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Небесная энциклопедия

Космические корабли и станции, автоматические КА и методы их проектирования, бортовые комплексы управления, системы и средства жизнеобеспечения, особенности технологии производства ракетно-космических систем

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Мониторинг СМИ

Мониторинг СМИ и социальных сетей. Сканирование интернета, новостных сайтов, специализированных контентных площадок на базе мессенджеров. Гибкие настройки фильтров и первоначальных источников.

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Поддерживает ввод нескольких поисковых фраз (по одной на строку). При поиске обеспечивает поддержку морфологии русского и английского языка
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Применить Всего найдено 3713. Отображено 100.
19-07-2012 дата публикации

Nanohybrid phase interfaces for foaming in oil field applications

Номер: US20120181033A1
Автор: Lewis R. Norman, Rajesh K. Saini
Принадлежит: Halliburton Energy Services Inc

Methods of using nanohybrid-containing fluids in a well are provided. The methods include the steps of: (a) forming or providing a well fluid comprising a nanohybrid; and (b) introducing the well fluid into a well. The methods can be used in various applications, such as in drilling, completion, or intervention operations.

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Номер записи: 1
28-02-2013 дата публикации

Alternative ligand formulations for cellulose products

Номер: US20130053283A1
Автор: Antonius Franciscus Maas
Принадлежит: CP KELCO OY

This disclosure provides compositions suitable as drilling fluids, completion fluids, work-over fluids, or stimulation/fracking fluids, which exhibit shale inhibiting, thermostabilizing, viscosifying, and fluid loss reducing effects when used for these purposes. In some embodiments, this disclosure provides compositions that include a cellulose product comprising the contact product of: at least one cellulosic ether; at least one salt of a polyvalent metal ion; and at least one ligand or a salt of the ligand. The resulting cellulose products are useful in drilling of oil, gas, and other wells.

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Номер записи: 2
18-04-2013 дата публикации

NANOEMULSIONS

Номер: US20130096036A1
Автор: Clark David E., McKellar Alexander John, Quintero Lirio
Принадлежит: BAKER HUGHES INCORPORATED

Nanoemulsions have been discovered to be useful to the oil field. More particularly water-in-oil (W/O), oil-in-water (O/W) and other classes of nanoemulsions have found beneficial application in drilling, completion, well remediation and other oil and gas industry related operations. Additionally, nanoemulsions may reduce friction pressure losses, as well as reduce subsidence of solid weight material during oil and gas operations. New preparation methods for nanoemulsions have also been discovered. 1. A thermodynamically unstable nanoemulsion composition comprising:(1) a non-polar based continuous phase,(2) a polar based discontinuous phase with a mean droplet size of less than 1000 nm,(3) a surfactant, and(4) a solid weighting agent.2. The thermodynamically unstable nanoemulsion composition of claim 1 , wherein the mean droplet size of the discontinuous phase is between 400 nm and 700 nm claim 1 , and the non-polar based phase is an oil phase and the polar based phase is an aqueous phase.3. The thermodynamically unstable nanoemulsion composition of claim 2 , wherein the solid weighting agent is selected from the group consisting of barium sulfate claim 2 , calcium carbonate claim 2 , hematite claim 2 , ilmenite claim 2 , siderite claim 2 , manganese tetraoxide and combinations thereof.4. The thermodynamically unstable nanoemulsion composition of claim 2 , wherein the aqueous phase comprises water and a dissolved salt claim 2 , the dissolved salt being different from the material chosen for the surfactant (3) and for the solid weighting agent (4).5. The thermodynamically unstable nanoemulsion composition of claim 4 , wherein the dissolved salt in the aqueous phase is selected from the group consisting of:a chloride of sodium, potassium, calcium, silver, cobalt, nickel, copper, zinc or iron;a bromide of sodium, potassium, calcium, silver, cobalt, nickel, copper, zinc or iron; a sulfate of sodium, potassium, calcium, silver, cobalt, nickel, copper, zinc or iron;a ...

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Номер записи: 3
16-05-2013 дата публикации

Use of polylysine as a shale inhibitor

Номер: US20130123148A1
Автор: Bernd Bruchmann, Marta Reinoso Garcia, Oscar Lafuente Cerda, Sophie Maitro-Vogel
Принадлежит: BASF SE

What is proposed is the use of hyperbranched polylysine in the development, exploitation and completion of underground mineral oil and natural gas deposits, and in deep wells, especially as a shale inhibitor in water-based drilling muds, completion fluids or stimulation fluids.

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Номер записи: 4
08-08-2013 дата публикации

Water-Based Mud Lubricant Using Fatty Acid Polyamine Salts and Fatty Acid Esters

Номер: US20130203636A1
Автор: Remy Azrai Mohd Amin, Tao Xiang
Принадлежит: Baker Hughes Inc

Water-based drilling mud lubricants using a blend of fatty acid polyamine salts and fatty acid esters give synergistically better lubricity results than either component used separately. For example, the blends with different ratios of fatty acid diethylenetriamine salt and fatty acid methyl ester demonstrate much better lubricity in water-based drilling fluids than those where only fatty acid diethylene-triamine salt or fatty acid methyl ester are separately used. The amines in fatty acid amine salt might also include other polyamines, such as butanediamine pentamethylenediamine, spermidine, spermine, propylene diamine and propylene polyamines. The fatty acid esters might also include fatty acid ethyl ester, fatty acid glycerol ester and fatty acid trimethylolpropane ester. The carbon numbers of the fatty acids used to make the components in the lubricant blend may range from C4 to C28.

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Номер записи: 5
29-08-2013 дата публикации

Drilling fluid and method for drilling in coal-containing formations

Номер: US20130225457A1
Автор: Carl Keith Smith, Stefan Alexandru Stoian
Принадлежит: Tech Star Fluid Systems Inc

A drilling fluid and method for drilling in a coal containing formation. The method includes: providing a mixed metal-viscosified drilling fluid including at least 1% potassium salt; circulating the drilling fluid through the well; and drilling into a coal seam.

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Номер записи: 6
12-09-2013 дата публикации

Consolidation

Номер: US20130233623A1
Автор: Dana Aytkhozhina, Mark Shelton Aston
Принадлежит: BP Exploration Operating Co Ltd

A method of strengthening subterranean formation by drilling and completing a wellbore penetrating at least one unconsolidated or weakly consolidated formation, the method comprising: (a) drilling at least one interval of the wellbore that penetrates the unconsolidated or weakly consolidated formation using a drilling mud comprising a base fluid comprising an aqueous phase containing up to 25% weight by volume (% w/v) of a water soluble silicate, wherein the drilling mud has an acid-soluble particulate bridging solid suspended therein that is formed from a salt of a multivalent cation, wherein the salt of the multivalent cation is capable of providing dissolved multivalent cations when in the presence of an acid; (b) subsequently introducing a breaker fluid containing an acid and/or an acid precursor into the wellbore; (c) allowing the breaker fluid to soak in the interval that penetrates the unconsolidated or weakly consolidated formation for a predetermined period and strengthening formation by reacting with silicate now present in formation; and (d) removing the breaker fluid.

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Номер записи: 7
14-11-2013 дата публикации

Methods and Materials to Enhance High Temperature Rheology in Invert Emulsions

Номер: US20130303411A1
Автор: Kulkarni Sandeep D., MAGHRABI Shadaab Syed, Savari Sharath, Wagle Vikrant Bhavanishankar
Принадлежит:

An invert emulsion drilling fluid, and a method of drilling with such fluid, having improved rheology at low mud weights and high temperatures. The improved rheology is effected with addition of a rheology additive of the invention comprising fatty dimer diamines or dimer diamines and an organic acid or ester of the acid. A nonlimiting example of such a rheology additive comprises a C36 fatty dimer diamine and adipic acid or dimethyl adipate. 1. A method for drilling in a subterranean formation comprising providing or using in the drilling an invert emulsion drilling fluid having ana. oleaginous continuous phase,b. a non-oleaginous discontinuous phase, and a i. hydrophobic amine and', 'ii. an organic acid or corresponding ester of the organic acid or combinations thereof., 'c. rheology additive comprising a'}2. The method of wherein the drilling fluid with the additive claim 1 , when compared to the drilling fluid without the additive claim 1 , restricts the increase in plastic viscosity to 50% or less and has a characteristic selected from the group consisting of: an increased yield point; an increased low shear yield point; an increased gel strength; and any combination thereof.4. The invert emulsion drilling fluid of wherein the organic acid has at least one COOH group.5. The method of wherein the organic acid is selected from the group consisting of: lactic acid claim 1 , formic acid claim 1 , acrylic acid claim 1 , acetic acid claim 1 , chloroacetic acid claim 1 , dichloroacetic acid claim 1 , trichloroacetic acid claim 1 , trifluoroacetic acid claim 1 , propanoic acid claim 1 , butyric acid claim 1 , pentanoic acid claim 1 , hexanoic acid claim 1 , heptanoic acid claim 1 , oxalic acid claim 1 , malonic acid claim 1 , succinic acid claim 1 , glutaric acid claim 1 , adipic acid claim 1 , pimelic acid claim 1 , suberic acid claim 1 , azelaic acid claim 1 , sebacic acid claim 1 , maleic acid claim 1 , fumaric acid claim 1 , aspartic acid claim 1 , citric acid ...

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Номер записи: 8
05-12-2013 дата публикации

Salt-tolerant, thermally-stable rheology modifiers

Номер: US20130324443A1
Автор: David Farrar, Janice Jianzhao Wang, Jun Zheng, Osama M. Musa
Принадлежит: ISP Investments LLC

A salt-tolerant, thermally-stable rheology modifier and, in particular, a rheology modifier for applications in oil-field well-bore fluids. In accordance with one aspect, the rheology modifier comprises a terpolymer of acrylamide, 2-acrylamido-2-methyl-propanesulfonic acid (AMPS) and a long-chain alkyl acrylate wherein the terpolymer is prepared by dispersion polymerization.

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Номер записи: 9
30-01-2014 дата публикации

Lignin production from lignocellulosic biomass

Номер: US20140030524A1
Автор: George Steven Dowe, Kiran Kadam, Michel A. Simard
Принадлежит: Renmatix Inc

Methods are disclosed for preparing lignin from lignocellulosic biomass using rapid full or partial pressure reduction to separate and pulverize the lignin without fouling the equipment and with improved energy recovery.

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Номер записи: 10
13-03-2014 дата публикации

Emulsions to enhance microbial activity in a reservoir

Номер: US20140069635A1
Автор: Johnny Mark Cordiner
Принадлежит: PROFERO ENERGY Inc

The present application relates to methods of repressurizing petroleum reservoirs by increasing the rate of methane production.

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Номер записи: 11
03-04-2014 дата публикации

INVERT WELLBORE FLUID

Номер: US20140090897A1
Автор: Chapman John, Lee Lijein, Young Steven
Принадлежит: M-I L.L.C.

There is described an invert emulsion wellbore fluid that includes: an oleaginous external phase; a non-oleaginous internal phase; an emulsifier; and a rheological additive comprising a sulphonated polymer formed from 100 to 10,000 monomers. There is also described a method of drilling a subterranean hole using the invert emulsion drilling fluid. 1. A wellbore fluid that comprising:an oleaginous external phase;a non-oleaginous internal phase;an emulsifier; anda rheological additive comprising a sulphonated polymer formed from 100 to 10,000 monomers.2. The fluid of claim 1 , wherein the sulphonated polymer is a chlorosulphonated polymer.3. The fluid of claim 1 , wherein the sulphonated polymer is an α-olefin copolymer.4. The fluid of claim 1 , wherein the sulphonated polymer is comprised of repeat units which are derived from ethylene and an α-olefin that contains from 3 to 20 carbon atoms.5. The fluid of claim 1 , wherein the sulphonated polymer is a chlorosulphonated α-olefin copolymer which is comprised of repeat units which are derived from ethylene and an α-olefin that contains from 3 to 20 carbon atoms.6. The fluid of claim 1 , wherein the non-oleaginous internal phase comprises a plurality of droplets claim 1 , said droplets having an average diameter in the range of from 0.5 to 5 micrometers.7. The fluid of claim 6 , wherein the average diameter of the droplets is in the range of from 1 to 3 micrometers.8. The fluid of claim 1 , wherein the ratio of the oleaginous external phase to the non-oleaginous internal phase is greater than 50:50.9. The fluid of claim 8 , wherein the ratio of the oleaginous external phase to the non-oleaginous internal phase ranges from 50:50 to 95:5.10. The fluid of claim 1 , wherein the non-oleaginous internal phase comprises brine with a specific gravity greater than 1.4.11. The fluid of claim 1 , wherein the emulsifier is an alkoxylated ether acid.12. The fluid of claim 1 , wherein the emulsifier is an alkoxylated ether acid ...

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Номер записи: 12
06-01-2022 дата публикации

METHOD FOR EXTRACTING PETROLEUM FROM UNDERGROUND DEPOSITS HAVING HIGH SALINITY

Номер: US20220002614A1
Автор: Bittner Christian, LEY David, Oetter Guenter, SIGGEL Lorenz, Spindler Christian
Принадлежит:

The present invention relates to a method of producing mineral oil from an underground mineral oil deposit, in which an aqueous saline surfactant formulation comprising a surfactant mixture, for the purpose of lowering the interfacial tension between oil and water to <0.1 mN/m, is injected through at least one injection well into the mineral oil deposit and crude oil is withdrawn from the deposit through at least one production well, wherein the mineral oil deposit is at a temperature of ≥25° C. and <130° C. and has formation water with a salinity of ≥50 000 ppm of dissolved salts, and wherein the surfactant mixture comprises at least one anionic surfactant (A) of the general formula R—O—(CHCHO)—(CH)—YM (I) and at least one anionic surfactant (B) of the general formula R—O—(CHCHO)—(CH)—YM (II), wherein there is a molar ratio of anionic surfactant (A) to anionic surfactant (B) in the surfactant mixture on injection of 90:10 to 10:90, and wherein the surfactant mixture does not comprise any ionic surfactant of the general formula (R)—N(R)R(X)(III). The invention further relates to a concentrate of the surfactant mixture and to the use thereof. 1. A method of producing mineral oil from an underground mineral oil deposit , in which an aqueous saline surfactant formulation comprising a surfactant mixture , for the purpose of lowering the interfacial tension between oil and water to <0.1 mN/m , is injected through at least one injection well into the mineral oil deposit and crude oil is withdrawn from the deposit through at least one production well , whereinthe mineral oil deposit is at a temperature of ≥25° C. and <130° C. and has formation water with a salinity of ≥50 000 ppm of dissolved salts, {'br': None, 'sup': 1', '−', '+, 'sub': 2', '2', 'o', '2', 'p, 'R—O—(CHCHO)—(CH)—YM\u2003\u2003(I)'}, 'and wherein the surfactant mixture comprises at least one anionic surfactant (A) of the general formula (I)'} {'br': None, 'sup': 2', '−', '+, 'sub': 2', '2', 'o', '2', 'p, 'R ...

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Номер записи: 13
07-01-2016 дата публикации

ADDITIVES FOR BOOSTING PERFORMANCE OF WATER-BASED DRILLING FLUIDS, DRILLING FLUIDS INCLUDING SAME, AND METHODS OF MAKING AND USING SAME

Номер: US20160002522A1
Автор: Gaertner James P., Peterson Corey G.
Принадлежит: VICHEM SPECIALTY PRODUCTS, LLC

An additive composition for boosting performance of water-based drilling fluids. Modified water-based drilling fluids including the additive composition. Methods of making the additive compositions. Methods of using the modified drilling fluids to drill or perform other operations in reactive shale formations. The additive compositions include one or more multi-hydroxyl alcohols, a lubricant mix, a shale inhibitor, a strong base to adjust pH, and optionally water up to about 20 percent by volume, based on total volume of the additive composition. 2. The additive composition of wherein the one or more multi-hydroxyl alcohols is selected from the group consisting of monomeric or polymeric polyols including but not limited to glycols claim 1 , substituted glycols claim 1 , glycol ethers claim 1 , glycol esters claim 1 , glycerols claim 1 , substituted glycerols claim 1 , glycerol ethers claim 1 , glycerol esters claim 1 , polyglycerols claim 1 , substituted polyglycerols claim 1 , and alkyl glucosides wherein the alkyl has from 1 to 30 carbon atoms claim 1 , and mixtures and combinations of two or more thereof.3. The additive composition of wherein the two or more vegetable oil phospholipids are selected from the group consisting of soybean phospholipid claim 2 , phosphatidyl choline and mixtures and combinations thereof.4. The additive composition of wherein the one or more free fatty acids are selected from the group consisting of one or more saturated claim 1 , monounsaturated claim 1 , and polyunsaturated fatty acids claim 1 , and mixtures and combinations of two or more thereof.5. The additive composition of wherein the one or more lecithins are selected from the group consisting of phosphatidylcholines claim 1 , phosphatidylethanolamine claim 1 , phosphatidylinositol claim 1 , and mixtures and combinations of two or more thereof.6. The additive composition of wherein the one or more shale inhibitor is selected from the group consisting of KOH claim 1 , CHCOK ...

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Номер записи: 14
04-01-2018 дата публикации

IN SITU SWELLING OF WATER-SWELLABLE POLYMERS DOWNHOLE

Номер: US20180002590A1
Автор: BHAMIDIPATI Venkata Satya Srikalyan, Lu Zheng, OLIVEIRA Humberto Almeida
Принадлежит:

Invert emulsions may be used in downhole operations to delay the swelling of water-swellable polymers. For example, a treatment fluid may be introduced into a wellbore penetrating a subterranean formation, the treatment fluid comprising an emulsion with an continuous oil phase and a discontinuous aqueous phase, an emulsifier, and a water-swellable polymer suspended in the continuous oil phase, wherein the aqueous discontinuous phase has a pH of about 0 to about 11; the emulsion may be broken while the treatment fluid in a portion of the subterranean formation; and the water-swellable polymer may be swollen into a swollen polymer, thereby reducing fluid flow through the portion of the subterranean formation. In some instances, for carbonate subterranean formation, the aqueous discontinuous phase may have a pH of about 7 to about 11. 1. A method comprising:introducing a treatment fluid into a wellbore penetrating a subterranean formation, the treatment fluid comprising an emulsion with an continuous oil phase and a discontinuous aqueous phase, an emulsifier, and a water-swellable polymer suspended in the continuous oil phase, wherein the aqueous discontinuous phase has a pH of about 0 to about 11;breaking the emulsion while the treatment fluid in a portion of the subterranean formation; andswelling the water-swellable polymer to a swollen polymer, thereby reducing fluid flow through the portion of the subterranean formation.2. The method of claim 1 , wherein the emulsifier is present in an amount of about 0.01% to about 10% by weight of the treatment fluid.3. The method of claim 1 , wherein the water-swellable polymer is present in an amount of about 0.001% to about 25% by weight of the treatment fluid.4. The method of claim 1 , wherein the discontinuous aqueous phase comprises seawater.5. The method of claim 1 , wherein the treatment fluid further comprises a breaker.6. The method of claim 1 , wherein the portion of the subterranean formation is about 200° F. or ...

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Номер записи: 15
04-01-2018 дата публикации

CROSSLINKED POLYMER COMPOSITIONS FOR USE IN SUBTERRANEAN FORMATION OPERATIONS

Номер: US20180002593A1
Автор: GALINDO Kay A., Shumway William Walter, Zha Weibin
Принадлежит:

A crosslinked polymer comprising reactants of a first repeating unit, a second repeating unit, and a crosslinker that react to form the crosslinked polymer, wherein the first repeating unit is a sulfonic acid-containing monomer present from 50% to 99% by weight of the reactants, wherein the second repeating unit is selected from the group consisting of an N-vinyl amide-containing monomer, a terminal double bond-containing monomer, and any combination thereof, and is present from 1% to 50% by weight of the reactants, and wherein the crosslinker comprises at least two olefinic bonds, and is present in the range of about 9% to about 25% by weight of the reactants. 1. A crosslinked polymer comprising: wherein the first repeating unit is a sulfonic acid-containing monomer present from 50% to 99% by weight of the reactants,', 'wherein the second repeating unit is selected from the group consisting of an N-vinyl amide-containing monomer, a terminal double bond-containing monomer, and any combination thereof, and is present from 1% to 50% by weight of the reactants, and', 'wherein the crosslinker comprises at least two olefinic bonds, and is present in the range of about 9% to about 25% by weight of the reactants., 'reactants of a first repeating unit, a second repeating unit, and a crosslinker that react to form the crosslinked polymer,'}2. The crosslinked polymer of claim 1 , wherein the sulfonic acid-containing monomer is selected from the group consisting of an acrylic sulfonic acid claim 1 , a methylallyl sulfonic acid claim 1 , an allyl sulfonic acid claim 1 , a styrene sulfonic acid claim 1 , a vinyl sulfonic acid claim 1 , a vinyl aromatic sulfonic acid claim 1 , any salt thereof claim 1 , and any combination thereof.3. The crosslinked polymer of claim 1 , wherein the sulfonic acid-containing monomer is selected from the group consisting of 2-acrylamido-2-methylpropane sulfonic acid claim 1 , 2-methacrylamido-2-methylpropanesulfonic acid claim 1 , α-methyl ...

