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

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Применить Всего найдено 10736. Отображено 100.
12-01-2012 дата публикации

Hybrid Cement Set-On-Command Compositions

Номер: US20120010324A1
Автор: Alexander Bismarck, Angelika Menner, Gary Funkhouser, Natasha Shirshova
Принадлежит: Halliburton Energy Services Inc

The present invention relates to methods and compositions useful for isolating a portion of a wellbore. In one embodiment, a method includes preparing a sealant composition containing two phases. The sealant composition is placed into the wellbore where one phase sets upon subjecting the sealant composition to a thermal source followed by the setting of the other phase.

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Номер записи: 1
26-01-2012 дата публикации

Cement compositions with a high-density additive of silicon carbide or sintered bauxite

Номер: US20120018155A1
Автор: Keith Armstrong, Rahul Chandrakant Patil, Sandip Prabhakar Patil
Принадлежит: Halliburton Energy Services Inc

A method of cementing in a subterranean formation comprising the steps of: (A) introducing a cement composition into the subterranean formation, the cement composition comprising: (i) cement; (ii) water; and (iii) a high-density additive selected from the group consisting of silicon carbide, sintered bauxite, and any combination thereof, wherein the cement composition has a density of at least 16 pounds per gallon; and (B) allowing the cement composition to set. According to an embodiment, the high-density additive is in a concentration of at least 30% by weight of the cement. A cement composition for use in an oil or gas well comprises: (A) cement; (B) water; and (C) a high-density additive selected from the group consisting of silicon carbide, sintered bauxite, and a combination thereof, wherein the high-density additive is in a concentration of at least 30% by weight of the cement, and wherein the cement composition has a density of at least 16 pounds per gallon.

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Номер записи: 2
22-03-2012 дата публикации

Magnetically Controlled Delivery of Subterranean Fluid Additives for Use in Subterranean Applications

Номер: US20120067577A1
Автор: Craig W. Roddy
Принадлежит: Halliburton Energy Services Inc

The invention relates to providing controlled delivery of subterranean fluid additives to a well bore treatment fluid and/or a surrounding subterranean environment using intelligent materials that respond to a magnetic stimulus to release subterranean fluid additives downhole in a subterranean environment. Methods disclosed include a method of releasing a subterranean fluid additive in a subterranean formation comprising: providing a magnetically-sensitive component that comprises a subterranean fluid additive; providing a magnetic source; and releasing the subterranean fluid additive in the subterranean formation from the magnetically-sensitive component using a magnetic force generated from the magnetic source.

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Номер записи: 3
28-06-2012 дата публикации

Use of Seeds as a Cement Set Retarder

Номер: US20120160490A1
Автор: Lloyd Spangle
Принадлежит: Individual

A cement retarder composition, method, kit and system are herein disclosed. Seeds are added to cement to delay the setting of cement. Cement retarders are added to cement to delay the setting of the cement until it is pumped to the desired position.

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Номер записи: 4
05-07-2012 дата публикации

Weighted Elastomers, Cement Compositions Comprising Weighted Elastomers, and Methods of Use

Номер: US20120172261A1
Автор: Craig W. Roddy, D. Chad Brenneis, Jeffery D. Karcher, Rickey L. Morgan
Принадлежит: Halliburton Energy Services Inc

Methods and compositions are provided that relate to weighted elastomers. The weighted elastomers may comprise an elastomer and a weighting agent attached to an outer surface of the elastomer. An embodiment includes a method of cementing that comprises providing a cement composition containing cement, water, and a weighted elastomer. In addition, the cement composition may be introduced into a subterranean formation and allowed to set therein.

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Номер записи: 5
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: 6
26-07-2012 дата публикации

Permeability blocking with stimuli-responsive microcomposites

Номер: US20120190593A1
Автор: David S. Soane, Philip Wuthrich, Robert P. Mahoney, Rosa Casado Portilla
Принадлежит: Soane Energy LLC

Disclosed is a two-component fluid loss control system comprising a core substrate and a polymeric shell cooperating with each other to form a microcomposite, wherein the core substrate and the polymeric shell are formed from different materials. The system can demonstrate switchable behavior. The core substrate and the polymeric shell can be further modified, where modifications cooperate with each other to form the microcomposite. Also disclosed are formulations for fluid loss control and methods for controlling fluid loss in a well.

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Номер записи: 7
02-08-2012 дата публикации

Expoxy Acid Based Biodegradable Set Retarder

Номер: US20120196954A1
Автор: Abhijit Tarafdar, Dibyadarshani Senapati, Girish Dinkar Sarap, Rahul Chandrakant Patil
Принадлежит: Halliburton Energy Services Inc

A cement composition or method of using the cement composition in a subterranean formation, the composition having: (A) cement; (B) water; and (C) a polymer, wherein the polymer: (i) comprises a monomer or monomers selected from the group consisting of epoxysuccinic acid, a substituted epoxysuccinic acid, and an alkali metal salt, alkaline earth metal salt, or ammonium salt of any of the foregoing, and any combination of any of the foregoing; (ii) has the following characteristics: (a) is water soluble; and (b) is biodegradable; and (iii) is capable of providing: (a) a thickening time of at least 2 hours for a test composition at a temperature of 190° F. and a pressure of 5,160 psi; and (b) an initial setting time of less than 24 hours for the test composition at a temperature of 217° F. and a pressure of 3,000 psi.

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Номер записи: 8
09-08-2012 дата публикации

Low Heat of Hydration Cement Compositions and Methods of Using Same

Номер: US20120199350A1
Автор: Anthony V. Palmer, Lance E. Brothers
Принадлежит: Halliburton Energy Services Inc

A method of servicing a wellbore in a subterranean formation, comprising preparing a cement composition comprising water and a cementitious material, wherein the cementitious material further comprises blast furnace slag, vitrified shale, calcium sulfate hemi-hydrate or combinations thereof, and placing the cement composition in the wellbore. A cement composition comprising water and a cementitious material, wherein the cementitious material further comprises blast furnace slag, vitrified shale, calcium sulfate hemi-hydrate or combinations thereof. A cement composition comprising water and a cementitious material, wherein the cementitious material further comprises blast furnace slag.

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Номер записи: 9
09-08-2012 дата публикации

Cement compositions comprising particulate foamed elastomers and associated methods

Номер: US20120202901A1
Автор: Benjamin J. Iverson, Christopher L. Gordon, Jeffery D. Karcher, Robert P. Darbe
Принадлежит: Halliburton Energy Services Inc

Methods of subterranean cementing involving cement compositions comprising particulate foamed elastomers and associated methods are provided. In one embodiment, the cement composition comprises a hydraulic cement, a particulate foamed elastomer, and an aqueous fluid. In one embodiment, the particulate foamed elastomer may comprise polyurethane foam.

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Номер записи: 10
16-08-2012 дата публикации

Method for Wellbore Servicing to Enhance the Mechanical Strength of Cement Using Electrochemically Activated Water

Номер: US20120204764A1
Автор: Billy Slabaugh, Jim Weaver, Mark Savery, Roger Cromwell
Принадлежит: Halliburton Energy Services Inc

A wellbore servicing method comprises converting a water into an electrochemically activated water, preparing a wellbore servicing composition comprising the electrochemically activated water, and placing the wellbore servicing composition in a wellbore. Also, cement composition comprises a cement and an electrochemically activated water.

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Номер записи: 11
23-08-2012 дата публикации

Well Treatment Compositions and Methods Utilizing Nano-Particles

Номер: US20120211227A1
Автор: Carl J. Thaemlitz, Craig W. Roddy, D. Chad Brenneis, Jiten Chatterji, Ricky L. Covington
Принадлежит: Halliburton Energy Services Inc

Disclosed embodiments relate to well treatment fluids and methods that utilize nano-particles. Exemplary nano-particles are selected from the group consisting of particulate nano-silica, nano-alumina, nano-zinc oxide, nano-boron, nano-iron oxide, and combinations thereof. Embodiments also relate to methods of cementing that include the use of nano-particles. An exemplary method of cementing comprises introducing a cement composition into a subterranean formation, wherein the cement composition comprises cement, water and a particulate nano-silica. Embodiments also relate to use of nano-particles in drilling fluids, completion fluids, simulation fluids, and well clean-up fluids.

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Номер записи: 12
27-09-2012 дата публикации

Use of high ratio aqueous alkali silicates for profile modification, water control and stabilization

Номер: US20120245062A1
Автор: Michael J. Mcdonald
Принадлежит: Individual

Soluble silicates are commonly used to block and strengthen permeable zones in subterranean formations. These applications include conformance for oil field, grouting for the construction industry and water shut-off for mining. It was discovered that set times and set properties could be improved by using novel, high ratio alkali silicates. Ratio being defined as the mol ratio of SiO 2 :Me 2 O, where Me is an alkali metal and is most commonly sodium or potassium (i.e. Na 2 O and K 2 O).

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Номер записи: 13
25-10-2012 дата публикации

Foamed Spacer Fluids Containing Cement Kiln Dust and Methods of Use

Номер: US20120267107A1
Автор: Christopher Jay Garrison, Craig W. Roddy, D. Chad Brenneis, James Robert Benkley, Joseph V. Spencer, Zachary Robert Kranz
Принадлежит: Halliburton Energy Services Inc

Disclosed are spacer fluids comprising cement kiln dust (“CKD”) and methods of use in subterranean formations. An embodiment discloses a method comprising: providing a foamed spacer fluid comprising CKD, a foaming agent, a gas, and water; and introducing the foamed spacer fluid into a well bore to displace at least a portion of a first fluid present in the well bore. Another embodiment discloses a method comprising: providing a foamed spacer fluid comprising a partially calcined kiln feed removed from a gas stream, a foaming agent, a gas, and water, wherein the partially calcined kiln feed comprises SiO 2 , Al 2 O 3 , Fe 2 O 3 , CaO, MgO, SO 3 , Na 2 O, and K 2 O; and introducing the foamed spacer fluid into a well bore to displace at least a portion of a first fluid present in the well bore.

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Номер записи: 14
15-11-2012 дата публикации

Settable Compositions Containing Metakaolin Having Reduced Portland Cement Content

Номер: US20120285682A1
Автор: Ashok K. Santra, Benjamin Iverson, Crystal Lynne Keys, Krishna M. Ravi, Rahul Patil, Sandip Patil
Принадлежит: Halliburton Energy Services Inc

Of the many compositions and methods provided herein, one method includes providing a settable fluid that comprises an aqueous-based medium, a lime composition, and a cementitious blend that comprises metakaolin particulates and aluminosilicate particulates, wherein the cementitious blend is essentially free of Portland cement; introducing the settable fluid into a wellbore penetrating a subterranean formation that comprises a corrosive component; and allowing the settable fluid to set therein.

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Номер записи: 15
20-12-2012 дата публикации

Drag Reducer for Cement Compositions

Номер: US20120322912A1
Автор: Colm Monaghan, Salim Taoutaou
Принадлежит: Individual

A cement composition for use in preparation for a wellbore cementing slurry comprising cement dry powder and fibres for reducing drag forces.

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Номер записи: 16
03-01-2013 дата публикации

Radiation-Induced Triggering for Set-On-Command Compositions and Methods of Use

Номер: US20130000891A1
Автор: Andrew K. Dummer, Anthony Badalamenti, David F. Myers, James Lynn Davis, Lawrence R. Roberts, Michele Ostraat, Mike Lamvik, Samuel J. Lewis, Vijay Gupta, Vikram Rao
Принадлежит: Halliburton Energy Services Inc

Methods of isolating a portion of a wellbore comprising placing a sealant composition into a subterranean formation after drilling of the wellbore therein and subjecting the sealant composition to ionizing radiation wherein subjecting the sealant composition to the ionizing radiation alters the set modifier. The sealant composition comprises a set modifier selected from the group consisting of an accelerator, an oxidizing agent, a set retarder, and combinations thereof. And the sealant composition comprises a polymeric component.

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Номер записи: 17
14-02-2013 дата публикации

System and Method for Improving Zonal Isolation in a Well

Номер: US20130037267A1
Автор: Loic Regnault De La Mothe, Sylvaine Le Roy-Delage
Принадлежит: Schlumberger Technology Corp

The disclosure relates to a system ( 10 ) for improving zonal isolation in a well in a subterranean formation, comprising: a tubular ( 1 ) having a outer surface ( 11 ); and a swellable coating ( 2 ) coating the outer surface ( 11 ) of said tubular ( 1 ), said swellable coating ( 2 ) having an external surface ( 21 ); and/or a composition ( 20 ) provided in an annular space outside said tubular ( 1 ). The swellable coating ( 2 ) is made of a first swellable material ( 3 ) able to swell in contact with a first fluid ( 6 ) on said external surface ( 21 ) and/or the composition ( 20 ) is made of a second swellable material ( 4 ) able to swell in contact with a second fluid ( 7 ), and wherein said first ( 3 ) and/or said second ( 4 ) swellable materials include an elastomer compounded with an aqueous inverse emulsion of particles of a polymer comprising a betaine group, said elastomer being able to swell in contact with hydrocarbon and saline aqueous fluids.

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Номер записи: 18
28-02-2013 дата публикации

Methods for Determining Reactive Index for Cement Kiln Dust, Associated Compositions, and Methods of Use

Номер: US20130048286A1
Автор: Craig W. Roddy, D. Chad Brenneis, Ronnie G. Morgan
Принадлежит: Halliburton Energy Services Inc

A variety of methods and compositions are disclosed, including, in one embodiment, a method of treating a well comprising: providing a treatment fluid comprising a base fluid and a blended cementitious component, wherein the blended cementitious component comprises kiln dust from two or more different sources; and introducing the treatment fluid into a well bore.

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Номер записи: 19
07-03-2013 дата публикации

Downhole sealing system using cement activated material and method of downhole sealing

Номер: US20130056207A1
Автор: Edward T. Wood, James R. Korte, Justin Cash Bowersock
Принадлежит: Baker Hughes Inc

A downhole sealing system includes a reactive material provided on a tubular and including an oxidizable substance; and a sealing material, wherein the oxidizable substance oxidizes when in contact with the sealing material. Also included is a method of providing a seal in a downhole system.

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Номер записи: 20
14-03-2013 дата публикации

Settable Compositions Comprising Unexpanded Perlite and Methods of Cementing in Subterranean Formations

Номер: US20130061779A1
Автор: Chad Brenneis, Craig W. Roddy, Jeffery Karcher
Принадлежит: Halliburton Energy Services Inc

An embodiment of the present invention comprises a method of cementing comprising: placing a settable composition into a well bore, the settable composition comprising unexpanded perlite, cement kiln dust, and water; and allowing the settable composition to set. Another embodiment of the present invention comprises a method of cementing comprising: placing a settable composition into a well bore, the settable composition comprising ground unexpanded perlite, Portland cement interground with pumicite, and water; and allowing the settable composition to set. Yet another embodiment of the present invention comprises a settable composition comprising: ground unexpanded perlite; cement kiln dust; and water.

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Номер записи: 21
18-04-2013 дата публикации

USE OF A CHOPPER MECHANISM TO ADD FIBERS TO A WELL

Номер: US20130092377A1
Автор: Abbas Raafat, Leugemors Edward, Mcintire William R., Pessin Jean-Louis, Rhein-Knudsen Erik
Принадлежит: SCHLUMBERGER TECHNOLOGY CORPORATION

A chopper mechanism for providing a fiber to a fluid at an oilfield. The chopper mechanism may be employed to process the fiber from an uncut form to a cut form in order to provide a mixture of the fluid and the fiber with flowback inhibiting character. Techniques of employing the chopper mechanism may be utilized at the site of an oilfield for applications such as fracturing, cementing, and drilling. Additionally, the chopper mechanism itself may be made available as a large high capacity chopper assembly, or a smaller handheld chopper gun for slower rate fiber supply operations. 1. A method of treating a well at an oilfield with a fluid mixture , the method comprising:providing a fluid to the oilfield; and feeding the fiber to a chopper gun in an uncut form, wherein said feeding is configured to be performed continuously for the duration of the treating;', 'operating the chopper gun to convert the uncut form of the fiber to a cut form of the fiber to form a plurality of cut fibers;', 'gun to the fluid to provide the mixture with a flowback inhibiting character; and', 'delivering and metering the plurality of cut fibers from the chopper'}], 'adding a fiber to the fluid to form the mixture, said adding comprisinginjecting the fluid mixture into the well.2. The method of claim 1 , wherein said operating of the chopper gun to convert the uncut form of the fiber to the cut form of the fiber to form a plurality of cut fibers comprises forming a plurality of cut fibers having a predetermined size range.3. The method of claim 2 , wherein the predetermined size range is between about 10 mesh and about 100 mesh.4. The method of claim 1 , wherein the treating of the well is a well fracturing operation claim 1 , and wherein said delivering of the plurality of cut fibers from the chopper gun to the fluid occurs at a rate of between about 100 and about 300 lbs. per minute.5. The method of claim 1 , wherein the treating of the well is a well cementing operation claim 1 , and ...

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Номер записи: 22
25-04-2013 дата публикации

CEMENT COMPOSITION CONTAINING A SUBSTITUTED ETHOXYLATED PHENOL SURFACTANT FOR USE IN AN OIL-CONTAMINATED WELL

Номер: US20130098273A1
Автор: JOSEPH Trissa, SATHE Vineet Vasant, TARAFDAR Abhijit
Принадлежит: Halliburton Energy Services, Inc.

A well treatment composition comprises a surfactant comprising a substituted ethoxylated phenol having at least one substituent, 1 to 14 moles of ethylene oxide, and the substituent being an alkyl, alkene, or alkyne with a carbon chain length in the range of 4 to 25, wherein the substituted ethoxylated phenol is selected from the group consisting of: ortho-, para-, or meta-substituted ethoxylated phenol; cardanol ethoxylate; derivatives thereof; and combinations of any of the foregoing. Preferably, the surfactant comprises cardanol ethoxylate, a substituted cardanol ethoxylate, and derivatives thereof. A method of cementing in a subterranean formation comprises: introducing a cement composition into the subterranean formation, wherein the cement composition comprises: (A) cement; (B) water; and (C) the surfactant; and allowing the cement composition to set. 2. The composition according to claim 1 , wherein the cement is selected from the group consisting of Class A cement claim 1 , Class C cement claim 1 , Class G cement claim 1 , Class H cement claim 1 , and any combination thereof.3. The composition according to claim 1 , wherein the water is selected from the group consisting of freshwater claim 1 , brackish water claim 1 , saltwater claim 1 , and any combination thereof.4. The composition according to claim 1 , wherein the surfactant is non-ionic.5. The composition according to claim 1 , wherein the surfactant comprises a para-substituted ethoxylated phenol derivative in which R=an alkyl with a carbon chain length of 9.7. The composition according to claim 1 , wherein n=6-13.8. The composition according to claim 1 , wherein the surfactant is biodegradable.9. The composition according to claim 1 , wherein the surfactant is in a concentration in the range of about 0.05% to about 5% by weight of the cement.10. The composition according to claim 1 , wherein the composition has a thickening time in the range of about 4 to about 15 hours at a temperature of 185° F. ( ...

