the use of methyl glycoside and a glycerine component for use in onshore (fresh water), offshore (sea water), cold water ( ⁇ 40° F) and high density (mud weight > 14ppg) or electrolyte formulations. These formulation have achieved 100% return permeability as contrasted with typical water base fluids which generally exhibit only 75% return permeability.
  • the invention described herein comprises the use of glucorine as an inhibitor in water based drilling fluids, invert oil based drilling fluids and as a completion fluid specially tailored
  • glycerine and polyglycerine material has also been added to many mud formulations in the past to provide lubricity and shale inhibition.
  • the present invention provides lubricity and shale inhibition as well as a natural remedy for gumbo clay, torque, drag and hydrate difficulties
  • the glucorine based fluids therefore address the drilling
  • formulations are thus desirable for use in deepwater, where prevention of gas hydrate formation and realization of low viscosities at low temperatures are imperative.
  • a high density e.g.
  • drilling fluid is desirable or where an electrolyte formulation is called for, inhibitive
  • salts including but not limited to, calcium chloride, gypsum, lime, potassium sulfate, potassium
  • magnesium sulfate, aluminum salts, formates, etc. may be combined with glucorine.
  • glucorine has been found to be the inhibitor of choice in water base drilling fluids, as the internal
  • Drilling mud or drilling fluid is a more-or-less complex mixture of chemicals used in drilling of a well to perform a variety of functions.
  • Drilling mud comprises a liquid or slurry that is pumped down the drill string to exit through nozzles in the bit immediately adjacent the formation being penetrated.
  • the drilling mud flows upwardly in the annulus between the drill string and the wall of the hole to the surface and provides a variety of functions.
  • the drilling mud cools and lubricates the bit, delivers hydraulic horsepower to the bit, carries cuttings upwardly in the hole during circulation, suspends the cuttings in the bore hole when circulation
  • drilling muds There are all sorts of drilling muds. The most elementary drilling mud is water mixed with drilled solids and is often called "native" drilling mud. Some of the drilled solids are clays which, when finely ground, provide several of the functions of drilling mud. Some of the drilled solids add weight to the slurry which raises the density of mud to 9.2-9.9 #/gallon which is sufficient to control
  • Native mud was the earliest used in the rotary drilling of oil and gas wells. It was soon discovered that native drilling mud provides almost no control over the loss of water into permeable formations, tends to wash out or enlarge the diameter of the hole, accumulate shale balls on the bit and have other major disadvantages. Since that time, a wide variety of chemicals
  • One desirable characteristic of a drilling mud is that it sets up or gels, within the well bore. This characteristic is desirable so that cuttings or weight material in the drilling mud don't fall by gravity through the drilling mud toward the bottom of the hole when circulations stops. This characteristic is imparted to drilling mud by a gelling agent, such as drilled solids, bentonite
  • a drilling mud creates a filter cake of low permeability on the face or permeable formations.
  • the filter cake should be relatively thin and hard as opposed to thick and gooey.
  • the filter cake is created because the pressure in the bore hole exceeds the pressure in a permeable formation penetrated thereby and liquid from the mud is moved into the permeable formation, leaving on the face of the formation a filter cake comprising the solids entrained in the mud.
  • the liquid lost to the formation is called filtrate.
  • filtrate When a large amount of filtrate passes across the formation face, a thick filter cake is deposited.
  • a small amount of filtrate passes across the
  • a thin filter cake is deposited.
  • One function of the filter cake is to limit additional
  • One purpose of a good filter cake is to reduce the quantity of filtrate lost to a permeable formation which is desirable for two reasons. First, a large amount of filtrate in the formation can affect the characteristics of many electric logs. Second, there is a danger of the filtrate causing materials in the permeable formation to swell, thereby reducing the permeability of a possibly productive formation to an extent where the formation will not produce successfully.