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Номер записи: 16
13-01-2022 дата публикации

Rheology Modifier With a Fatty Alcohol For Organoclay-Free Invert Emulsion Drilling Fluid Systems

Номер: US20220010189A1
Автор: Al-Yami Abdullah, Ramasamy Jothibasu, Wagle Vikrant
Принадлежит:

An invert emulsion drilling fluids having a combination of fatty acids derived from waste vegetable oil (WVO) and a fatty alcohol as a rheology modifier. An invert emulsion drilling fluid may include a water in oil emulsion, an invert emulsifier, a fatty alcohol having six to thirty carbon atoms, and a fatty acid having six to eighteen carbon atoms. The fatty acid is provided by esterifying a waste vegetable oil to produce a methyl ester of the waste vegetable oil and cleaving an ester group from the methyl ester of the waste vegetable oil. The invert emulsion drilling fluid may be formulated free of organoclay. Methods of drilling a wellbore using an invert emulsion drilling fluid are also provided. 1. An invert emulsion drilling fluid , comprisinga water in oil emulsion;an invert emulsifier to stabilize the water in oil emulsion in an amount operable to stabilize the water in oil emulsion;a fatty alcohol having six to thirty six carbons; esterifying a waste vegetable oil to produce a methyl ester of the waste vegetable oil; and', 'cleaving an ester group from the methyl ester of the waste vegetable oil., 'a fatty acid having six to eighteen carbons, the fatty acid produced by2. The invert emulsion drilling fluid of claim 1 , comprising a filtration control agent claim 1 , lime claim 1 , calcium chloride claim 1 , a bridging agent claim 1 , and a weighting agent.3. The invert emulsion drilling fluid of claim 2 , consisting of:the water in oil emulsion;the invert emulsifier to stabilize the water in oil emulsion in an amount operable to stabilize the water in oil emulsion;the fatty alcohol having six to thirty six carbons;the fatty acid having six to eighteen carbons;the filtration control agent;lime;calcium chloride;the bridging agent; andthe weighting agent.4. The invert emulsion drilling fluid of claim 2 , wherein the filtration control agent is an amount in the range of 0.1 pounds-per-barrel (ppb) to 15 ppb.5. The invert emulsion drilling fluid of claim 2 , ...

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Номер записи: 17
08-01-2015 дата публикации

Lost Circulation Drilling Fluids Comprising Elastomeric Rubber Particles and a Method for Decreasing Whole Mud Loss Using Such Composition

Номер: US20150008044A1
Автор: James Blair Fontenot
Принадлежит: Individual

The disclosed invention is a unique drilling fluid composition and method for reducing lost mud circulation in wellbores due to seepage loss into fluid permeable subterranean formations. The drilling fluid composition comprises a variety of shapes and sizes of distinctive unadulterated elastomeric rubber particles derived from the tire retreading (recapping) process. These elastomeric rubber particles are incorporated into an aqueous, hydrocarbon, or synthetic drilling fluid in sufficient amounts as to plug holes, fractures, and fissures, form a mud cake, and thus stem the loss of drilling fluids from the lost circulation zone.

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Номер записи: 18
08-01-2015 дата публикации

THERMOSET NANOCOMPOSITE PARTICLES, PROCESSING FOR THIER PRODUCTION, AND THEIR USE IN OIL AND NATURAL GAS DRILLING APPLICATIONS

Номер: US20150011439A1
Автор: BICERANO Jozef
Принадлежит: SUN DRILLING PRODUCTS CORPORATION

Use of two different methods, either each by itself or in combination, to enhance the stiffness, strength, maximum possible use temperature, and environmental resistance of thermoset polymer particles is disclosed. One method is the application of post-polymerization process steps (and especially heat treatment) to advance the curing reaction and to thus obtain a more densely crosslinked polymer network. The other method is the incorporation of nanofillers, resulting in a heterogeneous “nanocomposite” morphology. Nanofiller incorporation and post-polymerization heat treatment can also be combined to obtain the benefits of both methods simultaneously. The present invention relates to the development of thermoset nanocomposite particles. Optional further improvement of the heat resistance and environmental resistance of said particles via post-polymerization heat treatment; processes for the manufacture of said particles; and use of said particles in the construction, drilling, completion and/or fracture stimulation of oil and natural gas wells are described. 189-. (canceled)90. A polymeric-nanocomposite spherical bead exhibiting at least one of enhanced resistance to deformation under load , enhanced retention of resistance at elevated temperature , and enhanced retention of resistance in acidic , basic , or hydrocarbon environments; comprising: a polymer matrix; and from 0.001 to 60 volume percent of nanofiller particles possessing a length that is less than 0.5 microns in at least one principal axis direction , wherein said nanofiller particles comprise at least one of fine particulate material , fibrous material , discoidal material , or a combination of such materials; and wherein said nanofiller particles are selected from the group consisting of natural nanoclays , synthetic nanoclays or mixtures thereof , said nanofiller particles being-dispersed throughout said polymeric nanocomposite spherical bead , wherein said spherical bead has diameter ranging from 0.1 ...

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Номер записи: 19
14-01-2021 дата публикации

Synergist for water-based drilling fluid and preparation method therefor, water-based drilling fluid and application thereof

Номер: US20210009887A1
Автор: Ang Li, Haiping FENG, Jianmin Chen, JING Yang, Junling Zhao, Wei Quan, Weizhi YOU, Xiaohu Quan, Yihu WANG, Yu Cao
Принадлежит: Beijing Shida Bocheng Technology Co Ltd

The present disclosure provides a synergist for a water-base drilling fluid and a preparation method therefor, a water-base drilling fluid and an application thereof, and belongs to the field of drilling fluid technologies. The synergist is prepared from raw materials comprising the following parts by weight: 15˜25 parts of sodium styrene sulfonate, 8˜15 parts of allyl trimethyl ammonium chloride, 2˜8 parts of didodecyldimethylammonium bromide, 1˜5 parts of n-octyl triethoxysilane, 1˜5 parts of propyltriethoxysilane, 1˜5 parts of disodium lauryl sulfosuccinate, 10˜20 parts of nano silica, 8˜15 parts of paraffin, and the like.

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Номер записи: 20
14-01-2021 дата публикации

Cationic Formation Stabilizers Compatible with Anionic Friction Reducing Polymers

Номер: US20210009888A1
Автор: Benoit Denise Nicole, Holan Kristina Henkel, III Antonio, Recio
Принадлежит:

A wellbore servicing fluid comprising (a) a cationic formation stabilizer having (i) a molecular weight in a range of from equal to or greater than 0.05 to equal to or less than 2.0 kiloDaltons (kDa), or (ii) cationic charge functional groups of greater than 2 to equal to or less than 5 cationic charges per molecule, or (iii) both (i) and (ii), (b) an anionic friction reducer, and (c) an aqueous fluid. 1. A wellbore servicing fluid comprising:(a) a cationic formation stabilizer having (i) a molecular weight in a range of from equal to or greater than 0.05 to equal to or less than 2.0 kiloDaltons (kDa), or (ii) cationic charge functional groups of greater than 2 to equal to or less than 5 cationic charges per molecule, or (iii) both (i) and (ii);(b) an anionic friction reducer; and(c) an aqueous fluid.2. The wellbore servicing fluid of claim 1 , wherein the cationic formation stabilizer comprises an oligomer.3. The wellbore servicing fluid of claim 2 , wherein the oligomer is composed of 2 to 20 monomeric units claim 2 , wherein each monomeric unit ranges in weight from 0.01 kDa to 0.3 kDa.4. The wellbore servicing fluid of claim 2 , wherein the oligomer comprises one or more of functional groups selected from the group consisting of (a) 1°- claim 2 , 2°- claim 2 , 3°- claim 2 , or quaternary alkyl claim 2 , vinyl claim 2 , aryl amines; (b) 1°- claim 2 , 2°- claim 2 , 3°- claim 2 , or quaternary alkyl claim 2 , vinyl claim 2 , aryl claim 2 , cyclic amines; (c) 1°- claim 2 , 2°- claim 2 , 3°- claim 2 , or quaternary cyclic alkyl claim 2 , vinyl claim 2 , aryl claim 2 , diamines; (d) 1°- claim 2 , 2°- claim 2 , 3°- claim 2 , or quaternary cyclic alkyl claim 2 , vinyl claim 2 , aryl claim 2 , triamines; (e) 1°- claim 2 , 2°- claim 2 , 3°- claim 2 , or quaternary alkyl claim 2 , vinyl claim 2 , aryl claim 2 , aminoalcohol moieties; (f) diol or glycerol alcohol moiety; (g) 1 claim 2 ,2-propanediol-3-trialkyl ammonium salts; (h) aminoacid moiety; (i) 1°- claim 2 , 2°- ...

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Номер записи: 21
19-01-2017 дата публикации

ENVIRONMENTALLY PREFERABLE MICROEMULSION COMPOSITION

Номер: US20170015898A1
Автор: Beach Sean R., Hebert Joel A., Mouton Derek C.
Принадлежит: KMP HOLDINGS, LLC

The present invention relates to an environmentally preferable microemulsion composition that is suitable for formation stimulation, remediation, and drilling operations, and a method to make and use the same. Specifically, the environmentally preferable microemulsion composition of the present invention can comprise glycol ether, terpene, ethoxylated alcohol, polyoxyethylene sorbitan ester, and a carrier fluid. 1. A microemulsion composition comprising a glycol ether , a terpene , an ethoxylated alcohol , a polyoxyethylene sorbitan ester , and a carrier fluid.2. The microemulsion composition according to claim 1 , wherein said glycol ether is a compound according to Formula I:{'br': None, 'sup': '1', 'sub': m', '2m', 'n, 'RO[(CH)O]H\u2003\u2003(Formula I),'}{'sup': 1', '2', '2, 'sub': 1', '12', 'm', '2m', '1', '6, 'wherein Ris a C-Cstraight or branched alkyl , m is 2 to 10, n is 1 to 10, and at least one of hydrogens on any carbon may be optionally substituted with —OR, Cl, or F, wherein (CH) may be a straight or branched alkyl chain, and Ris H or a C-Cstraight or branched alkyl.'}3. The microemulsion composition according to claim 2 , wherein said glycol ether is selected from the group consisting of CHO[CHCH(CH)O]H claim 2 , CHO[CH(CH)CHO]H claim 2 , CHO(CHCHCHO)H claim 2 , and any combination thereof.4. The microemulsion composition according to claim 1 , wherein said terpene is D-Limonene.5. The microemulsion composition according to claim 1 , wherein said ethoxylated alcohol is a compound according to Formula III:{'br': None, 'sup': '1', 'sub': 2', '2', 'y, 'R(OCHCHO)H\u2003\u2003(Formula III),'}{'sup': '1', 'sub': 2', '18, 'wherein Ris H or a C-Cstraight or branched alkyl, and y is 1 to 10.'}6. The microemulsion composition according to claim 1 , wherein said polyoxyethylene sorbitan ester is selected from the group consisting of polyoxyethylene sorbitan monooleate claim 1 , polyoxyethylene sorbitan dioleate claim 1 , polyoxyethylene sorbitan trioleate claim ...

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Номер записи: 22
18-01-2018 дата публикации

BARRIER PILLS

Номер: US20180016485A1
Автор: Galindo Kay Ann, Jamison Dale E., Kulkarni Sandeep, Miller Matthew Lynn, Ramirez Angulo Jessica Paola, Shumway William Walter
Принадлежит:

The present disclosure relates to systems and methods for wellbore pressure control with separated fluid columns. One embodiment is a composition comprising: a base fluid, a hectorite clay, a secondary clay comprising at least one clay selected from the group consisting of an attapulgite clay, a sepiolite clay, a polygorskite clay, and any combination thereof, and a plurality of fibers. Another embodiment is a method comprising: introducing a first fluid into a wellbore; introducing a barrier pill into the wellbore, wherein the barrier pill comprises: a base fluid, a hectorite clay, and a plurality of fibers; and introducing a second fluid into the wellbore. Another embodiment is a method comprising: introducing a first fluid into a wellbore; introducing a barrier pill into the wellbore, wherein the barrier pill comprises: a base fluid, a hectorite clay, and a secondary clay comprising at least one clay selected from the group consisting of an attapulgite clay, a sepiolite clay, a polygorskite clay, and any combination thereof; and introducing a second fluid into the wellbore. 1. A composition comprising:a base fluid,a hectorite clay,a secondary clay comprising at least one clay selected from the group consisting of an attapulgite clay, a sepiolite clay, a polygorskite clay, and any combination thereof, anda plurality of fibers.2. The composition of claim 1 , wherein the composition further comprises a strong base selected from the group consisting of a hydroxide base claim 1 , quick lime claim 1 , and any combination thereof.3. The composition of claim 1 , wherein the composition further comprises a weighting agent.4. The composition of claim 1 , wherein the fibers comprise at least one material selected from the group consisting of: polypropylene claim 1 , polyaramide claim 1 , polyester claim 1 , polyacrylonitrile claim 1 , polyvinyl alcohol claim 1 , chitosan claim 1 , soya claim 1 , modified chitosan claim 1 , polycaprolactone claim 1 , poly(3-hydroxybutyrate) ...

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Номер записи: 23
18-01-2018 дата публикации

Crosslinked fluid treatment and methods for fracturing underground formations based on flowback, production water, seawater, fresh water, and mixtures of same

Номер: US20180016486A1
Автор: Fabio GERMAN BORGOGNO
Принадлежит: Sotro Financial Inc

The present invention provides cross-linked fracture fluids that allow for reusing return water with no treatment, minimizing the environmental impact thereof and reducing the use of fresh water to very low levels to stimulate wells or re-stimulate wells stimulated in the past. Preparation and use methods of said fluids in fractured subterranean formations drilled by wells, based on return water, production water, sea water, fresh water and mixtures thereof, are provided. Fluids are basically composed of: return water, production water, sea water, fresh water and mixtures thereof present in a sufficient amount to moisten the gelling agent and to form a gellified aqueous agent; a gelling agent; an iron control agent; an alkaline buffer; a delayed cross-linking agent, and a rupture system to “break” the fluid and improve fracture cleaning.

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Номер записи: 24
21-01-2021 дата публикации

THIXOTROPIC SEALING COMPOSITION AND INJECTION THEREOF FOR USE DURING DRILLING

Номер: US20210017442A1
Автор: Jones Paul Joseph, Lewis Samuel J., Pisklak Thomas Jason
Принадлежит: Halliburton Energy Services, Inc.

A thixotropic composition having a cross-linkable polymer, cross-linking agent, initiator and a thixotropic agent. The thixotropic agent may be a clay or a saccharide polymer. The thixotropic composition may be introduced into a drill string via a batch or on-the-fly process to prevent loss of drilling fluid into the surrounding formation. 1. A method comprising: an aqueous base fluid,', 'a cross-linkable polymer,', 'a cross-linking agent for the cross-linkable polymer,', 'a retarding agent,', 'a weighting agent,', 'an initiator, and', 'a thixotropic agent imparting thixotropic properties to the composition;, 'introducing into a tubular drill string disposed within a wellbore, a thixotropic composition comprisingflowing the thixotropic composition out of an exit of the downhole drilling device into the wellbore; andcontinuing drilling with the downhole drilling device.2. A method of claim 1 , wherein the thixotropic composition is introduced via an on-the-fly continuous process claim 1 , the on-the-fly continuous process comprising:mixing the thixotropic agent with the aqueous base fluid to form a prehydrated thixotropic agent; andadding at least the cross-linkable polymer, cross-linking agent and initiator to the prehydrated thixotropic agent.3. A method of claim 2 , wherein the cross-linkable polymer claim 2 , cross-linking agent and initiator is added to the prehydrated thixotropic agent at or before a recirculating mixer.4. A method of claim 2 , wherein the cross-linkable polymer claim 2 , cross-linking agent and initiator to the prehydrated thixotropic agent is added to the prehydrated thixotropic agent at the pump.5. A method of claim 2 , wherein the thixotropic composition is mixed via a batch process prior to introducing into a tubular string.6. A method of claim 1 , wherein the drilling device has a bottom hole assembly having a drill bit claim 1 , and the exit of the downhole drilling device is located along the bottom hole assembly.7. The method of claim ...

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Номер записи: 25
22-01-2015 дата публикации

BREAKER FLUIDS FOR WELLBORE FLUIDS AND METHODS OF USE

Номер: US20150021098A1
Автор: Kippie David P.
Принадлежит: M-I L.L.C.

Compositions for controlling fluid loss may include an aqueous fluid, a viscosifier, a water soluble polar organic solvent, a delayed acid source, and a weighting agent. The composition may further comprise at least one selected from bridging solids, cleaning agent, dispersant, interfacial tension reducer, pH buffer, thinner, or surfactant. Such compositions may be used in producing a hydrocarbon from a formation by drilling the formation with a drill-in fluid to form a wellbore, emplacing the composition in the wellbore, and shutting the well for a predetermined time to allow the viscosity of the fluid loss composition to decrease. 1. A composition comprising:an aqueous fluid;a viscosifier;a water soluble polar organic solvent;a delayed acid source; anda weighting agent.2. The composition of claim 1 , wherein the water soluble polar organic solvent is a glycol or glycol ether.3. The composition of claim 1 , wherein the delayed acid source is a formic acid or acetic acid ester of a C2 to C30 alcohol.4. The composition of claim 1 , wherein the weighting agent comprises at least one of halide or formate salts of alkali or alkaline earth metals.5. The composition of claim 1 , further comprising:at least one selected from bridging solids, a cleaning agent, a dispersant, an interfacial tension reducer, a pH buffer, a thinner, or a surfactant.6. The composition of claim 1 , wherein the aqueous fluid is selected from fresh water claim 1 , sea water claim 1 , a brine containing organic and/or inorganic dissolved salts claim 1 , liquids containing water-miscible organic compounds or combinations thereof.7. The composition of claim 1 , wherein the viscosifier comprises a hydratable natural polymer.8. The composition of claim 7 , wherein the hydratable natural polymer comprises hydroxyethyl cellulose.9. The composition of claim 1 , wherein the viscosifier comprises one or more viscoelastic surfactant.10. The composition of claim 1 , wherein the viscosifier comprises starch.11. ...

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Номер записи: 26
25-01-2018 дата публикации

Crosslinked polymer compositions and methods for use in subterranean formation operations

Номер: US20180022979A1
Автор: Hui Zhou, Weibin ZHA
Принадлежит: Halliburton Energy Services Inc

A crosslinked polymer comprising reactants of a first repeating unit, a second repeating unit, and a crosslinker that react to form the crosslinked polymer, wherein the first repeating unit is a sulfonic acid-containing monomer present from 1% to 45% by weight of the reactants, wherein the second repeating unit is selected from the group consisting of an N-vinyl amide-contain ing monomer, a terminal double bond-containing monomer, and any combination thereof, and is present from 55% to 99% by weight of the reactants, and wherein the crosslinker comprises at least two olefinic bonds.

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Номер записи: 27
24-01-2019 дата публикации

Additive to enhance sag stability of drilling fluid

Номер: US20190023964A1
Автор: Chesnee Lae Davis, Philip Wayne Livanec, William Walter Shumway
Принадлежит: Halliburton Energy Services Inc

A method including providing a drilling fluid that comprises a base fluid, a weighting agent, and a sag stability enhancer, wherein the sag stability enhancer comprises polyethylene glycol (PEG) having a molecular weight of greater than or equal to about 200 g/mol; and placing the drilling fluid in a subterranean formation via a wellbore penetrating the subterranean formation. A method including forming a fluid comprising a base fluid, a weighting agent, and from about 0.5 ppb (1.4 kg/m 3 ) to about 30 ppb (85.5 kg/m 3 ) of a sag stability enhancer, wherein the sag stability enhancer comprises a glycol; and introducing the fluid into at least a portion of a well. A drilling fluid containing a base fluid, a weighting agent, and a sag stability enhancer comprising polyethylene glycol (PEG) having a molecular weight of greater than or equal to about 200 g/mol.

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Номер записи: 28
23-01-2020 дата публикации

SYNTHESIZED LUBRICANTS FOR WATER-BASED DRILLING FLUID SYSTEMS

Номер: US20200024499A1
Автор: AMANULLAH Md, Radhwan Ali, Ramasamy Jothibasu
Принадлежит: Saudi Arabian Oil Company

The present application discloses water-based drilling fluid systems and methods of making water-based drilling fluids systems. According to one embodiment, a drilling fluid system may include a drilling fluid and a lubricant. The lubricant may be synthesized from waste vegetable oil. 1. A water-based drilling fluid system comprising:a water-based drilling fluid; anda synthesized lubricant comprising a plant-based alkyl ester, and a plant-based free fatty acid;wherein the synthesized lubricant comprises more plant-based alkyl ester than plant-based free fatty acid.2. The water-based wellbore drilling fluid system of claim 1 , wherein the ratio of plant-based alkyl ester to plant-based free fatty acids is from 1.5:1 to 3:1 by weight.3. The water-based wellbore drilling fluid system of claim 1 , wherein the plant-based alkyl ester is derived from a plant-based oil.4. The water-based wellbore drilling fluid system of claim 3 , wherein the plant-based alkyl ester is derived from a waste vegetable oil.5. The water-based wellbore drilling fluid system of claim 1 , wherein the plant-based alkyl ester is a methyl ester.6. The water-based wellbore drilling fluid system of claim 1 , wherein the plant-based free fatty acid is derived from a tall oil.7. The water-based wellbore drilling fluid system of claim 1 , wherein the synthesized lubricant is a homogenous mixture.8. The water-based wellbore drilling fluid system of claim 1 , wherein the drilling fluid system has a before hot rolled (BHR) coefficient of friction of from about 0.01 to about 0.10 when measured according to API Recommended Practice 13B.9. The water-based wellbore drilling fluid system of claim 1 , wherein the drilling fluid system has an after hot rolled (AHR) coefficient of friction of from about 0.01 to about 0.09 when measured according to API Recommended Practice 13B.10. The water-based wellbore drilling fluid system of claim 1 , wherein the system comprises from about 0.5 weight percent (wt. %) to about ...

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Номер записи: 29
23-01-2020 дата публикации

ENVIRONMENTALLY-FRIENDLY LUBRICANT FOR OIL FIELD DRILLING FLUID APPLICATIONS

Номер: US20200024500A1
Автор: AMANULLAH Md, Ramasamy Jothibasu
Принадлежит: Saudi Arabian Oil Company

The present application discloses water-based drilling fluid system compositions and methods for making water-based drilling fluids systems. According to one embodiment, a drilling fluid system may include a drilling fluid and a lubricant. The lubricant may be synthesized from plant-based raw material oil. 1. A method of producing a synthesized lubricant for water-based drilling fluid systems comprising:contacting a plant-based raw material oil with a base to produce a mixture comprising free fatty acids and glycerol;treating the mixture with a brine to isolate the glycerol; andremoving the glycerol to produce a synthesized lubricant comprising free fatty acids.2. The method of claim 1 , wherein the base comprises sodium hydroxide.3. The method of claim 1 , wherein the plant-based raw material oil is contacted with the base at a temperature from about 50° C. to about 75° C.4. The method of claim 3 , further comprising heating the plant-based raw material oil and the base for a period of from about 4 hours to about 8 hours.5. The method of claim 1 , wherein the plant-based raw material oil comprises a vegetable oil.6. The method of claim 1 , wherein the plant-based raw material oil is a waste vegetable oil.7. A method of producing a water-based drilling fluid system comprising:treating a plant-based raw material oil with a base to produce a synthesized lubricant comprising free fatty acids; andcombining the synthesized lubricant with a base drilling fluid to produce a water-based drilling fluid system; andwherein the water-based drilling fluid system is homogeneous.8. The method of claim 7 , wherein the base comprises sodium hydroxide.9. The method of claim 7 , wherein treating the plant-based raw material oil further comprises heating the plant-based raw material oil and the base at a temperature from about 50° C. to about 75° C.10. The method of claim 7 , wherein the plant-based raw material oil is treated for a period of from about 4 hours to about 8 hours.11. The ...

