WO2013068771A1 - Composition et procédé - Google Patents

Composition et procédé Download PDF

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Publication number
WO2013068771A1
WO2013068771A1 PCT/GB2012/052810 GB2012052810W WO2013068771A1 WO 2013068771 A1 WO2013068771 A1 WO 2013068771A1 GB 2012052810 W GB2012052810 W GB 2012052810W WO 2013068771 A1 WO2013068771 A1 WO 2013068771A1
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WO
WIPO (PCT)
Prior art keywords
water
polysaccharide
wellbore fluid
hydroxyalkyi
based wellbore
Prior art date
Application number
PCT/GB2012/052810
Other languages
English (en)
Inventor
Stephen Cliffe
Peter A Williams
Ian Ratcliffe
Musarrat MOHAMMED
Hugh Christopher GREENWELL
Richard Lloyd ANDERSON
James SUTER
Peter COVENEY
Karen PADMORE
Adrian J FEWINGS
James S MASKERY
Original Assignee
M-I Drilling Fluids Uk Limited
Glyndwr University
Durham University
University College London
Centre For Advanced Software Technology Limited
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 Drilling Fluids Uk Limited, Glyndwr University, Durham University, University College London, Centre For Advanced Software Technology Limited filed Critical M-I Drilling Fluids Uk Limited
Priority to GB1408236.6A priority Critical patent/GB2509877B/en
Publication of WO2013068771A1 publication Critical patent/WO2013068771A1/fr
Priority to NO20140723A priority patent/NO20140723A1/no

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    • 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
    • C09K8/03—Specific additives for general use in well-drilling compositions
    • C—CHEMISTRY; METALLURGY
    • C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
    • C08L—COMPOSITIONS OF MACROMOLECULAR COMPOUNDS
    • C08L1/00—Compositions of cellulose, modified cellulose or cellulose derivatives
    • C08L1/02—Cellulose; Modified cellulose
    • C—CHEMISTRY; METALLURGY
    • C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
    • C08L—COMPOSITIONS OF MACROMOLECULAR COMPOUNDS
    • C08L3/00—Compositions of starch, amylose or amylopectin or of their derivatives or degradation products
    • C08L3/02—Starch; Degradation products thereof, e.g. dextrin
    • C—CHEMISTRY; METALLURGY
    • C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
    • C08L—COMPOSITIONS OF MACROMOLECULAR COMPOUNDS
    • C08L5/00—Compositions of polysaccharides or of their derivatives not provided for in groups C08L1/00 or C08L3/00
    • 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
    • C09K8/08—Clay-free compositions containing natural organic compounds, e.g. polysaccharides, or derivatives thereof
    • 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
    • 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
    • C09K2208/12—Swell inhibition, i.e. using additives to drilling or well treatment fluids for inhibiting clay or shale swelling or disintegrating