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Номер записи: 23
02-05-2013 дата публикации

Compositions and Methods for Well Treatment

Номер: US20130105160A1
Автор: Brice Lecampion, Inès Khalfallah, Katia Dennis, Matteo Loizzo
Принадлежит: Schlumberger Technology Corp

A self-healing cement for use in wells in which carbon dioxide is injected, stored or extracted, comprises a carbonaceous material. In the event of cement-matrix failure, or bonding failure between the cement/casing interface or the cement/borehole-wall interface, the material swells when contacted by carbon dioxide. The swelling seals voids in the cement matrix, or along the bonding interfaces, thereby restoring zonal isolation.

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Номер записи: 24
02-05-2013 дата публикации

Compositions and methods for improving the toughness of set cements

Номер: US20130105162A1
Автор: Carlos Abad, Hemant K.J. Ladva
Принадлежит: Schlumberger Technology Corp

The toughness of set cement may be enhanced by incorporating partially cured waterborne resins in the cement matrix. A hardening agent is added to the waterborne resin, and the mixture is allowed to react for periods between about 1 min and 15 min. The waterborne resin with hardening agent is then combined with an inorganic cement to form a pumpable slurry. After curing, the set cement may withstand at least 1.5% strain before failure.

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Номер записи: 25
09-05-2013 дата публикации

Consolidating Spacer Fluids and Methods of Use

Номер: US20130112405A1
Автор: Craig W. Roddy, Crystal L. Keys, D. Chad Brenneis, James R. Benkley, Jiten Chatterji, Rickey L. Morgan, Ronnie G. Morgan
Принадлежит: Halliburton Energy Services Inc

Disclosed are spacer fluids and methods of use in subterranean formations. Embodiments may include use of consolidating spacer fluids in displacement of drilling fluids from a well bore annulus.

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Номер записи: 26
13-06-2013 дата публикации

Self-Repairing Cements

Номер: US20130146286A1
Автор: Le Roy-Delage Sylvaine, Martin-Al-Khatib Laure
Принадлежит:

A self-adaptive cement formulation includes cement, water and thermoplastic block-polymer particles. The set cement demonstrates self-healing properties when exposed to methane, and is particularly suited for well-cementing applications. After placement and curing, the self healing properties help maintain zonal isolation should bonding be disrupted between the set cement and the formation or a casing string, should cracks or defects appear in the set-cement matrix, or both. 1. A method for maintaining zonal isolation in a subterranean well in which a borehole penetrates one or more hydrocarbon-containing formations , comprising:(i) pumping a cement slurry comprising thermoplastic block-polymer particles into the well; and(ii) allowing the cement slurry to set to form a cement sheath;wherein, should microannuli, cracks or defects occur in the cement sheath, allowing hydrocarbons from the formation to contact the particles, allowing the particles to swell, and enabling the cement sheath to have self-healing properties.2. The method of claim 1 , wherein the particles comprise styrene-isoprene-styrene polymer particles claim 1 , styrene-butadiene-styrene polymer particles or both.3. The method of claim 1 , wherein the concentration of the particles is between about 10% and 55% by volume of cement-slurry solids.4. The method of claim 1 , wherein the size of the particles is between about 100 μm and 900 μm.5. The method of claim 1 , wherein the slurry further comprises one or more particles of the list comprising: an aqueous inverse emulsion of polymer comprising a betaine group claim 1 , poly-2 claim 1 ,2 claim 1 ,1-bicyclo heptene (polynorbornene) claim 1 , alkylstyrene claim 1 , crosslinked substituted vinyl acrylate copolymers claim 1 , diatomaceous earth claim 1 , natural rubber claim 1 , vulcanized rubber claim 1 , polyisoprene rubber claim 1 , vinyl acetate rubber claim 1 , polychloroprene rubber claim 1 , acrylonitrile butadiene rubber claim 1 , hydrogenated ...

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Номер записи: 27
13-06-2013 дата публикации

MAGNETICALLY CONTROLLED DELIVERY OF SUBTERRANEAN FLUID ADDITIVES FOR USE IN SUBTERRANEAN APPLICATIONS

Номер: US20130150267A1
Автор: Roddy Craig W.
Принадлежит: Halliburton Energy Services, Inc.

Various compositions are provided herein that include a composition that includes a well bore treatment fluid and a magnetically-sensitive component that includes a subterranean fluid additive. In some instances, the magnetically-sensitive component may be a ferrogel. In some instances, the ferrogel may include a polymer matrix and a magnetic species. 132-. (canceled)33. A well bore composition comprising:a well bore treatment fluid; anda magnetically-sensitive component that comprises a subterranean fluid additive.34. The well bore composition of wherein the magnetically-sensitive component includes a magnetically activated device.35. The well bore composition of wherein the magnetically-sensitive component is a ferrogel.36. The well bore composition of wherein the ferrogel comprises a polymer matrix and a magnetic species.37. The well bore composition of wherein the subterranean fluid additive comprises an additive selected from the group consisting of a cement activator claim 33 , a crosslinking agent claim 33 , and a curing agent.38. The well bore composition of wherein the well bore treatment fluid is a cement composition.39. The well bore composition of wherein the well bore treatment fluid is a pill.40. The well bore composition of wherein the well bore treatment fluid further comprises a consolidating agent.41. The well bore composition of wherein the magnetically activated device includes a remote control signal source capable of generating an electromagnetic control signal.42. The well bore composition of wherein the magnetically activated device is microfabricated.43. The well bore composition of wherein the magnetically activated device is nanofabricated.44. The well bore composition of wherein the magnetically activated device comprises at least one selected from the following: a polymer claim 34 , a ceramic claim 34 , a plastic claim 34 , a dielectric claim 34 , metals claim 34 , and any combination thereof.45. A well bore composition comprising:a well ...

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Номер записи: 28
13-06-2013 дата публикации

Thermally-Activated, High-Temperature Cement Suspending Agent

Номер: US20130150483A1
Автор: Funkhouser Gary, Kellum Matthew G.
Принадлежит: Halliburton Energy Services, Inc.

A cementing fluid may include an aqueous fluid, a hydraulic cement, and a cement suspending agent comprising a crosslinked particulate, wherein the crosslinked particulate is made from a reaction comprising: a first monofunctional monomer, a primary crosslinker, and a secondary crosslinker. In some instances, the reaction may further comprise a second monofunctional monomer. 120-. (canceled)21. A cementing fluid comprising:an aqueous fluid,a hydraulic cement, and a first monofunctional monomer,', 'a primary crosslinker, and', 'a secondary crosslinker., 'a cement suspending agent comprising a crosslinked particulate, wherein the crosslinked particulate is made from a reaction comprising22. The cementing fluid of further comprising at least one selected from the group consisting of a weighting agent claim 21 , a fine aggregate particulate claim 21 , and any combination thereof.23. The cementing fluid of claim 21 , wherein the first monofunctional monomer comprises a monomer selected from the group consisting of N claim 21 ,N-dimethylacrylamide claim 21 , sodium 2-acrylamido-2-methylpropanesulfonate claim 21 , 2-acrylamido-2-methylpropanesulfonic acid claim 21 , N-(hydroxymethyl)acrylamide claim 21 , N-(hydroxyethyl)acrylamide claim 21 , acrylamide claim 21 , methacrylamide claim 21 , N-vinylformamide claim 21 , 1-vinyl-2-pyrrolidinone claim 21 , N-vinylcaprolactam claim 21 , N-acryloyl morpholine claim 21 , N-methyl-N-vinylacetamide claim 21 , N-isopropylacrylamide claim 21 , N claim 21 ,N-diethylacrylamide claim 21 , sodium 4-styrenesulfonate claim 21 , and vinylsulfonic acid.24. The cementing fluid of claim 21 , wherein the primary crosslinker is present in the reaction at about 0.1% to about 20% by weight of total monomer.25. The cementing fluid of claim 21 , wherein the primary crosslinker comprises a crosslinking agent selected from the group consisting of ethylene diacrylate claim 21 , polyethylene glycol diacrylate with 2 to 30 ethylene glycol units claim 21 , ...

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Номер записи: 29
20-06-2013 дата публикации

Electrolytic composite materials

Номер: US20130152824A1
Автор: James B. Crews, Othon Rego Monteiro
Принадлежит: Individual

A composition comprising a metallic composition, an inorganic oxide-based polymer, and a solvent. A cure product of the metallic composition, inorganic oxide-based polymer, and solvent, the cure product having a network structure, are also disclosed.

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Номер записи: 30
20-06-2013 дата публикации

Compositions Containing Kiln Dust and/or Biowaste Ash and Methods of Use

Номер: US20130153214A1
Автор: Benkley James R., Brenneis D. Chad, Morgan Ronnie G., Roddy Craig W.
Принадлежит: Halliburton Energy Services, Inc.

An embodiment of the present invention comprises a method of treating a subterranean formation comprising: providing a treatment fluid comprising a kiln dust, biowaste ash, and water; and introducing the treatment fluid into a subterranean formation. Another embodiment of the present invention comprises a method of cementing comprising: introducing a cement composition into a subterranean formation, wherein the cement composition comprises a kiln dust, biowaste ash, and water; and allowing the cement composition to set in the subterranean formation. Yet another embodiment of the present invention comprises a method comprising: providing a spacer fluid comprising biowaste ash and water; introducing the spacer fluid into a well bore to displace at least a portion of a first fluid from the well bore; and introducing a cement composition into the well bore, wherein the spacer fluid separates the cement composition and the first fluid. 1. A method of treating a subterranean formation comprising:providing a treatment fluid comprising a kiln dust, biowaste ash, and water; andintroducing the treatment fluid into a subterranean formation.2. The method of wherein the biowaste ash comprises at least one biowaste ash selected from the group consisting of agricultural waste ash claim 1 , municipal waste ash claim 1 , municipal solid waste ash claim 1 , waste-water treatment waste ash claim 1 , animal waste ash claim 1 , non-human claim 1 , non-animal industrial waste ash claim 1 , and combinations thereof.3. The method of wherein the biowaste ash comprises biowaste that was burned at a temperature of about 400° C. to about 900° C. for a time period of from about 2 hours to about 8 hours.4. The method of wherein the kiln dust is a partially calcined kiln feed removed from a gas stream comprising SiO claim 1 , AlO claim 1 , FeO claim 1 , CaO claim 1 , MgO claim 1 , SO claim 1 , NaO claim 1 , and KO.5. The method of wherein the kiln dust comprises cement kiln dust.6. The method of ...

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Номер записи: 31
20-06-2013 дата публикации

Spacer Fluids Containing Cement Kiln Dust and Methods of Use

Номер: US20130157903A1
Автор: Benkley James Robert, Brenneis D. Chad, Roddy Craig W.
Принадлежит: Halliburton Energy Services, Inc.

Disclosed are spacer fluids comprising cement kiln dust (“CKD”) and methods of use in subterranean formations. 1. A spacer fluid comprising:cement kiln dust, andwater, (a) a higher yield point at 130° F. than at 80° F.,', '(b) a higher yield point at 180° F. than at 80° F., and/or', '(c) a higher plastic viscosity at 180° F. than at 80° F., 'wherein the spacer fluid has2. The spacer fluid of wherein the cement kiln dust is present in the spacer fluid in an amount of about 1% to about 65% by weight of the spacer fluid.3. The spacer fluid of wherein the cement kiln dust comprises oxides selected from the group consisting of: SiO claim 1 , AlO claim 1 , FeO claim 1 , CaO claim 1 , MgO claim 1 , SO claim 1 , NaO claim 1 , KO claim 1 , and any combination thereof.4. The spacer fluid of wherein the spacer fluid further comprises fly ash.5. The spacer fluid of wherein the fly ash is present in an amount of about 1% to about 60% by weight of the spacer fluid.6. The spacer fluid of wherein the water is present in the spacer fluid in an amount of about 15% to about 95% by weight of the spacer fluid.7. The spacer fluid of wherein the spacer fluid comprises the cement kiln dust in an amount of about 1% to about 65% by weight of the spacer fluid claim 1 , and wherein the spacer fluid further comprises fly ash in an amount of about 1% to about 60% by weight of the spacer fluid.8. The spacer fluid of wherein the spacer fluid further comprises at least one additive selected from the group consisting of a free water control additive claim 1 , a weighting agent claim 1 , a viscosifying agent claim 1 , a fluid loss control additive claim 1 , a lost circulation material claim 1 , a filtration control additive claim 1 , a dispersant claim 1 , a defoamer claim 1 , a corrosion inhibitor claim 1 , a scale inhibitor claim 1 , a formation conditioning agent claim 1 , and any combination thereof.9. The spacer fluid of wherein the spacer fluid further comprises at least one additive selected ...

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Номер записи: 32
18-07-2013 дата публикации

SETTABLE SPACER FLUIDS COMPRISING PUMICITE AND METHODS OF USING SUCH FLUIDS IN SUBTERRANEAN FORMATIONS

Номер: US20130180716A1
Автор: Karcher Jeffery Dwane, Lende Gunnar
Принадлежит:

Methods and compositions for the treatment of subterranean formations, and more specifically, treatment fluids containing pumicite and methods of using these treatment fluids in subterranean formations, are provided. An example of a method is a method of displacing a fluid in a well bore. Another example of a method is a method of separating fluids in a well bore in a subterranean formation. An example of a composition is a settable spacer fluid comprising pumicite, an activating agent, and a base fluid. 1. A settable spacer fluid comprising pumicite , an activating agent , and a base fluid.2. The settable spacer fluid of claim 1 , wherein the activating agent comprises at least one activating agent selected from the group consisting of: lime;calcium chloride; calcium bromide; sodium hexametaphosphate; sodium silicate; sodium sulfate; and a combination thereof3. The settable spacer fluid of claim 1 , further comprising a set accelerator.4. The settable spacer fluid of claim 1 , wherein the pumicite is present in an amount from about 0.01% to about 90% by weight of the settable spacer fluid.5. The settable spacer fluid of claim 1 , wherein the activating agent is present in an amount from about 0.01% to about 35% by weight of the settable spacer fluid.6. The settable spacer fluid of claim 1 , wherein the base fluid comprises at least one of the following: an aqueous-based fluid claim 1 , an emulsion claim 1 , a synthetic fluid claim 1 , or an oil-based fluid.7. The settable spacer fluid of claim 1 , wherein the 300/3 ratio of the settable spacer fluid is from about 5 to about 50.8. A method of using a settable fluid in a well bore claim 1 , comprising:providing a well bore having a first fluid disposed therein;placing a second fluid into the well bore to displace at least a portion of the first fluid therefrom, wherein the second fluid comprises pumicite, an activating agent, and a base fluid; andallowing the second fluid to at least partially set in the well bore.9. ...

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Номер записи: 33
05-09-2013 дата публикации

Slag Compositions and Methods of Use

Номер: US20130231416A1
Автор: Brenneis D. Chad, Chatterji Jiten, Jarratt Callie R.
Принадлежит: Halliburton Energy Services, Inc.

Methods and compositions are provided that relate to cementing operations. Methods and compositions that include a latex strength enhancer for enhancing the compressive strength of slag compositions. 1. A method of preparing a slag composition , comprising:preparing a base fluid comprising a latex strength enhancer, a defoaming agent, and a dispersant;preparing a dry blend comprising slag and a hydroxyl source; andcombining the base fluid and the dry blend to form the slag composition.2. The method of claim 1 , wherein the hydroxyl source is present in an amount of about 0.1% to about 25% by weight of cementitious components in the slag composition.3. The method of claim 1 , wherein the hydroxyl source comprises a basic material selected from the group consisting of sodium hydroxide claim 1 , sodium bicarbonate claim 1 , sodium carbonate claim 1 , lime claim 1 , and any combination thereof.4. The method of claim 1 , wherein the slag composition has a density of about 12 pounds per gallon to about 20 pounds per gallon.5. The method of claim 1 , wherein the latex strength enhancer comprises a rubber material selected from the group consisting of ethylene-propylene rubber claim 1 , styrene-butadiene rubber claim 1 , nitrile rubber claim 1 , nitrile butadiene rubber claim 1 , butyl rubber claim 1 , neoprene rubber claim 1 , polybutadiene rubber claim 1 , acrylonitrile-styrene-butadiene rubber claim 1 , polyisoprene rubber claim 1 , 2-acrylamido-2-methylpropanesulfonic acid-styrene-butadiene rubber claim 1 , and any combination thereof.6. The method of claim 1 , wherein the latex strength enhancer is present in an amount of about 1% to about 45% by weight of cementitious components in the slag composition.7. The method of claim 1 , wherein the slag composition further comprises an additive selected from the group consisting of a dispersant claim 1 , a defoaming agent claim 1 , a strength-retrogression additive claim 1 , a set accelerator claim 1 , a set retarder claim 1 ...

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Номер записи: 34
12-09-2013 дата публикации

Methods and Systems for Evaluating a Boundary Between a Consolidating Spacer Fluid and a Cement Composition

Номер: US20130233538A1
Автор: Benkley James R., Brenneis D. Chad, Chatterji Jiten, Morgan Ronnie G., Roddy Craig W.
Принадлежит: Halliburton Energy Services, Inc.

Disclosed are spacer fluids and methods of use in subterranean formations. Embodiments may include use of consolidating spacer fluids in displacement of drilling fluids from a well bore annulus. Embodiments may include determining the boundary between a cement composition and a consolidating spacer fluid based on presence of tagging material in the well bore. 1. A method of evaluating a boundary between a consolidating spacer fluid and a cement composition comprising:introducing a consolidating spacer fluid into a well bore to displace at least a portion of a drilling fluid from the well bore;introducing a cement composition into the well bore behind the consolidating spacer fluid;allowing at least a portion of the consolidating spacer fluid to consolidate in the well bore; anddetermining the boundary between the cement composition and the consolidating spacer fluid based on presence of a tagging material in the well bore.2. The method of claim 1 , wherein the determining the boundary comprises running a neutron log in the well bore.3. The method of claim 1 , wherein the tagging material is present in a first portion of the cement composition that is introduced into the well bore.4. The method of claim 3 , wherein the tagging material is present in an amount in a range of from about 0.1% to about 5% by weight of the first portion.5. The method of claim 1 , wherein the tagging material is present in a trailing portion of the consolidating spacer fluid.6. The method of claim 5 , wherein the tagging material is present in an amount in a range of from about 0.1% to about 5% by weight of the trailing portion.7. The method of claim 1 , wherein the tagging material comprises a thermal neutron absorbing material.8. The method of claim 1 , wherein the tagging material comprises at least one tagging material selected from the group consisting of boron carbide claim 1 , cadmium hydroxide claim 1 , and any combination thereof.9. The method of claim 1 , further comprising ...