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Номер записи: 30
02-02-2017 дата публикации

THERMOSET NANOCOMPOSITE PARTICLES, PROCESSING FOR THEIR PRODUCTION, AND THEIR USE IN OIL AND NATURAL GAS DRILLING APPLICATIONS

Номер: US20170029330A1
Автор: BICERANO Jozef
Принадлежит: SUN DRILLING PRODUCTS CORPORATION

Use of two different methods, either each by itself or in combination, to enhance the stiffness, strength, maximum possible use temperature, and environmental resistance of thermoset polymer particles is disclosed. One method is the application of post-polymerization process steps (and especially heat treatment) to advance the curing reaction and to thus obtain a more densely crosslinked polymer network. The other method is the incorporation of nanofillers, resulting in a heterogeneous “nanocomposite” morphology. Nanofiller incorporation and post-polymerization heat treatment can also be combined to obtain the benefits of both methods simultaneously. The present invention relates to the development of thermoset nanocomposite particles. Optional further improvement of the heat resistance and environmental resistance of said particles via post-polymerization heat treatment; processes for the manufacture of said particles; and use of said particles in the construction, drilling, completion and/or fracture stimulation of oil and natural gas wells are described. 189.-. (canceled)90. A method for lightening a load of cement comprising: a polymer matrix; and', 'from 0.001 to 60 volume percent of nanofiller particles possessing a length that is less than 0.5 microns in at least one principal axis direction; said nanofiller particles comprising at least one of fine particulate material, fibrous material, discoidal material, or a combination of such materials, said nanofiller particles being selected from the group consisting of natural nanoclays, synthetic nanoclays or mixtures thereof wherein said nanofiller particles are substantially dispersed throughout said polymeric nanocomposite particles, wherein said polymeric nanocomposite particle has a diameter ranging from 0.1 mm to 4 mm; and, '(a) mixing an uncured cement composition with an effective amount of a polymeric nanocomposite bead comprising(b) placing the mixture in a selected location.91. The method of claim 90 , ...

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Номер записи: 31
02-02-2017 дата публикации

WELLBORE FLUIDS FOR USE DOWNHOLE

Номер: US20170029686A1
Автор: Bailey Robert, Bouguetta Chemsseddine, Conn Henry Lee, Friedheim James, Matlock Roger Wayne
Принадлежит: M-I L.L.C.

A wellbore fluid may include a base fluid, and a ground weight material comprising barite and quartz and having a dbetween about 4 and 8 microns and a dbetween about 15-25 microns. The ground weight material of the wellbore fluid may have a specific gravity of less than or equal to about 42. 1. A wellbore fluid comprising:a base fluid; and{'sub': 50', '90, 'a ground weight material comprising barite and quartz and having a dbetween about 4 and 8 microns and a dbetween about 15-25 microns.'}2. The wellbore fluid of claim 1 , wherein the weight material has a specific gravity of less than or equal to about 4.2.3. The wellbore fluid of claim 1 , wherein the weight material has a weight percent of silica of about 4 to 12 percent.4. The wellbore fluid of claim 5 , wherein the ground weight material has a weight percent of quartz ranging between about 5 and 7 percent.5. The wellbore fluid of claim 1 , wherein the quartz has a larger average particle size than the barite.6. The wellbore fluid of claim 1 , wherein the weight material has a dbetween about 18-22 microns.7. The wellbore fluid of claim 1 , wherein the weight material has a dbetween about 4-8 microns.8. The wellbore fluid of claim 1 , wherein the weight material has a dbetween about 12-14 microns.9. The wellbore fluid of claim 1 , wherein the weight material has a dbetween about 15-17 microns.10. The wellbore fluid of claim 1 , wherein the weight material has a dbetween about 24-34 microns.11. The wellbore fluid of claim 1 , wherein the weight material has a dbetween about 32-60 microns.12. The wellbore fluid of claim 1 , wherein the weight material has a dbetween about 32-60 microns.13. The wellbore fluid of claim 1 , wherein the weight material has a dbetween about 48-120 microns.14. The wellbore fluid of claim 1 , wherein the base fluid is one selected from a water-based fluid claim 1 , an invert emulsion and a direct emulsion.15. The wellbore fluid of claim 1 , wherein the mixed wellbore fluid has a ...

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Номер записи: 32
04-02-2016 дата публикации

Polymers and emulsions for use in oil and/or gas wells

Номер: US20160032172A1
Автор: Arun Kharghoria, Charles Earl HAMMOND, David GERMACK, Deepankar Biswas, Glenn S. Penny, John T. PURSLEY, Nicole MAST
Принадлежит: CESI Chemical Inc

Methods and compositions comprising an emulsion or a microemulsion and a polymer for use in an oil and/or gas well are provided. In some embodiments, the emulsion or the microemulsion comprises water, a solvent, and a surfactant, and optionally, one or more additives. In certain embodiments, the polymer comprises a copolymer comprising an acrylamide.

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Номер записи: 33
04-02-2021 дата публикации

WATER-BASED DRILLING FLUIDS THAT INCLUDE LUBRICANTS

Номер: US20210032524A1
Автор: AMANULLAH Md, Radhwan Ali, Ramasamy Jothibasu
Принадлежит: Saudi Arabian Oil Company

One or more embodiments presently described are directed to drilling fluid compositions that include lubricants, methods for making drilling fluids, and methods for drilling subterranean wells utilizing the drilling fluids. According to one embodiment, a drilling fluid composition may include a base fluid including water, a weighting agent in an amount of from 0.1 weight percent (wt. %) to 75 wt. % relative to the total weight of the water-based drilling fluid, and a lubricant in an amount of from 1 wt. % to 10 wt. % relative to the total weight of the water-based drilling fluid. The lubricant may include one or more alkyl esters and a fatty acid blend including at least palmitic acid and stearic acid. The sum of the weight percent of the palmitic acid and stearic acid may be at least 50 wt. % of the fatty acid blend. 1. A water-based drilling fluid comprising:a base fluid comprising water;a weighting agent in an amount of from 0.1 wt. % to 75 wt. % relative to the total weight of the water-based drilling fluid; and one or more alkyl esters; and', 'a fatty acid blend comprising at least palmitic acid and stearic acid, where the sum of the weight percent of the palmitic acid and stearic acid is at least 50 wt. % of the fatty acid blend., 'a lubricant in an amount of from 1 wt. % to 10 wt. % relative to the total weight of the water-based drilling fluid, the lubricant comprising2. The water-based drilling fluid of claim 1 , further comprising at least one salt selected from a monovalent salt claim 1 , a divalent salt claim 1 , or combinations of these.3. The water-based drilling fluid of claim 2 , where the at least one salt is present in an amount from 0.01 wt. % to 10 wt. % relative to the total weight of the water-based drilling fluid.4. The water-based drilling fluid of claim 2 , where the at least one salt is selected from KCl claim 2 , NaCl claim 2 , CaCl claim 2 , or combinations of these.5. The water-based drilling fluid of claim 1 , where the weight ratio of ...

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Номер записи: 34
04-02-2021 дата публикации

SPACER FLUIDS AND CEMENT SLURRIES THAT INCLUDE SURFACTANTS

Номер: US20210032525A1
Автор: Al-Yami Abdullah, AlBahrani Hussain, Wagle Vikrant
Принадлежит: Saudi Arabian Oil Company

According to at least one embodiment of the present disclosure, a well bore cementing system may comprise a spacer fluid and a cement slurry. The spacer fluid may be positioned within a well bore, and the spacer fluid may comprise a first surfactant package comprising one or more surfactants. The cement slurry may be positioned within the well bore, and the cement slurry may comprise a second surfactant package comprising one or more surfactants. 1. A well bore cementing system comprising: a base fluid that is an aqueous-based fluid; and', {'sub': 2', '4', 'x1, 'a first surfactant package consisting essentially of one or more surfactants having the chemical structure R1-(OCH)—OH, where R1 is a hydrocarbyl group having from 5 to 20 carbon atoms, and x1 is an integer from 5 to 15, where the one or more surfactants of the first surfactant package has a HLB of from 11 to 13.5; and'}], 'a spacer fluid positioned within a well bore, the spacer fluid comprising{'sub': 2', '4', 'x2, 'a cement slurry positioned within the well bore, the cement slurry comprising a second surfactant package consisting essentially of one or more surfactants having the chemical structure R2-(OCH)—OH, where R2 is a hydrocarbyl group having from 5 to 20 carbon atom, and x2 is an integer from 5 to 15, where the one or more surfactants of the second surfactant package has a HLB of from 11 to 13.5.'}2. The well bore cementing system of claim 1 , where the cement slurry is in contact with the spacer fluid.3. The well bore cementing system of claim 1 , where the spacer fluid is in contact with a drilling fluid and the cement slurry.4. The well bore cementing system of claim 1 , where the one or more surfactants of the first surfactant package has a HLB of from 12.5 to 13 claim 1 , the one or more surfactants of the second surfactant package has a HLB of from 12.5 to 13 claim 1 , or both.5. The well bore cementing system of claim 1 , where x1 is an integer from 5 to 10 claim 1 , x2 is an integer from 5 ...

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Номер записи: 35
04-02-2021 дата публикации

LUBRICANTS THAT INCLUDE ALKYL ESTERS AND FATTY ACIDS

Номер: US20210032556A1
Автор: AMANULLAH Md, Radhwan Ali, Ramasamy Jothibasu
Принадлежит: Saudi Arabian Oil Company

One or more embodiments presently described are directed to lubricants and methods for making such lubricants. According to one embodiment, a lubricant suitable for use in a water-based drilling fluid may comprise one or more alkyl esters and a fatty acid blend comprising at least palmitic acid and stearic acid. The sum of the weight percent of the palmitic acid and stearic acid may be at least 50 wt. % of the fatty acid blend. The weight ratio of the one or more alkyl esters to the fatty acid blend may be from 1:1 to 3:1. The molar ratio of palmitic acid to stearic acid may be from 20:80 to 40:60. 1. A lubricant suitable for use in a water-based drilling fluid , the lubricant comprising:one or more alkyl esters; anda fatty acid blend comprising at least palmitic acid and stearic acid, where the sum of the weight percent of the palmitic acid and stearic acid is at least 50 wt. % of the fatty acid blend, and where the fatty acid blend is a liquid,where the weight ratio of the one or more alkyl esters to the fatty acid blend is from 1:1 to 3:1; andthe molar ratio of palmitic acid to stearic acid is from 20:80 to 40:60.2. The lubricant of claim 1 , where the weight ratio of the one or more alkyl esters to the fatty acid blend is from 1.5:1 to 2.5:1.3. The lubricant of claim 1 , where the molar ratio of palmitic acid to stearic acid is from 24:76 to 32:68.4. The lubricant of claim 1 , where the one or more alkyl esters are derived from vegetable oil.5. The lubricant of claim 1 , where the one or more alkyl esters are from 50 wt. % to 75 wt. % of the lubricant.6. The lubricant of claim 1 , where the fatty acid blend is from 25 wt. % to 50 wt. % of the lubricant.7. (canceled)8. A method for making a drilling fluid lubricant claim 1 , the method comprising:mixing solid palmitic acid and solid stearic acid to make a solid fatty acid blend;heating the solid fatty acid blend to form a liquid fatty acid blend;mixing the liquid fatty acid blend with one or more alkyl esters to ...

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Номер записи: 36
05-02-2015 дата публикации

PROCESS FOR PREVENTING OR MITIGATING BIOFOULING

Номер: US20150038471A1
Автор: Lee Crystal, Penkala Joseph E., Wunch Kenneth G.
Принадлежит: BAKER HUGHES INCORPORATED

Biofouling may be prevented or at least mitigated by employing a cinnamaldehyde additive to augment the affect of the conventional biocide. Exemplary cinnamaldehyde additives include, but are not limited to, cinnamaldehyde, cinnamic acid and cinnamyl alcohol. A cinnamaldehyde additive by itself, in some embodiments, may also inhibit biofouling. 1. A process for preventing or mitigating the occurrence of biofouling comprising introducing an effective amount of a biocidal blend comprising a cinnamaldehyde additive and a conventional biocide into an industrial water system , where the biocidal blend decreases the growth of a bacteria selected from the group consisting of acid-producing bacteria , sulfate-reducing bacteria and combinations thereof.3. The process of where the biocidal blend has a pH below 7 and the cinnamaldehyde additives may be in the form of an acetal or a hemiacetal.4. The process of where the cinnamaldehyde additive is selected from the group consisting of cinnamaldehyde claim 1 , cinnamyl acetate claim 1 , 3-phenylpropionaldehyde claim 1 , 2-bromocinnamaldehyde claim 1 , phenyl propiolic aldehyde claim 1 , benzalacetone claim 1 , ethyl cinnamate claim 1 , 4-chlorocinnamaic acid claim 1 , 4-nitrocinnamaic acid claim 1 , and 4 aminocinnamic acid claim 1 , vanillin claim 1 , capsaicin claim 1 , eugenol claim 1 , and combinations thereof.5. The process of where the conventional biocide is non-oxidizing and is selected from the group consisting of:quaternary ammonium compounds;thiocarbamates;dithiocarbamates;thiocyanates;hydroxyalkylaminoalkanols;formaldehyde;p-formaldehyde;glutaraldehyde;isothiazolin-3-ones;complexed copper;metaborate;sodium dodecylbenzene sulphonate;sodium benzoate;thione;tetrakis (hydroxymethyl) phosphonium sulfate (THPS);chloromethylphenol; andcombinations thereof.6. The process of where the conventional biocide is tetrakis (hydroxymethyl) phosphonium sulfate (THPS).7. The process of where the industrial water system is selected ...

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Номер записи: 37
09-02-2017 дата публикации

DRILLING FLUID ADJUSTING AGENT AND DRILLING FLUID USING THE SAME

Номер: US20170037294A1
Автор: MANDAI Shusaku, TAKEDA Hiroki
Принадлежит: THE NIPPON SYNTHETIC CHEMICAL INDUSTRY CO., LTD.

A drilling fluid adjusting agent using a PVA-based resin capable of contributing to the reduction of hydration swelling of bentonite even in the presence of salts; and a drilling fluid using the same are provided. The drilling fluid adjusting agent contains a PVA containing 1,2-diol structural unit in a side chain thereof. The drilling fluid adjusting agent has excellent solubility even in the presence of salts such as potassium ion, and also has excellent reduction of hydration swelling of bentonite. 2. The drilling fluid adjusting agent according to claim 1 , wherein the polyvinyl alcohol-based resin (A) has a saponification degree of 80 to 100%.3. The drilling fluid adjusting agent according to claim 1 , wherein the polyvinyl alcohol-based resin (A) has an average polymerization degree of 500 to 4000.4. The drilling fluid adjusting agent according to claim 1 , wherein the content of the 1 claim 1 ,2-diol structural unit with the formula (1) is from 0.1 to 20 mol %.5. The drilling fluid adjusting agent according to claim 1 , further comprising a salt.6. A drilling fluid comprising liquid medium claim 1 , bentonite-based compound claim 1 , and a drilling fluid adjusting agent according to .7. The drilling fluid according to claim 6 , wherein the liquid medium is water-based medium.8. The drilling fluid according to claim 6 , wherein the content of the drilling fluid adjusting agent is from 0.01 to 5%.10. The drilling fluid adjusting agent according to claim 9 , wherein the polyvinyl alcohol-based resin (A) has an average polymerization degree of 500 to 4000.11. The drilling fluid adjusting agent according to claim 9 , wherein the content of the 1 claim 9 ,2-diol structural unit with the formula (1) is from 0.1 to 20 mol %.12. The drilling fluid adjusting agent according to claim 9 , further comprising a salt. The present invention relates to an adjusting agent added to a drilling fluid used for drilling the earth formation in foundation works of civil engineering ...

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Номер записи: 38
08-02-2018 дата публикации

Methods of making and using lignin derivatives

Номер: US20180037598A1
Автор: Chin Li Cheung, Mark Alan HELLE
Принадлежит: NuTech Ventures Inc

Materials and methods for preparing reactive lignin and for preparing a bio-based adhesive are described herein.

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Номер записи: 39
08-02-2018 дата публикации

SURFACTANT COMPOSITIONS

Номер: US20180037794A1
Автор: Dwarakanath Varadarajan, Malik Taimur, Naae Douglas G., Pinnawala Arachchilage Gayani, Winslow Gregory A.
Принадлежит:

Provided herein are novel surfactant compositions and methods having application in a variety of fields including enhanced oil recovery, the cleaning industry as well as groundwater remediation. The surfactant compositions are based on lignin bio-oil with a phenol hydroxyl group as the main functional group. The compositions include carboxylic surfactant s and mixed hydrophilic and hydrophobic surfactant structures, which can be used for the recovery of crude oil compositions from challenging reservoirs. 1. A method of producing a lignin amphiphile from lignin , the method comprising:providing a lignin phenol characterized as having an oxygen content of <=7%, a phenolic to carboxylic ratio ranging from 90:10 to 99:1, and an average molecular weight ranging from 150 to 450, and wherein the lignin phenol is produced in a reduction reaction at a hydrogen partial pressure from about 3.4 MPa (500 psig) to about 15 MPa (2200 psig); andconverting the lignin phenol into the lignin amphiphile in one or more reactions of alkoxylation, alkylation, sulfonation, sulfation, alkoxysulfation, sulfomethylation, sulfoalkylation, carboxylation, carboxymethylation, carboxyalkylation, or combinations thereof.2. The method of claim 1 , wherein the phenolic to carboxylic ratio ranges from 95:2 to 98:2.3. The method of claim 1 , wherein the phenolic to carboxylic ratio ranges from 90:10 to 99:1.4. The method of claim 1 , wherein the lignin phenol is produced in a reduction reaction in the presence of a catalyst of iron oxide; iron sulfides; supported iron oxide catalyst;and iron hydroxide mixed with sulfur, inorganic sulfur compound and organic sulfur compounds.5. The method of claim 1 , wherein the lignin phenol is produced in a reduction reaction in the presence of a reducing agent of carbon monoxide claim 1 , hydrogen claim 1 , hydrogen sulfide claim 1 , or combinations thereof.6. The method of claim 1 , wherein the lignin amphiphile is a co-solvent.7. The method of claim 1 , wherein ...

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Номер записи: 40
08-02-2018 дата публикации

Downhole fluids and methods of use thereof

Номер: US20180037795A1
Автор: B. Raghava Reddy, Jay P. Deville, Lee J. Hall, Peter James Boul, Samuel J. Lewis, Trissa Joseph, Vivek S. Goel, Xiangnan YE, Xueyu Pang
Принадлежит: Halliburton Energy Services Inc

The present disclosure relates to downhole fluid additives including a clay, a hydroxylated polymer, a cation, and water. The disclosure further relates to downhole fluids, including drilling fluids, spaces, cements, and proppant delivery fluids containing such as downhole fluid additive and methods of using such fluids. The downhole fluid additive may have any of a variety of functions in the downhole fluid and may confer any of a variety of properties upon it, such as salt tolerance or desired viscosities even at high downhole temperatures.

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Номер записи: 41
12-02-2015 дата публикации

NOVEL AGENT FOR INHIBITING THE SWELLING OF CLAYS, COMPOSITIONS COMPRISING SAID AGENT AND METHODS IMPLEMENTING SAID AGENT

Номер: US20150041138A1
Автор: Badel Thierry, Cadix Arnaud
Принадлежит:

The present invention concerns the use of a novel additive as an agent for inhibiting the swelling of clays, in particular in the field of boreholes. More specifically, the present invention concerns the use of a specific diamine and diacid salt as an agent for inhibiting the swelling of clays in an aqueous medium, and a drilling or hydraulic fracturing fluid composition comprising the salt according to the invention and methods for drilling or hydraulic fracturing implementing said salt. 1. A method for inhibiting swelling of clays in an aqueous medium , comprising adding to the aqueous medium a salt of a diamine and a dicarboxylic acid according to formula I:{'br': None, 'HOOC-A-COOH\u2003\u2003(I)'}wherein A is a covalent bond or a saturated or unsaturated, linear or branched divalent aliphatic hydrocarbon group that comprises a main linear chain that extends between the two COON end groups of the dicarboxylic acid and comprises from 1 to 3 carbon atoms.2. The method according to claim 1 , wherein the diacid is chosen from malonic acid claim 1 , succinic acid claim 1 , glutaric acid claim 1 , methylmalonic acid claim 1 , dimethylmalonic acid claim 1 , ethylmalonic acid claim 1 , mesaconic acid claim 1 , methylsuccinic acid claim 1 , ethylsuccinic acid claim 1 , maleic acid claim 1 , fumaric acid claim 1 , itaconic acid claim 1 , methylglutaric acid and glutaconic acid.3. The method according to claim 2 , wherein the diacid is chosen from malonic acid claim 2 , succinic acid claim 2 , glutaric acid claim 2 , methylmalonic acid claim 2 , dimethylmalonic acid claim 2 , ethylmalonic acid claim 2 , methylsuccinic acid claim 2 , ethylsuccinic acid and methylglutaric acid.4. The method according to claim 3 , wherein the diacid is chosen from succinic acid claim 3 , glutaric acid and methylglutaric acid.5. The method according to claim 1 , wherein the diamine is a primary diamine of following formula II:{'br': None, 'sub': 2', '2, 'HN—Z—NH\u2003\u2003(II)'}{'sub': '2', ' ...