Definitions

  • the present invention relates to a shale hydration inhibitor and method of use thereof, and particularly relates to a water-based wellbore fluid comprising water and a hydration inhibitor including a hydroxyalkyl polysaccharide, a method of drilling a subterranean hole with the water-based wellbore fluid and a method of forming the water-based wellbore fluid.
  • a drilling fluid or mud is commonly used when drilling a wellbore for the production of oil and/or gas from a hydrocarbon reservoir.
  • the drilling fluid is circulated through the wellbore to remove drill cuttings from the area around the drill bit, stabilise the wellbore walls prior to casing of the wellbore and reduce friction between components of the drill pipe or drill string and the wellbore walls.
  • the drilling fluid may be used to form a filter cake on the walls of the wellbore to reduce the flow of fluids from the surrounding rock formation into the wellbore before drilling is finished and production starts.
  • drilling fluid there are different types of drilling fluid, including water-based fluids, non- water-based such as oil-based fluids and gaseous (or pneumatic) fluids.
  • Formation solids including drill cuttings and material that falls into the wellbore from the surrounding rock formation, are dispersed in the drilling fluid during its use downhole. These formation solids are characterised by the rock formation through which the wellbore is drilled. It is common for the rock formation to include a layer of clay. Clay formation solids are dispersed in the drilling fluid like any other type of formation solid, but due to the inherent characteristics of clay, the clay formation solids may swell on contact with the drilling fluid. This is especially a problem if the drilling fluid is water-based.
  • the clay formation solids When the clay formation solids swell they increase in volume and thereby, amongst other things, reduce the ability of the drilling fluid to remove drill cuttings from the area around the drill bit and prevent formation of a filter cake, which should be thick enough to reduce the flow of fluids from the surrounding rock formation into the wellbore but thin enough not to impede the flow of fluids or movement of the drill string/drill pipe in the wellbore.
  • Clays swell when water molecules enter spaces between the unit layers of the clay macrostructure.
  • Various shale/clay swelling and/or hydration inhibitors are known and it is known to add these swelling and/or hydration inhibitors to drilling fluid or mud used when drilling a wellbore for the production of oil and/or gas from a hydrocarbon reservoir.
  • the particular problem when adding a swelling and/or hydration inhibitor to a drilling fluid is that the inhibitor must be compatible with other components, including additives, in the drilling fluid. Compatibility is important to maintain the required performance of the drilling fluid. For this reason previous water- based drilling fluids have been formulated including polyalkyleneglycol and potassium chloride or polyetheramine.
  • the polyalkyleneglycol can include polyethylene glycols (PEG) and polypropylene glycols (PPG).
  • the potassium chloride is used as an electrolyte and can instead be sodium chloride.
  • US 2010/0144561 in the name M-l L.L.C describes a water-based drilling fluid including an aqueous based continuous phase, a weighting agent, and a shale hydration inhibition agent, the shale hydration inhibition agent having the eneral formula:
  • R is independently selected from alkyl and hydroxyl alkyl groups comprising 1 to 15 carbon atoms, and X is an anion.
  • the agent is a bis- quaternary amine shale hydration inhibitor.
  • the shale hydration inhibitor is present in sufficient concentration to reduce the swelling of shale drilling cuttings upon contact with the drilling fluid.
  • US 2008/0277620 describes a depolymerised-carboxyalkyi polysaccharide formed by depolymerising a polysaccharide having between 0.5 and 3.0 degrees of substitution and reducing the molecular weight of said
  • polysaccharide before or after said depolymerising.
  • This provides a biodegradable scale inhibitor that can be used to prevent the deposition of scale comprising, for example, calcium, barium, sulphate and salts thereof.
  • the depolymerised-carboxyalkyi polysaccharide can be useful in offshore oil production squeeze treatments and in the treatment of scale formed in industrial water treatment.
  • a water- based wellbore fluid comprising water, a hydration inhibitor including a hydroxyalkyl polysaccharide with a weight average molar mass of less than 5,000 and at least one other component selected from the group comprising a rheology modifier, fluid loss control agent, inorganic or organic salt, dispersant and weighting agent.
  • the hydroxyalkyl polysaccharide has a weight average molar mass in the range of 4,999 to 800, typically in the range of 3,000 to 800 and preferably in the range of 1 ,500 to 800.
  • the polysaccharide is an oligosaccharide.
  • the polysaccharide is formed from the polymerisation of less than 22 monosaccharide monomers, preferably between 5 and 12 monosaccharide monomers.
  • the polysaccharide is an oligosaccharide, it may be formed from between 2 and 10 monosaccharide monomers. Those monomers which do not terminate the polysaccharide may or may not be identical. Typically the mononers which do not terminate the
  • polysaccharide are identical.
  • the two monomers which terminate the polysaccharide may be the same or different from each other and may be the same or different to those monomers which do not terminate the
  • the polysaccharide may be formed from one or more of the monomers:
  • polysaccharide may be a depolymerised derivative of one or more of the polymers: cellulose, chitin, chitosan, maltodextrin, starch, inulin, glycogen, amylopectin, pullulan, dextran, cyclodextrin and alkyl derivatives thereof.
  • These polymers may be depolymerised using alkali hydrolysis, enzyme degradation and/or oxidative degradation to produce polymers having sufficiently low molecular weight.
  • the polymer may be converted into a cation, as discussed in further detail below.
  • the hydroxyalkyi polysaccharide is a polysaccharide that has had hydroxyalkyi substituents added to at least some of the hydroxy groups of a polysaccharide through ester or ether bonding.
  • the polysaccharide comprises amino groups, or substituted amino groups
  • the hydroxyalkyi substituents may be added to at least some of the amino groups of a polysaccharide through, for example, nucleophilic substitution and subsequent treatment of the ammonium salt, typically with a base.
  • the water-based wellbore fluid may be selected from the group comprising a drilling fluid, a completion fluid, a packer fluid, a viscous plug fluid and a workover fluid.