  • a fresh water filtrate for example, causes many clays such as montmorillonite and illite to swell.
  • Sodium hydroxide is added to many drilling muds to raise the pH thereof. As will become more fully apparent hereinafter, most pre-existing muds to which the additives of this invention are used are quite alkaline because sodium hydroxide has usually been added thereto.
  • Drilling of a typical well begins by using a so called “spud” mud.
  • spud mud is prepared by pumping highly treated mud from a previous well into a vacuum truck and watering it down with sufficient water to make it thin.
  • spud mud is prepared by mixing bentonite in water so the resultant suspension contains 25-30# of bentonite per barrel of
  • the additives of this invention are mixed with the preexisting mud.
  • gelling agent i.e. drilled solids, bentonite, subbentonitic clays, and mixtures thereof, in the mud.
  • defoamer is simply added to the mud.
  • the volume of a mud system is the sum of the volume of the hole and the volume of the mud tanks or pits.
  • the volume of a mud tank or pit is usually assumed to be constant even though they partially fill up with drilled solids during the course of drilling a well.
  • the volume of the hole increases substantially with drilling because the hole gets deeper.
  • the volume of mud in a mud system has to increase during the course of drilling a well or the mud tank or pit will run dry.
  • liquid is more-or-less continuously added to a mud system.
  • liquid is added by allowing a stream of water from a water hose to flow into the mud return line or across the shale shaker.
  • water is added conventionally but liquid additives are prepared and placed in a tank of adequate size, e.g. a frac tank, and periodically pumped into the mud tank.
  • a mud engineer determines this needed volume addition and leaves instructions for each driller to operate the compressed air driven pump for a predetermined number of minutes each tour, thereby adding the necessary volume of glucorine-defoamer solution as needed.
  • a mud engineer conducts a variety of analyses on the drilling
  • glycoside as used in glucorine is applied to a type of compound in which a sugar (reducing saccharide) is combined through its reducing group with an, organic substance containing an alcoholic hydroxyl group, such as phenol or an alcohol.
  • a sugar reducing saccharide
  • an organic substance containing an alcoholic hydroxyl group such as phenol or an alcohol.
  • glycosides occur naturally in plants and animals and were originally isolated from sources. Some of these naturally occurring glycosides are the familiar and exotic sounding coniferin, slicin, amygdalin, arbutin, hesperidin, quercitrin, indican, delphinin, and chrysanthemin.
  • the sugar portion of most naturally occurring glycosides is glucose and, accordingly, these glycosides are known specifically as glucosides.
  • the glycosides are specifically designed as galactosides.
  • aglycon a phenol or alcohol
  • the compound is known, respectively, as an aryl glycoside or an alkyl glycoside.
  • phenyl glucoside the aryl glucoside.
  • the glycoside arising from the combination of methanol and glucose is the alkyl glycosides in general: M. L. Wolfrom and A. Thompson, H. Baumann and W. Pigman, in "The Carbohydrates" (W. Pigmall, ed.).
  • a glycoside is the compound resulting from the exchange of an organic radical (aryl, alkyl, etc.) for the hydrogen of the hemiacetal hydroxyl group (that attached to carbon (1) in formula I of a cyclic form of a reducing sugar.
  • V Methyl ⁇ -D-glucofuranoside
  • An alkyl glucoside such as a methyl glucoside can exist in several isometric forms.
  • the carbon atom containing the organic radical (carbon (1)) is asymmetric and the ring structure may shift from 6-membered to 5-membered (pyranose and furanose).
  • ⁇ - and ⁇ -pyranosides formulas II and III
  • ⁇ - and ⁇ -pyranosides formulas IV and V.
  • alkyl glycoside (or alkyl D-glycoside) is used generically to include all isometric forms of the alkyl glycoside.
  • alkyl and ⁇ - D-glycoside and alkyl ⁇ -D-glycoside are used when referring to glycoside having the specific ⁇ - or ⁇ -rotation of the alkyl group.
  • methyl ⁇ - D-glycoside includes the isomers methyl ⁇ - D-pyranoside and methyl ⁇ -furanoside