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Номер записи: 42
06-02-2020 дата публикации

DEVELOPMENT OF ANTI-BIT BALLING FLUIDS

Номер: US20200040247A1
Автор: Al-Yami Abdullah, AlBahrani Hussain, AlHareth Nasser, Awadh Abdulla H., Ba Hamdan Abdulaziz A., Haidary Saleh A., Safran Ali, Wagle Vikrant
Принадлежит: Saudi Arabian Oil Company

Anti-bit balling drilling fluids and methods of making and using drilling fluids are provided. The anti-bit balling drilling fluid contains water, a clay-based component, and at least one of a surfactant having the formula: R—(OCH)—OH, where R is a hydrocarbyl group having from 10 to 20 carbon atoms and x is an integer from 1 and 10, or a polyethylene glycol having the formula: H—(O—CH—CH)—OH, where n is an integer from 1 to 50. Methods of making and using these drilling fluids are also provided. 2. The method of claim 1 , where the surfactant has an HLB of from 8 to 16.3. The method of claim 1 , where R is:an alkyl group comprising 12 to 15 carbons; oran alkenyl group comprising from 12 to 15 carbon atoms.4. The method of claim 1 , where x is from 5 to 10.5. The method of claim 1 , where the surfactant has an HLB of from 13 to 15.6. The method of claim 1 , where the surfactant comprises ethylene oxide condensate of branched isotridecyl alcohol.7. The method of claim 1 , where the polyethylene glycol has a weight average molecular weight of from 300 grams per mol (g/mol) to 500 g/mol claim 1 , as measured according to GPC.8. The method of claim 1 , where the drilling fluid comprises from 28 to 850 lb/bbl water based on total weight of the drilling fluid.9. The method of claim 1 , where the drilling fluid comprises from 28 to 720 lb/bbl of the clay-based component based on total weight of the drilling fluid.10. The method of claim 1 , where the drilling fluid comprises from 0.02 to 180 lb/bbl of the surfactant claim 1 , the polyethylene glycol claim 1 , or both claim 1 , based on total weight of the drilling fluid.11. The method of claim 1 , where the clay-based component comprises one or more components selected from the group consisting of lime (CaO) claim 1 , CaCO claim 1 , bentonite claim 1 , montmorillonite clay claim 1 , barium sulfate (barite) claim 1 , hematite (FeO) claim 1 , mullite (3AlO.2SiOor 2AlO.SiO) claim 1 , kaolin claim 1 , (AlSiO(OH)or kaolinite) ...

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Номер записи: 43
19-02-2015 дата публикации

POLYESTER RESIN COMPOSITION AND MOLDED ARTICLE OF SAME

Номер: US20150051119A1
Автор: KOBAYASHI Takuma, Masaki Takashi, Sato Hiroyuki, Yamazaki Masahiro
Принадлежит:

A polyester resin composition comprising: 100 parts by mass of a polyester resin having at least 50% by mass of a glycolic acid resin; and from 0.5 to 50 parts by mass of a carboxylic acid anhydride. 1. A polyester resin composition comprising: 100 parts by mass of a polyester resin having at least 50% by mass of a glycolic acid resin; and from 0.5 to 50 parts by mass of a carboxylic acid anhydride.2. The polyester resin composition according to claim 1 , wherein the carboxylic acid anhydride is at least one type selected from the group consisting of an aliphatic monocarboxylic acid anhydride claim 1 , an aromatic monocarboxylic acid anhydride claim 1 , an aliphatic dicarboxylic acid anhydride claim 1 , an aromatic dicarboxylic acid anhydride claim 1 , an aromatic tricarboxylic acid anhydride claim 1 , an alicyclic dicarboxylic acid anhydride claim 1 , an aliphatic tetracarboxylic dianhydride claim 1 , and an aromatic tetracarboxylic dianhydride.3. The polyester resin composition according to claim 1 , further comprising from 0.01 to 10 parts by mass of a phosphorus compound per 100 parts by mass of the polyester resin.4. The polyester resin composition according to claim 3 , wherein the phosphorus compound is at least one type of organic phosphorus compound selected from the group consisting of phosphate and phosphite.5. The polyester resin composition according to claim 4 , wherein the organic phosphorus compound has at least one structure selected from the group consisting of a long-chain alkyl group having from 8 to 24 carbons claim 4 , an aromatic ring claim 4 , and a pentaerythritol skeleton.6. A molded article formed from the polyester resin composition described in .7. The molded article according to having any one form selected from powder claim 6 , a pellet claim 6 , a film claim 6 , and a fiber.8. A well-treatment fluid comprising the molded article described in .9. A well-treatment fluid comprising the molded article described in . The present invention ...

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Номер записи: 44
14-02-2019 дата публикации

Aqueous ampholyte polymer containing solutions for subterranean applications

Номер: US20190048246A1
Автор: Hsinchen Chung, Kevin Walter FREDERICK, Michael A. McCabe, Narongsak Tonmukayakul, Randy Jack LOEFFLER, Shih-Ruey Tom CHEN, Xiangnan YE, Yuntao Thomas Hu
Принадлежит: Solvay USA Inc

A aqueous solution that includes water, from 100,000 to 300,000 ppm of dissolved solids, from 0.5 to 3 gallons per thousand gallons of a water-in-oil emulsion, and an inverting surfactant. The water-in oil emulsion includes an oil phase and an aqueous phase where the oil phase is a continuous phase comprising an inert hydrophobic liquid and the aqueous phase is present as dispersed distinct particles in the oil phase. The aqueous phase contains water, a water soluble polymer, and surfactants. The water soluble polymer includes 30 to 50 weight percent of a non-ionic monomer, 5 to 15 weight percent of a sulfonic acid containing monomer, and 40 to 60 weight percent of a cationic monomer. The water soluble polymer makes up from 10 to 35 weight percent of the water-in-oil emulsion.

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Номер записи: 45
05-03-2015 дата публикации

METHODS OF TREATMENT OF A SUBTERRANEAN FORMATION WITH COMPOSITE POLYMERIC STRUCTURES FORMED IN SITU

Номер: US20150060072A1
Автор: Abivin Patrice, Busby Brent, Cambournac Marie, Godoy-Vargas Jazmin, Makarychev-Mikhailov Sergey, Sullivan Philip F.
Принадлежит:

Methods of treating a subterranean formation are disclosed that include placing a treatment fluid into a subterranean formation, the treatment fluid containing a solid agent and one or more polymers capable of consolidating to form a composite polymeric structure at a downhole location. 1. A method for treating a subterranean formation comprising:placing a treatment fluid including at least one or more polymers and a solid agent into a subterranean formation via a wellbore;adjusting at least one parameter of the treatment fluid;exposing the treatment fluid to a shear event; andconsolidating the one or more polymers into at least one composite polymeric structure comprising the solid agent.2. The method of claim 1 , wherein the composite polymeric structure is elongated.3. The method of claim 1 , wherein the at least one parameter being adjusted is selected from the group consisting of a temperature of the treatment fluid claim 1 , an ionic concentration of the treatment fluid claim 1 , a concentration of polyelectrolyte complexes in the treatment fluid claim 1 , a pH of the treatment fluid claim 1 , a hydrophobicity of the one or more polymers claim 1 , a solvent composition of the treatment fluid claim 1 , a crosslinking of the one or more polymers claim 1 , and an average molecular weight of the one or more polymers.4. The method of claim 1 , wherein the at least one parameter is adjusted at a surface of the wellbore before the treatment fluid is placed into the wellbore.5. The method of claim 1 , wherein the at least one parameter is adjusted within the wellbore to consolidate the one or more polymers after the treatment fluid has been placed into the wellbore.6. The method of claim 1 , wherein the exposing the treatment fluid to a shear event to form the composite polymeric structure occurs at a surface of the wellbore before the treatment fluid is placed into the wellbore.7. The method of claim 1 , wherein the exposing the treatment fluid to a shear event to ...

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Номер записи: 46
05-03-2015 дата публикации

Reservoir activated emulsion breaking for lost circulation

Номер: US20150060146A1
Автор: Cameron James Geddes, Patrick Brunelle
Принадлежит: Laricina Energy Ltd, Secure Energy Drilling Services Inc

An oil-in-water emulsion is provided to place a sealant within a subterranean formation by being deployed into the formation to reacte with the formation's included water to break the emulsion, leaving the emulsified components, some of which act as the sealant to form at least a partial seal. The emulsion does not form a seal until emulsified in response to formation water conditions (salinity, pH, calcium ion concentration, temperature), and can be a drilling fluid or a pill during drilling activities.

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Номер записи: 47
10-03-2022 дата публикации

DILUTED MICROEMULSIONS WITH LOW SURFACE TENSIONS

Номер: US20220073812A1
Автор: Forbes Natalie, Hill Randal M., Silas James
Принадлежит: Flotek Chemistry, LLC

Compositions relating to microemulsions or diluted microemulsions for treating gas wells having wellbores and methods related to treating gas wells having wellbores using the same are generally provided. In some embodiments, the microemulsions or diluted microemulsions have an especially low surface tension at a gas well bottom hole temperature and pressure. 1. A microemulsion suitable for treating a gas well , comprising:an aqueous phase;a surfactant; anda non-aqueous phase comprising a combination of solvents comprising a first solvent and a second solvent,wherein the first solvent comprises a methylated cyclic alkane solvent and/or a methyl siloxane solvent of less than or equal to 800 g/mol molecular weight; and{'sub': ['6', '10'], '#text': 'wherein the second solvent comprises a terpene, an alkyl aliphatic carboxylic acid ester, an unsaturated hydrocarbon solvent, an aromatic solvent, a dialkyl ether, a bicyclic hydrocarbon solvent, a C-Clinear or branched alkane solvent, and/or an alcohol.'}2. The microemulsion of claim 1 , wherein the first solvent comprises the methyl siloxane solvent of less than or equal to 800 g/mol molecular weight.3. The microemulsion of claim 1 , wherein the second solvent comprises the terpene claim 1 , and the terpene comprises d-limonene claim 1 , dipentene claim 1 , alpha terpineol claim 1 , alpha-pinene claim 1 , beta-pinene claim 1 , alpha-terpinene claim 1 , alpha-terpinyl acetate claim 1 , menthone claim 1 , cineole claim 1 , citranellol claim 1 , carvone claim 1 , linanool claim 1 , geraniol claim 1 , nopol claim 1 , menthol claim 1 , eucalyptol claim 1 , 1 claim 1 ,8-cineol claim 1 , a terpene containing an aldehyde claim 1 , a terpene containing an ether claim 1 , and/or a terpene containing a ketone.4. The microemulsion of claim 1 , wherein the second solvent comprises the alkyl aliphatic carboxylic acid ester claim 1 , and the alkyl aliphatic carboxylic acid ester comprises butyl 3-hydroxybutyrate claim 1 , isopropyl 3- ...

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Номер записи: 48
02-03-2017 дата публикации

DRILLING FLUID AND METHOD FOR DRILLING IN COAL-CONTAINING FORMATIONS

Номер: US20170058178A1
Автор: SMITH CARL KEITH
Принадлежит:

A drilling fluid and method for drilling in a coal containing formation with a mixed metal-viscosified drilling fluid including at least 0.05% calcium sulfate. 1. A drilling fluid comprising:an aqueous mixture of bentonite and a mixed metal viscosifier with a pH above about pH 10; andat least 0.05% calcium sulfate (w/v).2. The drilling fluid of wherein the drilling fluid comprises 15 to 50 kg/m3 bentonite claim 1 , mixed metal viscosifier at a weight ratio of 1:8 to 1:12 claim 1 , viscosifier to bentonite claim 1 , a base to maintain the pH above about 10.0 and the at least 0.05% calcium sulfate.3. The drilling fluid of wherein the drilling fluid comprises 25 to 45 kg/m3 bentonite claim 1 , mixed metal viscosifier at a weight ratio of 1:9.5 to 1:10.5 claim 1 , viscosifier to bentonite claim 1 , a base to maintain the pH between about 10.5 to 13 and about 0.05 to 1.0% calcium sulfate.4. The drilling fluid of wherein the drilling fluid comprises about 30 to 40 kg/m3 bentonite claim 1 , a mixed metal viscosifier in a quantity of about 1:10 MMO claim 1 , MMH or MMOH to bentonite with a pH controlled to greater than pH 11 and 0.1 to 0.5% calcium sulfate.5. The drilling fluid of wherein the drilling fluid is prepared by:mixing bentonite in water to form a bentonite mixture;adding a mixed metal viscosifier to the bentonite mixture;adjusting pH to greater than about pH 10;adding the calcium sulfate.6. The drilling fluid of further comprising at least one of a fluid loss control additive and/or a lost circulation material.7. The drilling fluid of wherein the drilling fluid includes a yield point of greater than 10 Pa.8. The drilling fluid of wherein the calcium sulfate is in the form of gypsum.9. The drilling fluid of wherein the calcium sulfate concentration is 0.5 to 50 kg/m3.10. The drilling fluid of further comprising an amount of potassium salt selected from the group consisting of potassium sulfate claim 1 , potassium chloride claim 1 , potassium acetate and potassium ...

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Номер записи: 49
02-03-2017 дата публикации

METHOD FOR MAKING AND USING A DRILLING FLUID

Номер: US20170058179A1
Автор: SMITH CARL KEITH, STOIAN STEFAN ALEXANDRU
Принадлежит:

A drilling fluid and method for drilling in a coal containing formation. The method includes: providing a mixed metal-viscosified drilling fluid including at least 1% potassium salt; circulating the drilling fluid through the well; and drilling into a coal seam. 1. A method for drilling in a coal containing a well into a formation , the method comprising:providing a mixed metal-viscosified drilling fluid including bentonite, and a mixed metal viscosifier of inorganic magnesium/aluminum oxides and/or hydroxides and 1% to 10% potassium sulfate (w/v); andcirculating the drilling fluid through the well.2. The method of wherein providing the mixed metal-viscosified drilling fluid includes providing an aqueous-based drilling fluid including 15 to 45 kg/m3 bentonite clay claim 1 , the mixed metal viscosifier at a weight ratio of 1:8 to 1:12 claim 1 , viscosifier to bentonite claim 1 , a base to maintain the pH above about 10.0 and potassium sulfate.3. The method of wherein providing the mixed metal-viscosified drilling fluid includes providing an aqueous-based drilling fluid including about 30 kg/m3 bentonite clay claim 1 , the mixed metal viscosifier in a quantity of about 1:10 mixed metal viscosifier to bentonite with a pH controlled to greater than pH 11 and 1 to 5% potassium sulfate.4. The method of wherein providing the mixed metal-viscosified drilling fluid includes:mixing bentonite clay in water to form a bentonite mixture;adding the mixed metal viscosifier to the bentonite mixture;adjusting pH to greater than above about pH 10;adding the potassium sulfate.5. The method of further comprising adding any of fluid loss control additives and/or lost circulation materials.6. The method of wherein providing the mixed metal-viscosified drilling fluid includes obtaining a drilling fluid with a yield point greater than 10 Pa.7. The method of further comprising continuing circulation with entrained coal fines in the drilling fluid.8. The method of wherein rheology of the ...

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Номер записи: 50
04-03-2021 дата публикации

MICRONIZED LOSS PREVENTION MATERIAL (LPM) FOR PREVENTIVE LOSS CONTROL

Номер: US20210062063A1
Автор: Al-Subaie Turki, AMANULLAH Md
Принадлежит:

A micronized date tree particle mix loss prevention material (LPM) is provided. The micronized date tree particle mix LPM includes date palm seed particles produced from date palm seeds and date tree fiber particles produced from date tree waste such as date tree trunks. The date palm seed particles may have a size in the range of 1 micron to less than 150 microns. The date tree waste fiber particles may have a size in the range of 1 micron to less than 250 microns. Methods of loss prevention and manufacture of a micronized date tree particle mix LPM are also provided. 1. A method to prevent lost circulation of a drilling fluid in a wellbore in a formation , comprising:introducing an altered drilling fluid into the wellbore while drilling such that a loss prevention material (LPM) contacts a loss zone, wherein the altered drilling fluid comprises the drilling fluid and the LPM, wherein the LPM consists of:a first plurality of particles produced from date tree seeds, wherein each of the first plurality of particles produced from date tree seeds has a diameter in the range of 1 micron to less than 150 microns; anda second plurality of particles produced from date tree trunks, wherein each of the first plurality of particles produced from date tree trunks has a diameter in the range of 1 micron to less than 150 microns.2. The method of claim 1 , wherein the altered drilling fluid consists of the drilling fluid and the LPM.3. The method of claim 1 , wherein the drilling fluid comprises a water-based drilling mud or an oil-based drilling mud.4. The method of claim 1 , wherein the first plurality of particles has a concentration of 4 pounds-per-barrel (ppb) in the altered drilling fluid and the second plurality of particles has a concentration of 4 ppb in the altered drilling fluid.5. The method of claim 1 , wherein the first plurality of particles comprises a plurality of untreated particles produced from untreated date tree seeds.6. The method of claim 1 , wherein the ...

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Номер записи: 51
17-03-2022 дата публикации

DOWNHOLE FLUIDS AND METHODS OF USE THEREOF

Номер: US20220081603A1
Автор: Boul Peter James, DEVILLE Jay P., Goel Vivek S., HALL Lee J., JOSEPH Trissa, Lewis Samuel J., Pang Xueyu, Reddy B. Raghava, YE Xiangnan
Принадлежит:

The present disclosure relates to downhole fluid additives including a clay, a hydroxylated polymer, a cation, and water. The disclosure further relates to downhole fluids, including drilling fluids, spaces, cements, and proppant delivery fluids containing such as downhole fluid additive and methods of using such fluids. The downhole fluid additive may have any of a variety of functions in the downhole fluid and may confer any of a variety of properties upon it, such as salt tolerance or desired viscosities even at high downhole temperatures. 133-. (canceled)34. A spacer , comprising:a clay;a hydroxylated polymer;a cation;the clay, the hydroxylated polymer, and the cation together in an amount sufficient to render the downhole fluid thermally stable at a temperature of 400° F.; andat least one additional downhole fluid component.35. The spacer of claim 34 , wherein the clay comprises a phyllosilicate clay.36. The spacer of claim 35 , wherein the phyllosilicate clay comprises a smectite clay claim 35 , a sepiolite clay or a palygorskite clay.37. The spacer of claim 34 , further comprising salt water.38. The spacer of claim 34 , further comprising a surfactant claim 34 , a defoamer claim 34 , a salt claim 34 , a viscosifier or any combinations thereof.39. The spacer of claim 38 , wherein the salt comprises sodium chloride or calcium chloride.40. The spacer of claim 38 , wherein the viscosifier comprises nanoparticles of 100 nm or less in size.41. The spacer of claim 34 , wherein the at least one additional downhole fluid component is an aqueous component with a pH of at least 9.42. The spacer of claim 34 , wherein the spacer has a transition temperature of around 150° F. at which viscosity rapidly increases.43. The spacer of claim 34 , wherein the hydroxylated polymer comprises microcellulose or nanocellulose.44. A system for introducing a spacer into a subterranean formation claim 34 , the system comprising: a clay;', 'a hydroxylated polymer;', 'a cation;', 'the clay ...

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Номер записи: 52
12-03-2015 дата публикации

Oil based mud system

Номер: US20150072904A1
Автор: "DElia Orlando", Guzman Fernando Javier
Принадлежит:

Emulsions usable within a wellbore as drilling fluids can be prepared by adding an internal phase to an external phase to form an emulsion base, and adding solid organophilizated mineral structures, a matrix stabilizing agent, a weighting agent, and a secondary stabilizer to the emulsion base. The solid organophilizated mineral structures stabilize the emulsion base and affect the rheology thereof, and the matrix stabilizing agent and the secondary stabilizer can retain the stability and viscosity of the emulsion base in the presence of hydrophilic solids. In addition to use as a wellbore fluid independently, usable emulsions can be compatible with and combined with traditional emulsions to form a mixture usable within a wellbore a drilling fluid. 1. A method for preparing an emulsion usable within a wellbore , the method comprising the steps of:adding an internal phase to an external phase to form an emulsion base;adding solid organophilizated mineral structures to the emulsion base to stabilize the emulsion base and affect rheology thereof;adding a matrix stabilizing agent to the emulsion base;adding a weighting agent to the emulsion base; andadding a secondary stabilizer to the emulsion base, wherein the matrix stabilizing agent, the secondary stabilizer, or combinations thereof retain stability of the emulsion base in the presence of the weighting agent, formation solids, hydrophilic solids, or combinations thereof.2. The method of claim 1 , wherein the solid organophilizated mineral structures comprise a clay and a cationic amine.3. The method of claim 1 , wherein the matrix stabilizing agent comprises an amphoteric surfactant with a mineral matrix covered with a fatty acid.4. The method of claim 1 , wherein the weighting agent comprises a hydrophilic solid.5. The method of claim 1 , wherein the secondary stabilizer comprises a vegetable oil claim 1 , an animal or plant fat claim 1 , or combinations thereof.6. The method of claim 5 , wherein the animal or plant ...

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Номер записи: 53
11-03-2021 дата публикации

METHOD FOR MAKING AND USING A DRILLING FLUID

Номер: US20210071058A1
Автор: SMITH CARL KEITH, STOIAN STEFAN ALEXANDRU
Принадлежит:

A drilling fluid and method for drilling in a coal containing formation. The method includes: providing a mixed metal-viscosified drilling fluid including at least 1% potassium salt; circulating the drilling fluid through the well; and drilling into a coal seam. 1. A method for producing a drilling fluid for drilling a wellbore , the method comprising:providing a mixed metal-viscosified drilling fluid including clay and a mixed metal viscosifier of inorganic magnesium/aluminum oxides and/or hydroxides;monitoring rheology of the mixed metal-viscosified drilling fluid; and,adding potassium sulfate in an amount of 1%-10% (w/v) to the mixed metal-viscosified drilling fluid to avoid adverse rheological changes.2. The method of wherein providing the mixed metal-viscosified drilling fluid includes mixing an aqueous-based drilling fluid including 15 to 45 kg/mbentonite claim 1 , a mixed metal viscosifier at a weight ratio of 1:8 to 1:12 viscosifier to bentonite and a base to maintain a pH above about 10.0.3. The method of wherein providing the mixed metal-viscosified drilling fluid includes mixing the aqueous-based drilling fluid including about 25 to 45 kg/mbentonite and a mixed metal viscosifier in a quantity of about 1:10 of mixed metal viscosifier to bentonite with a pH controlled to greater than pH 11.4. The method of wherein monitoring rheology includes monitoring for fluid thinning and adding potassium sulfate to avoid adverse rheological changes includes avoiding fluid thinning.5. The method of wherein providing the mixed metal-viscosified drilling fluid includes:mixing the clay in the form of bentonite in water to form a bentonite mixture;adding the mixed metal viscosifier to the bentonite mixture; andadjusting pH to greater than about pH 10.6. The method of further comprising adding any of fluid loss control additives and/or lost circulation materials.7. The method of wherein adding the mixed metal-viscosified drilling fluid includes obtaining a drilling fluid ...