  • the hydration inhibitor may also function as one or more of a rheology modifier, fluid loss control agent, dispersant and weighting agent.
  • the water-based wellbore fluid as described herein requires the presence of at least one other component.
  • the water-based wellbore fluid comprises at least two, sometimes at least three, optionally at least four and may be all five of the other components selected from the group comprising a rheology modifier, fluid loss control agent, inorganic or organic salt, dispersant and weighting agent.
  • the hydroxyalkyi polysaccharide may at least partially inhibit shale swelling and/or hydration.
  • the hydroxyalkyi polysaccharide can reduce clay mineral hydration and/or swelling by intercalating into the shales.
  • the hydroxyalkyi polysaccharide may further provide the wellbore fluid with anticorrosion and/or antimicrobial characteristics.
  • Corrosion inhibition may be achieved by migration of a hydroxyalkyi polysaccharide in cationic form to a metal/solution interface to form a mono-atomic film at one or more anodic sites. Adsorption of the hydroxyalkyi polysaccharide in cationic form on one or more cell walls may disrupt the cell metabolic processes to provide the antimicrobial effect.
  • the polysaccharide forming the hydroxyalkyi polysaccharide may be naturally occurring or semi-synthetic being based on a modified naturally occurring material.
  • inulin may be used as the naturally occurring polysaccharide.
  • the inventors of the present invention have appreciated that these polysaccharides are inherently biodegradable. In contrast,
  • polyetheramine-based shale hydration inhibitors are not inherently
  • the hydroxyalkyi polysaccharide of the present invention may make use of an amine or quaternary ammonium group attached to the polysaccharide, preferably as a substituent on the hydroxyalkyi moiety.
  • an amine or quaternary ammonium group attached to the polysaccharide, preferably as a substituent on the hydroxyalkyi moiety.
  • polysaccharides and oligosaccharides do not tend to exist as naturally occurring materials since the parent polymer structures are essentially used as skeletal or supporting tissue, or as an energy store in biological systems.
  • Amino acids might be considered for use as hydration inhibitors and occur widely in nature, although these materials are unsuitable as they can easily be denatured and are subsequently more difficult to separate and are less suitable for secondary synthesis reactions.
  • a bis-quaternary amine shale hydration inhibitor generally has less cationic groups available to bind to clay surfaces compared to the hydroxyalkyi polysaccharide of the present invention and consequently, the level of shale hydration inhibition provided is not as great. Also, problems with accretion and cuttings agglomeration can be linked to the early-time hydration of clay cuttings. Compounds that are more effective shale hydration inhibitors, such as those of the invention, would therefore help to improve performance of the wellbore fluid.
  • the hydroxyalkyi polysaccharide may be selected from the group comprising a hydroxyalkyi cellulose, a hydroxypropylalkyl polyglucosamine, and a hydroxypropylalkyl polyglucose.
  • a polysaccharide, oligosaccharide or saccharide can also be referred to as a carbohydrate.
  • the hydroxyalkyi moiety of the hydroxyalkyi polysaccharide may be a hydroxyethyl, a substituted hydroxyethyl, a hydroxypropyl, a substituted hydroxypropyl, a di hydroxypropyl and a substituted dihydroxypropyl.
  • the polysaccharide forming the hydroxyalkyi polysaccharide may be an acid digested (depolymerised) cellulose derivative such as
  • Glucosamine and N-acetyl-D-glucosamine may be obtained by chemical and/or enzyme extraction and depolymerisation of chitin and/or chitosan.
  • the hydroxyalkyi polysaccharide may have a branched or straight chain structure.
  • the hydroxyalkyi polysaccharide may be water insoluble, partially soluble or completely water soluble. Solubility of the hydroxyalkyi polysaccharide may increase with derivatisation.
  • the polysacchande may be depolymehsed. As used herein, the term
  • depolymerised means that the polysaccharide has undergone acid digestion.
  • the polysaccharide may be converted into cationic form or aminated.
  • a polysaccharide in cationic form has a permanent positive charge, whereas an aminated polysaccharide may develop a positive charge under acid conditions.
  • the hydroxyalkyi polysaccharide may include, and preferably comprises, a backbone having one or more of the repeat units shown below, wherein "n" is a number between 1 and 20.
  • R 1 , R 2 and R 3 can independently be selected from the group comprising: hydrogen; C1 to C6 alkyl; R 8 N + R 9 R 10 R 11 X " wherein R 8 may be absent or is a C1 to C6 alkylene group, R 9 to R 11 are independently selected from hydrogen or C1 to C6 alkyl groups and X " is an organic or inorganic anion having a single negative charge, such as a halide, sulphonate, carboxylate or alkylene carboxylate; and substituted or unsubstituted hydroxy C1 -C6 alkyl moiety. At least one of R 1 , R 2 and R 3 should be a substituted or unsubstituted hydroxy C1 -C6 alkyl moiety.
  • the substituted hydroxy C1 -C6 alkyl moiety may comprise a linking group substituent connecting the C1 -C6 alkyl portion to the hydroxyalkyl
  • polysaccharide backbone such as an alkylene ether, such as -CH 2 CH 2 O- or CH 2 CH(CH 3 )O-, or a polyalkylene oxide, such as polyethylene oxide or linear or branched polypropylene oxide.
  • the hydroxyalkyi moiety may be substituted with a R 8 N + R 9 R 10 R 11 X " substituent, as defined above.
  • the hydroxyalkyi moiety may be substituted by one or more of sulphonate, carboxylate and alkylene carboxylate in order to provide the hydroxyalkyi polysaccharide in anionic form.
  • R 1 , R 2 and R 3 groups can independently be selected from the group comprising hydrogen; CH 2 CH 3 ; CH 2 N + (CH 3 ) 3 Cr;
  • R 1 , R 2 and R 3 is independently selected from the group comprising:
  • R 4 can independently be selected from the group comprising a hydrogen atom and a methyl group
  • R 5 , R 6 , R 7 can independently be selected from the group comprising hydrogen and a C1 to C6 alkyl group
  • X " is a halide, such as chloride or bromide.
  • R 1 , R 2 and R 3 groups can comprise a C1 -C6 alkyl quaternary ammonium group, for instance as a substituent on the
  • the portion is an alkylene ether or a polyalkylene oxide linking group
  • hydroxyalkyi polysaccharide is formed from the monomer chitosan or glucosamine and R 3 is hydrogen, it may have a low molecular weight compared to hydroxyalkyi polysaccharide based on the other monomers listed above.
  • a hydroxyalkyi polysaccharide based on less than 20 monomers of glucosamine and preferably less than 10 monomers of glucosamine is a particularity effective hydration inhibitor.