  • methyl ⁇ -D- glucoside includes the isomers methyl ⁇ -D-pyranoside and methyl ⁇ -D-furanoside.
  • the alkyl glycosides for the purpose of this invention are water soluble.
  • the alkyl radical may contain from one to four carbon atoms, i.e., the alkyl radical may be selected from the group consisting of methyl, ethyl, n-propyl, isopropyl, n-butyl, iso-butyl, sec-butyl, t-butyl, and mixtures thereof.
  • the preferred alkyl radical is methyl or ethyl, most preferably methyl.
  • the preferred glycosides are methyl glucoside and ethyl glucoside, most preferably methyl glucoside.
  • alkyl glycoside as used herein is defined as a material which contains from 1 to 5 units of a sugar source, such as glucose, and an alkyl radical, or substituted alkyl radical, containing 1 to 4 carbon atoms. If the glycoside contains 2 or more units of glucose, e.g., a polymer, then the material may be referred to as a polyglucoside. If the glycoside contains 2 units of glucose, then the material may be referred to as a glucoside or a-polyglucoside having a degree of polymerization (D.P.) of 2. The D.P. value is normally stated as an average insofar as a mixture
  • glycosides having different degrees of polymerization will normally be obtained.
  • D.P. of the glycosides herein is from 1.0 to about 5, more preferably from 1.0 to 3.0.
  • glycoside also embraces ether derivatives of glycosides such as the methyl, ethylene oxide and propylene oxide adducts, provided the number of moles of methyl, chloride, ethylene oxide and/or propylene oxide reacted per mole of the reducing sugar monomer does not render the glycoside water insoluble.
  • the alkyl glucoside will have the empirical formula
  • alkyl glycoside known for the preparation of the alkyl glycoside. See for example the following U.S. Patents, incorporated herein by reference: U.S. Pat. Nos. 2,276,621; 2,390,507; 2,606,186; 3,296,245; 3,375,243 and 3,928,318.
  • a preferred alkyl glucoside is a 70% methyl glucoside product available from Grain Processing Corporation, Muscatine, Iowa and is known as Geo-Meg ® 207.
  • the glycerine component to be used in glucorine may be simple glycerol, polyglycerol,
  • glycerine diglycerine, triglycerine, tetraglycerine, pentaglycerine, heavier polyglycerines and mixtures thereof.
  • a preferred glycerine component is a mixture of glycerine and polyglycerines I. II. III.
  • Polyglycerine (W-80) available from Dow Chemical is a byproduct of some chemical manufacturing operation of which applicant is unaware. Thus, it would seem that the available material would vary from batch to batch, although no noticeable differences have been perceived in using this material in several wells. It is believed that Polyglycerine (W-80) is an azeotropic mixture of water and glycerines because heating this mixture causes the mixture to boil off at a constant temperature and creates a reduction in the volume of material but does not apparently change the composition of the remaining material.
  • the glycerine component in the glucorine of this invention has a plurality of functions.
  • Glucorine may be formed by combining alkyl glucoside with the glycerine component to form a mixture thereof. Typically, the water content of the respective mixtures is determined in order to account for the inherent water in the mixture. Once this is determined, then the appropriate amount of water may be added to adjust the mixture to the desired concentration.
  • the alky glucoside is first added to the glycerine component. Water and acetic acid is then added. The acetic acid is added to adjust the mixture to a pH of between
  • An existing mud may also be converted to a glucorine based mud.
  • the volume of the existing mud must generally be reduced. This is simply accomplished by pumping excess mud to storage.
  • the amount of existing mud to be pumped may be determined by analyzing the existing muds reological properties and comparing them to the desired glucoring based mud.
  • the MBT of the existing mud should be reduced to a value generally less than or about 10 ppb bentonite equivalent and preferably about 7.5 ppb bentonite equivalent. Care should
  • Bentonite should generally not be used for rheology. Minor rheology adjustment may be made with a viscosifier such as sepiolite or xanthan polymer. After reaching the desired
  • the mud may then be reconstituted by adding glucorine and filtration fluid loss control agents such a Dynalose W, DynaPlex and NewPac LV, and adding a viscosifier such as xanthan or sepiolite as necessary.