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Номер записи: 54
11-03-2021 дата публикации

CATIONIC AND ANIONIC SHALE INHIBITORS AND CLAY STABILIZERS

Номер: US20210071059A1
Автор: Li Chunli, Ogle James William, Santos Catherine Martin, Xu Liang
Принадлежит:

Compositions and methods of using of such compositions to, for example, inhibit shale are provided. In one embodiment, the methods include introducing an additive including a cationic clay stabilizer and an anionic clay stabilizer into a treatment fluid; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation. In some embodiments, the methods include introducing an additive including a cationic shale inhibitor and an anionic shale inhibitor into a treatment fluid; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation. 1. A method comprising:introducing an additive comprising a cationic shale inhibitor and an anionic shale inhibitor into a treatment fluid, wherein the cationic shale inhibitor is present in the additive at a ratio of about 1:2 to about 1:10 by volume of the anionic shale inhibitor; andintroducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.2. The method of claim 1 , wherein the cationic shale inhibitor is selected from the group consisting of: polydiallyldimethylammonium chloride claim 1 , a cationic polyamine claim 1 , a quaternary ammonium salt claim 1 , and any combination thereof.3. The method of claim 1 , wherein the cationic shale inhibitor comprises a cationic polyamine having a molecular weight of from about 1 claim 1 ,000 g/mol to about 200 claim 1 ,000 g/mol.4. The method of claim 1 , wherein the anionic shale inhibitor comprises a polyacrylamide polymer claim 1 , copolymer claim 1 , or terpolymer.5. The method of claim 1 , wherein the treatment fluid is introduced into at least a portion of the wellbore or subterranean formation having a temperature of 150° F. or higher.6. The method of claim 1 , wherein the additive further comprises a salt selected from the group consisting of: CaCl claim 1 , NaCl claim 1 , KCl claim 1 , CaBr claim 1 , ammonium chloride claim 1 , ammonium ...

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Номер записи: 55
11-03-2021 дата публикации

Drilling fluids and methods of making thereof

Номер: US20210071060A1
Автор: Abdullah Saleh Al-Yami, Ali Radhwan, Jothibasu RAMASAMY, Md Amanullah
Принадлежит: Saudi Arabian Oil Co

Drilling fluids and methods of making and using drilling fluids are provided. The drilling fluid includes an emulsion comprising an oleaginous phase suspended within an aqueous phase, a clay-based component in the aqueous phase, CaCl 2 , KCl, or both in the aqueous phase, and a polyglycerol-fatty acid complex. The polyglycerol-fatty acid complex may be free of covalent crosslinks. The polyglycerol-fatty acid complex may include polyglycerol hydrogen bonded to a fatty acid, and the oleaginous phase may include safra oil and the polyglycerol-fatty acid complex. Methods of producing the drilling fluid include reacting polyglycerol and a fatty acid at a temperature of less than 250° C. thereby forming a polyglycerol-fatty acid complex. The method further includes mixing an aqueous phase, a clay-based component, and the polyglycerol-fatty acid complex to produce a drilling fluid.

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Номер записи: 56
05-06-2014 дата публикации

LOW CONDUCTIVITY WATER BASED WELLBORE FLUID

Номер: US20140151128A1
Автор: Patel Arvind D., Stamatakis Emanuel
Принадлежит: M-I L.L.C.

A low electrical conductivity water-based wellbore fluid for use in drilling wells through a formation containing a clay which swells in the presence of water, said wellbore fluid that includes an aqueous base fluid; and a polymeric non-ionic tertiary amine is disclosed. Methods of using such fluids are also disclosed. 18-. (canceled)9. A method of reducing the swelling of clay in a well comprising: an aqueous base fluid; and', 'a polymeric non-ionic tertiary amine., 'circulating in the well a water based wellbore fluid comprising10. The method of claim 9 , wherein the polymeric non-ionic tertiary amine comprises a condensation reaction product of a tri-hydroxyalkyl amine.12. The method of claim 10 , wherein the tri-hydroxyalkyl amine is selected from the group consisting of trimethanolamine claim 10 , triethanolamine or tripropanolamine.13. The method of claim 9 , wherein the wellbore fluid has an electrical conductivity of less than about 10 claim 9 ,000 μS/cm.14. The method of claim 13 , wherein the wellbore fluid has an electrical conductivity of less than about 2000 μS/cm.15. The method of claim 9 , further comprising:disposing of at least a portion of the wellbore fluid or cuttings on land.16. A method for controlling shale hydration in the drilling of subterranean wells comprising: an aqueous base fluid; and', 'a polymeric non-ionic tertiary amine., 'adding to said well a water-based wellbore fluid comprising17. The method of claim 16 , wherein the polymeric non-ionic tertiary amine comprises a condensation reaction product of a tri-hydroxyalkyl amine.19. The method of claim 17 , wherein the tri-hydroxyalkyl amine is selected from the group consisting of trimethanolamine claim 17 , triethanolamine or tripropanolamine.20. The method of claim 16 , wherein the wellbore fluid has an electrical conductivity of less than about 10 claim 16 ,000 μS/cm.21. The method of claim 20 , wherein the wellbore fluid has an electrical conductivity of less than about 2000 μS/cm. ...

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Номер записи: 57
05-06-2014 дата публикации

PROCESS FOR UPGRADING LOW VALUE RENEWABLE OILS

Номер: US20140154392A1
Автор: Borsinger Gregory G., HASSAN Abbas, Hassan Aziz
Принадлежит: H R D Corporation

Steps in the processing of oils derived from plants or vegetables include the degumming, deodorizing and bleaching of the oil before it can be used for further applications. By eliminating one or more of these steps from the processing of the oil, followed by hydrogenating the oil to a specified degree of hydrogenation, the resulting upgraded oils can be incorporated into products having commercial applications. The process uses a high shear mixing device and a hydrogenation catalyst. The process can utilize a single or multiple high shear devices, and utilize renewable oils instead of increasingly scarce petroleum based products. The resulting hydrogenated products may then be utilized in a variety of other commercial applications, such as to render cellulosic products water resistant, provide a coating for numerous cellulosic products, adhesive compositions, ink compositions, firelog compositions, drilling muds or asphalt modifiers. 1. A hot-melt adhesive composition , the adhesive composition comprising:(a) about 25% to about 35% by weight of a thermoplastic copolymer comprising an ethylene containing copolymer, the copolymer being selected from the group consisting of an ethylene vinyl acetate copolymer, and copolymers and terpolymers thereof,the copolymer having a vinyl acetate content from about 18% to about 28%;(b) about 15% to about 40% by weight of a tackifier resin; and subjecting an oil feedstock and hydrogen to high shear in at least one high shear device; wherein the at least one high shear device comprises a vessel containing the oil feedstock and at least one inlet for a stream comprising hydrogen gas, and comprising an outlet for a dispersion; and', 'forming the dispersion in the high shear device whereby the hydrogen reacts with the oil feedstock to saturate at least a portion of the oil feedstock, whereby the dispersion comprises hydrogen bubbles having an average bubble size of less than about 5 μm., '(c) about 15 to about 35% by weight of an ...

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Номер записи: 58
05-03-2020 дата публикации

SYNTHETIC FUNCTIONALIZED ADDITIVES, METHODS OF SYNTHESIZING, AND METHODS OF USE

Номер: US20200071591A1
Автор: PATEL Hasmukh A., Thaemlitz Carl J.
Принадлежит: Aramco Services Company

Embodiments of the present disclosure are directed to embodiments of synthetic functionalized additives. The synthetic functionalized additive may include a layered magnesium silicate. The layered magnesium silicate may include a first functionalized silicate layer including a first tetrahedral silicate layer covalently bonded to at least two different functional groups, an octahedral brucite layer, including magnesium, and a second functionalized silicate layer including a second tetrahedral silicate layer covalently bonded to at least two different functional groups. The octahedral brucite layer may be positioned between the first functionalized silicate layer and the second functionalized silicate layer. The at least two different functional groups covalently bonded to the first tetrahedral silicate layer may be the same or different than the at least two different functional groups covalently bonded to the second tetrahedral silicate layer. 1. A method of producing a synthetic functionalized additive , the method comprising:mixing a magnesium salt with a fluid medium to produce a magnesium-containing fluid;adding a first silane and a second silane to the magnesium-containing fluid to produce a reactant mix, where the first silane and the second silane have different compositions;adding an aqueous hydroxide to the reactant mix to produce a reaction mixture;mixing the reaction mixture for a mix period;refluxing the reaction mixture for a reflux period to produce a product mix;treating the product mix to separate the synthetic functionalized additive,where the synthetic functionalized additive comprises a layered magnesium having mixed functionalities.2. The method of claim 1 , where the first silane and the second silane are selected from the group consisting of phenyltrimethoxysilane claim 1 , trimethoxy(propyl)silane claim 1 , trimethoxymethylsilane claim 1 , hexadecyltrimethoxysilane claim 1 , octyltriethoxysilane claim 1 , tetraethyl orthosilicate claim 1 , N ...

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Номер записи: 59
12-06-2014 дата публикации

DRAG REDUCING AGENTS FOR OIL- AND SYNTHETIC-BASED FLUIDS

Номер: US20140158360A1
Автор: BLAND RONALD G., CLAPPER DENNIS C., HALLIDAY WILLIAM S.
Принадлежит: BAKER HUGHES INCORPORATED

Minimizing circulating pressure loss and/or reducing friction in drilling fluid operations to minimize equivalent circulating density (ECD) and maximize flow for borehole cleaning, tool optimization and efficient drilling may be achieved by the addition of friction improvers or drag reducers while circulating drilling fluids. Suitable drag reducers may include, but not necessarily be limited to, poly(alpha-olefins); polyisobutylene; condensation polymers of dicarboxylic acids or anhydrides, or polyols and monocarboxylic acids, addition polymers of unsaturated esters; copolymers of alpha-olefins with unsaturated esters; polystyrene acylated with long chain fatty acids; polyalkylene oxides; copolymers of alkyl acrylates with N-containing olefins; and combinations thereof. 1. A method of working on or treating a well in a subterranean formation comprising: an oil selected from the group consisting of naturally-occurring oils, synthetic-based oils and combinations thereof; and', poly(alpha-olefins);', 'polyisobutylene;', 'condensation polymers of monomers selected from the group consisting of monocarboxylic acids, dicarboxylic acids, anhydrides, polyols and combinations thereof;', 'addition polymers of unsaturated esters;', 'copolymers of alpha-olefins with unsaturated esters;', 'polystyrene acylated with long chain fatty acids;', 'polyalkylene oxides;', 'copolymers of alkyl acrylates with N-containing olefins; and', 'combinations thereof; and, 'at least one drag reducing agent in an amount effective to reduce circulating pressure loss and/or friction of the O/SBF, where the drag reducing agent does not possess an electric charge and is selected from the group consisting of], 'pumping an oil/synthetic based fluid (O/SBF) using a pump into a wellbore, where the oil/synthetic based fluid comprisessubjecting the O/SBF to a shearing force.2. The method of where the effective amount of the drag reducing agent in the O/SBF is between about 10 ppm to about 10 lbs/bbl (28.6 g/L ...

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Номер записи: 60
14-03-2019 дата публикации

LUBRICANT FOR WATER BASED DRILLING FLUID

Номер: US20190078009A1
Автор: Chang Zen-Yu, Mettath Sashikumar
Принадлежит:

The invention relates an additive composition for a drilling fluid, as well as a method of increasing the lubricity and reducing the coefficient of friction of a drilling fluid. The additive composition may further contain a sulfurized olefin and/or a metal dithiophosphate compound, which further enhances the lubricating effect. 1. A lubricant additive composition for a water based drilling fluid comprising at least one oligomer , wherein the oligomer comprises the reaction product of:a. at least one hydrocarbyl substituted carboxylic acid or an ester or anhydride thereof; andb. at least one polyalkylene glycol.2. The additive composition of claim 1 , wherein the carboxylic acid of the hydrocarbyl substituted carboxylic acid comprises oxalic acid claim 1 , malonic acid claim 1 , succinic acid claim 1 , glutaric acid claim 1 , adipic acid claim 1 , pimelic acid claim 1 , suberic acid claim 1 , azelic acid claim 1 , sebacic acid claim 1 , undecanedioic acid claim 1 , dodecanedioic acid claim 1 , maleic acid claim 1 , fumaric acid claim 1 , glutaconic acid claim 1 , traumatic acid and muconic acid claim 1 , phthalic acid claim 1 , isophthalic acid claim 1 , terephthalic acid or diphenic acid.3. The additive composition of any of or claim 1 , wherein the hydrocarbyl substituent of the hydrocarbyl substituted carboxylic acid comprises a Cto Cstraight chain or branched alkane or alkene.4. The additive composition of any of to claim 1 , wherein the hydrocarbyl substituted carboxylic acid comprises dodecenyl succinic anhydride.5. The additive composition of any of to claim 1 , wherein the hydrocarbyl substituted carboxylic acid comprises octadecenyl succinic anhydride6. The additive composition of any of to wherein the polyalkylene glycol comprises one or more of polyethylene glycol or polypropylene glycol.7. The additive composition of any of to claim 1 , wherein the polyalkylene glycol comprises diethylene glycol.8. The additive composition of claim 6 , wherein the ...

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Номер записи: 61
31-03-2022 дата публикации

METHODS FOR PRODUCING AN EMULSIFIER SUITABLE FOR USE IN AN EMULSION DRILLING FLUID

Номер: US20220098466A1
Автор: AMANULLAH Md, Ramasamy Jothibasu
Принадлежит: Saudi Arabian Oil Company

According to one or more embodiments of the present disclosure, a method for producing an emulsifier suitable for use in an emulsion drilling fluid may comprise esterifying a processed vegetable oil to produce a first mixture comprising fatty acid alkyl esters. The processed vegetable oil may comprise less than 1 wt. % of compounds having an atmospheric boiling point less than or equal to 150° C. The method may further comprise removing at least 99 wt. % of each of glycerol, water, and short-chain alcohols having a main chain of less than or equal to 12 carbon atoms from the first mixture to produce a modified mixture, and hydrolyzing the fatty acid alkyl esters of the modified mixture with a base to produce the emulsifier comprising at least one salt of a fatty acid. Emulsion drilling fluids comprising the emulsifier and methods of producing emulsion drilling fluids are also disclosed. 1. A method for producing an emulsifier suitable for use in an emulsion drilling fluid , the method comprising:esterifying a processed vegetable oil to produce a first mixture comprising fatty acid alkyl esters, wherein the processed vegetable oil comprises less than 1 wt. % of compounds having an atmospheric boiling point less than or equal to 150° C.;removing at least 99 wt. % of each of glycerol, water, and short-chain alcohols from the first mixture to produce a modified mixture, wherein short-chain alcohols are alcohols having a main chain of less than or equal to 12 carbon atoms; andhydrolyzing the fatty acid alkyl esters of the modified mixture with a base to produce the emulsifier comprising at least one salt of a fatty acid.2. The method of claim 1 , wherein the processed vegetable oil is a previously unprocessed vegetable oil that was used in a food preparation process.3. The method of claim 1 , wherein the processed vegetable oil comprises less than 1 wt. % of 2 claim 1 ,4-decadienal claim 1 , 1-octen-3-ol claim 1 , 2-penten-1-ol claim 1 , nonanal claim 1 , hexanal claim 1 ...

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Номер записи: 62
25-03-2021 дата публикации

Degradable Polymeric Nanoparticles and Uses Thereof

Номер: US20210087454A1
Автор: Guan Hulli, Liang Jenn-Tai
Принадлежит: Texas A&M University

Provided herein are drilling muds, including water-based drilling muds. The components of the drilling muds are a degradable fluid loss additive, for example, synthetic degradable nanoparticles, a clay mineral, for example, a smectite, and a base fluid, for example, water. Also provide are methods for preventing leak-off during a drilling operation and for automatically cleaning-up filter cake after completion of a drilling process both of which utilize the drilling muds and water-based drilling muds. 1. A drilling mud comprising:a degradable fluid loss additive;a clay mineral; anda base fluid.2. The drilling mud of claim 1 , wherein the degradable fluid loss additive is a synthetic degradable polymeric nanoparticle.3. The drilling mud of claim 2 , wherein the synthetic degradable polymeric nanoparticle comprises a plurality of monomers cross-linked by a self-degrading crosslinker.4. The drilling mud of claim 3 , wherein the plurality of monomers comprises 2-acrylamido-2-methylpropane sulfonic acid sodium salt (AMPS) and methacrylic acid.5. The drilling mud of claim 3 , wherein the self-degrading crosslinker is an acrylamide claim 3 , a methacrylamide claim 3 , an acrylate claim 3 , or a methacrylate ester.6. The drilling mud of claim 2 , wherein the synthetic degradable polymeric nanoparticle has a concentration of about 0.21 wt % to about 1.00 wt % in the base fluid.7. The drilling mud of claim 1 , wherein the clay mineral is a smectite claim 1 , a kaolinite claim 1 , an illite claim 1 , a vermiculite claim 1 , a chlorite or a combination thereof.8. The drilling mud of claim 1 , wherein the base fluid is water.9. A water-based drilling mud claim 1 , comprising:a synthetic degradable polymeric nanoparticle having a plurality of monomers crosslinked by a self degrading crosslinker;a smectite; andwater.10. The water-based drilling mud of claim 9 , wherein the plurality of monomers comprises 2-acrylamido-2-methylpropane sulfonic acid sodium salt (AMPS) and methacrylic ...

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Номер записи: 63
25-03-2021 дата публикации

METHODS AND COMPOSITIONS FOR ENHANCING CLAY VISCOSIFIERS

Номер: US20210087455A1
Автор: MAY Preston Andrew
Принадлежит:

Methods and compositions for improving the rheological properties of fluids including sepiolite are provided. In one or more embodiments, the compositions comprise a clay selected from the group consisting of: sepiolite, palygorskite, attapulgite, and a combination thereof; and an extender comprising sodium polyacrylate, wherein the extender is present in an amount from about 0.01 lbs/ton of the clay to about 10 lbs/ton of the clay. In one or more embodiments, the methods comprise introducing a treatment fluid into a wellbore penetrating at least a portion of a subterranean formation, wherein the treatment fluid comprises an aqueous base fluid, a clay selected from the group consisting of: sepiolite, palygorskite, attapulgite, and a combination thereof, and an extender comprising sodium polyacrylate. 1. A method comprising:introducing a treatment fluid into a wellbore penetrating at least a portion of a subterranean formation, wherein the treatment fluid comprises an aqueous base fluid, a clay selected from the group consisting of: sepiolite, palygorskite, attapulgite, and a combination thereof, and an extender comprising sodium polyacrylate.2. The method of claim 1 , wherein the extender is present in an amount from about 0.01 lbs/ton of the clay to about 10 lbs/ton of the clay.3. The method of claim 1 , wherein the extender further comprises an additional component selected from the group consisting of: polyacrylamide claim 1 , magnesium oxide claim 1 , calcium oxide claim 1 , calcium magnesium oxide claim 1 , potassium polyacrylate claim 1 , polyacrylic acid claim 1 , soda ash and any combination thereof.4. The method of claim 1 , wherein the aqueous base fluid is selected from the group consisting of: fresh water claim 1 , salt water claim 1 , brine claim 1 , seawater claim 1 , and any combination thereof.5. The method of claim 1 , wherein the aqueous base fluid comprises one or more salts in an amount of about 50 mg/L of the aqueous base fluid to about 500 ...

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Номер записи: 64
25-03-2021 дата публикации

Stable Emulsion Drilling Fluids

Номер: US20210087456A1
Автор: Miller Jeffrey J., Shumway William Walter
Принадлежит: Halliburton Energy Services, Inc.

A method of reducing a density of a density of a stable emulsion drilling fluid may comprise providing a stable emulsion drilling fluid comprising: an aqueous liquid; a biopolymer; an emulsifier; solid particulates; and an oil; wherein the stable emulsion drilling fluid is capable of remaining in quiescent storage at approximately 70° F. and atmospheric pressure without phase separation for about 8 hours or longer; circulating the stable emulsion drilling fluid though a drill string and annulus; adding additional oil to the stable emulsion drilling fluid to decrease the density of the stable emulsion drilling fluid and produce a reduced density stable emulsion drilling fluid; and circulating the reduced density stable emulsion drilling fluid though the drill string and the annulus. 1. A method of extending a wellbore though a subterranean formation , the method comprising: an aqueous liquid;', 'a biopolymer;', 'an emulsifier;', 'solid particulates; and', 'an oil;, 'providing a stable emulsion drilling fluid comprisingwherein the stable emulsion drilling fluid is capable of remaining in quiescent storage at approximately 100° F. and atmospheric pressure with less than about 5% by volume phase separation for about 24 hours or longer; andcirculating the stable emulsion drilling fluid though a drill string and a bottom hole assembly.2. The method of wherein the aqueous fluid comprises a saturated brine.3. The method of wherein the biopolymer is selected from the group consisting of xanthan gum claim 1 , welan gum claim 1 , guar gum claim 1 , hydroxyethyl cellulose claim 1 , hydroxy-propyl guar claim 1 , carboxy-methyl-hydroxy-propyl guar claim 1 , starches and modified polysaccharides claim 1 , partially-hydrolyzed polyacrylamide claim 1 , diutan gum claim 1 , scleroglucan claim 1 , carboxy-methyl-cellulose claim 1 , polyanionic cellulose claim 1 , and combinations thereof.4. The method of wherein the emulsifier is selected from the group consisting of fatly amines ...