  • the hydroxyalkyi moiety may be attached to the polysaccharide backbone in the repeat unit:
  • the quaternary ammonium derivative of the hydroxyalkyi polysaccharide including a nitrogen atom may be an effective shale hydration inhibitor over a wide range of salinity including freshwater and a saturated salt solution.
  • the nitrogen atom in the amine or quaternary ammonium group is important for the strong interaction and therefore binding of the hydroxyalkyi
  • polysaccharide to the clay If the nitrogen atom is part of a hydrazide group, it may also be important for the strong interaction and therefore binding of the hydroxyalkyi polysaccharide to the clay.
  • the hydroxyalkyi polysaccharide repeat unit (i.e. the backbone repeat unit) and R 1 , R 2 and R 3 groups may be selected such that there is on average between 0.1 and 3 quaternary ammonium groups per repeat unit, wherein at least one of the R 1 , R 2 and R 3 groups in at least one of the repeat units is a hydroxyalkyi moiety.
  • the substituted or unsubstituted C1 to C6 alkyl group is a methyl group, ethyl or propyl group.
  • the hydroxyalkyi polysaccharide may be obtainable by the reaction of one or more of ethylene oxide, propylene oxide, glycidol, and 3-chloro-1 ,2- propanediol with a polysaccharide to produce the hydroxyalkyi
  • a dihydroxypropyl polysaccharide may be produced by the reaction of glycidyltrimethylammonium chloride (GTAC):
  • the concentration of the hydroxyalkyl polysaccharide in the water-based wellbore fluid is optionally between 0.1 kg/m 3 and 200 kg/m 3 ; typically between 3 kg/m 3 and 50 kg/m 3 ; and normally between 15 kg/m 3 and 30 kg/m 3 .
  • the polysaccharide may be a salt and include, or have associated with it, metal ions.
  • the associated metal ions may be alkaline earth metals, which may include magnesium (Mg) and calcium (Ca), or alkali metals, which could include lithium (Li), sodium (Na), potassium (K), and caesium (Cs) ions, or transition metal or other metal ions, which may include iron (Fe) and aluminium (Al).
  • the substituent used is selected depending on the
  • a method of drilling a subterranean hole with a water-based wellbore fluid comprising at least the steps of:
  • a hydration inhibitor including a hydroxyalkyl polysaccharide with a weight average molar mass of less than 5,000 and at least one other component selected from the group comprising a rheology modifier, fluid loss control agent, inorganic or organic salt, dispersant and weighting agent; and
  • the wellbore fluid may be pumped down to the bottom of the wellbore through a drill pipe, where for example the fluid emerges through ports in the drilling bit.
  • the fluid may be used in conjunction with any drilling operation, which may include, for example, vertical drilling, extended reach drilling, and directional drilling. Specific formulations may depend on the state of drilling a wellbore at a particular time, for example, depending on the depth and/or the composition of the formation.
  • the method of drilling a subterranean hole preferably uses the hydroxyalkyl polysaccharide according to the first aspect of the present invention.
  • the water-based wellbore fluid with hydration inhibitor may be used in drilling, cementing, workover, fracturing and abandonment of subterranean wells through a formation containing a shale or a clay which swells in the presence of water.
  • a method of drilling a subterranean hole with a water-based wellbore fluid comprising at least the step of drilling a subterranean hole using the water-based wellbore fluid of the first aspect of the present invention.
  • the method of drilling a subterranean hole may further comprise the step of providing the water-based wellbore fluid of the first aspect of the present invention prior to drilling the subterranean hole.
  • the method of the third aspect may comprise one or more of the preferable features of the previous aspect.
  • a method of forming a water-based wellbore fluid comprising at least the steps of mixing water and a hydration inhibitor including a hydroxyalkyl
  • the method of forming a water-based wellbore fluid preferably uses the hydroxyalkyi polysaccharide according to the first aspect of the present invention.
  • the hydroxalkyl polysaccharide used in the method may be as described above with reference to the first aspect of the present invention. Accordingly, the water-based wellbore fluid formed may be in accordance with the first aspect of the present invention.
  • the molecular weight of the hydroxyalkyi polysaccharide may be reduced by reacting the polysaccharide with one or more of an oxidising agent, an enzyme reducing agent and an acid reducing agent, and/or by exposing the polysaccharide to ionising radiation and/or electronic beam radiation.
  • the molecular weight of the hydroxyalkyi polysaccharide may be reduced before the hydroxyalkyi polysaccharide is used in the wellbore.
  • the polysaccharide may be depolymerised.
  • a depolymerised quaternary ammonium hydroxypropylalkyi polysaccharide may be produced by reaction with glycidyltrimethylammonium chloride and one or more of methyl cellulose, methylhydroxyethylcellulose, ethylhydroxyethylcellulose, glucosamine, glucose syrup, matodextrin, inulin, konjac glucomannan, glucosamine, chitosan, and chitin.
  • the polysaccharide may be cationic form.
  • hydroxypropylalkyi polysaccharide in cationic form may be produced by reaction with one or more of carboxymethyl trimethylammonium hydrazide and glycidyltrialkylammonium halides including glycidyltrimethylammonium chloride, glycidyltriethylammonium chloride and glycidyltrimethylammonium bromide.
  • a depolymerised hydroxypropylalkyi polysaccharide may be produced by the additional reaction with a suitable alkyl halide to produce an alkyl ether derivative.
  • the hydroxypropylalkyi polysaccharide may be in cationic form.
  • the alkyl halide may be selected from the group comprising ethyl chloride, propyl chloride and butyl chloride.
  • the hydroxyalkyl polysaccharide may have a biodegradation in sea water (OECD 306) of between 20 and 100% elimination after 28 days.
  • OECD 306 biodegradation in sea water
  • the inventors of the present invention have appreciated that the degree of cationic derivatisation does not adversely increase aquatic toxicity.
  • the skeletonema algae toxicity of the hydroxyalkyl polysaccharide may be greater than
  • water- based wellbore fluid of the first aspect of the present invention as a drilling fluid, a completion fluid, a packer fluid, a viscous plug fluid or a workover fluid.
  • the linear swelling may be reduced with the quaternary ammonium
  • the water-based wellbore fluid is principally composed of an aqueous solution as the continuous phase.