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Номер записи: 35
12-09-2013 дата публикации

Two-Component Mortar Composition and its Use

Номер: US20130237634A1
Автор: BUERGEL Thomas
Принадлежит: Hilti Aktiengesellschaft

A description is given of a two-component mortar composition having a curable resin component having a content of at least one free-radically polymerizable resin, fillers, accelerators, stabilizers and optionally further conventional mortar constituents and a hardener component which is arranged separately therefrom to inhibit reaction and has a content of at least one peroxide for chemical fastening of anchoring means in boreholes, which is characterized in that the resin component contains from 0.1 to 0.5% by weight of at least one accelerator and from 0.003 to 0.03% by weight of at least one stabilizer and the hardener component contains from 0.1 to 0.35% by weight of organic peroxide, in each case based on the total weight of resin component and hardener component, and also the use of this two-component mortar composition for chemical fastening of anchoring means in boreholes. 1. A two-component mortar composition having a curable resin component having a content of at least one free-radically polymerizable resin , fillers , accelerators , stabilizers and optionally further conventional mortar constituents and a hardener component , which is arranged separately therefrom to inhibit reaction and has a content of at least one peroxide for chemical fastening of anchoring means in boreholes , characterized in that the resin component contains from 0.1 to 0.5% by weight of at least one accelerator and from 0.003 to 0.03% by weight of at least one stabilizer and the hardener component contains from 0.1 to 0.35% by weight of peroxide , in each case based on the total weight of resin component and hardener component.2. The two-component mortar composition according to claim 1 , characterized in that the resin component contains from 8 to 25% by weight of free-radically polymerizable resin claim 1 , from 8 to 25% by weight of reactive diluent claim 1 , from 0.1 to 0.5% by weight of accelerator and from 0.003 to 0.03% by weight of stabilizer claim 1 , from 40 to 70% by ...

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Номер записи: 36
19-09-2013 дата публикации

Lost Circulation Materials and Methods of Using the Same

Номер: US20130244910A1
Автор: Matthew Lynn Miller, Philip Wayne Livanec
Принадлежит: Halliburton Energy Services Inc

A method of servicing a wellbore in contact with a subterranean formation, comprising placing a wellbore servicing fluid comprising a drilling fluid and lost circulation material into a lost circulation zone within the wellbore, wherein the lost circulation material comprises a polyelectrolyte multilayer material and a first counterion. A wellbore servicing fluid comprising a drilling fluid and a lost circulation material comprising a polyelectrolyte multilayer material and a counterion comprising a halide, wherein the LCM has a first state that is hydrophilic. A tunable lost circulation material comprising a base material, a polyelectrolyte multilayer on said base material, wherein the polyelectrolyte multilayer comprises a first electrolyte layer, a second electrolyte layer, and a charged surface, and a counterion, wherein wettability of the lost circulation material is a function of the counterion.

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Номер записи: 37
19-09-2013 дата публикации

Foamed Spacer Fluids Containing Cement Kiln Dust and Methods of Use

Номер: US20130244911A1
Автор: Benkley James Robert, Brenneis D. Chad, Garrison Christopher Jay, Kranz Zachary Robert, Roddy Craig W., Spencer Joseph V.
Принадлежит: Halliburton Energy Services, Inc.

Disclosed are foamed spacer fluids comprising kiln dust for use in subterranean formations. An embodiment discloses a foamed spacer fluid comprising a partially calcined kiln feed removed from a gas stream comprising SiO2, Al2O3, Fe2O3, CaO, MgO, SO3, Na2O, and K2O; a foaming agent; a gas; and water. 1. A foamed spacer fluid for displacing at least a portion of a first fluid present in a well bore comprising:{'sub': 2', '2', '3', '2', '3', '3', '2', '2, 'a partially calcined kiln feed removed from a gas stream comprising SiO, AlO, FeO, CaO, MgO, SO, NaO, and KO;'}a foaming agent;a gas; andwater.2. The foamed spacer fluid of claim 1 , wherein the foamed spacer fluid has a yield point at 80° F. that is higher than a yield point of the first fluid at 80° F.3. The foamed spacer fluid of claim 1 , wherein the foamed spacer fluid has a yield point at 180° F. that is higher than a yield point of the first fluid at 180° F.4. The foamed spacer fluid of claim 1 , wherein the foamed spacer fluid has a higher yield point at bottom hole static temperature of the well bore than at 80° F.5. The foamed spacer fluid of claim 1 , wherein the yield point of the foamed spacer fluid at 180° F. is greater than about 20 lb/100 ft.6. The foamed spacer fluid of claim 1 , wherein the foamed spacer fluid has a density in the range of from about 4 lb/gal to about 13 lb/gal.7. The foamed spacer fluid of claim 1 , wherein the partially calcined kiln feed is present in the foamed spacer fluid in an amount in a range of from about 1% to about 65% by weight of the foamed spacer fluid.8. The foamed spacer fluid of claim 1 , wherein the gas comprises at least one gas selected from the group consisting of air claim 1 , nitrogen claim 1 , and any combination thereof; and wherein the foaming agent comprises at least one additive selected from the group consisting of a mixture of an ammonium salt of an alkyl ether sulfate claim 1 , a cocoamidopropyl betaine surfactant claim 1 , a cocoamidopropyl ...

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Номер записи: 38
19-09-2013 дата публикации

Composition and method of converting a fluid from oil external to water external for cleaning a wellbore

Номер: US20130244913A1
Автор: David N. Harry, Fati Malekahmadi, L. Jack Maberry
Принадлежит: Individual

An environmentally acceptable water-in-oil microemulsion composition includes at least one emulsifying surfactant, at least one biodegradable hydrocarbon solvent, at least one co-solvent, at least one hydrocarbon co-surfactant, and water. The microemulsion composition may be used in a method for rendering fluids from oil external to water external. The microemulsion composition may be combined with water or a water based fluid to produce a spacer fluid utilized in removing oil and oil-residues from a surface, particularly that of wellbores in the drilling of oil and gas wells.

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Номер записи: 39
03-10-2013 дата публикации

Compositions and Methods for Well Completions

Номер: US20130255948A1
Автор: Gabilly Laurent, Michaux Michel
Принадлежит:

Well-cementing compositions for use in high-pressure, high-temperature (HPHT) wells are often densified, and contain weighting agents such as hematite, ilmenite, barite and hausmannite. The weighting agents are usually finely divided to help keep them suspended in the cement slurry. At high temperatures, finely divided weighting agents based on metal oxides react with the calcium-silicate-hydrate binder in set Portland, cement, leading to cement deterioration. Finely divided weighting agents based on metal sulfates are inert with respect to calcium silicate hydrate; consequently, set-cement stability is preserved. 1. A well-cementing composition , comprising water and solids comprising Portland cement , silica and an additive comprising one or more metal sulfates in the list comprising barite , celestine and anglesite , wherein the median particle size of the additive is smaller than about 10 μm and wherein the additive concentration is between about 1% and about 150% by weight of cement.2. The composition of claim 1 , wherein the density of the composition is higher than about 2035 kg/m.3. (canceled)4. The composition of claim 1 , further comprising one or more additives in the list comprising: accelerators claim 1 , retarders claim 1 , extenders claim 1 , fluid-loss additives claim 1 , dispersants claim 1 , gas-generating agents claim 1 , antifoam agents claim 1 , chemical-expansion agents claim 1 , flexible additives claim 1 , pozzolans and fibers.5. The composition of claim 1 , wherein the solids are present in at least two particle-size ranges.6. The composition of claim 1 , wherein the viscosity of said composition is lower than 1000 mPa-s at a shear rate of 100 s.7. The composition of claim 1 , wherein the median particle size of the additive is smaller than about 5 μm.8. A method for maintaining the compressive strength of a well-cementing composition claim 1 , comprising:(i) providing a cement slurry comprising water, Portland cement and silica; and(ii) ...

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Номер записи: 40
03-10-2013 дата публикации

Low Viscosity Synthetic Cement

Номер: US20130261220A1
Автор: Erin Murphy
Принадлежит: KRATON POLYMERS US LLC

The present invention relates to a synthetic cement that comprises a low viscosity monofunctional monomer, a dicyclopentadienyl moiety having a pendant free radical reactive species, 1,3-butyleneglycol dimethacrylate, unsaturated styrenic block copolymer, and a peroxide curing agent. Additionally it may include weighting agents depending on the circumstances of the well, as is well known to those skilled in the art. Other additional components such as oil based mud, suspending agents, Portland cement, acrylates and methacrylates, retardant curing additives, and clays may optionally be incorporated into the synthetic cement. The synthetic cement is activated by heat, for example, and can be crafted to set within a certain time frame, for example in 4 hours, so that it pumpable for as long as need be, and then be set to seal the well in the manner desired.

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Номер записи: 41
17-10-2013 дата публикации

Retarded Cement Compositions and Methods for Well Completions

Номер: US20130269940A1
Автор: Laurent Gabilly, Michel Michaux
Принадлежит: Schlumberger Technology Corp

Cement retarders are based on blends of lignosulfonate compounds, borate compounds and gluconate compounds. The compounds are present in certain ratios that allow the retarders to operate at temperatures and pressures up to and exceeding about 176° C. and 152 MPa. The retarders may also be provided in liquid form, improving their suitability for use at offshore well-site locations.

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Номер записи: 42
31-10-2013 дата публикации

Wide temperature range cement retarder

Номер: US20130284439A1
Автор: Rahul Chandrakant Patil, Ramesh Muthusamy, Sandip Prabhakar Patil, Tushar Sureshgir Gosavi
Принадлежит: Halliburton Energy Services Inc

According to an embodiment, a composition is provided that can be used in a cementing. The composition includes at least: (i) a hydraulic cement; and (ii) a copolymer comprising at least the monomeric units (a) through (d) of the following formula: wherein the monomeric units (a) through (d) can be any sequence and any proportion in the copolymer. With water, the composition of the hydraulic cement and such a copolymer becomes a cement composition. According to the method, the cement composition is introduced into a well and allowed to set in the well.

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Номер записи: 43
14-11-2013 дата публикации

OIL AND GAS WELL CEMENT SYSTEMS USING ELEMENTAL SULFUR

Номер: US20130299171A1
Автор: Mahmoudkhani Amir, WARRENDER Neil
Принадлежит: SANJEL LIMITED PARTNERSHIP

A cement composition for cementing an oil or gas well includes Portland cement, water and a sulfur component. The cement composition may be used to cement a well bore by creating a cement slurry including the sulfur component, pumping the slurry into the well bore to a selected location and allowing it to solidify. 1. A method of cementing a subterranean wellbore , comprising the step of creating a pumpable cement slurry , and introducing the slurry into the wellbore , wherein said slurry comprises water and a cement composition comprising a Portland cement and a sulfur component , the slurry being free of aggregate.2. The method of which is a primary cementing method.3. The method of which is a remedial cementing process.4. The method of wherein the cement composition further comprises one or more of the following additives: a retarder claim 1 , a fluid loss control agent claim 1 , an accelerator claim 1 , a dispersant claim 1 , a cementitious material claim 1 , or a pozzolanic material.5. The method of wherein the Portland cement is a type A or a type G cement.6. The method of wherein the slurry further comprises fly ash.7. The method of wherein the sulfur component comprises finely divided elemental sulfur claim 1 , or its reaction products claim 1 , or both.8. The method of wherein the elemental sulfur has an average particle size less than about 1 mm in size.9. The method of wherein the sulfur component comprises more than 0% and less than about 40% by weight of blend of the cement composition.10. The method of wherein the sulfur component comprises more than about 5% and less than about 30% by weight of blend of the cement composition.11. The method of wherein the sulfur component comprises more than about 10% and less than about 20% by weight of blend of the cement composition.12. The method of wherein the elemental sulfur comprises high purity sulfur claim 7 , with less than about 2% impurities by weight.13. The method of wherein the cement composition ...

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Номер записи: 44
28-11-2013 дата публикации

Compositions Comprising Kiln Dust and Wollastonite and Methods of Use in Subterranean Formations

Номер: US20130312641A1
Автор: Adams Baya, Brenneis Darrell Chad, Chatterji Jiten, Roddy Craig Wayne
Принадлежит: Halliburton Energy Services, Inc.

Embodiments relate to cementing operations and, more particularly, in certain embodiments, to settable compositions that comprise kiln dust and wollastonite and methods of use in subterranean formations. An embodiment discloses a method of cementing comprising: providing a settable composition comprising kiln dust, wollastonite, and water; and allowing the settable composition to set. 1. A method of cementing comprising:providing a settable composition comprising kiln dust, wollastonite, and water; andallowing the settable composition to set.2. The method of wherein the kiln dust comprises at least one partially calcined kiln feed selected from the group consisting of cement kiln dust claim 1 , lime kiln dust claim 1 , and a combination thereof.3. The method of wherein the kiln dust comprises SiO claim 1 , AlO claim 1 , FeO claim 1 , CaO claim 1 , MgO claim 1 , SO claim 1 , NaO claim 1 , and KO.4. The method of wherein the kiln dust is present in the settable composition in an amount in a range of from about 1% to about 99% by weight of a total amount of cementitious components present in the settable composition.5. The method of wherein the wollastonite is present in the settable composition in an amount in a range of from about 1% to about 75% by weight of a total amount of cementitious components present in the settable composition.6. The method of wherein the settable composition further comprises Portland cement.7. The method of wherein the Portland cement is present in the settable composition in an amount in a range of from about 1% to about 75% by weight of a total amount of cementitious components present in the settable composition.8. The method of wherein the Portland cement is present in the settable composition in an amount in a range of from about 10% to about 50% by weight of a total amount of cementitious components present in the settable composition claim 6 , wherein the kiln dust is present in the settable composition in an amount in a range of ...

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Номер записи: 45
05-12-2013 дата публикации

SLURRY OF MANGANOMANGANIC OXIDE PARTICLES AND METHOD FOR THE PRODUCTION OF SLURRY

Номер: US20130319295A1
Автор: Al-Bagoury Mohamed, Rostol Vidar Frank
Принадлежит: ELKEM AS

A stable non-settling slurry of water and manganomanganic oxide particles having a particle size below 10 μm. The slurry comprises water and up to 92 wt % manganomanganic oxide particles bade on the weight of the slurry. The slurry has a pH between 9 and 11 and contains 0.05 to 0.5 wt % of a dispersant based on the weight of dry manganomanganic oxide particles. The dispersant can be an ethoxylated polycarboxylate or a polyacrylic acid salt and has a molecular weight between 500 and 50 000 g/mol. 114-. (canceled)13. A stable , non-settling slurry comprising:water;manganomanganic oxide particles having a particle size below 10 μm, the manganomanganic oxide particles present in the slurry in an amount up to 92 wt % based on the weight of the slurry;a dispersant in an amount of 0.05 to 0.5 wt % based on the weight of dry manganomanganic oxide particles in the slurry, the dispersant having a molecular weight between 500 and 50,000 g/mol and selected from an ethoxylated polycarboxylate and a polyacrylic acid salt; anda ph of the slurry being 9 to 11.14. The slurry of claim 13 , wherein the amount of the manganomanganic particles present in the slurry is greater than 80 wt % based on the weight of the slurry.15. The slurry of claim 13 , wherein the amount of the dispersant is 0.07 to 0.15 wt % based on to weight of dry manganomanganic oxide particles.16. The slurry of claim 13 , wherein:the dispersant is a polyacrylic sodium salt having a molecular weight of about 3000 g/mol.17. The slurry of claim 13 , wherein:the dispersant is an ethoxylated polycarboxylate; with a hydrophobic chain as a side chain.18. The slurry of claim 13 , wherein:the ethoxylated polycarboxylate has a molecular weight of about 20,000 g/mol.19. The slurry of claim 13 , wherein:the ph of the slurry is 9.5 to 10.5.201. The slurry of claim claim 13 , wherein the ph of the slurry is adjusted using sodium hydroxide.21. A method of producing a stable claim 13 , non-settling aqueous slurry of manganomanganic ...

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Номер записи: 46
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: 47
02-01-2014 дата публикации

Set-Delayed Cement Compositions Comprising Pumice and Associated Methods

Номер: US20140000893A1
Автор: Kyriacos Agapiou, Peter James Boul, Samuel J. Lewis, Thomas Jason Pisklak
Принадлежит: Halliburton Energy Services Inc

Set-delayed cement compositions and methods of using set-delayed cement compositions in subterranean formations. Embodiments include a method of drilling a wellbore in a subterranean formation comprising: circulating a drilling fluid comprising a set-delayed cement composition in the wellbore while drilling the wellbore, wherein the set-delayed cement composition comprises: pumice, hydrated lime, a set retarder, and water. A method of displacing a fluid in a wellbore comprising: introducing a spacer fluid comprising a set-delayed cement composition into a wellbore such that the spacer fluid displaces one or more prior fluids from the wellbore, and wherein the set-delayed cement composition comprises: pumice, hydrated lime, a set retarder, and water.

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Номер записи: 48
09-01-2014 дата публикации

METHODS FOR CEMENTING IN A SUBTERRANEAN FORMATION USING A CEMENT COMPOSITION CONTAINING A SET RETARDER OF A POLYESTER

Номер: US20140011908A1
Автор: FITZGERALD Russel, GAUGLER Drew, Reddy B. Raghava
Принадлежит: Halliburton Energy Services, Inc.