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Номер записи: 65
09-04-2015 дата публикации

Reusable high performance water based

Номер: US20150096808A1
Автор: César Misino, Gaston Wray Curtis, Luc Leoni, Shaohua Lu
Принадлежит: Clearwater International Inc

Compositions emulate oil based fluids include an aqueous phase and an organic internal phase, which creates an osmotic membrane within the aqueous continuous phase. The osmotic membrane allows hydration-dehydration mechanisms to be in place and control interactions between formation and fluid, where the non-aqueous phase is composed of glycerols, polyglycerols, poly hydroxyl alcohols, monosaccharide derivatives, polysaccharide derivatives, or mixtures and combinations thereof, while the aqueous phase contains additives that impart different inhibiting mechanisms to the overall composition, where the additives include, without limitation, amphoteric polymers, potassium and/or sodium salts up to saturation and/or acrylamides.

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Номер записи: 66
19-03-2020 дата публикации

EMULSIFIER COMPOSITIONS FOR INVERT EMULSION FLUIDS AND METHODS OF USING THE SAME

Номер: US20200087560A1
Автор: Al-Yami Abdullah, Wagle Vikrant
Принадлежит: Saudi Arabian Oil Company

Drilling fluid compositions include invert emulsion fluids having an oleaginous phase, an aqueous phase, and an emulsifier composition that includes an ethoxylated alcohol compound and a polyaminated fatty acid compound. The ethoxylated alcohol compound has the formula R—(OCHCH)—OH, where Ris a hydrocarbyl group having from 8 to 22 carbon atoms and n is from 1 to 8. The ethoxylated alcohol compound has a Hydrophilic-Lipophilic Balance (HLB) of less than or equal to 6. The polyaminated fatty acid compound has the formula R—CO—NH—CH—CH—N(COR)—CH—CH—NH—CO—R, where Ris a hydrocarbyl group having from 1 to 20 carbon atoms and Ris a hydrocarbyl group having 1 to 10 carbon atoms or an alkylene carboxylate group having formula —R—COOH, where Ris a saturated or unsaturated hydrocarbylene having from 1 to 10 carbon atoms. Methods of drilling wells include operating a drill in a wellbore in the presence of drilling fluid compositions. 1. A method of drilling a subterranean well , the method comprising: [ [{'br': None, 'sup': '1', 'sub': 2', '2', 'n, 'R—(OCHCH)—OH\u2003\u2003(I)'}, {'sup': '1', 'where Ris a hydrocarbyl group having from 8 to 22 carbon atoms and n is an integer from 1 to 6, the ethoxylated alcohol compound having a Hydrophilic-Lipophilic Balance (HLB) of less than or equal to 6; and'}], 'an ethoxylated alcohol compound having formula (I), [{'br': None, 'sup': 2', '2', '3, 'sub': 2', '2', '2', '2, 'R—CO—NH—CH—CH—N(COR)—CH—CH—NH—CO—R\u2003\u2003(II)'}, {'sup': 2', '3', '4', '4, 'where Ris hydrocarbyl group having from 1 to 20 carbon atoms and Ris a hydrocarbyl group having 1 to 10 carbon atoms or an alkylene carboxylate group having formula —R—COOH, where Ris a saturated or unsaturated hydrocarbylene having from 1 to 10 carbon atoms.'}], 'a polyaminated fatty acid compound having formula (II)], 'operating a drill in a wellbore in the presence of an invert emulsion fluid composition comprising a weighting material and an invert emulsion fluid, the invert emulsion ...

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Номер записи: 67
01-04-2021 дата публикации

DRILLING FLUID COMPRISING A LUBRICANT

Номер: US20210095178A1
Автор: DAVIES Craig Allan, DUNCAN Kevin John, SARGINSON Helen Rachel
Принадлежит:

The present invention provides a drilling fluid comprising a compound c) which comprises a dimer and/or trimer fatty acid residue and an alkyleneoxy chain comprising a first ethyleneoxy section, a second ethyleneoxy section and a propyleneoxy section located between said first and second ethyleneoxy sections, wherein the propyleneoxy section comprises from 1 to 20 propyleneoxy groups. Use of such a drilling fluid to lubricate a drill bit, and a method of drilling a well bore comprising circulating such a drilling fluid, are also provided. 1. A drilling fluid comprising:a) an aqueous brine phase;b) a particulate solid phase;c) a compound comprising a dimer and/or trimer fatty residue and an alkyleneoxy chain comprising a first ethyleneoxy section, a second ethyleneoxy section, and a propyleneoxy section located between the first ethyleneoxy section and the second ethyleneoxy section, wherein the propyleneoxy section comprises from 1 to 20 propyleneoxy groups; andd) optionally, one or more additives selected from rheology modifiers, fluid loss control agents, shale inhibitors, gas hydrate inhibitors and dispersants;wherein the drilling fluid is suitable for lubricating a drill bit during drilling in a geological formation.2. A drilling fluid according to wherein the particulate solid phase comprises barium.3. A drilling fluid according to comprising the particulate solid phase in an amount of from 1 to 75 wt % by weight of the drilling fluid.4. A drilling fluid according to wherein the drilling fluid has a density of at least 1.1 g/cm.5. A drilling fluid according to wherein the aqueous brine phase comprises at least one of:i) dissolved calcium, particularly at a concentration of at least 0.1 molar,ii) dissolved formate, particularly at a concentration of at least 0.5 molar;iii) dissolved silicate, particularly at a concentration of at least 0.4 molar; oriv) brine salts at a concentration of at least 90% by weight of the concentration at saturation.6. A drilling fluid ...

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Номер записи: 68
01-04-2021 дата публикации

BOREHOLE FLUID WITH A THIAMINE-BASED SHALE INHIBITOR

Номер: US20210095179A1
Автор: MAY Preston Andrew
Принадлежит: Halliburton Energy Services, Inc.

A subterranean product extraction composition may include a borehole fluid that may include a thiamine based shale inhibitor active to inhibit reactivity of a formation shale to a base fluid of a borehole fluid. A method of extracting a subterranean product via a borehole may include providing a borehole fluid containing a thiamine-based shale inhibitor and inhibiting reactivity of a formation shale contacted with the borehole fluid. A system for extracting a subterranean product via a borehole may include a tubular having an end in proximity to a formation shale and in fluid communication with a container dispensing a borehole fluid containing a thiamine-based shale inhibitor. The thiamine-based shale inhibitor is inert to the borehole fluid and has superior activity as compared to potassium chloride to inhibit shale reactivity. The borehole fluid may be a drilling fluid. The base fluid may be water. 1. A method of extracting a subterranean product via a borehole in a formation comprising:placing a borehole fluid containing a base fluid and a thiamine-based shale inhibitor in the borehole;contacting the borehole fluid with shale in the formation; andinhibiting reactivity of the shale to the base fluid with the thiamine-based shale inhibitor.2. The method of claim 1 , wherein the thiamine-based shale inhibitor comprises a cationic amine.3. The method of claim 2 , wherein the thiamine-based shale inhibitor is selected from the group consisting of thiamine claim 2 , thiamine derivatives claim 2 , and combinations thereof.4. The method of claim 3 , wherein the thiamine-based shale inhibitor is selected from the group consisting of thiamine claim 3 , thiamine monophosphate claim 3 , thiamine diphosphate claim 3 , thiamine triphosphate claim 3 , and combinations thereof.5. The method of claim 3 , wherein the thiamine-based shale inhibitor comprises an anion.6. The method of claim 5 , wherein the anion is selected from the group consisting of chloride claim 5 , bromide ...

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Номер записи: 69
12-05-2022 дата публикации

STABLE MAGNETIC DRILLING MUD AND METHOD

Номер: US20220145158A1
Автор: GHUMARE Anant, Liu Qi, Santamarina Juan Carlos
Принадлежит:

A magnetic drilling mud for use in a well, the magnetic drilling mud including water; bentonite; magnetic micro-particles; and an anionic surfactant that prevents separation of the bentonite and the magnetic micro-particles in the water. The magnetic micro-particles have a diameter less than 100 μm. 1. A magnetic drilling mud for use in a well , the magnetic drilling mud comprising:water;bentonite;magnetic micro-particles; andan anionic surfactant that prevents separation of the bentonite and the magnetic micro-particles in the water,wherein the magnetic micro-particles have a diameter less than 100 μm.2. The magnetic drilling mud of claim 1 , wherein the anionic surfactant has a molecular concentration smaller than or equal to a critical micelle concentration of the anionic surfactant.3. The magnetic drilling mud of claim 1 , wherein the anionic surfactant is sodium dodecyl sulfate (SDS).4. The magnetic drilling mud of claim 3 , wherein the SDS has a molar concentration between 4 and 8 mM.5. The magnetic drilling mud of claim 4 , wherein the magnetic micro-particles are FeO.6. The magnetic drilling mud of claim 5 , wherein the FeOmicro-particles have a diameter of 50 μm.7. The magnetic drilling mud of claim 6 , wherein a concentration of the FeOmicro-particles is less than 10% of a total volume of the magnetic drilling mud.8. A method for making a magnetic drilling mud for use in a well claim 6 , the method comprising:adding bentonite to water to obtain a mixture;aging the mixture by exposing the mixture to a temperature larger than a room temperature;adding magnetic micro-particles to the mixture; andadding an anionic surfactant that prevents separation of the bentonite and the magnetic micro-particles in the water,wherein the magnetic micro-particles have a diameter less than 100 μm, andwherein the anionic surfactant has a molecular concentration smaller than or equal to a critical micelle concentration of the anionic surfactant.9. The method of claim 8 , wherein ...

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Номер записи: 70
28-03-2019 дата публикации

DISPERSANT IN CEMENT FORMULATIONS FOR OIL AND GAS WELLS

Номер: US20190092996A1
Автор: Al-Yami Abdullah, AlBahrani Hussain, Safran Ali, Wagle Vikrant
Принадлежит: Saudi Arabian Oil Company

Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries are provided. The cement slurries have, among other attributes, improved rheology, such as improved flowability and pumpability and may be used, for instance, in the oil and gas drilling industry. The cement slurry contains water, a cement precursor material and a surfactant having the formula R—(OCH)—OH where R is a hydrocarbyl group comprising from 10 to 20 carbon atoms and x is an integer from 1 and 10. The cured cement have improved strength and density properties due to reduced fluid loss and even placement during curing. The cured cement contains a surfactant having the formula R—(OCH)—OH where R is a hydrocarbyl group comprising from 10 to 20 carbon atoms and x is an integer from 1 and 10. 1. A cement slurry comprising:water;a cement precursor material; anda surfactant having a HLB of from 12 to 13.5.2. The cement slurry of claim 1 , where the cement slurry contains from 10 to 70 wt % BWOC (By Weight Of Cement Precursor) water.3. The cement slurry of claim 1 , where the cement slurry contains from 10 to 90 wt % BWOC of the cement precursor material.4. The cement slurry of claim 1 , where the cement slurry contains from 0.1 to 10 wt % BWOC of the surfactant.5. The cement slurry of claim 1 , where the cement slurry contains from 0.1 to 10 wt % BWOC of one or more additives selected from the group consisting of accelerators claim 1 , retarders claim 1 , extenders claim 1 , weighting agents claim 1 , fluid loss control agents claim 1 , lost circulation control agents claim 1 , antifoaming agents claim 1 , and combinations of these.6. The cement slurry of claim 1 , where the cement precursor material is a hydraulic or a non-hydraulic cement precursor.7. The cement slurry of claim 1 , where the cement precursor material is a hydraulic cement precursor.8. The cement slurry of claim 1 , where the cement precursor material comprises one or more components selected ...

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Номер записи: 71
28-03-2019 дата публикации

Random Copolymer and Preparation Method Thereof, and Drilling Fluid

Номер: US20190092997A1
Автор: He Jian, JIN Junbin, LIN Yongxue, Wang Haibo, WANG Lin, YANG Fan, YANG Xiaohua
Принадлежит:

A random copolymer, a preparation method of the random copolymer, a drilling fluid containing the random copolymer. The random copolymer contains structural unit (A) represented by formula (1), structural unit (B) represented by formula (2), structural unit (C) represented by formula (3), and structural unit (D) represented by formula (4) or (5): 2. The random copolymer according to claim 1 , wherein the apparent viscosity of water solution of the random copolymer at 1 wt % concentration is 10-40 mPa·s.3. The random copolymer according to claim 1 , wherein based on the total weight of the random copolymer claim 1 , the random copolymer contains 30-50 wt % structural unit (A) claim 1 , 40-60 wt % structural unit (B) claim 1 , 2-10 wt % structural unit (C) claim 1 , and 1-10 wt % structural unit (D).4. The random copolymer according to claim 3 , wherein the random copolymer contains 35-45 wt % structural unit (A) claim 3 , 45-55 wt % structural unit (B) claim 3 , 3-8 wt % structural unit (C) claim 3 , and 2-6 wt % structural unit (D).7. The method according to claim 6 , wherein the monomers are dosed as follows: the monomer (a) is 20-50 pbw claim 6 , the monomer (b) is 40-70 pbw claim 6 , the monomer (c) is 1-10 pbw claim 6 , and the monomer (d) is 0.5-8 pbw.8. The method according to claim 7 , wherein the monomers are dosed as follows: the monomer (a) is 35-42 pbw claim 7 , the monomer (b) is 45-55 pbw claim 7 , the monomer (c) is 3-7 pbw claim 7 , and the monomer (d) is 1-5 pbw.10. The method according to claim 6 , wherein the initiator is selected from oxidation-reduction initiators and/or azo initiators.11. The method according to claim 6 , wherein the total dose of the initiator is 0.1-1.6 wt % of the total weight of all monomers.12. The method according to claim 11 , wherein the total dose of the initiator is 0.3-1.5 wt % of the total weight of all monomers.13. The method according to claim 6 , wherein the method for free radical copolymerization reactions of ...

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Номер записи: 72
16-04-2015 дата публикации

VISCOELASTIC SURFACTANT BASED WELLBORE FLUIDS AND METHODS OF USE

Номер: US20150101805A1
Автор: EVANS Frank E., Moore LaTosha, Svoboda Charles
Принадлежит:

A wellbore fluid that includes an aqueous based fluid; an amphoteric, viscoelastic surfactant; and a modified starch is disclosed. Methods of drilling subterranean wells, methods of reducing the loss of fluid out of subterranean wells, and methods of completing wellbores using aqueous-based fluids having an ampoteric, viscoelastic surfactant and a modified starch are also disclosed. 110-. (canceled)11. A method of drilling a subterranean well , comprising: an aqueous based continuous phase;', 'an amphoteric, viscoelastic surfactant; and', 'a modified starch., 'drilling the subterranean well using a rotary drilling rig and circulating a wellbore fluid in the subterranean well, wherein the wellbore fluid comprises12. The method of claim 11 , wherein the wellbore fluid is used to drill a producing interval of the well.13. The method of claim 12 , wherein a different wellbore fluid is used to drill the well prior to the producing interval.15. The method of claim 11 , wherein the modified starch comprises at least one of corn claim 11 , wheat claim 11 , rice claim 11 , tapioca claim 11 , sago claim 11 , waxy maize claim 11 , waxy rice claim 11 , sorghum claim 11 , potato claim 11 , and pea as a starch source.16. A method of reducing the loss of fluid out of a subterranean well claim 11 , comprising: an aqueous based continuous phase;', 'an amphoteric, viscoelastic surfactant; and', 'a modified starch., 'injecting into the subterranean well a wellbore fluid comprising18. The method of claim 16 , wherein the modified starch comprises at least one of corn claim 16 , wheat claim 16 , rice claim 16 , tapioca claim 16 , sago claim 16 , waxy maize claim 16 , waxy rice claim 16 , sorghum claim 16 , potato claim 16 , and pea as a starch source.19. A method of completing a wellbore claim 16 , comprising: an aqueous based continuous phase;', 'an amphoteric, viscoelastic surfactant; and', 'a modified starch;, 'drilling the wellbore with a wellbore fluid to form a filter cake on the ...

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Номер записи: 73
26-03-2020 дата публикации

METHODS OF MAKING AND USING LIGNIN DERIVATIVES

Номер: US20200095270A1
Автор: Cheung Chin Li, Helle Mark Alan
Принадлежит:

Materials and methods for preparing reactive lignin and for preparing a bio-based adhesive are described herein. 1. A bioadhesive comprising an epoxidized vegetable oil and a vinyl sulfone precursor.2. The bioadhesive of claim 1 , wherein the vegetable oil is selected from the group consisting of soybean oil claim 1 , peanut oil claim 1 , canola oil claim 1 , crambe oil claim 1 , lesquerella oil claim 1 , meadowfoam oil claim 1 , rapeseed oil claim 1 , sunflower oil claim 1 , tall oil claim 1 , sesame oil claim 1 , corn oil claim 1 , linseed oil claim 1 , and combinations thereof.3. A method of making a bioadhesive claim 1 , comprising combining an epoxidized vegetable oil with a vinyl sulfone precursor claim 1 , thereby making a bioadhesive.4. The method of claim 3 , wherein the combining is performed under basic conditions.5. The method of claim 4 , wherein the basic conditions comprise a pH of between about 8 and about 10.6. The method of claim 3 , wherein the combining is performed under mild heat.7. The method of claim 6 , wherein the mild heat comprises a temperature of about 35° C. to about 85° C.8. The method of claim 3 , wherein the combining is performed in the absence of an organic solvent.9. A method of making a biocomposite material claim 1 , comprising combining the bioadhesive of with a natural material to form a biocomposite material.10. The method of claim 9 , wherein the natural material is selected from the group consisting of wood shavings claim 9 , wood chips claim 9 , wood particles claim 9 , pinewood shavings claim 9 , hemp claim 9 , waste cotton claim 9 , other crop wastes.11. The method of claim 9 , wherein the bio-composite material is selected from the group consisting of wood composite boards claim 9 , particle board claim 9 , plywood claim 9 , packaging materials and edible adhesives.12. The method of claim 9 , wherein the bio-composite material is selected from the group consisting of absorbents claim 9 , super-absorbents claim 9 , bio- ...

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Номер записи: 74
26-03-2020 дата публикации

DEVELOPMENT OF ANTI-BIT BALLING FLUIDS

Номер: US20200095491A1
Автор: Al-Yami Abdullah, AlBahrani Hussain, AlHareth Nasser, Awadh Abdulla H., Ba Hamdan Abdulaziz A., Haidary Saleh A., Safran Ali, Wagle Vikrant
Принадлежит: Saudi Arabian Oil Company

Anti-bit balling drilling fluids and methods of making and using drilling fluids are provided. The anti-bit balling drilling fluid contains water, a clay-based component, and at least one of a surfactant having the formula: R—(OCH)—OH, where R is a hydrocarbyl group having from 10 to 20 carbon atoms and x is an integer from 1 and 10, or a polyethylene glycol having the formula: H—(O—CH—CH)—OH, where n is an integer from 1 to 50. Methods of making and using these drilling fluids are also provided. 1. A method for using a drilling fluid in drilling operations , the method comprising: {'br': None, 'sub': 2', '4', 'x, 'R—(OCH)—OH\u2003\u2003Formula (I)'}, 'mixing water, a clay-based component, and a surfactant comprising Formula (I)where R is a hydrocarbyl group having from 10 to 20 carbon atoms,x is an integer from 1 and 10, andintroducing the drilling fluid to a subterranean formation.2. The method of claim 1 , where introducing the drilling fluid comprises injecting the drilling fluid and at least partially circulating the drilling fluid within the subterranean formation.3. The method of claim 1 , where the surfactant has an HLB of from 8 to 16.4. The method of claim 1 , where the drilling fluid comprises from 28 to 850 lb/bbl water claim 1 , from 28 to 720 lb/bbl of the clay-based component based on total weight of the drilling fluid claim 1 , and from 0.02 to 180 lb/bbl of the surfactant based on total weight of the drilling fluid.5. The method of claim 1 , where the drilling fluid has an accretion percentage of less than or equal to 18%.6. The method of claim 1 , where R is:an alkyl group comprising 12 to 15 carbons; oran alkenyl group comprising from 12 to 15 carbon atoms.7. The method of claim 1 , where x is from 5 to 10.8. The method of claim 1 , where the surfactant has an HLB of from 13 to 15.9. The method of claim 1 , where the surfactant comprises ethylene oxide condensate of branched isotridecyl alcohol.10. The method of claim 1 , where the drilling fluid ...

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Номер записи: 75
26-03-2020 дата публикации

CONFORMANCE CONTROL AND SELECTIVE BLOCKING IN POROUS MEDIA THROUGH DROPLET-DROPLET INTERACTIONS IN NANOPARTICLE STABILISED EMULSIONS

Номер: US20200095495A1
Автор: Bryant Steven, Pandey Aseem, Telmadarreie Ali, Trifkovic Milana
Принадлежит:

Processes are provided for conformance control in an enhanced oil recovery operation. These processes may for example provide for the use of cellulose nanocrystals (CNCs), for example desulfated CNCs, or chitin nanoparticles, for example having an average maximum dimension of ≤1 μm. These CNCs or chitin nanoparticles may be used to generate a CNC-stabilized oil in water emulsion, which may then be injecting into a zone of a porous subsurface formation. The injected CNC or chitin-stabilized emulsion may be allowed to form strong droplet networks with by resting in situ in the zone of the porous subsurface formation, so as to increase the viscosity of the rested injected CNC or chitin-stabilized emulsion. These emulsions may be used as a selective phase blocking agent or relative permeability modifier, as the strength of the droplet network is governed by the dielectric constant of the surrounding fluid. 1. A process for conformance control in an enhanced oil recovery operation , comprising:providing prepared cellulose nanocrystals (CNC) that are salted or desulfated, or chitin nanoparticles, having an average maximum dimension of ≤1 μm.generating a CNC or chitin-stabilized oil in water emulsion from the prepared CNC;injecting the CNC or chitin-stabilized emulsion into a zone of a porous subsurface formation; and,resting the injected CNC or chitin-stabilized emulsion in situ in the zone of the porous subsurface formation so as to increase the viscosity of the rested injected CNC or chitin-stabilized emulsion.2. The process of claim 1 , wherein sulfated cellulose nanocrystals are desulfated by treatment with a desulfating acid to provide the prepared CNC.3. The process of claim 2 , wherein the desulfating acid comprises hydrochloric acid or sulfuric acid.4. The process of claim 1 , wherein the cellulose nanocrystals have a rod-shaped morphology.5. The process of claim 4 , wherein the rod-shaped cellulose nanocrystals have an average length of less than about 900 claim ...