  • glucorine and filtration fluid loss control agents such as Dynalose W, DynaPlex and NewPac LV
  • a viscosifier such as xanthan or sepiolite
  • a component such as NewBar (barium sulfate) may be added as necessary for density.
  • API American Petroleum Institute water loss
  • hsi horsepower per square inch
  • HTHP High Temperature High Pressure filtration test
  • MBT Methylene Blue Test
  • P f p-alkalinity filtrate
  • Mf m-alkalinity filtrate
  • Pm p-alkalinity mud
  • Dynabse W Starch
  • DynaNite Gilsonite
  • Gypsum Calcium Sulfate
  • Lime Calcium
  • methyl glucoside used in the examples contained from about 45% to about 55% by weight of methyl ⁇ -D-glucoside and from about 45% to about 55% by weight of methyl ⁇ -D-glucoside. About 94% by weight of the methyl glucoside are the methyl glucopyranoside isomers and about 6% by weight are the methyl glycofuranoside isomers.
  • preferred glucorine of the present invention comprises 30-75% (v/v) Polyglycerine (W-80), about 10-40% (v/v) Geo-Meg 207 and about 15-30% (v/v) water.
  • a most preferred glucorine of the present invention comprises about 40-55% (v/v) Polyglycerine (W-80), about 20-30% (v/v) Geo- Meg 207 and about 25-30% (v/v) water. All drilling fluid data were obtained utilizing the procedures set forth in API Specification RP13B unless otherwise indicated.
  • EXAMPLE 1 A water base glucorine formulation was prepared for use in wells drilled on land. The formulation is disclosed in Table 1. This drilling fluid formulation was hot rolled at 150° F and rheological properties were measured at 120° F. The rheological properties for the onshore formulation are found in Table 2. The Glucorine inhibitor was 75% (v/v) Polyglycerine (W-80)
  • EXAMPLE 2 A water base glucorine formulation was prepared for use in wells drilled offshore. The formulation is disclosed in Table 3. This drilling fluid formulation was hot rolled at 250° F and rheological properties were measured at 120° F. The rheological properties for the seawater formulation are found in Table 4. The Glucorine inhibitor was 75% (v/v) Polyglycerine (W-80)
  • EXAMPLE 3 A water base glucorine formulation was prepared for use in wells drilled in cold water. The
  • EXAMPLE 4 A water base glucorine formulation was prepared for use in wells where a 17pps fluid was required. The formulation is disclosed in Table 7. This drilling fluid formulation was hot rolled at 275° F and rheological properties were measured at 120° F. The rheological properties for the electrolyte formulation are found in Table 8. The Glucorine inhibitor was 75% (v/v)
  • a water base glucorine formulation was prepared for use in wells where a 17ppg fluid was
  • the formulation is disclosed in Table 9. This drilling fluid formulation was hot rolled at 275° F and rheological properties were measured at 120° F. The rheological properties for the electrolyte formulation are found in Table 10.
  • the Glucorine inhibitor was 75% (v/v)
  • the formulation is disclosed in Table 11. This drilling fluid formulation was hot rolled at 275° F and rheological properties were measured at 120° F. The rheological properties for the electrolyte formulation are found in Table 12.
  • the Glucorine inhibitor was 75% (v/v)
  • EXAMPLE 7 A water base glucorine formulation was prepared for use in wells drilled in electrolyte. The
  • Electrolyte (potassium sulfate format)
  • the lubricity coefficient of friction of a glucorine base fluid was compared with that of a
  • lubricity tester was calibrated with distilled water at a speed of 60 rpm with 150 lbs of torque to determine a correction factor for the coefficient reading.
  • the muds were run at 60 rpm with 150 lbs of torque for five minutes and the lubricity coefficient read from the dial. The lubricity coefficient reading was then multiplied by the correction factor to determine the actual coefficient of friction.
  • Table 15 The data obtained are given in Table 15.
  • the glucorine base fluid formulation and the diesel oil-based mud had the same lubricity
  • test well number two was a re-drill of an
  • glucorine inhibitor was 75% (v/v) polyglycerine (W-80) and 10%) (v/v) Geo-Meg 207.
  • Glucorine formulation was introduced, the standpipe pressure dropped 400 psi. Lubricity was
  • the glucorine inhibitor was 75% (v/v) polyglycerine (W-80) and 10% (v/v) Geo-Meg 207.