A cement composition for use in an oil or gas well, the cement composition comprises: cement; water; and a polymer, wherein the polymer: (i) comprises a monomer or monomers capable of forming a polyester; and (ii) is capable of providing a thickening time of at least 2 hours at a temperature of 400° F. (204.4° C.) and a pressure of greater than about 500 psi (3.4 MPa) for a test composition consisting essentially of: the cement; the water; and the polymer, and in the same proportions as in the cement composition. A method of cementing in a subterranean formation comprises: introducing the cement composition into the subterranean formation; and allowing the cement composition to set. 1. A cement composition for use in an oil or gas well , the cement composition comprising:cement, wherein the cement is a calcium aluminate cement;water; and (i) comprises a monomer or monomers capable of forming a polyester; and', '(ii) is capable of providing a thickening time of at least 2 hours at a temperature of 400° F. (204.4° C.) and a pressure of greater than about 500 psi (3.4 MPa) for a test composition consisting essentially of: the cement; the water; and the polymer, and in the same proportions as in the cement composition., 'a polymer, wherein the polymer2. The composition according to claim 1 , wherein the water is selected from the group consisting of freshwater claim 1 , brackish water claim 1 , and saltwater claim 1 , in any combination thereof in any proportion.3. The composition according to claim 1 , wherein the polymer is a thermoplastic aliphatic polyester.4. The composition according to claim 1 , wherein the first monomer is selected from the group consisting of ethylene glycol claim 1 , propylene glycol claim 1 , butanediol claim 1 , pentaerythritol claim 1 , and butane diol.5. The composition according to claim 1 , wherein the second monomer is selected from the group consisting of (ortho- meta- or para-)phthalic acid claim 1 , citric acid claim 1 , malic acid ...

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Номер записи: 49
23-01-2014 дата публикации

Foaming of Set-Delayed Cement Compositions Comprising Pumice and Hydrated Lime

Номер: US20140020895A1
Автор: Agapiou Kyriacos, Boul Peter James, Brothers Lance Everett, Lewis Samuel J., Otieno Pauline Akinyi, Pisklak Thomas Jason
Принадлежит: Halliburton Energy Services, Inc.

A variety of methods and compositions are disclosed, including, in one embodiment a method a cementing in a subterranean formation comprising: providing a set-delayed cement composition comprising water, pumice, hydrated lime, and a set retarder; foaming the set-delayed cement composition; activating the set-delayed cement composition; introducing the set-delayed cement composition into a subterranean formation; and allowing the set-delayed cement composition to set in the subterranean formation. Additional methods, foamed set-delayed cement composition, and systems for cementing are also provided. 1. A method of cementing in a subterranean formation comprising:providing a set-delayed cement composition comprising water, pumice, hydrated lime, and a set retarder;foaming the set-delayed cement composition;activating the set-delayed cement composition;introducing the set-delayed cement composition into a subterranean formation; andallowing the set-delayed cement composition to set in the subterranean formation.2. The method of wherein the foaming the set-delayed cement composition comprises adding a foaming additive to the set-delayed cement composition and entraining a gas into the set-delayed cement composition.3. The method of wherein the foaming additive is selected from the group consisting of: a betaine; hydrolyzed keratin; an amine oxides; an alkyl or alkene dimethyl amine oxide; a cocoamidopropyl dimethyl amine oxide; a methyl ester sulfonate; an alkyl or alkene dimethyl amidobetaine; cocoamidopropyl betaine; an alpha-olefin sulfonate; a quaternary surfactant; trimethyltallowammonium chloride; trimethylcocoammonium chloride; a C8 to C22 alkylethoxylate sulfate; and any combination thereof.4. The method of wherein the foaming the set-delayed cement composition produces a foamed set-delayed cement composition comprising a foam quality between about 5% to about 80%.5. The method of wherein the foaming the set-delayed cement composition produces a foamed set- ...

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Номер записи: 50
06-02-2014 дата публикации

NON-RADIOACTIVE TAGGED CEMENT ADDITIVE FOR CEMENT EVALUATION IN A WELL SYSTEM

Номер: US20140034823A1
Автор: Hyde-Barber Catherine
Принадлежит: BP CORPORATION NORTH AMERICA INC.

An inert (non-radioactive) tagging material can be added to cement in a wellbore. The non-radioactive tagging material can emit radiation at a specific energy level when irradiated with radiation. A logging tool containing a radiation source can be introduced into a wellbore and activated to emit radiation. The logging tool can detect the radiation emitted from the non-radioactive tags within the wellbore. Accordingly, integrity of cement, particularly low density cements that have a density close to that of fluid provided to or contained within a hydrocarbon-bearing formation, can be determined from the detected radiation. 1. A method of evaluating a bonding material location in a wellbore , the method comprising:inducing a radiation generating source to emit a first type of radiation into the wellbore;detecting a second type of radiation emitted by the bonding material in response to the bonding material interacting with the first type of radiation; andevaluating, by a processor, the second type of radiation to determine a location of the bonding material in the wellbore.2. The method according to claim 1 , wherein the first type of radiation comprises neutron radiation.3. The method according to claim 2 , wherein the neutron radiation comprises neutrons with energy of about 14.1 MeV.4. The method according to claim 1 , wherein the second type of radiation comprises at least one of neutrons claim 1 , protons claim 1 , alpha particles claim 1 , and gamma rays.5. The method according to claim 1 , wherein the bonding material is arranged in an annulus between a wall of the wellbore and a surface of a tubular member.6. The method according to claim 1 , wherein the bonding material includes a composition including a cement material and a non-radioactive tagging material claim 1 , wherein the non-radioactive tagging material is operable to interact with the first type of radiation and emit the second type of radiation at a characteristic energy level.7. The method ...

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Номер записи: 51
13-02-2014 дата публикации

Method For Reducing Permeability Of A Subterranean Reservoir

Номер: US20140041870A1
Автор: Mark Sanders, Russell Watson
Принадлежит: MI Drilling Fluids UK Ltd

The present invention provides a method of isolating a selected reservoir zone in a subterranean reservoir comprising at least the step of squeezing a treatment fluid into the selected reservoir zone, the treatment fluid comprising: a viscosifying agent; a fluid loss control agent; and a particulate material. The invention further provides a treatment fluid comprising a base fluid; a viscosifying agent; at least 20 kg/m 3 of a fluid loss control agent; and a particulate material.

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Номер записи: 52
13-02-2014 дата публикации

Equipment and Methods for Preparing Curved Fibers

Номер: US20140045731A1
Автор: Daccord Gerard
Принадлежит: SCHLUMBERGER TECHNOLOGY CORPORATION

The invention is related in general to equipment and methods for preparing curved fibers in a batch or continuous process. Fiber strands comprising a thermoplastic material are placed on a cylindrical surface and heated such that they soften and become malleable. The fiber strands assume the curvature of the cylindrical surface and, upon cooling below their softening temperature, retain the curvature. The curved-fiber strands are then cut to a desired length. 1. An apparatus for preparing curved fibers , comprising:i. a rotating cylindrical screw feeder;ii. a rolling zone comprising means for transporting and guiding one or more strands of fiber onto the screw feeder;iii. a heating zone comprising means for heating the fiber as it travels down the screw feeder;iv. a cooling zone comprising means for cooling the fiber as it travels down the screw feeder;v. an unrolling zone comprising means for guiding and transporting one or more strands of fiber away from the screw feeder;vi. means for cutting the fiber.2. The apparatus of claim 1 , wherein the means for heating the apparatus is one or more members of the list comprising: an oven claim 1 , a heating rod claim 1 , a forced-air heater and an infrared heater.3. A method of preparing curved fibers claim 3 , using the apparatus of claim 3 , comprising;i. selecting a cylindrical screw feeder whose diameter between the threads provides a desired curvature;ii. selecting one or more continuous fiber strands, the fibers having a composition with a workability-temperature range;iii. threading the fiber strands through the opposing wheels in the rolling zone, and wrapping the strands onto the entire length of the screw feeder between the threads toward the unrolling zone;iv. guiding the fiber strands off of the screw feeder and threading them through the opposing wheels in the unrolling zone;v. initiating rotation of the screw feeder;vi. activating a heat source in the heating zone, such that the fiber composition passing ...

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Номер записи: 53
20-02-2014 дата публикации

COHESIVE SETTABLE CEMENT SYSTEM

Номер: US20140048265A1
Автор: Combs N. Kyle, SABINS Fred, Watters Larry
Принадлежит:

A lightweight cross-linked gelled settable cement fluid system derived by pre-hydrating a water gelling agent, and then using that to mix with a cement blend which results in a very stable cement blend, which will matriculate through any fluid and not disperse, and form a cohesive plug wherever it comes to rest; wherein the fluid is injected at the bottom of the 10 pound/gal brine, and the fluid rises to the top of the brine where it reforms into a cohesive plug and hardens; and wherein the fluid can be applied to any density solution, and provide stability and cohesiveness to any settable plug; and wherein the cement/gelled water mixture is then cross-linked using standard hydraulic fracturing cross-linkers to provide a stable structure and ability to matriculate through another fluid and not disperse into that fluid. In a second embodiment the lightweight cross-linked gelled settable cement fluid which is cohesive and stable to be used as a balanced plug during cementing procedures to avoid the plug from becoming dilute in order to develop compressive strength, prevent fluid interchange from occurring and ensuring that all the cement placed would set in place. 1. A cross-linked gelled settable cement fluid system derived by pre-hydrating a cross-linkable water gelling agent , and then using that to mix with a hydraulic cement blend comprising density modification additives and a particulate substance containing borate which results in a very stable hydraulic cement blend , which will matriculate through any fluid and not disperse , and form a cohesive plug wherever it comes to rest.2. The system in claim 1 , wherein the fluid is injected below a heavier fluid such as brine claim 1 , and the injected fluid rises to the top of the brine where it reforms into a cohesive plug and hardens.3. The system in claim 1 , wherein the fluid can be applied as any density solution claim 1 , and provide stability and cohesiveness to any settable plug.4. The system in claim 1 , ...

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Номер записи: 54
20-02-2014 дата публикации

Methods for Determining Reactive Index for Cement Kiln Dust, Associated Compositions and Methods of Use

Номер: US20140048266A1
Автор: Brenneis D. Chad, Morgan Ronnie G., Roddy Craig W.
Принадлежит: Halliburton Energy Services, Inc.

A variety of methods and compositions are disclosed, including, in one embodiment, a method of treating a well comprising: providing a treatment fluid comprising a base fluid and a blended cementitious component, wherein the blended cementitious component comprises kiln dust from two or more different sources; and introducing the treatment fluid into a well bore. 1. A method of cementing comprising:providing a settable composition comprising water and a blended cementitious component, wherein the blended cementitious component comprises kiln dust and an additional cementitious component, the kiln dust and the additional cementitious component each have a determined reactive index; andallowing the settable composition to set to form a hardened mass.2. The method of further comprising introducing the settable composition into a well bore.3. The method of wherein settable composition is used in primary cementing in the well bore.4. The method of wherein the base fluid comprises water selected from the group consisting of freshwater claim 1 , saltwater claim 1 , brine claim 1 , and any combination thereof claim 1 , and wherein the kiln dust is selected from the group consisting of lime kiln dust claim 1 , cement kiln dust claim 1 , and a combination thereof.5. The method of wherein the kiln dust comprises cement kiln dust claim 1 , the cement kiln dust being present in the treatment fluid in an amount in a range of from about 0.01% to 99% by weight of by weight of the blended cementitious component.6. The method of wherein the amount of the kiln dust and the additional cementitious component is adjusted based on a parameter selected from the group consisting of compressive strength claim 1 , Young's modulus claim 1 , fluid loss claim 1 , thickening time claim 1 , a rheological value claim 1 , free water claim 1 , and any combination thereof.8. The method of wherein the measured parameter is compressive strength claim 7 , Young's modulus claim 7 , fluid loss claim 7 , ...

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Номер записи: 55
20-02-2014 дата публикации

Solubilized Polymer Concentrates, Methods of Preparation Thereof, and Well Drilling and Servicing Fluids Containing the Same

Номер: US20140051606A1
Автор: Dobson, JR. James W., Tresco Kim O.
Принадлежит: TUCC Technology, LLC

The invention provides concentrates for reducing the fluid loss on an oil base well drilling or servicing fluid, the concentrates comprising an oleagineous liquid and (1) a polymer which is solublized in the oleagineous liquid, or (2) a polymer which is solublized in the oleaginous liquid together with an organophilic polyphenolic material which is solublized and/or dispersed in the oleagineous liquid. The method of preparing the concentrate and the method of reducing the fluid loss of an oil base well drilling or servicing fluid utilizing the concentrates is also disclosed. The preferred oil soluble polymer is a styrene-butadiene rubber crumb. The preferred oleagineous liquid is an aromatic-free hydrogenated oil essentially containing only saturated hydrocarbons. The preferred polyphenolic material is a source of humic acid, such as mined lignite. 1. A solubilized polymer concentrate for use in reducing the fluid loss of an oil base well drilling or servicing fluid , the concentrate comprising:an oleaginous liquid;an organophilic polyphenolic material; anda polymer soluble in the oleaginous liquid,wherein the concentration of the polymer is from about 0.0168 grams per milliliter (g/mL) of the oleaginous liquid to about 0.0348 g/mL of the oleaginous liquid, andwherein the particle size of the pre-solubilized polymer is less than about 2000 microns, and wherein the concentration of the organophilic polyphenolic material is from about 0.1677 g/mL of the oleaginous liquid to about 0.3482 g/mL of the oleaginous liquid.2. The concentrate of claim 1 , wherein the polymer is a styrene-butadiene rubber (SBR) crumb or a styrene-butadiene-styrene block copolymer crumb.3. The concentrate of claim 2 , wherein the polymer is a cold-type SBR crumb.4. The concentrate of claim 1 , wherein the oleaginous liquid is an aromatic-free claim 1 , hydrogenated oil comprising only saturated hydrocarbons of medium- to high-molecular weight.5. The concentrate of claim 1 , wherein the ...

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Номер записи: 56
06-03-2014 дата публикации

Compositions Comprising Kiln Dust and Wollastonite and Methods of Use in Subterranean Formations

Номер: US20140060389A1
Автор: Adams Baya, Brenneis Darrell Chad, Chatterji Jiten, Roddy Craig Wayne
Принадлежит: Halliburton Energy Services, Inc.

Embodiments relate to cementing operations and, more particularly, in certain embodiments, to settable compositions that comprise kiln dust and wollastonite and methods of use in subterranean formations. An embodiment discloses a method of cementing comprising: providing a settable composition comprising kiln dust, wollastonite, and water; and allowing the settable composition to set. 1. A cementing system comprising:kiln dust;wollastonite; andwater.2. The cementing system of wherein the kiln dust comprises at least one partially calcined kiln feed selected from the group consisting of cement kiln dust claim 1 , lime kiln dust claim 1 , and a combination thereof.3. The cementing system of wherein the kiln dust comprises SiO claim 1 , AlO claim 1 , FeO claim 1 , CaO claim 1 , MgO claim 1 , SO claim 1 , NaO claim 1 , and KO.4. The cementing system of wherein the kiln dust is present in the settable composition in an amount in a range of from about 1% to about 99% by weight of the total amount of cementitious components present in the settable composition.5. The cementing system of wherein the wollastonite is present in the settable composition in an amount in a range of from about 1% to about 75% by weight of the total amount of cementitious components present in the settable composition.6. The cementing system of wherein the settable composition further comprises Portland cement.7. The cementing system of wherein the Portland cement is present in the settable composition in an amount in a range of from about 1% to about 75% by weight of the total amount of cementitious components present in the settable composition.8. The cementing system of wherein the Portland cement is present in the settable composition in an amount in a range of from about 10% to about 50% by weight of the total amount of cementitious components present in the settable composition claim 6 , wherein the kiln dust is present in the settable composition in an amount in a range of from about 10% to ...

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Номер записи: 57
06-03-2014 дата публикации

METHOD OF ANALYSIS OF POLYMERIZABLE MONOMERIC SPECIES IN A COMPLEX MIXTURE

Номер: US20140060818A1
Автор: Hermes Robert E.
Принадлежит:

Method of selective quantitation of a polymerizable monomeric species in a well spacer fluid, said method comprising the steps of adding at least one solvent having a refractive index of less than about 1.33 to a sample of the complex mixture to produce a solvent phase, and measuring the refractive index of the solvent phase. 1. A method of selective quantitation of a polymerizable monomeric species in well spacer fluid , said method comprising adding at least one solvent having a refractive index of less than about 1.33 to a sample of the well spacer fluid to produce a solvent phase , measuring the refractive index of the solvent phase , and thereafter using the well spacer fluid with a drilled well.2. The method of claim 1 , wherein the solvent is a simple alcohol.3. The method of claim 2 , wherein the simple alcohol is methanol.4. The method of claim 1 , wherein the solvent is substantially free of methanol.5. The method of claim 1 , wherein the polymerizable monomeric species is an acrylate monomer.6. The method of claim 1 , wherein the polymerizable monomeric species is selected from the group consisting of methyl acrylate claim 1 , methyl methacrylate claim 1 , methacrylic acid claim 1 , acrylamide claim 1 , n-vinyl pyrrolidone claim 1 , N-butylurethane-O-ethyl acrylate claim 1 , methyl ether polyethylene glycol monomethacrylate claim 1 , 2-hydroxyethyl methacrylate claim 1 , styrene claim 1 , and mixtures thereof.7. The method of claim 6 , wherein the polymerizable monomeric species is methyl methacrylate.8. The method of wherein the well spacer fluid further comprises a polymer comprised of the polymerizable monomeric species claim 1 , wherein said polymer is substantially insoluble in the solvent phase.9. The method of claim 8 , wherein the polymer is selected from the group consisting of poly(methylmethacrylate) claim 8 , poly(methacrylic acid) claim 8 , polystyrene claim 8 , and mixtures thereof.10. The method of claim 9 , wherein the polymer is poly( ...

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Номер записи: 58
13-03-2014 дата публикации

Sealant Compositions and Methods of Use

Номер: US20140073537A1
Автор: Lende Gunnar, RAVI Krishna M.
Принадлежит: Halliburton Energy Services, Inc.

Of the many methods and compositions provided herein, one method includes a method comprising introducing a sealant composition into a well bore that penetrates a subterranean formation, wherein the sealant composition comprises a base fluid, a binder material, and a filler material; and allowing the sealant composition to form a cohesive sealant. One composition provided herein includes a sealant composition comprising a base fluid, a binder material, and a filler material, wherein the sealant composition will form a cohesive sealant. 119-. (canceled)20. A cohesive sealant composition in a wellbore , the cohesive sealant composition comprising a fly ash , hydrated lime , and at least one filler material selected from the group consisting of barite , calcium carbonate , ground marble , iron oxide , manganese oxide , glass beads , crushed glass , crushed drill cuttings , ground vehicle tire , crushed rock , ground asphalt , crushed concrete , crushed cement , salt , ilmenite , hematite , silica flour , diatomaceous earth , a highly swellable clay miner , and any derivative thereof , and wherein the fly ash and hydrated lime together are present in an amount from about 0.25% to about 30% by weight of the cohesive sealant composition.21. The cohesive sealant composition of claim 20 , wherein the at least one material further comprises ilmenite.22. The cohesive sealant composition of claim 21 , wherein the ilmenite is present in an amount from about 0.25% to about 30% by weight of the cohesive sealant composition.23. The cohesive sealant composition of claim 20 , wherein the filler is present in an amount from about 40% to about 70% by weight of the cohesive sealant composition.24. The cohesive sealant composition of claim 20 , wherein the cohesive sealant composition is ductile.25. The cohesive sealant composition of claim 20 , wherein the cohesive sealant composition elastically yields to shear and compressional stresses present in the well bore.26. The cohesive ...