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Номер записи: 76
20-04-2017 дата публикации

Mixing and Injecting Fiber-based Stimulation Fluids

Номер: US20170107788A1
Автор: Mustapha Abbad, Stephen Dyer
Принадлежит: Schlumberger Technology Corp

An emulsion is mixed with fibers while the emulsion is moving through a surface tubing using a venturi. The fiber/emulsion mixture is injected into a pressurized tank and the pressurized fiber/emulsion mixture is injected from the pressurized tank into a desired location in a wellbore. Pumps and pressure boosters may be used to move the fluid.

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Номер записи: 77
26-04-2018 дата публикации

Reverse Emulsion-based Slick Water Concentration System with Drag Reduction, Flow Back Enhancement and Clay Stabilization Functions

Номер: US20180112119A1
Автор: Jun Wu, Wei-Chu Yu
Принадлежит: Yangtze University

A reverse emulsion-based slick water concentration system, wherein the reverse emulsion is obtained by dispersing an aqueous phase A to an oil phase B under mechanical agitation; wherein the aqueous phase A is composed of a water-soluble monomer A1, a water-soluble fluorocarbon surfactant A2, a water-soluble quaternary ammonium clay stabilizer A3 and water A4; wherein the oil phase B comprises an oil-soluble dispersant/surfactant Bi, an oil-soluble radical initiator B2 and a hydrophobic solvent B3 as a dispersing medium; wherein, the percentages of each component described above, relative to the total weight of the reaction system is as the following: water-soluble monomer A1: 5.0-30.0%; water-soluble fluorocarbon surfactant A2: 0.1-5.0%; water-soluble quaternary ammonium clay stabilizer A3: 0.1-15.0%; water A4: 5.0-35.0%; oil-soluble dispersant/surfactant B1: 0.1-5.0%; oil-soluble radical initiator B2: 0.000001-0.100%; hydrophobic solvent B3: remainder.

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Номер записи: 78
27-04-2017 дата публикации

WATER-BASED DRILLING FLUID FOR REDUCING BITUMEN ACCRETION

Номер: US20170114265A1
Автор: MA Kuangbiao
Принадлежит:

A drilling fluid for reducing bitumen accretion to wellbore drilling components is provided. The drilling fluid includes an anti-accretion additive including a soluble polyamino acid. In various embodiments, the soluble polyamino acid is an alkali metal salt of a polyamino acid, an example being sodium salt of polyaspartic acid. Further, the drilling fluid may be an aqueous-based drilling fluid. The soluble polyamino acid may alternatively or additionally include one or more of a homo-polymer of amino acids, a sequential co-polymer of amino acids, or a random co-polymer of amino acids. The drilling fluids may be used in a method for reducing bitumen accretion to wellbore drilling components. 1. A drilling fluid for reducing bitumen accretion to wellbore drilling components , comprising an anti-accretion additive , the anti-accretion additive comprising a soluble polyamino acid.2. The drilling fluid of claim 1 , wherein the soluble polyamino acid is an alkali metal salt of a polyamino acid.3. The drilling fluid of claim 1 , wherein the drilling fluid is an aqueous-based drilling fluid.4. The drilling fluid of claim 1 , wherein the soluble polyamino acid comprises one or more of a homo-polymer of amino acids claim 1 , a sequential co-polymer of amino acids claim 1 , or a random co-polymer of amino acids.5. The drilling fluid of claim 1 , wherein the soluble polyamino acid is sodium salt of polyaspartic acid.6. The drilling fluid of claim 1 , wherein the molecular weight of the soluble polyamino acid is from about 500 to about 50 claim 1 ,000 Dalton.7. The drilling fluid of claim 6 , wherein the molecular weight of the soluble polyamino acid is from about 500 to about 25 claim 6 ,000 Dalton.8. The drilling fluid of claim 6 , wherein the molecular weight of the soluble polyamino acid is from about 1 claim 6 ,000 to about 5 claim 6 ,000 Dalton.9. The drilling fluid of claim 1 , wherein the soluble polyamino is present in an amount of from about 0.05 to about 25% by ...

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Номер записи: 79
03-05-2018 дата публикации

RESERVOIR PROTECTING AGENT COMPOSITION FOR RESERVOIR WITH CRACKS, DRILLING FLUID CONTAINING THE SAME AND USE THEREOF

Номер: US20180118993A1
Автор: Liu Jingping, LV Kaihe, SUN Jinsheng
Принадлежит: CHINA UNIVERSITY OF PETROLEUM (EAST CHINA)

The present invention relates to the technical field of petroleum drilling, discloses a reservoir protecting agent composition for reservoir with cracks, a drilling fluid containing the same and use thereof. The reservoir protecting agent composition contains an elastic polymer particle, and at least one of a synthetic fiber and a film-forming agent; the elastic polymer particle contains an intermediate product, base, salt and water with specific amounts; and the intermediate product is made of raw materials comprising acrylamide, a cationic monomer, a cross-linking agent, an initiator, a toughening material and water with specific amounts. The reservoir protecting agent composition of the present invention can effectively prevent the drilling fluid from invading the reservoir with cracks, and rapidly block off cracks in the reservoir with cracks. The reservoir protecting agent composition has a high blocking rate and the blocking layer is easily flowback and has advantages such as easy use, good environmental protection performances, and good protection performances for the reservoir. 1. A reservoir protecting agent composition , wherein the reservoir protecting agent composition contains an elastic polymer particle , and at least one of a synthetic fiber and a film-forming agent ,wherein the elastic polymer particle comprises an intermediate product, base, salt and water, and based on 100 parts by weight of the elastic polymer particle, the intermediate product is present in 5-40 parts by weight, the base is present in 1-10 parts by weight, and the salt is present in 1-12 parts by weight, andwherein the intermediate product is prepared by raw materials comprising acrylamide, a cationic monomer, a cross-linking agent, an initiator, a toughening material and water, and based on 100 parts by weight of the raw materials, the acrylamide is present in 8-30 parts by weight, the cationic monomer is present in 1-10 parts by weight, the cross-linking agent is present in 0. ...

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Номер записи: 80
25-04-2019 дата публикации

STAR-SHAPED POLYACRYLAMIDE COPOLYMER AND PREPARATION METHOD THEREOF AND DRILLING FLUID INCLUDING THE COPOLYMER

Номер: US20190119550A1
Автор: Luo Zhihua, Wang Yu, Wang Ziming, Xia Bairu, Xing Xuesong, Yu Peizhi
Принадлежит:

A star-shaped polyacrylamide copolymer and a preparation method thereof are provided, as well as a drilling fluid containing the star-shaped polyacrylamide copolymer. Only the star-shaped polyacrylamide copolymer is added into the drilling fluid; under a high-temperature environment, the filtration volume of the drilling fluid can be reduced, the high-temperature rheological property of the drilling fluid is improved, and the pressure loss of a circulation system of the drilling fluid is reduced. 2. A synthesizing method of synthesizing the star polyacrylamide copolymer of claim 1 , the synthesizing method comprising:mixing pyromellitic dianhydride, azo-4-cyano-pentanol, tetrahydrofuran, a nucleophilic catalyst and a dehydrating agent for an esterification reaction to obtain a tetrafunctional initiator; andmixing the tetrafunctional initiator, water, acrylamide and 2-acrylamido-2-methylpropanesulfonic acid for a copolymerization reaction under an oxygen-free condition to obtain the star-shaped polyacrylamide copolymer having a structure shown in Formula I.3. The synthesizing method of claim 2 , wherein a time of the esterification reaction is 24-36 hours.4. The synthesizing method of claim 2 , wherein the nucleophilic catalyst is 4-dimethylaminopyridine claim 2 , and the dehydrating agent is 1 claim 2 ,3-dicyclohexylcarbodiimide.5. The synthesizing method of claim 4 , wherein a time of the esterification reaction is 24-36 hours.6. The synthesizing method of claim 2 , wherein a dosage ratio of pyromellitic dianhydride claim 2 , azo-4-cyano-pentanol claim 2 , tetrahydrofuran claim 2 , the nucleophilic catalyst and the dehydrating agent is 1 g:(2-4)g:(10-15) ml:(0.05-0.1)g:(0.25-0.5)g.7. The synthesizing method of claim 4 , wherein a time of the esterification reaction is 24-36 h.8. The synthesizing method of claim 2 , wherein the dosage ratio of tetrafunctional initiator claim 2 , water claim 2 , acrylamide claim 2 , and 2-acrylamido-2-methylpropanesulfonic acid is (0 ...

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Номер записи: 81
25-08-2022 дата публикации

LUBRICANT FORMULATION FOR MULTIPLE WATER-BASED MUDS

Номер: US20220267693A1
Автор: AMANULLAH Md, Radhwan Ali, Ramasamy Jothibasu
Принадлежит: Saudi Arabian Oil Company

Provided is a lubricant, which may include a mixture of alkyl-esterified fatty acids from waste vegetable oil and a C8/C10 fatty acid blend. The C8/C10 fatty acid blend may include a caprylic fatty acid (C8) and a capric fatty acid (C10). Provided is a method of preparing a lubricant, which may include providing alkyl-esterified fatty acids from waste vegetable oil and a C8/C10 fatty acid blend, and mixing them such that a homogeneous lubricant composition forms. Further provided is a water-based mud, which may include an aqueous base solution and a lubricant composition. Further provided is a method off preparing the water-based mud, which may include providing an aqueous base solution and a lubricant composition and mixing them such that the water-based mud forms. Further provided is a method of using a water-based mud, which may include introducing into a wellbore the water-based mud comprising a lubricant composition. 1. A lubricant comprising a mixture of:alkyl-esterified fatty acids from waste vegetable oil; anda C8/C10 fatty acid blend comprising a caprylic fatty acid (C8) and a capric fatty acid (C10),wherein the mixture has an acid content of less than about 1.5 mg KOH/g of the mixture (milligram of potassium hydroxide per gram of the mixture of the alkyl-esterified fatty acids and the C8/C10 fatty acid blend).2. The lubricant of claim 1 , wherein the alkyl-esterified fatty acids from the waste vegetable oil is at a volume percent in a range of from about 50% to about 90% of the lubricant.3. The lubricant of claim 1 , wherein the C8/C10 fatty acid blend is at a volume percent in a range of from about 10% to about 50% of the lubricant.4. The lubricant of claim 1 , wherein the caprylic fatty acid (C8) is in a range of from about 50% by volume to about 60% by volume of the C8/C10 fatty acid blend.5. The lubricant of claim 1 , wherein the capric fatty acid (C10) is in a range of from about 40% by volume to about 50% by volume of the C8/C10 fatty acid blend.6. ...

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Номер записи: 82
16-04-2020 дата публикации

PLUGGING AGENT FOR TEMPERATURE-RESISTANT CALCIUM-RESISTANT WATER-BASED DRILLING FLUID USED IN OIL AND GAS RESERVOIR PROTECTION, DRILLING FLUID, AND USES THEREOF

Номер: US20200115611A1
Автор: Guo Lei, Li Dongyang, Li Long, LI Lulu, Liu Jingping, Yang Yuping, ZHANG Wei
Принадлежит:

The present invention relates to the technical field of well drilling, and discloses a plugging agent for temperature-resistant calcium-resistant water-based drilling fluid used in oil and gas reservoir protection, a drilling fluid, and uses of the plugging agent and the drilling fluid. The plugging agent for temperature-resistant calcium-resistant water-based drilling fluid used in oil and gas reservoir protection contains acrylamide-diallyldimethylammonium chloride copolymer modified graphene, wherein in the acrylamide-diallyldimethylammonium chloride copolymer, a molar ratio of structural units provided by acrylamide to structural units provided by diallyldimethylammonium chloride is 1:5-15, and the number-average molecular weight of the acrylamide-diallyldimethylammonium chloride copolymer is 15,000-30,000. The water-based drilling fluid described in the present invention is especially applicable to well drilling in deep salt-gypsum formations, and can exhibit good filtrate reducing, plugging, temperature-resistant, anti-collapsing, and reservoir protection performance. 1. A method for preparing acrylamide-diallyldimethylammonium chloride copolymer modified graphene comprising: dispersing graphene oxide by ultrasonic dispersion in water to obtain a dispersion , and making the dispersion to react with acrylamide-diallyldimethylammonium chloride copolymer and hydrazine hydrate , wherein in the acrylamide-diallyldimethylammonium chloride copolymer , the molar ratio of structural units provided by acrylamide to structural units provided by diallyldimethylammonium chloride is 1:(5-15); the number-average molecular weight of the acrylamide-diallyldimethylammonium chloride copolymer is 15 ,000-30 ,000.2. The method according to claim 1 , wherein the molar ratio of structural units provided by acrylamide to structural units provided by diallyldimethylammonium chloride is 1:(8-10).3. The method according to claim 1 , wherein the number-average molecular weight of the ...

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Номер записи: 83
16-04-2020 дата публикации

FILTRATE REDUCER FOR TEMPERATURE-RESISTANT CALCIUM-RESISTANT WATER-BASED DRILLING FLUID USED IN OIL AND GAS RESERVOIR PROTECTION, DRILLING FLUID, AND USES THEREOF

Номер: US20200115612A1
Автор: Fang Pingliang, Hao Weiwei, Li Long, Liu Jingping, Liu Yushuang, Wang Ying, Yang Yuping, ZHANG Wei, Zhang Yan
Принадлежит:

The present invention relates to the technical field of petroleum and natural gas well drilling, and discloses a filtrate reducer for temperature-resistant calcium-resistant water-based drilling fluid used in oil and gas reservoir protection, a drilling fluid, and uses of the filtrate reducer and the drilling fluid. The filtrate reducer for temperature-resistant calcium-resistant water-based drilling fluid used in oil and gas reservoir protection contains structural units represented by formula (1), structural units represented by formula (2), and structural units represented by formula (3), wherein the mass ratio of the structural units represented by formula (1) to the structural units represented by formula (2) to the structural units represented by formula (3) is (0.1-0.2):1:(0.05-0.1), and the number-average molecular weight of the filtrate reducer is 10,000-100,000. The water-based drilling fluid described in the present invention contains the filtrate reducer, and exhibits good inhibitive, rheological, filtrate reducing, and reservoir protection performance when it is applied in the drilling process in a high-temperature high-calcium deep salt-gypsum formation. 2. The copolymer according to claim 1 , wherein R1 claim 1 , R2 claim 1 , R3 claim 1 , R4 claim 1 , R5 claim 1 , R6 claim 1 , R7 claim 1 , R9 claim 1 , R10 claim 1 , and R11 are H claim 1 , methyl claim 1 , ethyl claim 1 , methoxy claim 1 , or ethyoxy respectively and independently; R8 is selected from methylene or ethylidene.3. The copolymer according to claim 1 , wherein the mass ratio of the structural units represented by formula (1) to the structural units represented by formula (2) to the structural units represented by formula (3) is (0.1-0.15):1:(0.05-0.075).5. The method according to claim 4 , wherein R1 claim 4 , R2 claim 4 , R3 claim 4 , R4 claim 4 , R5 claim 4 , R6 claim 4 , R7 claim 4 , R9 claim 4 , R10 claim 4 , and R11 H claim 4 , methyl claim 4 , ethyl claim 4 , methoxy claim 4 , or ...

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Номер записи: 84
16-04-2020 дата публикации

TEMPERATURE-RESISTANT CALCIUM-RESISTANT WATER-BASED DRILLING FLUID FOR OIL AND GAS RESERVOIR PROTECTION AND USE THEREOF

Номер: US20200115613A1
Автор: CHANG Min, Li Long, Liu Jingping, SUN Jinsheng, Wang Jinhong, Yang Yuping, Zhang Yan
Принадлежит:

The present invention relates to the technical field of well drilling, and discloses a temperature-resistant calcium-resistant water-based drilling fluid for oil and gas reservoir protection and a use thereof. The water-based drilling fluid contains a filtrate reducer and a plugging agent, wherein the filtrate reducer is a copolymer that contains structural units represented by formula (1), structural units represented by formula (2), and structural units represented by formula (3), wherein, the mass ratio of the structural units represented by formula (1) to the structural units represented by formula (2) to the structural units represented by formula (3) is (0.1-0.2):1:(0.05-0.1), and the number-average molecular weight of the copolymer is 10,000-100,000, the plugging agent is acrylamide-diallyldimethylammonium chloride copolymer modified graphene. The water-based drilling fluid described in the present invention can exhibit excellent filtrate reducing, plugging, temperature-resistant, anti-collapsing, and reservoir protective performance when it is applied in well drilling in deep high-temperature wells. 2. The water-based drilling fluid according to claim 1 , wherein measured on the basis of 100 mL said water-based drilling fluid claim 1 , the content of the filtrate reducer is 1-3 g claim 1 , and the content of the plugging agent is 2-7 g.3. The water-based drilling fluid according to claim 1 , wherein in the filtrated reducer claim 1 , R1 claim 1 , R2 claim 1 , R3 claim 1 , R4 claim 1 , R5 claim 1 , R6 claim 1 , R7 claim 1 , R9 claim 1 , R10 claim 1 , and R11 are H claim 1 , methyl claim 1 , ethyl claim 1 , methoxy claim 1 , or ethyoxy respectively and independently; R8 is selected from methylene or ethylidene.4. The water-based drilling fluid according to claim 1 , wherein in the filtrate reducer claim 1 , the mass ratio of the structural units represented by formula (1) to the structural units represented by formula (2) to the structural units represented by ...

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Номер записи: 85
14-05-2015 дата публикации

Aqueous ampholyte polymer containing solutions for subterranean applications

Номер: US20150133347A1
Автор: Hsinchen Chung, Kevin Walter FREDERICK, Michael A. McCabe, Narongsak Tonmukayakul, Randy Jack LOEFFLER, Shih-Ruey Tom CHEN, Xiangnan YE, Yuntao Thomas Hu
Принадлежит: Solvay USA Inc

A aqueous solution that includes water, from 100,000 to 300,000 ppm of dissolved solids, from 0.5 to 3 gallons per thousand gallons of a water-in-oil emulsion, and an inverting surfactant. The water-in oil emulsion includes an oil phase and an aqueous phase where the oil phase is a continuous phase comprising an inert hydrophobic liquid and the aqueous phase is present as dispersed distinct particles in the oil phase. The aqueous phase contains water, a water soluble polymer, and surfactants. The water soluble polymer includes 30 to 50 weight percent of a non-ionic monomer, 5 to 15 weight percent of a sulfonic acid containing monomer, and 40 to 60 weight percent of a cationic monomer. The water soluble polymer makes up from 10 to 35 weight percent of the water-in-oil emulsion.

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Номер записи: 86
02-05-2019 дата публикации

Modified Asphalt Particles and Preparation Method and Use Thereof

Номер: US20190127624A1
Автор: Fu Li, GUO Jiaohe, LIU Shuhua, YAO Hanrong, ZHANG Jianfeng
Принадлежит:

Modified asphalt particles contain asphalt and a modifier. The modifier comprises poly-sulfur and free sulfur. The sulfur element accounts for 10-40 weight percent of the total amount of the modified asphalt particles, and the poly-sulfur accounts for 30-70 weight percent of the total amount of the sulfur element. The total particle size of the modified asphalt particle is smaller than or equal to 150 μm. The modified asphalt particles have an excellent high temperature performance, and can be used for preparing drilling fluids. Water-in-oil based drilling fluid obtained from the modified asphalt particles has low plastic viscosity, high dynamic shear force, high dynamic plastic ratio, and high emulsion-breaking voltage, and improves the high temperature resistance and cutting carrying capability of a system. 119-. (canceled)20. Modified asphalt particles comprising asphalt and a modifier that contains poly-sulfur and free sulfur , wherein the sulfur element accounts for 10-40 wt % of the total weight of the modified asphalt particles , and the poly-sulfur accounts for 30-70 wt % of the total weight of the sulfur element.21. The modified asphalt particles according to claim 20 , wherein an infrared spectrogram of the modified asphalt particle has characteristic peaks of poly-sulfur within a range of 740-2960 cm.22. The modified asphalt particles according to claim 21 , wherein an infrared spectrogram of the modified asphalt particle has characteristic peaks of poly-sulfur in the vicinity of 740 claim 21 , 880 claim 21 , 1509 claim 21 , 1934 claim 21 , 2926 claim 21 , and 2960 cm.23. The modified asphalt particles according to claim 20 , wherein the poly-sulfur accounts for 55-70 wt % of the total weight of sulfur element.24. The modified asphalt particles according to claim 20 , wherein based on the total weight of the modified asphalt particles claim 20 , the sulfur element is 15-35 wt % claim 20 , and the asphalt is 65-85 wt %.25. The modified asphalt particles ...

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Номер записи: 87
02-05-2019 дата публикации

Modified Cellulose Nanocrystals and Their Use in Drilling Fluids

Номер: US20190127625A1
Автор: Li Meichun, WU QINGLIN
Принадлежит: Board of Supervisors of Louisiana State University and Agricultural and Mechanical College

Bentonite (or other clay) water-based drilling fluids incorporating functionalized cellulose nanocrystals are disclosed. Cellulose nanocrystals are modified with tailored surface charges or tailored levels of salt-tolerant polymer grafting, and combined with bentonite (or other clay) nanoplatelets in an aqueous suspension. Thermal performance of drilling fluids can also be enhanced by surface grafting of thermally functional polymers onto cellulose nanocrystals. 1. A composition of matter comprising nanocellulose covalently bonded to first and second polymers , wherein:(a) said nanocellulose comprises cellulose particles 1 μm or less in length, and 100 nm or less in diameter;(b) said first polymer is negatively charged at pH 7.5-10; and(c) said second polymer is positively charged at pH 7.5-10.2. The composition of claim 1 , wherein said composition will have the following properties claim 1 , if said composition is placed in an aqueous suspension at pH 7.5-10; wherein the aqueous suspension comprises clay particles and one or more dissolved mineral salts; andwherein at pH 7.5-10 the clay particles have both positively-charged surfaces and negatively-charged surfaces:(a) said first polymer will tend to associate with the positively-charged surfaces of the clay particles;(b) said second polymer will tend to associate with the negatively-charged surfaces of the clay particles;(c) the clay particles in suspension with said composition will aggregate with one another less than identical clay particles would otherwise aggregate with one another under otherwise identical conditions in an otherwise identical aqueous suspension, except that the otherwise identical suspension lacks the claimed composition.3. The composition of claim 1 , wherein said cellulose particles are selected from the group consisting of unmodified nanocellulose claim 1 , carboxylated nanocellulose claim 1 , and cationic nanocellulose.4. The composition of claim 1 , wherein said cellulose particles ...