  • the aqueous-based continuous phase is generally selected from the group comprising fresh water, seawater, natural brine solutions, brines formed by dissolving suitable salts in water, mixtures of water and water-soluble organic compounds, and combinations of these and similar compounds that should be known to one of skill in the art.
  • suitable inorganic salts include chloride and bromide salts of potassium, sodium, calcium, magnesium, zinc, and caesium.
  • Suitable organic salts include acetate and formate salts of potassium, sodium, calcium, magnesium, zinc, and caesium.
  • the amount of the aqueous-based continuous phase should be sufficient to form a water-based wellbore fluid, such as a drilling fluid. This amount may range from greater than 30 vol.% of the wellbore fluid to less than 100 vol.% of the wellbore fluid. Preferably, the amount of the aqueous-based
  • continuous phase is in the range from about 40 vol.% to about 90 vol.% of the wellbore fluid.
  • the hydroxyalkyl polysaccharides described herein can intercalate into the interlamellar spacing in clay dispersed in the wellbore fluid. This is not the same as surface intercalation or cation exchange in the clay.
  • Table 1 show the percentage recovery and percentage water content of native Oxford clay after treatment with various shale hydration inhibitors.
  • High percentage recovery and low percentage water content indicate good shale hydration inhibition, for example TMA-HP-maltodextrin (twice reacted), 85.3% (Ref. IR/060910A); TMA-HP-HP-maltodextrin (HP groups added first), 82.4% (Ref. IR/1 10810); TMA-HP-Glucosamine, higher DS, 86.8% (Ref. IR/100510); and TMA-HP-EHEC (acid digest), 44.9% (Ref. IR/150310).
  • This example describes the preparation of N,N,N-trimethyl-3-amino, 2- hydroxypropyl glucosamine in alkali conditions.
  • a reaction vessel was charged with deionised water, 1000g and glucosamine hydrochloride, 98wt%, Alfa Aesar A15532, 200g added with mixing. Sodium hydroxide solution, 50wt%, approx 70g was then added to bring the pH to 1 1 .0. A nitrogen purge was applied to the vessel and maintained. The vessel was heated to 60°C and mixing commenced. A pressure equalised dropping funnel was charged with glycidyl trimethylammonium chloride (GTAC), 90wt%, Aldrich 50053, 120.77g. After 15 minutes GTAC addition was commenced in a dropwise fashion, over approximately 20 minutes. Second and third additions of the same quantity of GTAC were added in the same manner two and four hours after commencement of the first addition. Two hours after commencement of the final addition, the vessel heating was turned off and the batch cooled with mixing to ambient temperature.
  • GTAC glycidyl trimethylammonium chloride
  • This example describes the preparation of N,N,N-trimethyl-3-amino, 2- hydroxypropyl glucosamine in pH neutral conditions.
  • a reaction vessel was charged with deionised water, 1000g and glucosamine hydrochloride, 98wt%, Alfa Aesar A15532, 200g added with mixing. Sodium hydroxide solution, 50wt%, 10g was then added. A nitrogen purge was applied to the vessel and maintained. The vessel was heated to 60°C and mixing commenced. A pressure equalised dropping funnel was charged with glycidyl trimethylammonium chloride (GTAC), 90wt%, Aldrich 50053, 120.77g. After 15 minutes GTAC addition was commenced in a dropwise fashion, over approximately 20 minutes. Second and third additions of the same quantity of GTAC were added in the same manner two and four hours after
  • This example describes the preparation of N,N,N,-trimethyl-3-amino, 2- hydroxypropyl ethyl hydroxyethyl cellulose.
  • This and other examples use an already partially derivatised polysaccharide and further derivatise the polysaccharide using hydroxyalkyl.
  • a reaction vessel was carefully charged with deionised water, 500g and hydrochloric acid, 32wt%, 500g and the vessel heated to 90°C.
  • Ethyl hydroxyethylcellulose, EHEC, Akzo Nobel Bermocoll E 230X, 200g was added to the vortex whilst mixing and mixing continued at this temperature for one hour. Cooling was applied to the vessel and slow addition of sodium hydroxide (pellet) 203.2g was made, such that 'boiling over' was avoided.
  • sodium hydroxide pellet
  • the digest was cooled to ambient temperature and, if necessary, corrected to pH 7.0 by appropriate addition of hydrochloric acid, 32wt%, or sodium hydroxide solution, 50wt%. Water, deionised was added to the 1 L mark on the reactor.
  • GTAC glycidyl trimethylammonium chloride
  • This example describes the preparation of N,N,N,-trimethyl-3-amino, 2- hydroxypropyl methyl cellulose.
  • a reaction vessel was charged with deionised water, 160g and isopropanol, IPA, 1580 ml.
  • Methylcellulose, MC, Ashland Culminal MC 3000P, 200g was added to the vortex whilst mixing.
  • a nitrogen purge was applied to the vessel and maintained.
  • the vessel was heated to 60°C and after 15 minutes, sodium hydroxide solution, 50wt%, 9.24g was added.
  • a pressure equalised dropping funnel was charged with glycidyl trimethylammonium chloride
  • GTAC tridecane
  • Aldrich 50053 73.56g
  • GTAC addition was commenced in a dropwise fashion, over approximately 30 minutes.
  • Second and third additions of the same quantity of GTAC were added in the same manner two and four hours after commencement of the first addition. Two hours after
  • This example describes the preparation of N,N,N,-trimethyl-3-amino,2- hydroxypropyl methylethyl hydroxyethylcellulose.
  • a reaction vessel was charged with deionised water, 160g and isopropanol, IPA, 1580 ml. Methylethyl hydroxyethylcellulose , MEHEC, Akzo Nobel Bermocoll M10, 200g was added to the vortex whilst mixing. A nitrogen purge was applied to the vessel and maintained. The vessel was heated to 60°C and after 15 minutes, sodium hydroxide solution, 50wt%, 9.24g was added. A pressure equalised dropping funnel was charged with glycidyl trimethylammonium chloride (GTAC), 90wt%, Aldrich 50053, 73.56g. GTAC addition was commenced in a dropwise fashion, over approximately 30 minutes. Second and third additions of the same quantity of GTAC were added in the same manner two and four hours after commencement of the first addition. Two hours after commencement of the final addition, the vessel heating was turned off and the batch cooled with mixing to ambient
  • This example describes the preparation of N,N,N,-trimethyl-3-amino, 2- hydroxypropyl ethyl hydroxyethyl cellulose.
  • a reaction vessel was carefully charged with deionised water, 500g and hydrochloric acid, 32wt%, 500g and the vessel heated to 90°C.
  • hydrophobically modified Ethyl hydroxyethylcellulose, HM-EHEC, Akzo Nobel Bermocoll EHM200, 200g was added to the vortex whilst mixing and mixing continued at this temperature for one hour. Cooling was applied to the vessel and slow addition of sodium hydroxide (pellet) 203.2g was made, such that 'boiling over' was avoided. Following completion of sodium hydroxide addition the digest was cooled to ambient temperature and, if necessary, corrected to pH 7.0 by appropriate addition of hydrochloric acid, 32wt%, or sodium hydroxide solution, 50wt%. Water, deionised was added to the 1 L mark on the reactor. Sodium hydroxide solution, 50wt%, 10g was then added. A nitrogen purge was applied to the vessel and maintained. The vessel was heated to 60°C and mixing commenced. A pressure equalised dropping funnel was charged with glycidyl trimethylammonium chloride