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Номер записи: 59
20-03-2014 дата публикации

Magnesium chloride in alcoholic solvent for sorel cement

Номер: US20140076561A1
Автор: B. Raghava Reddy
Принадлежит: Halliburton Energy Services Inc

A non-hydraulic cement composition including: (i) a non-aqueous liquid phase comprising one or more organic compounds characterized by: (a) having at least one hydroxyl group on a carbon atom, (b) being a liquid when pure under Standard Laboratory Conditions, and (c) being at least soluble in water; (ii) one or more magnesium chloride compounds selected from the group consisting of: magnesium chloride, a magnesium chloride hydrate, and any combination thereof; and (iii) magnesium oxide; wherein the one or more organic compounds comprise at least 40% by weight of the non-aqueous liquid phase excluding the weight of any dissolved solids. A method of treating a well including the steps of: (A) forming the non-hydraulic cement composition; and (B) introducing the non-hydraulic cement composition into the well.

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Номер записи: 60
20-03-2014 дата публикации

Method of Reducing Water or Gas Permeability in a Subterranean Formation

Номер: US20140076562A1
Автор: Bhaduri Sumit, Qu Qi
Принадлежит:

Water and gas flow into a subterranean reservoir may be reduced by pumping into the reservoir a primary amine crosslinking agent and an anionic or hydrolyzable nonionic polymer capable of crosslinking with the crosslinking agent. The reaction product forms a gel plug impermeable to water and gas. 2. The method of claim 1 , wherein the anionic or hydrolyzable nonionic polymer and primary amine crosslinking agent are pumped into the wellbore as dry powders.3. The method of claim 1 , wherein the primary amine crosslinking agent is selected from the group consisting of polyallylamines claim 1 , polyvinylamines claim 1 , polyamidoamines claim 1 , polyalkyl amines claim 1 , and polyarylamines claim 1 , and mixtures thereof.4. The method of claim 1 , wherein the viscosifying agent and primary amine crosslinking agent are pumped into the wellbore in an aqueous fluid.5. The method of claim 1 , wherein the viscosifying agent and primary amine crosslinking agent are pumped into the wellbore in separate stages.6. The method of claim 1 , wherein at least one of the viscosifying agent and primary amine crosslinking agent are pumped into the wellbore as dry powders.7. The method of claim 1 , wherein the viscosifying agent is hydrolyzed prior to being pumped into the wellbore.8. The method of claim 1 , wherein the viscosifying agent is a partially hydrolyzed polyacrylamide.9. The method of claim 3 , wherein the primary amine crosslinking agent is a polyallylamine or a salt thereof.10. The method of claim 9 , wherein the primary amine crosslinking agent is a quaternary amine salt of a polyallylamine.11. The method of claim 1 , wherein the molecular weight of the primary amine crosslinking agent is between from about 10 claim 1 ,000 to about 50 claim 1 ,000.13. The method of claim 1 , wherein the viscosifying agent is a polyvinylamine selected from the group consisting of polyvinylamine homopolymers; polyvinylamine copolymers; and poly[vinylbenzyl-tri(C-Calkyl)ammonium salts].14. A ...

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Номер записи: 61
20-03-2014 дата публикации

Thermally-Activated, High Temperature Particulate Suspending Agents and Methods Relating Thereto

Номер: US20140076565A1
Автор: Gary P. Funkhouser
Принадлежит: Halliburton Energy Services Inc

A particulate suspending agent may be useful for mitigating particulate settling in wellbore applications with high-temperature and/or at near-neutral and higher pH values. Methods of treating a wellbore may include providing a treatment fluid comprising an aqueous liquid, a plurality of particulates, and a particulate suspending agent, wherein the particulate suspending agent comprises a crosslinked polymer particulate formed by a reaction comprising a first monofunctional monomer and an orthoester crosslinker, the orthoester crosslinker comprising an orthoester linkage and at least two crosslinking moieties; and placing the treatment fluid in a wellbore penetrating a subterranean formation.

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Номер записи: 62
20-03-2014 дата публикации

Ferrosilicon weighting agents for wellbore fluids

Номер: US20140080741A1
Автор: Christopher Bean, Jarrod Hart, Jonathan Stuart Phipps, Mark Windebank, Thomas Parias
Принадлежит: Imerys Oilfield Minerals Inc

A weighting agent for use in a wellbore fluid composition is provided. The weighting agent includes a ferrosilicon material, wherein iron is present in the ferrosilicon material in an amount equal to or greater than about 50% by weight of the ferrosilicon material. A composition including a wellbore fluid and a weighting agent, as well as methods for using and making a weighting agent, are also provided.

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Номер записи: 63
27-03-2014 дата публикации

Cement Compositions for Cementing in Confined Locales and Methods for Use Thereof

Номер: US20140083698A1
Автор: Collins Ryan, Landis Charles, Stone Shantel
Принадлежит: Halliburton Energy Services, Inc.

When conducting cementing operations within confined locales, such as the annular space within a wellbore, it can sometimes be difficult to successfully deliver an uncured cement composition to a desired location. Cementing methods can comprise: providing a cement composition comprising a cement and a property control package, the property control package comprising: a filtration control agent; a friction reducer; and a setting accelerator; introducing the cement composition into a mineral exploration wellbore; and setting the cement composition in the wellbore. 1. A method comprising: a filtration control agent;', 'a friction reducer; and', 'a setting accelerator;, 'providing a cement composition comprising a cement and a property control package, the property control package comprisingintroducing the cement composition into a mineral exploration wellbore; andsetting the cement composition in the wellbore.2. The method of claim 1 , wherein the wellbore comprises an annular structure having an annular space ranging between about 3 mm and about 10 mm.3. The method of claim 2 , wherein the cement composition is set in the annular space.4. The method of claim 1 , wherein the cement composition is set in a lost circulation zone.5. The method of claim 1 , wherein the setting accelerator comprises a substance selected from the group consisting of a calcium salt claim 1 , a sodium salt claim 1 , an amine claim 1 , and any combination thereof.6. The method of claim 5 , wherein the setting accelerator comprises a calcium salt or a sodium salt selected from the group consisting of calcium chloride claim 5 , calcium sulfate claim 5 , calcium nitrate claim 5 , calcium nitrite claim 5 , calcium formate claim 5 , sodium thiocyanate claim 5 , sodium sulfate claim 5 , sodium chloride claim 5 , and any combination thereof.7. The method of claim 1 , wherein the filtration control agent comprises a cellulose derivative claim 1 , a latex polymer claim 1 , or a copolymer of acrylamido-2 ...

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Номер записи: 64
27-03-2014 дата публикации

Placing a Fluid Comprising Kiln Dust in a Wellbore Through a Bottom Hole Assembly

Номер: US20140083699A1
Автор: Benkley James Robert, Brenneis Darrell Chad, Chatterji Jiten, Menezes Clive Denis, MORGAN Ronnie Glen, Roddy Craig Wayne
Принадлежит: Halliburton Energy Services, Inc.

Embodiments relate to systems and methods for introduction of fluids comprising kiln dust into a wellbore through a bottom hole assembly. An embodiment discloses a method comprising: drilling a wellbore in a subterranean formation using a bottom hole assembly; and pumping a treatment fluid into the wellbore through the bottom hole assembly, wherein the treatment fluid comprises a kiln dust and water. 1. A method comprising:drilling a wellbore in a subterranean formation using a bottom hole assembly; andpumping a treatment fluid into the wellbore through the bottom hole assembly, wherein the treatment fluid comprises a kiln dust and water.2. The method of claim 1 , wherein the bottom hole assembly comprises a drill bit claim 1 , and wherein the treatment is pumped through the drill bit.3. The method of claim 1 , wherein the bottom hole assembly is retrievable.4. The method of claim 1 , wherein the bottom hole assembly is non-retrievable.5. The method of claim 1 , wherein the bottom hole assembly is attached to a tubular.6. The method of claim 5 , wherein the tubular is a drill pipe claim 5 , a casing claim 5 , or a combination thereof.7. The method of claim 1 , wherein at least a portion of the wellbore extends at a direction that is slanted from vertical.8. The method of claim 1 , wherein the treatment fluid is a consolidating treatment fluid.9. The method of claim 8 , further comprising circulating a drilling fluid in the wellbore while drilling the wellbore claim 8 , wherein at least a portion of the drilling fluid is displaced from the wellbore by the consolidating treatment fluid.10. The method of claim 8 , further comprising allowing at least a portion of the consolidating treatment fluid to consolidate in the wellbore to have a transition time of about 45 minutes or less.11. The method of claim 8 , further comprising allowing at least a portion of the consolidating treatment fluid to consolidate in the wellbore to have at least one property selected from the ...

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Номер записи: 65
27-03-2014 дата публикации

Cement Set Activators for Set-Delayed Cement Compositions and Associated Methods

Номер: US20140083701A1
Автор: Adams Baya, Agapiou Kyriacos, Boul Peter James, Brothers Lance Everett, Harris Cody Glenn, Lewis Samuel J., MORGAN Ronnie Glen, Otieno Pauline Akinyi, Pisklak Thomas Jason
Принадлежит: Halliburton Energy Services, Inc.

Disclosed herein are cement compositions and methods of using set-delayed cement compositions in subterranean formations. In one embodiment, a method of cementing in a subterranean formation is described. The method may comprise providing a set-delayed cement composition comprising water, pumice, hydrated lime, and a set retarder; activating the set-delayed cement composition with a liquid additive to produce an activated cement composition, wherein the liquid additive comprises a monovalent salt, a polyphosphate, a dispersant, and water; and allowing the activated cement composition to set. 1. A method of cementing comprising:providing a set-delayed cement composition comprising water, pumice, hydrated lime, and a set retarder;activating the set-delayed cement composition with a liquid additive to produce an activated cement composition, wherein the liquid additive comprises a monovalent salt, a polyphosphate, a dispersant, and water; andallowing the activated cement composition to set.2. The method of wherein the liquid additive is added to the set-delayed cement composition in an amount of about 1% to about 20% by weight of the set-delayed cement composition.3. The method of wherein the monovalent salt is present in the liquid additive in an amount of about 0.1% to about 30% by weight of the liquid additive claim 1 , wherein the polyphosphate is present in the liquid additive in an amount of about 0.1% to about 30% by weight of the liquid additive claim 1 , wherein the dispersant is present in the liquid additive in an amount of about 0.1% to about 90% by weight of the liquid additive claim 1 , and wherein the water is present in the liquid additive in an amount of about 50% to about 90% by weight of the liquid additive.4. The method of wherein the polyphosphate comprises sodium hexametaphosphate.5. The method of wherein the monovalent salt comprises sodium sulfate.6. The method of wherein the dispersant comprises a polycarboxylated ether.7. The method of wherein ...

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Номер записи: 66
27-03-2014 дата публикации

IN SITU POLYMERIZATION FOR COMPLETIONS SEALING OR REPAIR

Номер: US20140083702A1
Автор: Godfrey Matthew, KATS ROMAN, MUSSO Simone, ROBISSON AGATHE, ROWATT JOHN DAVID
Принадлежит: SCHLUMBERGER TECHNOLOGY CORPORATION

The isolation of selected regions downhole may be achieved using methods that include emplacing a polymerizable material within a wellbore, wherein the polymerizable material contains a polymerizable component and a latent curing agent; initiating polymerization of the polymerizable material; and forming a seal within the wellbore. Permanent or semi-permanent downhole seals may also be prepared using methods that include emplacing a section of pipe having a surrounding membrane into an interval of a wellbore, wherein the surrounding membrane contains a polymerizable material, and deploying the membrane downhole to form a seal. 1. A method comprising:emplacing a polymerizable material within a wellbore, wherein the polymerizable material comprises a polymerizable component and a latent curing agent;initiating polymerization of the polymerizable material; andforming a seal within the wellbore.2. The method of claim 1 , wherein the polymerizable material is a latent polymerizable material and initiating polymerization of the latent polymerizable material by emplacement within a downhole region having a temperature that is elevated with respect to surface temperature.3. The method of claim 1 , wherein emplacing the polymerizable material further comprises injecting the polymerizable material into a packer present in the wellbore.4. The method of claim 3 , wherein the polymerizable material is present within the packer and wherein the method further comprises longitudinally compressing the packer using mechanical or hydraulic force to form the seal prior to initiating polymerization of the polymerizable material.5. The method of claim 4 , wherein the packer is compressed until the polymerizable material sets.6. The method of claim 1 , wherein forming the seal within the wellbore comprises the formation of a polymer foam from the polymerizable material.7. A method comprising:deploying an elastic membrane downhole;expanding the elastic membrane downhole; andinitiating the ...

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Номер записи: 67
27-03-2014 дата публикации

HIGH WATER AND BRINE SWELL ELASTOMERIC COMPOSITIONS AND METHOD FOR MAKING AND USING SAME

Номер: US20140087977A1
Автор: Banta Deborah Lynn, Breach William David, Kim Byong Jun
Принадлежит:

Swellable compositions including at least one curable elastomer, a least one cure system, at least one high molecular weight (HMW) swelling agent and at least one low molecular weight (LMW) swelling agent. Methods for making swellable compositions including at least one curable elastomer, a least one cure system, at least one high molecular weight (HMW) swelling agent and at least one low molecular weight (LMW) swelling agent. Methods for using swellable compositions including at least one curable elastomer, a least one cure system, at least one high molecular weight (HMW) swelling agent and at least one low molecular weight (LMW) swelling agent. 1. A swellable system comprising:an elastomeric subsystem including at least one curable elastomer, anda swelling agent subsystem including at least one high molecular weight (HMW) swelling agent and at least one low molecular weight (LMW) swelling agent,characterized in that the LMW swelling agent assists the swelling of the HMW swelling agent.2. The system of claim 1 , wherein the elastomers are selected from the group consisting of nitrile-butadiene rubber (NBR) claim 1 , hydrogenated NBR claim 1 , hydrogenated nitrile rubber (HNBR) claim 1 , chemically functionalized NBR (Carboxylated NBR) claim 1 , ethylene-propylene-diene-copolymer (EPDM) claim 1 , ethylene-propylene ruber (EPR) claim 1 , fluorinated elastomers (FKM claim 1 , FFKM claim 1 , FEPM) claim 1 , styrene-butadiene rubber (SBR) claim 1 , hydrogenated styrene-butadiene rubber (hSBR) claim 1 , isoprene-butadiene rubber (IBR) claim 1 , hydrogenated isoprene-butadiene rubber (hIBR) claim 1 , styrene-isoprene rubber (SIR) claim 1 , hydrogenated styrene-isoprene rubber (hSIR) claim 1 , styrene-butadiene-isoprene (SIBR) claim 1 , hydrogenated styrene-butadiene-isoprene rubber (hSIBR) claim 1 , block claim 1 , triblock and multi-block polymers of styrene-isoprene claim 1 , styrene-butadiene claim 1 , styrene-butadiene-isoprene thermoplastic elastomers claim 1 , ...

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Номер записи: 68
03-04-2014 дата публикации

Use of Synthetic Smectite in Set-Delayed Cement Compositions

Номер: US20140090843A1
Автор: Agapiou Kyriacos, Boul Peter James, Brothers Lance Everett, MORGAN Ronnie Glen, Otieno Pauline Akinyi, Pisklak Thomas Jason
Принадлежит: Halliburton Energy Services, Inc.

Disclosed herein are cement compositions and methods of using set-delayed cement compositions in subterranean formations. In one embodiment a method of cementing in a subterranean formation is described. The method comprises providing a set-delayed cement composition comprising pumice, hydrated lime, a cement set retarder, a synthetic smectite, and water; introducing the set-delayed cement composition into a subterranean formation; and allowing the set-delayed cement composition to set in the subterranean formation. 1. A method of cementing in a subterranean formation comprising:providing a set-delayed cement composition comprising pumice, hydrated lime, a cement set retarder, a synthetic smectite, and water;introducing the set-delayed cement composition into a subterranean formation; andallowing the set-delayed cement composition to set in the subterranean formation.2. The method of further comprising preparing the set-delayed cement composition wherein preparing the set-delayed cement composition comprises adding the synthetic smectite to a heavier set-delayed cement composition as a liquid additive comprising the synthetic smectite and water.3. The method of wherein the liquid additive is added to the heavier set-delayed cement composition to reduce the density of the heavier set-delayed cement composition to a range of about 4 pounds per gallon to about 12 pounds per gallon.4. The method of wherein the set-delayed cement composition comprises a mechanical-property-enhancing additive.5. The method of wherein the mechanical-property enhancing additive comprises carbon fibers.6. The method of wherein the set-delayed cement composition comprises polyethyleneimine.7. The method of wherein the set-delayed cement composition has a density in a range of about 8 pounds per gallon to about 14 pounds per gallon.8. The method of wherein the pumice has a mean particle size in a range of about 10 micron to about 25 microns.9. The method of wherein the pumice and the hydrated ...