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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)
  • Dispersion Chemistry (AREA)
  • Agricultural Chemicals And Associated Chemicals (AREA)

Abstract

Cette invention concerne du glucorine que l'on utilise en qualité d'inhibiteur pour des fluides utilisés dans des puits de pétrole ou de gaz. Le glucorine est formé en combinant un composant glycoside soluble dans l'eau et biodégradable, tel que du glycoside d'alkyle, à un composant glycérine. Lorsque le glucorine est ajouté à la base aqueuse du fluide de forage, le mélange obtenu possède des propriétés rhéologiques comparables à celles d'un fluide de forage à base d'huile traditionnel. D'après cette invention, un fluide de forage à base d'eau peut être utilisé à la place d'un fluide de forage à base d'huile, dans la phase interne d'une boue à base d'huile afin de mieux exprimer les propriétés rhéologiques de ladite boue ou, encore, en qualité de fluide de complétion ou de fluide de forage de couche productive.
PCT/US1999/008212 1999-01-26 1999-04-15 Fluide de forage en eaux profondes a base d'eau WO2000043465A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU35615/99A AU3561599A (en) 1999-01-26 1999-04-15 Water based deep water drilling fluid

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US23732099A 1999-01-26 1999-01-26
US09/237,320 1999-01-26

Publications (1)

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WO2000043465A1 true WO2000043465A1 (fr) 2000-07-27

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Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2001081498A2 (fr) * 2000-04-19 2001-11-01 Shell Internationale Research Maatschappij B.V. Boue de forage
GB2365896A (en) * 2000-08-14 2002-02-27 Grain Processing Corp Drilling fluid
US6518223B2 (en) 2000-08-14 2003-02-11 Grain Processing Corporation Drilling fluid, apparatus, and method
US7018955B2 (en) 2000-08-14 2006-03-28 Grain Processing Corporation Drilling fluid, apparatus, and method
CN102604604A (zh) * 2012-02-06 2012-07-25 北京探矿工程研究所 一种钻井液材料及其制备和应用
WO2015052644A1 (fr) * 2013-10-08 2015-04-16 Clearwater International, Llc Fluides de forage aqueux haute performance réutilisables

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3928318A (en) * 1974-11-01 1975-12-23 Kaiser Aluminium Chem Corp Process for making methyl glucoside
US5003057A (en) * 1988-12-23 1991-03-26 Henkel Kommanditgesellschaft Auf Aktien Process for production of glycosides
US5403820A (en) * 1992-12-24 1995-04-04 O'brien-Goins-Simpson & Associates Environmentally safe water base drilling fluid
US5602082A (en) * 1994-12-23 1997-02-11 Shell Oil Company Efficiency of ethoxylated/propoxylated polyols with other additives to remove water from shale
US5686396A (en) * 1994-12-23 1997-11-11 Shell Oil Company Efficiency of polyglycerol with other additives to remove water from shale

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3928318A (en) * 1974-11-01 1975-12-23 Kaiser Aluminium Chem Corp Process for making methyl glucoside
US5003057A (en) * 1988-12-23 1991-03-26 Henkel Kommanditgesellschaft Auf Aktien Process for production of glycosides
US5403820A (en) * 1992-12-24 1995-04-04 O'brien-Goins-Simpson & Associates Environmentally safe water base drilling fluid
US5602082A (en) * 1994-12-23 1997-02-11 Shell Oil Company Efficiency of ethoxylated/propoxylated polyols with other additives to remove water from shale
US5686396A (en) * 1994-12-23 1997-11-11 Shell Oil Company Efficiency of polyglycerol with other additives to remove water from shale

Cited By (15)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2001081498A2 (fr) * 2000-04-19 2001-11-01 Shell Internationale Research Maatschappij B.V. Boue de forage
US7320951B2 (en) 2000-04-19 2008-01-22 Shell Oil Company Silica-based drilling mud comprising glycoside lubricants with amino-linked alkyl chains
WO2001081498A3 (fr) * 2000-04-19 2002-06-13 Shell Int Research Boue de forage
US6518223B2 (en) 2000-08-14 2003-02-11 Grain Processing Corporation Drilling fluid, apparatus, and method
GB2365896B (en) * 2000-08-14 2003-02-26 Grain Processing Corp Drilling fluid, apparatus, and method
US6806231B2 (en) 2000-08-14 2004-10-19 Grain Processing Corporation Drilling fluid, apparatus, and method
US7018955B2 (en) 2000-08-14 2006-03-28 Grain Processing Corporation Drilling fluid, apparatus, and method
US7265078B2 (en) 2000-08-14 2007-09-04 Grain Processing Corporation Drilling fluid apparatus and method
GB2365896A (en) * 2000-08-14 2002-02-27 Grain Processing Corp Drilling fluid
WO2003020844A1 (fr) * 2001-08-28 2003-03-13 Grain Processing Corporation Fluide, appareil et procede de forage
CN102604604A (zh) * 2012-02-06 2012-07-25 北京探矿工程研究所 一种钻井液材料及其制备和应用
CN102604604B (zh) * 2012-02-06 2014-01-29 北京探矿工程研究所 一种钻井液材料及其制备和应用
WO2015052644A1 (fr) * 2013-10-08 2015-04-16 Clearwater International, Llc Fluides de forage aqueux haute performance réutilisables
US10669468B2 (en) 2013-10-08 2020-06-02 Weatherford Technology Holdings, Llc Reusable high performance water based drilling fluids
US11015106B2 (en) 2013-10-08 2021-05-25 Weatherford Technology Holdings, Llc Reusable high performance water based drilling fluids

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