  • GTAC Trimethoxycarbonate
  • Second and third additions of the same quantity of GTAC were added in the same manner two and four hours after commencement of the first addition. Two hours after commencement of the final addition, the vessel heating was turned off and the batch cooled with mixing to ambient temperature.
  • Hydrochloric acid 32wt% was added to the batch with mixing until neutral (pH 7.0).
  • the product was reduced by rotary evaporation to a syrup and purified by solvent washing. In this instance 1 volume of syrup was mixed with 2 volumes of acetone.
  • the product and solvent layers separated and the upper acetone layer was removed by decanting. This process was twice repeated and traces of acetone removed from the syrup by rotary evaporation.
  • the syrup was allowed to stand to facilitate precipitation of salt.
  • the product was separated from excess salt by decanting off the upper product layer and setting aside. Further product was recovered from the salt precipitate by filtration under reduced pressure on a sinter, assisted by the use of a limited quantity of deionised water.
  • This example describes the preparation of N,N,N-trimethyl-3-amino, 2- hydroxypropyl maltodextrin.
  • a reaction vessel was charged with deionised water, 200g and maltodextrin, Cargill C * Dry MD 01905, 200g added with mixing. A nitrogen purge was applied to the vessel and maintained. The vessel was heated to 45°C with mixing. After 30 minutes sodium hydroxide solution, 10wt%, 35.5g was added. A pressure equalised dropping funnel was charged with glycidyl trimethylammonium chloride (GTAC), 90wt%, Aldrich 50053, 120.77g. GTAC addition was commenced in a dropwise fashion, over 30-90 minutes. Second and third additions of the same quantity of GTAC were added in the same manner two and four hours after commencement of the first addition.
  • GTAC glycidyl trimethylammonium chloride
  • This example describes the preparation of N,N,N,-trimethyl-3-amino, 2- hydroxypropyl ethyl cellulose.
  • a reaction vessel was charged with deionised water, 160g and isopropanol, IPA, 1580 ml.
  • Ethylcellulose, EC, Ashland Aqualon EC-N10, 200g was added to the vortex whilst mixing.
  • a nitrogen purge was applied to the vessel and maintained.
  • the vessel was heated to 60°C and after 15 minutes sodium hydroxide solution, 50wt%, 9.24g was added.
  • a pressure equalised dropping funnel was charged with glycidyl trimethylammonium chloride (GTAC), 90wt%, Aldrich 50053, 73.56g.
  • GTAC glycidyl trimethylammonium chloride
  • GTAC addition was commenced in a dropwise fashion, over approximately 20-25 minutes.
  • Second and third additions of the same quantity of GTAC were added in the same manner two and four hours after commencement of the first addition.
  • Two hours after commencement of the final addition the vessel heating was turned off and the batch cooled with mixing for 45 minutes.
  • Acetic acid, glacial was added to the batch with mixing until neutral (pH 7.0).
  • the crude product was purified by precipitation by the addition of excess water.
  • the solid was recovered on a glass sinter under reduced pressure and washed with copious amounts of water prior to air drying.
  • the resultant product was thus N,N,N,-trimethyl-3- amino, 2-hydroxypropyl ethyl cellulose.
  • This example describes the preparation of N,N,N-trimethyl-3-amino, 2- hydroxypropyl sucrose.
  • a reaction vessel was charged with deionised water, 200g and sucrose 200g added with mixing. A nitrogen purge was applied to the vessel and
  • the vessel was heated to 45°C with mixing and after 15 minutes, sodium hydroxide solution, 50wt%, 7.1g was added.
  • a pressure equalised dropping funnel was charged with glycidyl trimethylammonium chloride (GTAC), 90wt%, Aldrich 50053, 120.77g.
  • GTAC addition was commenced in a dropwise fashion, typically over 30 minutes.
  • Second and third additions of the same quantity of GTAC were added in the same manner two and four hours after commencement of the first addition. Eighteen hours after commencement of the final addition, the vessel heating was turned off and the batch cooled to ambient temperature.
  • Acetic acid, glacial was added to the batch with mixing until neutral (pH 7.0).
  • the product was reduced by rotary evaporation to a syrup and purified by solvent washing. In this instance 1 volume of syrup was mixed with 1 volume of isopropanol, IPA. On standing, the product and solvent layers separated and the upper IPA layer was removed by decanting. This process was twice repeated and traces of IPA removed from the syrup by rotary evaporation. The resultant product was thus a concentrated solution of N,N,N-trimethyl-3-amino, 2-hydroxypropyl sucrose.
  • This example describes the preparation of 3-amino, 2-hydroxypropyl ethyl hydroxyethyl cellulose.
  • a reaction vessel was carefully charged with deionised water, 1375g and hydrochloric acid, 32wt%, 625g and the vessel heated to 90°C.
  • Ethyl hydroxyethylcellulose, EHEC, Akzo Nobel Bermocoll E 230X, 200g was added to the vortex whilst mixing and mixing continued at this temperature for one hour. Cooling was applied to the vessel and slow addition of sodium hydroxide (pellet) 203.2g was made, such that 'boiling over' was avoided.
  • the digest was cooled to ambient temperature and, if necessary, corrected to pH 7.0 by appropriate addition of hydrochloric acid, 32wt%, or sodium hydroxide solution, 50wt%.
  • the product was reduced by rotary evaporation to a paste and transferred to a reaction vessel.
  • a nitrogen purge was applied to the vessel and the contents heated to 85°C.
  • Glacial acetic acid, 100ml_ was added and subsequently epichlorohydrin, 400ml_. After mixing for four hours at 85°C the batch was cooled by mixing at ambient temperature for 30 minutes. After standing overnight, the batch was diluted by addition of deionised water, 750ml_ and heated to 70°C.
  • Ammonium hydroxide, 35wt%, 1429ml_ was added and the batch was mixed for 8 hours. The batch was then allowed to cool without mixing. The product was reduced by rotary evaporation to a syrup and purified by solvent washing. In this instance 1 volume of syrup was mixed with 1 volumes of acetone. On standing, the product and solvent layers separated and the upper acetone layer was removed by decanting. This process was twice repeated and traces of acetone removed from the syrup by rotary evaporation. The resultant product was thus a concentrated solution of a 3-amino, 2-hydroxypropyl ethyl hydroxyethyl cellulose digest.