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Номер записи: 69
03-04-2014 дата публикации

Defoaming Compositions

Номер: US20140090845A1
Автор: Luciana Bava, Mahmoudkhani Amir H., WILSON ROBERT E.
Принадлежит: KEMIRA OYJ

Cement compositions and processes for reducing air entrainment in a cement composition generally include mixing a hydraulic cement with a defoamer compositions including one or more organic acid ester polymers selected from an organic acid ester of polyethylene oxide polymer, an organic acid ester of polypropylene oxide polymer, and a mixture thereof. The compositions may further comprise an organic acid ester of an ethylene oxide-propylene oxide block copolymer. 1. A defoaming composition comprising one or more organic acid ester polymers selected from an organic acid ester of polyethylene oxide polymer , an organic acid ester of polypropylene oxide polymer , and a mixture thereof.2. The composition of claim 1 , further comprising an organic acid ester of an ethylene oxide propylene oxide block copolymer.3. The composition of claim 1 , wherein the composition comprises an organic acid ester of polyethylene oxide polymer and an organic acid ester of polypropylene oxide polymer.4. The composition of claim 2 , wherein the composition comprises an organic acid ester of polyethylene oxide polymer and an organic acid ester of an ethylene oxide-propylene oxide block copolymer.5. The composition of claim 2 , wherein the composition comprises an organic acid ester of polypropylene oxide polymer claim 2 , and an organic acid ester of an ethylene oxide-propylene oxide block copolymer.9. The composition of claim 1 , wherein the composition further comprises a diluent system.10. The composition of claim 9 , wherein the diluent system comprises an organic diluent.11. The composition of claim 1 , wherein the organic acid ester is the reaction product of the polymer and an organic acid having at least one carboxylic acid group.12. The composition of claim 11 , wherein the organic acid is oleic acid claim 11 , stearic acid claim 11 , suberic acid claim 11 , azelaic acid claim 11 , sebacic acid claim 11 , phthalic acid claim 11 , isophthalic acid claim 11 , terephthalic acid claim ...

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Номер записи: 70
10-04-2014 дата публикации

ENCAPSULATED ACTIVATOR AND ITS USE TO TRIGGER A GELLING SYSTEM BY PHYSICAL MEANS

Номер: US20140100304A1
Автор: ARDAUD Pierre, Cadix Arnaud, Rached Rabih
Принадлежит: Rhodia Operations

A process allowing the encapsulation of a polymerization accelerator comprising the steps of: a) providing an reverse emulsion containing, in an oil phase, a water solution/dispersion containing the polymerisation activator, the oil phase including a heat curable mixture of an isocyanate and a polyalkyldiene hydroxylated or polyol, b) pouring the reverse emulsion in a water phase to make a multiple emulsion water/oil/water, containing drops of activators as the internal water phase, and then, c) heating the multiple emulsion obtained in step b) at a temperature of between 50 and 95° C., in order to cure the polyisocyanate in polyurethane and obtain drops of activator enclosed in shells of polyurethane dispersed in water. 1. A process for the encapsulation of a polymerization accelerator of water soluble or water dispersable monomers , said process comprising the steps of:a) providing an reverse emulsion containing, in an oil phase, a water solution or dispersion (W1) containing said polymerisation activator, the oil phase including a heat curable mixture of an isocyanate and a polyalkyldiene hydroxylated or polyol,b) pouring the reverse emulsion of step a) in a water phase (W2) to make a multiple emulsion water/oil/water, containing drops of activators as the internal water phase and, then,c) heating the multiple emulsion obtained in step b) at a temperature of between 50 and 95° C., in order to cure the polyisocyanate in polyurethane and obtain drops of activator enclosed in shells of polyurethane dispersed in water.2. The process of claim 1 , wherein in step a) a solvent or plasticizer is added to the oil phase.3. The process of claim 1 , wherein the solvent or plasticizer is di-isobutyl ester of succinate claim 1 , glutarate or adipate.4. The process of claim 1 , wherein claim 1 , in stepa), a non-ionic surfactant is added to the water wherein said activator is dispersed or in solution.5. The process of claim 4 , wherein said non-ionic surfactant is a diC-Calkyl ...

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Номер записи: 71
06-01-2022 дата публикации

STABLE HIGH SOLIDS SLURRY COMPOSITIONS

Номер: US20220002610A1
Автор: HALL Glenn, HUGHES Andrew, MELBOUCI Mohand, SINGLETON Terry, THOMPSON Samuel John
Принадлежит: KAO SPECIALTIES AMERICAS LLC

A slurry composition that includes (A) a solvent, (B) a suspension aid, (D) an alkoxylated fatty amine, (E) an active ingredient, and optionally (C) a polar activator. The slurry composition may be formulated with up to 75 wt. % of the active ingredient (E), based on a total weight of the slurry composition, and remain as a pumpable and stable suspension. A concentrated slurry base is also disclosed which includes the solvent (A), the suspension aid (B), the polar activator (C), and the alkoxylated fatty amine (D), all being present at a higher concentration in the concentrated slurry base than a slurry composition made therefrom. A method of treating a subterranean formation is also disclosed, whereby the slurry composition is mixed with an aqueous fluid to form a treatment fluid, and the treatment fluid is introduced through a wellbore penetrating the subterranean formation. 1. A slurry composition , comprising:(A) a solvent;(B) a suspension aid;(D) an alkoxylated fatty amine; and(E) an active ingredient.2. The slurry composition of claim 1 , wherein the solvent (A) is a hydrocarbon solvent.3. The slurry composition of claim 1 , wherein the solvent (A) is present in an amount of 10 to 70 wt. % claim 1 , based on a total weight of the slurry composition.4. The slurry composition of claim 1 , wherein the suspension aid (B) is an organophilic clay.5. The slurry composition of claim 4 , wherein the organophilic clay is a smectite-type clay modified with a quaternary ammonium cation.6. The slurry composition of claim 1 , wherein the suspension aid (B) is present in an amount of 0.1 to 15 wt. % claim 1 , based on a total weight of the slurry composition.7. The slurry composition of claim 1 , further comprising at least one polar activator (C) selected from the group consisting of water claim 1 , an alkylene carbonate claim 1 , and a Cto Cmonoalcohol.8. The slurry composition of claim 7 , wherein the polar activator (C) is present in an amount of 0.02 to 10 wt. % claim 7 ...

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Номер записи: 72
05-01-2017 дата публикации

High-Alumina Refractory Aluminosilicate Pozzolan in Well Cementing

Номер: US20170001908A1
Автор: Agapiou Kyriacos
Принадлежит: Halliburton Energy Services, Inc.

Methods and compositions are provided that utilize high-alumina refractory aluminosilicate pozzolans in well cementing. An embodiment discloses a method of cementing comprising: introducing a cement composition into a subterranean formation, wherein the cement composition comprises; a component selected from the group consisting of cement kiln dust, Portland cement and any combination thereof; a high-alumina refractory aluminosilicate pozzolan; and water; and allowing the cement composition to set. 1. A method of cementing comprising:introducing a cement composition into a subterranean formation, wherein the cement composition comprises: a component selected from the group consisting of cement kiln dust, Portland cement, and any combination thereof; a high-alumina refractory aluminosilicate pozzolan; and water; andallowing the cement composition to set.2. The method according to claim 1 , wherein the component comprises the Portland cement.3. The method according to claim 1 , wherein the component comprises the cement kiln dust.4. The method according to claim 1 , wherein the high-alumina refractory aluminosilicate pozzolan comprises a compound selected from firebrick claim 1 , firebrick grog claim 1 , refractory mortar claim 1 , fire clay claim 1 , Mullite claim 1 , fused Mullite claim 1 , and any combination thereof.5. The method according to claim 1 , wherein the high-alumina refractory aluminosilicate pozzolan is present in an amount of about 50% to about 150% by weight of the component.6. The method according to claim 1 , wherein the high-alumina refractory aluminosilicate pozzolan comprises Mullite in an amount of about 30 weight % or greater claim 1 , wherein the high-alumina refractory aluminosilicate pozzolan comprises Corrundum in an amount of about 10 weight % or greater claim 1 , and wherein high-alumina refractory aluminosilicate pozzolan is substantially devoid of amorphous material.7. The method according to claim 1 , wherein the cement composition ...

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Номер записи: 73
05-01-2017 дата публикации

Tunable Control of Pozzolan-Lime Cement Compositions

Номер: US20170001911A1
Автор: Agapiou Kyriacos, Pisklak Thomas Jason
Принадлежит: Halliburton Energy Services, Inc.

Disclosed herein are cement compositions and methods of using cement compositions in subterranean formations. An embodiment discloses a method of formulating a cement composition. The method may comprise measuring surface area of a group of pozzolans, wherein the smallest measured surface area of the group of pozzolans and the largest measured surface area of the group of pozzolans vary by about 50% or greater. The method may further comprise selecting one or more pozzolans from the group of pozzolans. The method may further comprise adding components comprising lime and water to the selected one or more pozzolans to form a cement composition. 1. A method of formulating a cement composition:measuring surface area of a group of pozzolans, wherein the smallest measured surface area of the group of pozzolans and the largest measured surface area of the group of pozzolans vary by about 50% or greater;selecting one or more pozzolans from the group of pozzolans;adding components comprising lime and water to the selected one or more pozzolans to form a cement composition.2. A method according to wherein the group of pozzolans are selected from the group consisting of: fly ash claim 1 , silica fume claim 1 , metakaolin claim 1 , pumice claim 1 , and any combination thereof.3. A method according to wherein the cement composition further comprises a set retarder claim 1 , wherein the set retarder comprises at least one retarder selected from the group consisting of a phosphonic acid claim 1 , a phosphonic acid derivative claim 1 , a lignosulfonate claim 1 , a salt claim 1 , an organic acid claim 1 , a cellulose derivate claim 1 , a synthetic co- or ter-polymer comprising sulfonate and carboxylic acid groups claim 1 , a borate compound claim 1 , and any combination thereof.4. A method according to wherein the cement composition further comprises at least one dispersant selected from the group consisting of a sulfonated-formaldehyde-based dispersant claim 1 , a polycarboxylated ...

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Номер записи: 74
04-01-2018 дата публикации

Using Biodegradable Oils for Controlling Dust from Additive Particles

Номер: US20180002122A1
Автор: Nguyen Philip D., Stanciu Corneliu, VO Loan K.
Принадлежит: Halliburton Energy Services, Inc.

Application of biodegradable oils to additive particles to control dusting. A method of reducing an amount of dust produced during transfer of additive particles comprising: treating at least some of the additive particles with one or more biodegradable oils; storing the additive particles; and transferring the additive particles prior to and after storage, wherein biodegradable oil reduces the amount of dust produced during at least one of the transfers of the additive particles. 1. A method of reducing an amount of dust produced during transfer of additive particles comprising:treating at least some of the additive particles with one or more biodegradable oils;storing the additive particles; andtransferring the additive particles prior to and after storage, wherein biodegradable oil reduces the amount of dust produced during at least one of the transfers of the additive particles.2. A method according to claim 1 , wherein the additive particles are bulk particles claim 1 , mesoscopic particles claim 1 , nanoparticles claim 1 , or combinations thereof.3. A method according to claim 2 , wherein the additive particles comprise at least material selected from the group consisting of include sand; bauxite; ceramic material; glass material; resin precoated sands; resin precoated proppants; polymer material; polytetrafluoroethylene material; nut shell pieces; seed shell pieces; cured resinous particulate comprising nut shell pieces; cured resinous particulate comprising seed shell pieces; fruit pit pieces; cured resinous particulate comprising fruit pit pieces; wood; composite particulates and combinations thereof.4. A method according to claim 1 , wherein the biodegradable oil comprises a biodegradable oil selected from the group consisting of a vegetable oil claim 1 , a nut oil claim 1 , a citrus oil claim 1 , and a combination thereof.5. A method according to claim 1 , wherein the biodegradable oil comprises a synthetic oil selected from the group consisting of a ...

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Номер записи: 75
03-01-2019 дата публикации

Manufacturing Method of Big-model Low-Permeability Microcrack Core

Номер: US20190002344A1
Автор: Chen Yijian, DU Jianfen, Du Yuhong, GUO Ping, HU Yisheng, Liu Huang, Ren Hongmei, WANG Zhouhua, Wu Shuai, Zhang Huimin, ZHANG Wanbo
Принадлежит: SOUTHWEST PETROLEUM UNIVERSITY

A manufacturing method of a big-model low-permeability microcrack core includes: (1) determining the size of a microcrack core to be manufactured; (2) placing stones in a baking oven to bake for 24 h under 120° C., placing the stones into a mixer, mixing and spraying oil, enabling the oil to seep into the stone, evenly forming a thin oil film on stone's surface; (3) mixing the oil sprayed stone with quartz sand and cement, adding water to mix evenly to obtain cement paste; (4) spreading butter on core mould's inner surface to form a thin butter film, pouring the cement paste into the core mould to obtain a cement sample; (5) loading confining pressure outside the core according to the requirements of porosity and permeability of the mould to adjust a pore permeability value; (6) obtaining the big-model core with microcrack after the cement sample is dried and formed. 1. A manufacturing method of a big-model low-permeability microcrack core , comprising the following step successively:(1) determining a size of a microcrack core to be manufactured;(2) placing a plurality of stones in a baking oven to bake for 24 h under 120° C., placing the plurality of stones into a mixer, mixing and spraying an oil, and placing the mixtue of the plurality of stones and the oil for 2 h after mixing evenly to enable the oil to seep into the plurality of stone and evenly forming a layer of thin oil film on a surface of the plurality of stones;(3) mixing the plurality of stones sprayed by the oil in step (2) with a quartz sand and a cement, and then adding water to mix evenly to obtain a cement paste;(4) spreading a butter on an inner surface of a core mould to form a layer of thin butter film on the inner surface of the core mould, pouring the cement paste in step (3) into the core mould, and vibrating the cement paste in the core mould by a vibrating spear during pouring to obtain a cement sample;(5) loading confining pressure outside the core according to requirements on a degree of ...

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Номер записи: 76
05-01-2017 дата публикации

Chitin nanocrystal containing wellbore fluids

Номер: US20170002256A1
Автор: Lee Jeremy Hall
Принадлежит: Halliburton Energy Services Inc

The current invention relates to the use of chitin nanocrystals and chitin nanocrystal derivatives. More specifically, the present invention relates to the use of chitin nanocrystals and chitin nanocrystals used in oil and gas operations. The chitin nanocrystals and chitin nanocrystals derivatives can be used as additives to cement and wellbore fluids and can be used to inhibit corrosion in pipelines, on downhole tools and on other oil and gas related equipment.

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Номер записи: 77
05-01-2017 дата публикации

Passivated Cement Accelerator

Номер: US20170002257A1
Автор: Agapiou Kyriacos, LEWIS Samuel Jason, Otieno Pauline Akinyi, Pisklak Thomas Jason
Принадлежит: Halliburton Energy Services, Inc.

Embodiments relate to cementing operations and, in certain embodiments, to passivated cement accelerators and methods of using passivated cement accelerators in subterranean formations. An embodiment may comprise a method of cementing comprising: providing a cement composition comprising cement, water, and a passivated cement accelerator; and allowing the cement composition to set. 1. A method of cementing comprising:providing a cement composition comprising cement, water, and a passivated cement accelerator; andallowing the cement composition to set.2. The method according to wherein the cement composition further comprises at least one set retarder selected from the group consisting of a phosphonic acid claim 1 , a phosphonic acid derivative claim 1 , a lignosulfonate claim 1 , a salt claim 1 , an organic acid claim 1 , a carboxymethylated hydroxyethylated cellulose claim 1 , a synthetic co- or ter-polymer comprising sulfonate and carboxylic acid groups claim 1 , a borate compound claim 1 , and any mixture thereof.3. The method according to wherein the cement composition further comprises at least one cement set activator selected from the group consisting of calcium chloride claim 1 , triethanolamine claim 1 , sodium silicate claim 1 , zinc formate claim 1 , calcium acetate claim 1 , sodium hydroxide claim 1 , sodium sulfate claim 1 , nanosilica claim 1 , sodium hexametaphosphate claim 1 , and any combinations thereof4. The method according to wherein the cement composition further comprises at least one dispersant selected from the group consisting of a sulfonated-formaldehyde-based dispersant claim 1 , a polycarboxylated ether dispersant claim 1 , and any combination thereof.5. The method according to claim 1 , wherein the passivated cement accelerator is selected from the group consisting of passivated Portland cement claim 1 , passivated pozzolana cement claim 1 , passivated gypsum cement claim 1 , passivated high alumina content cement claim 1 , passivated ...

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Номер записи: 78
07-01-2016 дата публикации

ISOLATION DEVICES CONTAINING A TRANSFORMING MATRIX AND A GALVANICALLY-COUPLED REINFORCEMENT AREA

Номер: US20160002999A1
Автор: FRIPP Michael L., Murphree Zachary R., WALTON Zachary W.
Принадлежит:

A method of using a wellbore isolation device comprises: introducing the wellbore isolation device into the wellbore, wherein the isolation device comprises: (A) a matrix, wherein the matrix has a phase transition temperature less than or equal to the bottomhole temperature of the wellbore; and (B) at least one reinforcement area, wherein the reinforcement area: (i) comprises at least a first material, wherein the first material undergoes galvanic corrosion; and (ii) has a greater tensile strength and/or shear strength than the matrix. 1. A method of using a wellbore isolation device comprising: (A) a matrix, wherein the matrix has a phase transition temperature less than or equal to the bottomhole temperature of the wellbore; and', (i) comprises at least a first material, wherein the first material undergoes galvanic corrosion; and', '(ii) has a greater tensile strength and/or shear strength than the matrix., '(B) at least one reinforcement area, wherein the reinforcement area], 'introducing the wellbore isolation device into the wellbore, wherein the isolation device comprises2. The method according to claim 1 , wherein the isolation device is a ball claim 1 , a plug claim 1 , a bridge plug claim 1 , a wiper plug claim 1 , or a packer.3. The method according to claim 1 , wherein the isolation device restricts or prevents fluid flow between a first zone and a second zone of a subterranean formation claim 1 , wherein the wellbore penetrates the subterranean formation.4. The method according to claim 1 , wherein the matrix comprises a metal claim 1 , a metal alloy claim 1 , a polymer claim 1 , or combinations thereof.5. The method according to claim 4 , wherein the metal alloy is a fusible metal alloy.6. The method according to claim 5 , wherein the matrix is a eutectic claim 5 , hypo-eutectic claim 5 , or hyper-eutectic composition.7. The method according to claim 4 , wherein the polymer is a thermoplastic.8. The method according to claim 1 , wherein the first ...

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Номер записи: 79
07-01-2016 дата публикации

METHODS AND COMPOSITIONS FOR USE IN OIL AND/OR GAS WELLS COMPRISING A TERPENE ALCOHOL

Номер: US20160003018A1
Автор: Ashcraft Paul, Hill Randal M., Saboowala Hasnain
Принадлежит: CESI CHEMICAL, INC.