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Номер записи: 88
19-05-2016 дата публикации

Wellbore servicing materials and methods of making and using same

Номер: US20160137907A1
Автор: FENG LIANG, Loan Vo, Philip D. Nguyen, Tingji Tang
Принадлежит: Halliburton Energy Services Inc

A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a particulate material, an aqueous base fluid, an oleaginous fluid, and a macromolecular surfactant, and placing the wellbore servicing fluid in the wellbore and/or subterranean formation to consolidate and/or enhance conductivity of at least a portion of the wellbore and/or subterranean formation. A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a particulate material, an aqueous base fluid, an oleaginous fluid, and a macromolecular surfactant, wherein the particulate material comprises sand, and the macromolecular surfactant comprises a hydrophobically modified polyethyleneimine, and placing the wellbore servicing fluid in the wellbore and/or subterranean formation to consolidate and/or enhance conductivity of at least a portion of the wellbore and/or subterranean formation.

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Номер записи: 89
03-06-2021 дата публикации

NANOMETER PLUGGING WATER-BASED DRILLING FLUID AND PREPARATION METHOD AND USE THEREOF

Номер: US20210163807A1
Автор: Bai Yang, Cheng Yan, Li Cheng, Li Guojun, LUO Pingya, ZHANG Hao
Принадлежит: SOUTHWEST PETROLEUM UNIVERSITY

A nanometer plugging water-based drilling fluid and preparation method and use thereof are within this disclosure. The nanometer plugging water-based drilling fluid comprise a nanometer plugging agent. The nanometer plugging agent may be surface modified SiOpowder with the surfactant. The surfactant may be sodium dodecyl benzene sulfonate and/or sodium dodecyl sulfate. The nanometer plugging water-based drilling fluid may perform effective anti-collapse of stratum and maintain the stability of stratum. 1. A nanometer plugging water-based drilling fluid comprising water , bentonite , an anti-collapse agent , a nanometer plugging agent , a weighting agent , a shale inhibitor , a filtrate reducer , and a lubricant; whereinthe anti-collapse agent is sulfonated asphalt;{'sub': '2', 'the nanometer plugging agent is surface modified SiOpowder comprising surfactant, and has an average particle size of 10-80 nm, wherein the surfactant is sodium dodecyl sulfate;'}the weighting agent is limestone with an average particle size of 2-10 μm;the shale inhibitor is an organic acid ester;the filtrate reducer is a polyanionic cellulose;the lubricant is graphite; andbased on 100 parts by weight of water, the bentonite is 1-5 parts by weight, the anti-collapse agent is 2-16 parts by weight, the nanometer plugging agent is 0.1-6 parts by weight, the weighting agent is 20-60 parts by weight, the shale inhibitor is 0.5-2 parts by weight, the filtrate reducer is 2-12 parts by weight and the lubricant is 0.2-4 parts by weight.2. The drilling fluid of claim 1 , wherein based on 100 parts by weight of water claim 1 , the bentonite is 2-4 parts by weight claim 1 , the anti-collapse agent is 4-12 parts by weight claim 1 , the nanometer plugging agent is 0.3-4 parts by weight and the weighting agent is 25-45 parts by weight.36.-. (canceled)7. The drilling fluid of claim 1 , wherein the method of preparing the nanometer plugging agent comprises the following steps:{'sub': '2', '(1) contacting an ...

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Номер записи: 90
03-06-2021 дата публикации

DRILLING FLUID COMPOSITION AND METHOD FOR COOLING IN HIGH TEMPERATURE FORMATIONS

Номер: US20210164327A1
Автор: HOLMES Michael, TOEWS Matthew
Принадлежит:

Methods for drilling in higher temperature rock formations such as geothermal formations with phase change material augmented drilling fluid are disclosed. By observing flow rate of the augmented fluid, heat exchange between the annulus returning fluid and tubular fluid can be minimized thereby facilitating a cooler fluid for contact with a rock face being drilled. The cooling assists in pre-fracturing the rock face prior to destruction by the drill bit. 1. A method of controlling the temperature of a drilling fluid during a drilling operation , said operation utilizing a drill string with tubing and a surrounding annulus , by reducing counter-current heat exchange between said tubing and said annulus by using a chemical mechanism within said drilling fluid.2. The method as set forth in claim 1 , wherein using said chemical mechanism includes providing a drilling fluid containing a phase change material; and controlling a pressure differential between said tubing and said annulus where maximum fusion temperature of said phase change material in said annulus is lower or equal to the minimum fusion temperature of said phase change material in said tubing.3. The method as set forth in claim 2 , further including the step of maintaining flow rate of said phase change material to retain at least partial solid state adjacent the bottom of said tubing whereby said drilling fluid is at a lower temperature than that of a formation face being drilled.4. The method as set forth in claim 1 , further including the step of including reagents within said drilling fluid that react endothermically.5. The method as set forth in claim 4 , wherein the reaction is pressure activated.6. The method as set forth in claim 4 , wherein the reaction is temperature activated.7. The method as set forth in claim 4 , wherein the reaction is spontaneous with reagents being provided in separate tubing strings that combine downhole at a target depth.8. The method as set forth in claim 1 , further ...

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Номер записи: 91
09-05-2019 дата публикации

COMPOSITION FOR DRILLING FLUID AND METHOD OF DRILLING A BOREHOLE

Номер: US20190136111A1
Автор: Humphrey Ryan, Hutchings Nathan R., Monsour Paxton
Принадлежит:

A drilling fluid composition comprises a concentrated mixture of mud additives. The concentrate comprises a water-based suspension medium comprising a colloidal solid and an effective amount of a water-sequestering polymer and an effective amount of at least one drilling mud additive mixed into the water-based suspension medium. 1. A drilling fluid composition comprising a concentrate , the concentrate comprising:a water-based suspension medium comprising a colloidal solid and an effective amount of a water-sequestering polymer; andan effective amount of at least one drilling mud additive mixed into the water-based suspension medium.2. The composition of wherein the colloidal solid comprises bentonite.3. The composition of wherein the water-sequestering polymer comprises polyacrylic acid claim 1 , polyether/polyethylene oxide and mixtures thereof.4. The composition of wherein the at least one drilling mud additive comprises at least one of a clay flocculent claim 1 , a viscosifier claim 1 , and a friction reducer.5. The composition of wherein the at least one drilling mud additive comprises at least one of a detergent and a clay stabilizer.6. The composition of wherein the concentrate further comprises at least one mud additive which may include one or more of the following: bentonite (including high-yield or other modified clay-based mud powders) claim 1 , xanthan gum claim 1 , guar gum claim 1 , poly-anionic cellulose claim 1 , other modified cellulose derivatives claim 1 , polyacrylamides claim 1 , 2-acrylamido-2-methylpropane sulfonate (AMPS) claim 1 , partially hydrolyzed polyacrylamide (HPAM claim 1 , PHPA) claim 1 , sodium polyacrylate polymers claim 1 , acrylamide/sodium acrylate copolymer (e.g. 2-Propenamide polymer) claim 1 , and/or PHPA/AMPS co-polymers claim 1 , non-ionic detergents claim 1 , foaming detergents claim 1 , defoamers claim 1 , clay stabilizers (e.g. choline chloride claim 1 , tetra-methyl ammonium chloride (TMAC) and the like) claim 1 , ...

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Номер записи: 92
09-05-2019 дата публикации

LUBRICANT ADDITIVES FOR WATER BASED DRILLING FLUID

Номер: US20190136112A1
Автор: Asrani Megha, Gupta Vivek, Indulkar Sakshi
Принадлежит:

The invention relates to powdered lubricants for water based drilling fluids. Conventional liquid lubricants containing particularly divalent ions have the tendency to grease out. The powdered lubricants have excellent dispersion properties and hence do not grease out, when added to the drilling mud in the concentrations, preferably of the order of about 3% or less. The powdered lubricant is a combination of inert fillers with fatty acids that are essentially free from fatty acid esters and metal soaps and have organic acids containing C10-C24 alkyl groups fatty acids. The improved lubricating properties of the drilling muds result in greatly increased life of the rotary drilling bits and marked reduction in torque required to rotate the bit. Solid powdered additives compositions greatly reduce transportation costs and simplify the logistics and environmental concerns associated with shipping large volumes of liquids and overcome the pour point issues associated with liquid additives. 1. A powdered lubricant additive , comprising:a fatty acid that is essentially free from fatty acid ester and metal soap, said fatty acid comprising organic acids containing C10-C24 alkyl groups fatty acids; andan inert filler,wherein the powdered lubricant additive does not grease or cheese out in the presence of mono, di or trivalent ions in water based drilling fluids.2. The powdered lubricant additive as claimed in wherein the C10-C24 alkyl group fatty acids are selected from the group consisting of saturated and unsaturated fatty acids claim 1 , vegetable oil fatty acid claim 1 , sulfurized vegetable fatty acids or combinations thereof.3. The powdered lubricant additive as claimed in wherein the inert filler is selected from the group consisting of precipitated silica of particle size about 10-180 microns claim 1 , diatomaceous earth of particle size about 10-200 microns claim 1 , expanded perlite of particle size about 10-5000 microns or combinations thereof.4. The powdered ...

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Номер записи: 93
09-05-2019 дата публикации

IMPROVED PERFORMANCE NON-EMULSIFIERS THAT EMPLOY BRANCHED ALCOHOLS AND A NEW HIGH-SOLVENCY CARRIER OIL

Номер: US20190136113A1
Автор: Alwattari ALi, Anderson Katelyn Lemm, Holan Kristina Henkel, Holtsclaw Jeremy A., Khamatnurova Tatyana V., Palla Venkata Chandra Sekhar
Принадлежит: Halliburton Energy Services, Inc.

Various embodiments disclosed relate to demulsifier compositions for treatment of subterranean formations or produced petroleum comprising an emulsion. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a demulsifier composition. The demulsifier composition includes at least one resin of formula (I) and at least one compound of formula (II). 2. The method according to claim 1 , wherein the composition further comprises: (C) at least one alcohol according to the formula:{'br': None, 'sub': 3', '20, 'HO-(branched C-C-alkyl).'}4. The method according to claim 1 , wherein the method comprises hydraulically fracturing the subterranean formation with the demulsifier composition or with a subterranean treatment fluid comprising the demulsifier composition.5. The method according to 1 claim 1 , further comprising reducing or eliminating an emulsion in the subterranean formation claim 1 , reducing or eliminating formation of an emulsion in the subterranean formation claim 1 , or a combination thereof.6. The method according to 1 claim 1 , wherein the demulsifier composition further comprises one or more or any combination of a water phase claim 1 , an organic solvent claim 1 , or an oil phase.7. (canceled)8. (canceled)9. The method according to claim 1 , wherein the demulsifier composition comprises an aqueous phase and an oil phase.10. The method according to 9 claim 1 , wherein the demulsifier composition comprises an emulsion comprising the aqueous phase and the oil phase.11. The method according to 10 claim 1 , wherein the emulsion is a microemulsion.12. The method according to claim 1 , wherein{'sup': 1', '2, 'Rand Rare independently selected from H and methyl; and'}{'sup': '3', 'sub': 3', '12, 'Ris C-C-alkyl.'}13. The method according to claim 12 , wherein{'sup': '1', 'Ris H or Me;'}{'sup': '2', 'Ris Me;'}{'sup': '3', 'sub': 3', '12, 'Ris C-C-alkyl;'}{'sub': '1 ...

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Номер записи: 94
25-05-2017 дата публикации

Fluids containing cellulose fibers and cellulose nanoparticles for oilfield applications

Номер: US20170145285A1
Автор: Mohan Kanaka Raju Panga, Richard Berry, Valerie Gisele Helene Lafitte
Принадлежит: Schlumberger Technology Corp

Treatment fluids containing a mixture of cellulose fibers and cellulose nanoparticles and methods for treating a subterranean formation are disclosed. The methods include introducing a treatment fluid into a subterranean formation, the treatment fluid containing a mixture of cellulose fibers and cellulose nanoparticles.

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Номер записи: 95
02-06-2016 дата публикации

Method of applying solvent treatments using emulsions

Номер: US20160152885A1
Автор: Balkrishna Gadiyar, Matthew OFFENBACHER
Принадлежит: MI LLC

Methods of delivering a low density solvent into a wellbore include combining an oleaginous solvent and a nonoleaginous fluid to form an emulsion, and injecting the emulsion into a wellbore. Other uses of low density solvent systems may include dissolving waxes and wax-containing residues in a wellbore, on downhole tools, from sand screens, or use in general cleanup operations in and outside of the wellbore.

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Номер записи: 96
07-05-2020 дата публикации

METHODS OF USING DRILLING FLUID COMPOSITIONS WITH ENHANCED RHEOLOGY

Номер: US20200140739A1
Автор: Al-Yami Abdullah, AlBahrani Hussain, Alhelal Abdulaziz, Safran Ali
Принадлежит: Saudi Arabian Oil Company

Drilling fluid compositions include a base fluid, at least one additive chosen from an emulsifier, weighting material, fluid-loss additive, viscosifier, or alkali compound, and from 0.1 wt. % to 1 wt. %, based on total weight of the drilling fluid composition, of an ethoxylated alcohol compound having the formula R—(OCHCH)—OH, in which R is a saturated or unsaturated, linear or branched hydrocarbyl group having from 8 to 20 carbon atoms. The base fluid may be an aqueous base fluid. Methods for drilling a subterranean well include operating a drill in a wellbore in the presence of a drilling fluid composition including the base fluid, the additive, and the ethoxylated alcohol compound. 1. A drilling fluid composition consisting essentially of:a base fluid;at least one additive chosen from an emulsifier, a weighting material, a fluid-loss additive, a viscosifier, or an alkali compound; and {'br': None, 'sub': 2', '2', '7, 'R—(OCHCH)—OH \u2003\u2003(I)'}, 'from 0.1 wt. % to 1 wt. %, based on the total weight of the drilling fluid composition, of an ethoxylated alcohol compound having formula (I){'sup': '3', 'where R is a hydrocarbyl group having exactly 12 carbon atoms; in which the drilling fluid composition has a density equal to or greater than 90 lbm/ft.'}2. The drilling fluid composition of where the drilling fluid composition has a yield point of from 45 lbf/100 ftto 100 lbf/100 ftand a 10-second gel strength of from 1 lbf/100 ftto 30 lbf/100 ftas determined according to test methods provided in API RP 13B-1.3. The drilling fluid composition of claim 1 , in which the base fluid is an aqueous base fluid.4. The drilling fluid composition of claim 3 , in which the aqueous base fluid comprises at least 50 weight percent water based on the total weight of the aqueous base fluid.5. The drilling fluid composition of claim 3 , in which the aqueous base fluid is chosen from fresh water claim 3 , filtered water claim 3 , distilled water claim 3 , sea water claim 3 , salt ...

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Номер записи: 97
17-06-2021 дата публикации

LUBRICANT FOR DRILLING AND DRILL-IN FLUIDS

Номер: US20210179910A1
Автор: GHOSH Shubhajit, Guo Li, Nzeadibe Kingsley Ihueze
Принадлежит: Halliburton Energy Services, Inc.

A lubricant composition containing a vegetable oil, and at least two nonionic surfactants. The vegetable oil may be castor oil, and the nonionic surfactants may include sorbitan esters and polyethoxylated sorbitan esters. Also provided is a wellbore fluid containing a base fluid and a lubricant containing vegetable oil and at least one nonionic surfactant. Methods of introducing the lubricant composition and wellbore fluids containing the lubricant composition into a subterranean formation zone are also provided. 1. A method comprising:introducing a lubricant comprising vegetable oil and at least one nonionic surfactant into a subterranean formation zone.2. The method of claim 1 , wherein the lubricant is introduced into the subterranean formation zone as a component of a wellbore fluid comprising the lubricant and a base fluid.3. The method of claim 2 , wherein the base fluid is selected from the group consisting of brines claim 2 , invert emulsions and combinations thereof.4. The method of claim 3 , wherein the wellbore fluid is in the form of an invert emulsion comprising a monovalent brine.5. The method of claim 4 , wherein the wellbore fluid comprises from about 0.5 weight percent to about 6 weight percent of the lubricant.6. The method of claim 1 , wherein the lubricant comprises from about 50 to about 90 weight percent vegetable oil claim 1 , and from about 10 to about 50 weight percent of the at least one nonionic surfactant.7. The method of claim 6 , wherein the at least one nonionic surfactant is selected to provide an HLB in the range of from about 12 to about 18.8. The method of claim 6 , wherein the vegetable oil comprises castor oil.9. The method of claim 8 , wherein the lubricant comprises three nonionic surfactants.10. The method of claim 9 , wherein the three nonionic surfactants are selected from the group consisting of sorbitan esters and polyethoxylated sorbitan esters.11. The method of claim 10 , wherein the lubricant comprises from about 0.5 to ...

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Номер записи: 98
17-06-2021 дата публикации

WATER-BASED DRILLING FLUID COMPOSITIONS AND METHODS FOR DRILLING SUBTERRANEAN WELLS

Номер: US20210179914A1
Автор: Al-Arfaj Mohammed Khalid, Al-Qasim Abdulaziz S., Alkhalaf Sara, Alouhali Raed, AMANULLAH Md, Radhwan Ali
Принадлежит: Saudi Arabian Oil Company

According to one or more embodiments of the present disclosure, water-based drilling fluids may include an aqueous base fluid and one or more additives. In embodiments, water-based drilling fluids may include a lubricant blend including at least oleic acid and palmitoleic acid. The sum of the volume percent of the oleic acid and palmitoleic acid may be from 0.1 vol. % to 10 vol. % of the total volume of the water-based drilling fluid. In embodiments, water-based drilling fluids may include a lesser melting point fraction of jojoba oil in an amount of from 0.1 vol. % to 10 vol. % relative to the total volume of the water-based drilling fluid. At least 90% of the lesser melting point fraction of jojoba oil may have a melting point less than or equal to 15° C. Methods for drilling subterranean wells with the water-based drilling fluids are also disclosed. 1. A water-based drilling fluid comprising:an aqueous base fluid;one or more additives; anda lesser melting point fraction of jojoba oil in an amount of from 0.1 vol. % to 10 vol. % relative to the total volume of the water-based drilling fluid, where at least 90% of the lesser melting point fraction of jojoba oil has a melting point less than or equal to 15° C.2. The water-based drilling fluid of claim 1 , where the lesser melting point fraction of jojoba oil comprises at least oleic acid and palmitoleic acid.3. The water-based drilling fluid of claim 2 , where the lesser melting point fraction of jojoba oil comprises oleic acid in an amount of from 75 vol. % to 99 vol. % relative to the total volume of the lesser melting point fraction of jojoba oil.4. The water-based drilling fluid of claim 2 , where the lesser melting point fraction of jojoba oil comprises palmitoleic acid in an amount of from 1 vol. % to 25 vol. % relative to the total volume of the lesser melting point fraction of jojoba oil.5. The water-based drilling fluid of claim 2 , where the molar ratio of oleic acid to palmitoleic acid is from 25:1 to 50: ...

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Номер записи: 99
22-09-2022 дата публикации

Drilling Fluid Lubricants

Номер: US20220298403A1
Автор: Bishop Marshall D., Jackson Christopher B., Watson Elan
Принадлежит:

A drilling fluid may include a carrier and a lubricant composition. The lubricant composition includes ethylene bottoms heavy pyrolysis oil. For example, the heavy pyrolysis oil may be bottoms of a fractionated fuel oil product separated from ethylene gas produced by a cracking of a hydrocarbon feedstock in a furnace. 1. A drilling fluid comprising:a carrier; anda lubricant composition,wherein the lubricant composition comprises ethylene bottoms heavy pyrolysis oil.2. The drilling fluid of claim 1 , wherein the heavy pyrolysis oil comprises bottoms from a hydrocarbon feedstock steam cracker furnace.3. The drilling fluid of claim 1 , wherein the heavy pyrolysis oil consists essentially of bottoms from a hydrocarbon feedstock steam cracker furnace.4. The drilling fluid of claim 2 , wherein the hydrocarbon feedstock comprises one or more of ethane claim 2 , propane claim 2 , butane claim 2 , Liquefied Petroleum Gas (LPG) claim 2 , Natural Gas Liquids (NGL) claim 2 , light (C-C) hydrocarbons claim 2 , or naphtha (C-C).5. The drilling fluid of claim 1 , wherein the heavy pyrolysis oil comprises from 75% to 80% by weight of petroleum hydrocarbons.6. The drilling fluid of claim 1 , wherein the heavy pyrolysis oil comprises:naphthalene in a range of from 10% to 30% by weight,biphenyl in a range of from 1% to 10% by weight,phenanthrene in a range of from 1% to 10% by weight, andanthracene in a range of from 1% to 10% by weight.7. The drilling fluid of claim 1 , wherein the heavy pyrolysis oil comprises:{'sub': 1', '6, 'less than 1000 ppm of Cto Corganic compounds,'}{'sub': 7', '8, 'less than 1000 ppm of Cto Corganic compounds,'}{'sub': 9', '10, 'about 500 ppm of Cto Corganic compounds,'}{'sub': 11', '12, 'from about 15,000 ppm to about 35,000 ppm of Cto Corganic compounds,'}{'sub': 13', '16, 'from about 250,000 ppm to about 450,000 ppm of Cto Corganic compounds,'}{'sub': 17', '21, 'from about 150,000 ppm to about 350,000 ppm of Cto Corganic compounds,'}{'sub': 22', '35, ' ...

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Номер записи: 100