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  • Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Medicinal Chemistry (AREA)
  • Polymers & Plastics (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Health & Medical Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Dispersion Chemistry (AREA)
  • Curing Cements, Concrete, And Artificial Stone (AREA)
  • Polysaccharides And Polysaccharide Derivatives (AREA)

Abstract

La présente invention concerne un fluide de puits de forage à base d'eau comprenant de l'eau, un inhibiteur d'hydratation comprenant un hydroxyalkyl polysaccharide ayant une masse molaire moyenne en poids inférieure à 5 000 et au moins un autre constituant choisi dans le groupe comprenant un agent modifiant la rhéologie, un agent de contrôle de la perte de fluide, un sel inorganique ou organique, un dispersant et un agent de charge. L'invention concerne en outre un procédé de forage d'un trou souterrain et un procédé de formation d'un fluide de puits de forage à base d'eau.
PCT/GB2012/052810 2011-11-10 2012-11-12 Composition et procédé WO2013068771A1 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
GB1408236.6A GB2509877B (en) 2011-11-10 2012-11-12 Wellbore fluid with hydroxyalkyl polysaccharide hydration inhibitor
NO20140723A NO20140723A1 (no) 2011-11-10 2014-06-05 Sammensetning og fremgangsmåte

Applications Claiming Priority (2)

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GBGB1119367.9A GB201119367D0 (en) 2011-11-10 2011-11-10 Composition and method
GB1119367.9 2011-11-10

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US20130153223A1 (en) * 2011-12-15 2013-06-20 Halliburton Energy Services, Inc. Wellbore Servicing Compositions and Methods of Making and Using Same
US20160186045A1 (en) * 2014-12-31 2016-06-30 Halliburton Energy Services, Inc., Composition including functionalized polysaccharide for treatment of subterranean formations
WO2016160097A1 (fr) * 2015-04-03 2016-10-06 Hppe Llc Compositions et procédés de stabilisation de sols contenant de l'argile
US9714403B2 (en) 2014-06-19 2017-07-25 E I Du Pont De Nemours And Company Compositions containing one or more poly alpha-1,3-glucan ether compounds
US9771548B2 (en) 2014-06-19 2017-09-26 E I Du Pont De Nemours And Company Compositions containing one or more poly alpha-1,3-glucan ether compounds
CN107338505A (zh) * 2016-12-13 2017-11-10 吴国宪 一种用于低频电磁理疗垫的抗菌纤维及其制备方法
US9957334B2 (en) 2013-12-18 2018-05-01 E I Du Pont De Nemours And Company Cationic poly alpha-1,3-glucan ethers
US10005850B2 (en) 2013-12-16 2018-06-26 E I Du Pont De Nemours And Company Use of poly alpha-1,3-glucan ethers as viscosity modifiers
US10030187B2 (en) 2014-08-05 2018-07-24 Halliburton Energy Services, Inc. Polymer-based drilling fluids containing non-biodegradable particulates and methods for use thereof
US10233374B2 (en) 2014-08-05 2019-03-19 Halliburton Energy Services, Inc. Polymer-based drilling fluids containing non-biodegradable materials and methods for use thereof
WO2019111946A1 (fr) * 2017-12-06 2019-06-13 花王株式会社 Dérivé de polysaccharide
WO2020014451A1 (fr) * 2018-07-13 2020-01-16 Integrity Bio-Chemicals, Llc Compositions comprenant des composés de dextrine aminés et procédés de traitement souterrain les utilisant
WO2020014442A1 (fr) * 2018-07-13 2020-01-16 Integrity Bio-Chemicals, Llc Composés de dextrine aminés et procédés de traitement souterrain les utilisant
US11359166B2 (en) 2017-12-06 2022-06-14 Kao Corporation Fabric treatment composition
US11655435B2 (en) 2017-12-06 2023-05-23 Kao Corporation Hydroxy alkyl cellulose soil release agent with a cationic group and a C4—C12 hydrophobic group
US11655434B2 (en) 2017-12-06 2023-05-23 Kao Corporation Composition