Methods and compositions comprising an emulsion or a microemulsion for use in various aspects of the life cycle of an oil and/or gas well are provided. In some embodiments, the emulsion or the microemulsion comprises an aqueous phase, a non-aqueous phase comprising a terpene alcohol a non-oxygenated terpene, and a surfactant, and optionally, one or more additives. 1. A method of treating an oil and/or gas well having a wellbore , comprising:injecting a fluid comprising an emulsion or microemulsion into the wellbore, wherein the emulsion or microemulsion comprises:an aqueous phase;a surfactant; anda non-aqueous phase comprising a first type of solvent and a second type of solvent, wherein the second type of solvent is a terpene alcohol.2. The method of claim 1 , wherein the second type of solvent is present in an amount between about 5 wt % and about 40 wt % versus the total amount of the non-aqueous phase.3. The method of claim 1 , wherein the terpene alcohol is a Cterpene alcohol.4. The method of claim 1 , wherein the terpene alcohol is selected from the group consisting of terpineol claim 1 , linalool claim 1 , borneol claim 1 , geraniol claim 1 , menthol claim 1 , citronellol claim 1 , nerol claim 1 , and nopol.5. The method of claim 1 , wherein the first type of solvent is not a terpene alcohol.6. The method of claim 1 , wherein the first type of solvent is selected from the group consisting menthone claim 1 , d-limonene claim 1 , terpinolene claim 1 , β-occimene claim 1 , γ-terpinene claim 1 , α-pinene claim 1 , beta-pinene claim 1 , dipentene claim 1 , and citronellene.7. The method of claim 1 , wherein the first type of solvent is d-limonene.8. The method of claim 1 , wherein the non-aqueous phase is present in an amount between about 3 wt % and about 50 wt % claim 1 , between about 5 wt % and about 35 wt % claim 1 , or between about 5 wt % and about 20 wt % versus the total emulsion or microemulsion composition.9. The method of claim 1 , wherein the emulsion ...

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Номер записи: 80
02-01-2020 дата публикации

Sulfur-Containing Polyether Surfactants for Cement Spacer Fluids and Other Downhole Applications

Номер: US20200002595A1
Автор: Banks Marcus D., Bishop Marshall D., Flom Shawn M.
Принадлежит:

Spacer fluid compositions comprising water, a clay, and a sulfur-containing polyether surfactant are disclosed, and such compositions often can further include a weighting additive, an antifoaming additive, and a co-solvent. These spacer fluid compositions can be used to treat metal casing and to remove drilling fluid residue for improved cement bonding in wellbore applications. 2. The method of claim 1 , wherein:{'sub': 10', '14, 'each R independently is a C-Calkyl group;'}each R′ independently is an ethylene group or a propylene group;each x independently is an integer from 3 to 10; andthe composition contains a mixture of the sulfur-containing polyether surfactant having formula (I) and the sulfur-containing polyether surfactant having formula (II).3. The method of claim 1 , wherein:the drilling fluid is an oil-based drilling fluid; andat least about 75 vol % of the drilling fluid in the annulus is displaced by the spacer fluid composition.4. The method of claim 3 , further comprising a step of introducing a cement slurry to the wellbore annulus for attaching at least a portion of the metal casing to the wellbore wall;wherein the cement slurry is a water-based cement slurry.5. The method of claim 4 , wherein the spacer fluid composition is compatible with the oil-based drilling fluid and the water-based cement slurry.6. The method of claim 1 , wherein a maximum temperature of the wellbore is in a range from about 100° C. to about 175° C.7. The method of claim 1 , wherein a volume of the spacer fluid composition needed to reach a conductivity of 175 Hogans in a mixture with 200 mL of a standard oil-based mud claim 1 , using a Fann C1001 wettability test apparatus in accordance with API 10B-2 water-wetting capability test (WWCT) claim 1 , is less than 375 mL.8. The method of claim 1 , wherein the spacer fluid composition contains claim 1 , per barrel of the composition:from about 2 lb to about 40 lb of the clay; andfrom about 0.05 gallons to about 10 gallons of the ...

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Номер записи: 81
02-01-2020 дата публикации

Methods of cementing a wellbore with the use of an oil swellable elastomer

Номер: US20200002596A1
Автор: Shannon E. Bryant, Thomas S. Sodhi
Принадлежит: Baker Hughes Inc

A method of cementing a wellbore penetrating a subterranean formation, the method comprising: injecting into the wellbore an oil-based fluid; injecting into the wellbore a cement spacer fluid comprising an aqueous carrier, an oil swellable elastomer, and a viscosifier; contacting the oil-based fluid with the cement spacer fluid to swell the oil swellable elastomer in the cement spacer fluid; injecting a cement slurry into the wellbore; and allowing the cement slurry to set.

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Номер записи: 82
02-01-2020 дата публикации

PROCESS TO PREPARE A SOLID CEMENT COMPOSITION

Номер: US20200002597A1
Автор: HAMELINK Cornelis Pieter, VAN EIJDEN Gerbrand Jozef Maria, VERBIST Guy Lode Magda Maria
Принадлежит:

A process to prepare a solid cement composition; 1. A process to prepare a solid cement composition , comprising the steps of:(a) adding a meltable compound to an aqueous slurry of cement;(b) mixing the meltable compound in the form of solid particles and the aqueous slurry of cement of step (a) until a homogeneous dispersion of cement comprising dispersed meltable compound is obtained;(c) placing a dispersion of step (b) in a mould, wherein the dispersion is set by hydration;(d) melting part of the meltable compound by exposing the meltable compound to a temperature range of which the maximum is above the melting point of the meltable compound and a minimum below the melting point of the meltable compound;(e) exposing a material, either still as a dispersion or an already setting cement of step (c), to heat development or temperature gradient such that the temperature is at least above the congealing point of the meltable compound to obtain a solid cement composition.2. The process according to claim 1 , wherein the amount of meltable compound added in step (a) to the aqueous slurry of cement is between 1 and 50 wt. % based on the amount of cement.3. The process according to claim 1 , wherein the meltable compound is a wax.4. The process according to claim 3 , wherein the wax has a congealing point of at least 30° C. and at most 120° C.5. The process according to claim 3 , wherein the wax has a congealing point of 105° C.6. The process according to claim 3 , wherein the wax is a Fischer-Tropsch derived wax.7. A solid cement composition obtainable by the process according to .8. A process for sealing a wellbore and/or for sealing within a wellbore claim 1 , comprising the steps of(a) adding a meltable compound to an aqueous slurry of cement;(b) mixing the meltable compound in the form of solid particles and the aqueous slurry of cement of step (a) until a homogeneous dispersion of cement comprising the dispersed meltable compound is obtained;(c) addition of the ...

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Номер записи: 83
07-01-2021 дата публикации

SYSTEM AND DEVICE FOR USE IN PERFORMING REVERSE-CEMENTING OPERATIONS IN DOWNHOLE WELL ENVIRONMENTS

Номер: US20210002975A1
Автор: Jadhav Rahul Nandkumar, PANGU Ganesh Shriniwas, Sen Tamal Kumar
Принадлежит:

A system for use in performing a reverse cementing operation in a downhole well operation and creating a sectional separation within a well casing and a process completion indicator. The system comprising a well casing, and a magnetic element, and a plurality of magnetizable particles. The magnetic element is coupled with a radial, interior section of the well casing and the plurality of magnetizable particles couple with the magnetic element forming an impediment between a first and second section of the well casing. The impediment creates a detectable resistive force. The magnetizable particles and the at least one magnet form a contiguous and porous wall and the resistive force creates a pressure spike at a surface of the well in response to the interaction of a cement slurry pumped into an annulus of a wellbore and the wall. 1. A system for use in a reverse cementing operation of a downhole well environment to create a process completion indicator , the system comprising:a well casing;a magnetic element fixed to a circumferential section of an interior section of the well casing, the circumferential sections extends at least half of the interior section; anda plurality of magnetizable particles;wherein the plurality of magnetizable particles couple with the magnetic element and form a semi-porous barrier between an upper section and a lower section of the well casing;wherein the semi-porous barrier creates an impediment against cement traversing the lower section, the impediment causing a detectable resistive force.2. The system of wherein the magnetic element comprises at least one magnet that forms a ring around a circumference of the interior section of the well casing.3. The system of wherein the magnetic element comprises a first at least one magnet and a second at least one magnet with each forming a ring around a circumference of the interior section of the well casing.4. The system of wherein the magnetic element comprises a magnetic screen having a mesh ...

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Номер записи: 84
13-01-2022 дата публикации

Method To Design For Thickening Time Using Cementitious Blend Composition

Номер: US20220009845A1
Автор: John Paul Bir Singh, Siva Rama Krishna JANDHYALA, Thomas Jason Pisklak
Принадлежит: Halliburton Energy Services Inc

A method of designing a cement slurry may include: (a) selecting at least a cement and concentration thereof, water and concentration thereof, and, optionally, at least one supplementary cementitious material and a concentration thereof, such that a cement slurry comprising the cement, the water, and, if present, the at least one supplementary cementitious material, meet a density requirement; (b) calculating a thickening time of the cement slurry using a thickening time model; (c) comparing the thickening time of the cement slurry to a thickening time requirement, wherein steps (a)-(c) are repeated if the thickening time of the cement slurry does not meet or exceed the thickening time requirement, wherein the selecting comprises selecting different concentrations and/or different chemical identities for the cement and/or the supplementary cementitious material than previously selected, or step (d) is performed if the thickening time of the cement slurry meets or exceeds the thickening time requirement; and preparing the cement slurry.

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Номер записи: 85
13-01-2022 дата публикации

Real Time Tailoring Of Cement Slurry For Downhole Thickening Time

Номер: US20220010190A1
Автор: Blaschke Keith Edward, Jandhyala Siva Rama Krishna, Singh John Paul Bir
Принадлежит: Halliburton Energy Services, Inc.

A method of cementing may include: measuring a feeding rate of water and a feeding rate of cement blend into a cement blender; calculating a cement retarder feeding rate and/or an accelerator feeding rate using a thickening time model, wherein the thickening time model uses at least a thickening time requirement, the feeding rate of water, and the feeding rate of cement blend, to calculate the cement retarder feeding rate and/or the accelerator feeding rate; introducing a cement retarder at the cement retarder feeding rate and/or an accelerator at the accelerator feeding rate into the cement blender; mixing at least the water, cement blend, and at least one of the cement retarder and/or the accelerator in the cement blender to provide a cement slurry; and placing the cement slurry in a wellbore. 1. A method of cementing comprising:measuring a feeding rate of water and a feeding rate of cement blend into a cement blender;calculating a cement retarder feeding rate and/or an accelerator feeding rate using a thickening time model, wherein the thickening time model uses at least a thickening time requirement, the feeding rate of water, and the feeding rate of cement blend, to calculate the cement retarder feeding rate and/or the accelerator feeding rate;introducing a cement retarder at the cement retarder feeding rate and/or an accelerator at the accelerator feeding rate into the cement blender;mixing at least the water, cement blend, and at least one of the cement retarder and/or the accelerator in the cement blender to provide a cement slurry; andplacing the cement slurry in a wellbore.5. The method of wherein the cement retarder is selected from phosphonic acid derivatives claim 1 , lignosulfonates claim 1 , salts claim 1 , organic acids claim 1 , cellulose derivatives claim 1 , synthetic co- or ter-polymers comprising sulfonate and carboxylic acid groups claim 1 , borate compounds claim 1 , and combinations thereof and wherein the accelerator is selected from ...

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Номер записи: 86
08-01-2015 дата публикации

USE OF TERPOLYMERS AS FLUID LOSS ADDITIVES IN WELL CEMENTING

Номер: US20150007992A1
Автор: Reichenbach-Klinke Roland, Wohlfahrt Markus
Принадлежит:

What is proposed is the use of a terpolymer comprising 5-95 mol % of 2-acrylamido-2-methylpropanesulfonic acid, 5-95 mol % of N,N-dimethylacrylamide and 5-12 mol % of acrylic acid as a fluid loss additive in well cementing. 18-. (canceled)9. A method of preventing fluid loss during well cementing comprising:adding to a slurry comprising a cement and a terpolymer; andcementing a well,wherein the terpolymer comprises:from 5-95 mol % of 2-acrylamido-2-methylpropanesulfonic acid;from 5-95 mol % of N,N-dimethylacrylamide; and5-12 mol % of acrylic acid.10. The method according to claim 9 , wherein the terpolymer comprises 8-12 mol % of acrylic acid.11. The method according to claim 9 , wherein the molar ratio of 2-acrylamido-2-methylpropanesulfonic acid to N claim 9 ,N-dimethylacrylamide is between 50:50 and 80:20.12. The method according to claim 10 , wherein the molar ratio of 2-acrylamido-2-methylpropanesulfonic acid to N claim 10 ,N-dimethylacrylamide is between 50:50 and 80:20.13. The method according claim 9 , wherein the 2 acrylamido-2-methylpropanesulfonic acid and the acrylic acid are present fully or partly in the form of salts of at least one member selected from the group consisting of an alkali metal and an alkaline earth metal.14. The method according claim 10 , wherein the 2 acrylamido-2-methylpropanesulfonic acid and the acrylic acid are present fully or partly in the form of salts of at least one member selected from the group consisting of an alkali metal and an alkaline earth metal.15. The method according claim 13 , wherein the 2 acrylamido-2-methylpropanesulfonic acid and the acrylic acid are present fully or partly in the form of salts of at least one member selected from the group consisting of Na claim 13 , K claim 13 , Mg and Ca.16. The method according claim 14 , wherein the 2 acrylamido-2-methylpropanesulfonic acid and the acrylic acid are present fully or partly in the form of salts of at least one member selected from the group consisting of ...

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Номер записи: 87
20-01-2022 дата публикации

Accelerating Agents For Resin Cement Composite Systems For Oil Well Cementing

Номер: US20220017809A1
Автор: Jones Paul Joseph, JR. William Cecil, LEWIS Samuel Jason, Pearl, Pisklak Thomas Jason
Принадлежит: Halliburton Energy Services, Inc.

A bulk dry cement may comprise a cement; a solid particle; and a liquid resin accelerator, wherein the liquid resin accelerator is disposed on a surface of the solid particle. 1. A bulk dry cement comprising:a cement;a solid particle; anda liquid resin accelerator, wherein the liquid resin accelerator is disposed on a surface of the solid particle.2. The bulk dry cement of wherein the liquid resin accelerator comprises at least one liquid resin accelerator selected form the group consisting of aliphatic amines claim 1 , aliphatic tertiary amines claim 1 , aromatic amines claim 1 , cycloaliphatic amines claim 1 , heterocyclic amines claim 1 , amido amines claim 1 , polyamides claim 1 , polyethyl amines claim 1 , polyether amines claim 1 , polyoxyalkylene amines claim 1 , carboxylic anhydrides claim 1 , triethylenetetraamine claim 1 , ethylene diamine claim 1 , N-cocoalkyltrimethylene claim 1 , isophorone diamine claim 1 , N-aminophenyl piperazine claim 1 , imidazoline claim 1 , 1 claim 1 ,2-diaminocyclohexane claim 1 , polyetheramine claim 1 , diethyltoluenediamine claim 1 , 4 claim 1 ,4′-diaminodiphenyl methane claim 1 , methyltetrahydrophthalic anhydride claim 1 , hexahydrophthalic anhydride claim 1 , maleic anhydride claim 1 , polyazelaic polyanhydride claim 1 , phthalic anhydride claim 1 , 6-Methyl-2 claim 1 ,4-bis(methylthio)phenylene-1 claim 1 ,3-diamine; 2-methyl-4 claim 1 ,6-bis(methylthio) phenylene-1 claim 1 ,3-diamine claim 1 , 2 claim 1 ,4 claim 1 ,6-tris(dimethylaminomethyl)phenol claim 1 , and combinations thereof.3. The bulk dry cement of wherein the solid particle comprises at least one solid selected from the group consisting of halloysite claim 1 , halloysite nanotubes claim 1 , silica dust claim 1 , silica flour claim 1 , fumed silica claim 1 , silica fume claim 1 , porous silica claim 1 , cement kiln dust (CKD) claim 1 , Portland cement claim 1 , calcium silicate claim 1 , pumice claim 1 , perlite claim 1 , metakaolin claim 1 , kaolinite claim 1 , ...

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Номер записи: 88
12-01-2017 дата публикации

CEMENTING COMPOSITIONS AND METHODS

Номер: US20170009122A1
Автор: Funkhouser Gary P., Hundt Greg Robert, Jones Paul Joseph
Принадлежит:

Cementing compositions including a di- or poly epoxide resin, and amine hardener, and a di-or polyfunctional alkylphosphonate ester fortifier and methods of using the cementing compositions such as in a subterranean zone penetrated by a well bore. 1. A composition comprising:(a) a di- or poly epoxide resin;(b) an amine hardener that is not dimethyl ethylenediamine or ethylenediamine; and(c) a di- or polyfunctional alkylphosphonate ester fortifier.2. The composition according to claim 1 , wherein(a) the di- or poly epoxide resin is one or more compounds selected from the group consisting of an epichlorohydrin adduct of a bisphenol, an epichlorohydrin adduct of a novolac, an epichlorohydrin adduct of an alkyl diol, and an epichlorohydrin adduct of a cycloalkyl diol.3. The composition according to claim 2 , wherein(a) the di- or poly epoxide resin is one or more compounds selected from the group consisting of a bisphenol A epoxy resin, a bisphenol F epoxy resin, an epoxy novolac resin, a diglycidyl ether of an aliphatic diol, a diglycidyl ether of a polyethylene glycol, a diglycidyl ether of a polypropylene glycol, a cyclohexanedimethanol diglycidyl ether, a butanediol diglycidyl ether, trimethylolpropane triglycidyl ether, a hexanediol diglycidyl ether, N,N-diglycidyl-4-glycidyloxyaniline, 4,4′-methylenebis(N,N-diglycidylaniline), neopentyl glycol diglycidyl ether, resorcinol diglycidyl ether, tetraphenylolethane glycidyl ether, tris(2,3-epoxypropyl) isocyanurate, and tris(4-hydroxyphenyl)methane triglycidyl ether.4. The composition according to claim 3 , wherein(a) the di- or poly epoxide resin is a bisphenol A diglycidyl ether resin and/or a cyclohexanedimethanol diglycidyl ether.5. The composition according to claim 1 , wherein(b) the amine hardener is an alkyl or aromatic di- or polyamine.6. The composition according to claim 5 , wherein(b) the amine hardener is one or more compounds selected from the group consisting of triethylenetetraamine, ethylenediamine, N- ...

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Номер записи: 89
12-01-2017 дата публикации

Transportation and Delivery of Set-Delayed Cement Compositions

Номер: US20170009123A1
Автор: Ballew Horton Colby, Brown Paul Alan, MORGAN Ronnie Glen
Принадлежит: Halliburton Energy Services, Inc.