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Cited By (32)

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Publication number Priority date Publication date Assignee Title
US20130153223A1 (en) * 2011-12-15 2013-06-20 Halliburton Energy Services, Inc. Wellbore Servicing Compositions and Methods of Making and Using Same
US9163173B2 (en) * 2011-12-15 2015-10-20 Halliburton Energy Services, Inc. Wellbore servicing compositions and methods of making and using same
US9428682B2 (en) 2011-12-15 2016-08-30 Halliburton Energy Services, Inc. Wellbore servicing compositions and methods of making and using same
US10865254B2 (en) 2013-12-16 2020-12-15 Dupont Industrial Biosciences Usa, Llc Use of poly alpha-1,3-glucan ethers as viscosity modifiers
US10005850B2 (en) 2013-12-16 2018-06-26 E I Du Pont De Nemours And Company Use of poly alpha-1,3-glucan ethers as viscosity modifiers
US10800860B2 (en) 2013-12-18 2020-10-13 Dupont Industrial Biosciences Usa, Llc Cationic poly alpha-1,3-glucan ethers
US10323102B2 (en) 2013-12-18 2019-06-18 E I Du Pont De Nemours And Company Cationic poly alpha-1,3-glucan ethers
US9957334B2 (en) 2013-12-18 2018-05-01 E I Du Pont De Nemours And Company Cationic poly alpha-1,3-glucan ethers
US11015150B2 (en) 2014-06-19 2021-05-25 Nutrition & Biosciences USA 4, Inc. Compositions containing one or more poly alpha-1,3-glucan ether compounds
US9714403B2 (en) 2014-06-19 2017-07-25 E I Du Pont De Nemours And Company Compositions containing one or more poly alpha-1,3-glucan ether compounds
US9771548B2 (en) 2014-06-19 2017-09-26 E I Du Pont De Nemours And Company Compositions containing one or more poly alpha-1,3-glucan ether compounds
US10190079B2 (en) 2014-06-19 2019-01-29 E I Du Pont De Nemours And Company Compositions containing one or more poly alpha-1,3-glucan ether compounds
US10221378B2 (en) 2014-06-19 2019-03-05 E I Du Pont De Nemours And Company Compositions containing one or more poly alpha-1,3-glucan ether compounds
US10233374B2 (en) 2014-08-05 2019-03-19 Halliburton Energy Services, Inc. Polymer-based drilling fluids containing non-biodegradable materials and methods for use thereof
US10030187B2 (en) 2014-08-05 2018-07-24 Halliburton Energy Services, Inc. Polymer-based drilling fluids containing non-biodegradable particulates and methods for use thereof
US20160186045A1 (en) * 2014-12-31 2016-06-30 Halliburton Energy Services, Inc., Composition including functionalized polysaccharide for treatment of subterranean formations
US9777565B2 (en) * 2014-12-31 2017-10-03 Halliburton Energy Services, Inc. Composition including functionalized polysaccharide for treatment of subterranean formations
US10072208B2 (en) * 2015-04-03 2018-09-11 Hppe Llc Compositions and methods for the stabilization of clay containing soils
CN107709511A (zh) * 2015-04-03 2018-02-16 高性能聚乙烯有限责任公司 稳定含粘土土壤的组合物和方法
US10351770B2 (en) 2015-04-03 2019-07-16 Integrity Bio-Chemicals, Llc Compositions and methods for the stabilization of clay containing soils
WO2016160097A1 (fr) * 2015-04-03 2016-10-06 Hppe Llc Compositions et procédés de stabilisation de sols contenant de l'argile
CN107338505A (zh) * 2016-12-13 2017-11-10 吴国宪 一种用于低频电磁理疗垫的抗菌纤维及其制备方法
CN111448220A (zh) * 2017-12-06 2020-07-24 花王株式会社 多糖衍生物
WO2019111946A1 (fr) * 2017-12-06 2019-06-13 花王株式会社 Dérivé de polysaccharide
US11359166B2 (en) 2017-12-06 2022-06-14 Kao Corporation Fabric treatment composition
US11401350B2 (en) 2017-12-06 2022-08-02 Kao Corporation Polysaccharide derivative
US11655435B2 (en) 2017-12-06 2023-05-23 Kao Corporation Hydroxy alkyl cellulose soil release agent with a cationic group and a C4—C12 hydrophobic group
US11655434B2 (en) 2017-12-06 2023-05-23 Kao Corporation Composition
WO2020014442A1 (fr) * 2018-07-13 2020-01-16 Integrity Bio-Chemicals, Llc Composés de dextrine aminés et procédés de traitement souterrain les utilisant
WO2020014451A1 (fr) * 2018-07-13 2020-01-16 Integrity Bio-Chemicals, Llc Compositions comprenant des composés de dextrine aminés et procédés de traitement souterrain les utilisant
US11028314B2 (en) 2018-07-13 2021-06-08 Integrity Bio-Chemicals, Llc Compositions comprising aminated dextrin compounds and subterranean treatment methods using the same
US11130905B2 (en) 2018-07-13 2021-09-28 Integrity Bio-Chemicals, Llc Aminated dextrin compounds and subterranean treatment methods using the same

Also Published As

Publication number Publication date
GB2509877B (en) 2018-04-04
GB2509877A8 (en) 2016-12-28
GB2509877A (en) 2014-07-16
GB201408236D0 (en) 2014-06-25
NO20140723A1 (no) 2014-06-05
GB201119367D0 (en) 2011-12-21

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