Disclosed herein are methods and systems for the transportation and delivery of set-delayed cement compositions to a well site. A method of cementing may comprise preparing a set-delayed cement composition. The method further may comprise storing the set-delayed cement composition. The method further may comprise transporting the set-delayed cement composition to a well site in a containment vessel. The method further may comprise discharging the set-delayed cement composition from the containment vessel and into a wellbore. 1. A method of cementing in a subterranean formation comprising:preparing a set-delayed cement composition;storing the set-delayed cement composition;transporting the set-delayed cement composition to a well site in a containment vessel; anddischarging the set-delayed cement composition from the containment vessel and into a wellbore.2. A method according to wherein the step of storing the set-delayed cement comprises storing the set-delayed cement composition for a period of about 1 day or longer prior to the step of transporting the set-delayed cement composition to the well site.3. A method according to further comprising intermittently mixing the set-delayed cement composition while the set-delayed cement composition is being stored.4. A method according to wherein the set-delayed cement composition is prepared and stored in the containment vessel used in the transporting and discharging steps.5. A method according to wherein the containment vessel comprises: a mixing chamber for holding the set-delayed cement composition claim 1 , the mixing chamber being defined by a shell; and a shaft holding one or more mixing blades in the mixing chamber.6. A method according to wherein the containment vessel further comprises baffles disposed on an interior surface of the shell claim 5 , and wherein the mixing blades comprise upward facing mixing blades and downward facing mixing blades arranged vertically on the shaft.7. A method according to further ...

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Номер записи: 90
08-01-2015 дата публикации

Foam resin sealant for zonal isolation and methods for making and using same

Номер: US20150011440A1
Автор: Frank Zamora, Kakadjian Sarkis R, Tina Garza
Принадлежит: Clearwater International Inc

Foamable epoxy-based zonal isolation sealing compositions include epoxy resin and a blowing agent and methods for isolating zones in borehole of oil and gas wells using the compositions, where the foam nature of the cured seals provide sufficient compressibility and resiliency to be used with expandable tubing without substantial loss in sealant integrity and in squeeze operations.

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Номер записи: 91
11-01-2018 дата публикации

COMPOSITIONS AND METHODS FOR COMPLETING SUBTERRANEAN WELLS

Номер: US20180010032A1
Автор: BARRAL Quentin, DROGER Nicolas, Kefi Slaheddine, REGNAULT DE LA MOTHE Loic
Принадлежит:

Well treatment compositions comprise water, a lipophilic anionic surfactant, a hydrophilic non-ionic surfactant, a second non-ionic surfactant, a water-solubilizing solvent, a water-immiscible solvent and a lipophilic non-ionic surfactant. Optionally, a second solvent may be incorporated. When added to spacer fluids, chemical washes or both, the compositions promote the removal of non-aqueous drilling fluids from casing surfaces. Additionally, the treated casing surfaces are water wet, thereby promoting optimal bonding to cement. 1. A well treatment composition , comprising:i. waterii. a lipophilic anionic surfactant;iii. a hydrophilic non-ionic surfactant;iv. a second non-ionic surfactant;v. a water-solubilizing solvent;vi. a water-immiscible solvent; andvii. a lipophilic non-ionic surfactant.2. The composition of claim 1 , wherein the anionic surfactant comprises oil-soluble alkaline claim 1 , alkaline earth metal and amine salts of dodecylbenzenesulfonic acid claim 1 , alkylsulfuric acid claim 1 , alkylsulfonic acid claim 1 , alpha olefin sulfonic acid claim 1 , alkyl sulfosuccinic acid claim 1 , alkyl ether sulfosuccinic acid claim 1 , alkyl ether sulfuric acid claim 1 , alkyl ether sulfonic acid claim 1 , carboxylic acid claim 1 , lignosulfonic acid claim 1 , phosphonate esters claim 1 , phosphate esters claim 1 , phosphonated polyglycol ethers or phosphated polyglycol ethers or combinations thereof claim 1 , wherein the HLB number is below 30;wherein the hydrophilic non-ionic surfactant comprises alkoxylated alcohols, alkoxylated mercaptans, alkoxylated alkylphenols, alkoxylated tristyrylphenols, alkoxylated castor oil, alkoxylated esters, alkoxylated diesters, alkoxylated alkylamines, alkoxylated alkylamides, copolymers of polyalkylene glycol, random sorbitan mono- or polyesters, di-block sorbitan mono- or polyesters, tri-block sorbitan mono- or polyesters, ethoxylated sorbitan monoesters, ethoxylated sorbitan polyesters, betaines, hydroxysultaines, taurines, ...

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Номер записи: 92
11-01-2018 дата публикации

METHODS AND COMPOSITIONS FOR TREATING A SUBTERRANEAN FORMATION WITH SALT-TOLERANT CEMENT SLURRIES

Номер: US20180010033A1
Автор: Bose Sohini, DESHPANDE Abhimanyu, Patil Rahul Chandrakant, Patil Sandip Prabhakar, RAVI Krishna M.
Принадлежит:

Methods and compositions for treating a subterranean formation with salt-tolerant cement slurries including treating a salt-containing subterranean formation having sodium salts, potassium salts, magnesium salts, calcium salts, or any combination thereof comprising: providing a salt-tolerant cement slurry comprising: a base fluid, a cementitious material, a pozzolanic material, a salt-tolerant fluid loss additive, a salt additive, and optionally, an elastomer, a weight additive, a fluid loss intensifier, a strengthening agent, a dispersant, or any combination thereof; introducing the salt-tolerant cement slurry into the subterranean formation; and allowing the salt-tolerant cement slurry to set. 1. A method of treating a salt-containing subterranean formation having sodium salts , potassium salts , magnesium salts , calcium salts , or any combination thereof comprising: a base fluid,', 'a cementitious material,', 'a pozzolanic material,', 'a salt-tolerant fluid loss additive,', 'a salt additive, and', 'optionally, an elastomer, a weight additive, a fluid loss intensifier, a strengthening agent, a dispersant, or any combination thereof;, 'providing a salt-tolerant cement slurry comprisingintroducing the salt-tolerant cement slurry into the subterranean formation; andallowing the salt-tolerant cement slurry to set.2. The method of claim 1 , wherein the cementitious material is a hydraulic cement.3. The method of claim 1 , wherein the pozzolanic material is selected from the group consisting of silica fume; metakaolin; fly ash; diatomaceous earth; calcined diatomite; uncalcined diatomite; calcined fullers earth; pozzolanic clay; calcined volcanic ash; uncalcined volcanic ash; bagasse ash; pumice; pumicite; rice hull ash; natural zeolite; synthetic zeolite; slag; vitreous calcium aluminosilicate; and any combination thereof.4. The method of claim 1 , wherein the salt-tolerant fluid loss additive is an amphoteric copolymer.5. The method of claim 1 , wherein salt tolerant ...

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Номер записи: 93
14-01-2016 дата публикации

MAGNETORHEOLOGICAL FLUIDS AND METHODS OF USING SAME

Номер: US20160010424A1
Автор: Cowan Kenneth M., Ferron Raissa, Nair Sriramya Duddukuri, van Oort Eric
Принадлежит:

Described herein are methods of cementing at least a portion of a well comprising feeding a magnetorheological cementitious slurry to a well and applying a magnetic field to the magnetorheological cementitious slurry concurrent with at least a portion of said feeding step to cause a mechanical response in said magnetorheological cementitious slurry in the well. Also disclosed herein are methods of temporarily blocking at least a portion of a well comprising providing a magnetorheological fluid in a well, applying a magnetic field to cause a mechanical response in said magnetorheological fluid thereby blocking at least a portion of the well, and removing the magnetic field to unblock the portion of the well. Also disclosed herein is a magnetorheological cement. 1. A method of cementing at least a portion of a well , comprising the steps of:feeding a magnetorheological cementitious slurry to a well, wherein said magnetorheological cementitious slurry comprises a hydraulic cement and a plurality of magnetic particles; andapplying a magnetic field to the magnetorheological cementitious slurry concurrent with at least a portion of said feeding step to cause a mechanical response in said magnetorheological cementitious slurry in the well.2. The method of claim 1 , wherein the mechanical response includes an increase in the viscosity of the magnetorheological cementitious slurry thereby resulting in blocking at least a portion of the well.3. The method of claim 1 , wherein the mechanical response includes directing the location of the magnetorheological cementitious slurry thereby resulting in blocking at least a portion of the well.4. The method of claim 1 , wherein the mechanical response includes an increase in the yield strength of the magnetorheological cementitious slurry.5. The method of claim 1 , wherein the mechanical response includes directing the location of the magnetorheological cementitious slurry thereby resulting in displacing at least one of a drilling ...

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Номер записи: 94
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: 95
10-01-2019 дата публикации

FUNCTIONALIZED NANOSILICA AS SHALE INHIBITOR IN WATER-BASED FLUIDS

Номер: US20190010377A1
Автор: Boul Peter J., Reddy B. Raghava, Thaemlitz Carl
Принадлежит: Saudi Arabian Oil Company

A nanosilica containing fluid system for shale stabilization in a shale formation. The nanosilica containing fluid system comprising a functionalized nanosilica composition operable to react with shale at the surface of the shale formation to form a barrier on the shale formation. The functionalized nanosilica composition comprising a nanosilica particle, the nanosilica particle having a mean diameter, and a functionalization compound, the functionalization compound appended to the surface of the nanosilica particle. And an aqueous-based fluid, the aqueous-based fluid operable to carry the functionalized nanosilica composition into the shale formation. The functionalization compound is an amino silane. The aqueous-based fluid is selected from the group consisting of water, deionized water, sea water, brine, and combinations thereof. 1. A method for shale stabilization in a shale formation , the method comprising the steps of: a functionalized nanosilica composition operable to inhibit shale erosion of the shale formation,', 'an aqueous-based fluid, the aqueous-based fluid operable to carry the functionalized nanosilica composition into the shale formation, and', 'a synergistic polymer additive;, 'introducing a nanosilica containing fluid into the shale formation, the nanosilica containing fluid comprisingallowing the nanosilica containing fluid to inhibit shale erosion of the shale formation, wherein the functionalized nanosilica composition and the synergistic polymer additive in the nanosilica containing fluid are operable to interact synergistically such that the synergy between the functionalized nanosilica composition and the synergistic polymer additive is operable to provide shale inhibition.2. The method of claim 1 , wherein the functionalized nanosilica composition comprises:a nanosilica particle; anda functionalization compound, the functionalization compound appended to the surface of the nanosilica particle.3. The method of claim 1 , wherein the ...

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Номер записи: 96
10-01-2019 дата публикации

Overcoming the Retardation of Cement Hydration from Dispersing Agents used in Suspension of Additives

Номер: US20190010378A1
Автор: Dias Toledo Filho Romildo, JR. William Cecil, Mendoza Reales Oscar, Pearl, Ravi Krishna
Принадлежит: Halliburton Energy Services, Inc.

A method of cementing a subterranean formation includes forming a cement composition comprising cementitious material, an aqueous base fluid, a nano-reinforcement particle suspension comprising a surfactant; and pozzolanic material; introducing the cement composition into a subterranean formation; and allowing the cement composition to set in the subterranean formation. A method of making a cement composition includes combining cementitious material, an aqueous base fluid, a nano-reinforcement particle suspension comprising a surfactant, and a pozzolanic material, where the rate of hydration of the surfaces of the cementitious material is less retarded by the surfactant than an equivalent cement composition without pozzolanic material. 1. A method of making a well cement composition comprising:combining a cementitious material; an aqueous base fluid; a nano-reinforcement particle suspension comprising a surfactant; and a pozzolanic material, wherein the pozzolanic material is selected from the group consisting of micro-pozzolanic material, nano-pozzolanic material, and combinations thereof; andwherein the rate of hydration of the surfaces of the cementitious material is less retarded by the surfactant than an equivalent cement composition without pozzolanic material.2. The method of claim 1 , wherein the nano-reinforcement particles are at least one selected from single wall carbon nano tubes (SWCNT) claim 1 , multi-wall carbon nanotubes (MWCNT) claim 1 , and combinations thereof.3. The method of claim 1 , wherein the surfactant is an anionic surfactant.4. The method of claim 1 , wherein the nano-reinforcement particle suspension comprising a surfactant and pozzolanic material are combined before adding the cementitious material and aqueous base fluid.5. The method of claim 1 , wherein the nano-reinforcement particles are present in an amount of about 0.01% to about 3.0% by weight of cement.6. The method of claim 1 , wherein the pozzolanic material is at least one ...

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Номер записи: 97
09-01-2020 дата публикации

SETTABLE COMPOSITIONS COMPRISING REMEDIATED FLY ASH (RFA) AND METHODS OF CEMENTING IN SUBTERRANEAN FORMATIONS

Номер: US20200010363A1
Автор: Thomas Joseph Earl, Whidden Jeffrey Alexander
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Some embodiments of the present invention comprise a method of cementing comprising: placing a settable composition into a well bore, the settable composition comprising RFA, hydraulic cement, and water; and allowing the settable composition to set. Other embodiments comprise a method of cementing comprising: placing a settable composition into a well bore, the settable composition comprising RFA, calcium hydroxide (lime), and water; and allowing the settable composition to set. Other embodiments comprise a settable composition comprising: RFA, hydraulic cement, calcium hydroxide, natural pozzolan and water; and allowing the composition to set. Other embodiments comprise a settable composition comprising RFA and any combination of hydraulic cement, calcium hydroxide, slag, fly ash, and natural or other pozzolan. 1. A settable composition for cementing , the settable composition comprising (a) remediated fly ash , (b) cement and/or calcium hydroxide , and (c) optionally water , wherein said remediated fly ash contains fly ash and a natural pozzolan , wherein said natural pozzolan is present in said remediated fly ash in a concentration of about 1 wt % to about 99 wt % , and wherein said remediated fly ash is pozzolanic.2. The settable composition of claim 1 , wherein said natural pozzolan is a pozzolanic ash.3. The settable composition of claim 1 , wherein said natural pozzolan is derived from pumice claim 1 , perlite claim 1 , ignimbrites claim 1 , or any other volcanic material.4. The settable composition of claim 1 , wherein said natural pozzolan is selected from the group consisting of pumice claim 1 , pumicite claim 1 , perlite claim 1 , volcanic ash claim 1 , metakaolin claim 1 , diatomaceous earth claim 1 , silica fume claim 1 , precipitated silica claim 1 , colloidal silica claim 1 , ignimbrites claim 1 , vitrified calcium alumino-silicates claim 1 , ground waste glass claim 1 , calcined shale claim 1 , calcined clay claim 1 , zeolites claim 1 , and ...

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Номер записи: 98
09-01-2020 дата публикации

APPLICATION OF METAL OXIDE-BASED CEMENTS

Номер: US20200010751A1
Автор: Abdulrazzaq Waseem, Alburaikan Reem, Jamison Dale E., Savari Sharath, WHITFILL Donald L.
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Methods for using cement compositions in subterranean formations are provided. In some embodiments, the methods comprise introducing a first treatment fluid comprising a first base fluid and a metal oxide into a wellbore penetrating at least a portion of a subterranean formation; introducing a spacer fluid into the wellbore that separates the first treatment fluid from at least a second treatment fluid; introducing the second treatment fluid into the wellbore, wherein the second treatment fluid comprises a second base fluid and a soluble salt; allowing the first treatment fluid to contact the second treatment fluid to form a cement mixture; and allowing the cement mixture to at least partially set. 1. A method comprising:introducing a first treatment fluid comprising a first base fluid and a metal oxide into a wellbore penetrating at least a portion of a subterranean formation;introducing a spacer fluid into the wellbore that separates the first treatment fluid from at least a second treatment fluid;introducing the second treatment fluid into the wellbore, wherein the second treatment fluid comprises a second base fluid and a soluble salt;allowing the first treatment fluid to contact the second treatment fluid to form a cement mixture; andallowing the cement mixture to at least partially set.2. The method of claim 1 , wherein the set cement mixture at least partially plugs a loss zone in the subterranean formation.3. The method of claim 1 , wherein at least one of the first treatment fluid and the second treatment fluid comprise a viscosifier.4. The method of claim 3 , wherein the viscosifier is an attapulgite clay.5. The method of claim 1 , wherein the first treatment fluid is introduced into the wellbore using one or more pumps.6. The method of claim 1 , wherein one or more properties of the spacer fluid introduced into the wellbore are determined based claim 1 , at least in part claim 1 , on a mixing model that simulates the interface behavior of the first ...

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Номер записи: 99
09-01-2020 дата публикации

TREATMENT FLUIDS COMPRISING SYNTHETIC SILICATES AND METHODS FOR USE

Номер: US20200010752A1
Автор: Jandhyala Siva Rama Krishna, Patil Sandip, Pearl William, RAVI Krishna M., Singh Sheetal, Urdaneta Javier
Принадлежит:

Methods for using treatment fluids comprising synthetic silicates in subterranean formations are provided. In some embodiments, the methods may comprise introducing a treatment fluid comprising an aqueous base fluid and a synthetic silicate into a wellbore penetrating at least a portion of a subterranean formation comprising a loss zone; allowing the treatment fluid to displace at least a portion of a first fluid present in the wellbore; and allowing the treatment fluid to at least partially plug the loss zone. 1. A method comprising:introducing a treatment fluid comprising an aqueous base fluid and a synthetic silicate into a wellbore penetrating at least a portion of a subterranean formation comprising a loss zone;allowing the treatment fluid to displace at least a portion of a first fluid present in the wellbore; andallowing the treatment fluid to at least partially plug the loss zone.2. The method of claim 1 , further comprising allowing the treatment fluid to displace substantially all of the first fluid.3. The method of claim 1 , wherein the synthetic silicate is a synthetic magnesium silicate.4. The method of claim 1 , wherein the synthetic silicate is selected from the group consisting of: sodium magnesium silicate claim 1 , sodium magnesium silicate tetrasodium pyrophosphate claim 1 , sodium magnesium fluorosilicate claim 1 , sodium magnesium fluorosilicate tetrasodium pyrophosphate claim 1 , and any combination thereof.5. The method of claim 1 , wherein the treatment fluid further comprises a weighting agent.6. The method of claim 1 , wherein the synthetic silicate is present in an amount from about 0.1 to about 5.0% by weight of water in the treatment fluid.7. The method of claim 1 , wherein the treatment fluid is not settable.8. The method of claim 1 , wherein the treatment fluid does not comprise a lost circulation material.9. The method of claim 1 , wherein the treatment fluid is thixotropic.10. The method of claim 1 , wherein the treatment fluid at ...

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Номер записи: 100