| Entries |
| Document | Title | Date |
|---|
| 20080269079 | Polymer Coated Bridging Solids and Weighting Agents for Use in Drilling Fluids - A wellbore fluid having at least two phases, including a fluid phase and a solid phase. The solid phase is a powdered solid material coated with a polymer that is the reaction product of a polyether amine and a dialdehyde crosslinking agent. Preferably the polyether amine is a diamine and more preferably the compound acts as a shale hydration inhibitor. The dialdehyde crosslinking agent reacts with the polyether amine compound and forms the polymeric material coating the solid. The polymer is substantially solubilized when the pH of the fluid has a value of less than about 7. | 10-30-2008 |
| 20080280787 | PHENOL-FORMALDEHYDE NOVOLAC RESIN HAVING LOW CONCENTRATION OF FREE PHENOL - A phenol-formaldehyde novolac resin having a low concentration of free phenol prepared by distilling residual phenol from a molten novolac resin and replacing at least a portion of the phenol with a solvent having a volatility equal to or less than phenol. Such modified novolac resins are suitable for the production of resin coated molding sands for shell molding and sand cores, as well as for the production of resin coated proppants for use in oil and gas recovery operations. | 11-13-2008 |
| 20090011960 | DRILLING FLUID COMPOSITION COMPRISING HYDROPHOBICALLY ASSOCIATING POLYMERS AND METHODS OF USE THEREOF - The present disclosure relates to drilling fluids for use in bitumen recovery from oil sands. In particular, the disclosure relates to a drilling fluid composition containing hydrophobically associating polymers which encapsulate the bitumen, and a method and use of the composition. | 01-08-2009 |
| 20090054271 | GLYCEROL POLYCARBONATE, ORGANIC COMPOSITIONS CONTAINING SAME AND METHOD FOR OBTAINING SAID COMPOSITIONS - The invention concerns an organic composition comprising glycerol polycarbonates, mixed with polyglycerols, [(a-hydroxymethyl)oxyethylene/(a-hydroxymethyl ethylene carbonate) copolymers; optionally [(a-alkyl)oxyethylene/(a-alkyl) ethylene carbonate] copolymers, optionally [(a-alkyl)oxyethylene/(a-hydroxyalkyl)oxyethylene] copolymers, glycerol carbonate and/or other organic carbonates, glycerol and/or other co-produced and/or residual compounds and a method for producing said composition. The inventive composition or the homopolymers and copolymers constituting same, are applicable in the technical fields of hydraulic fluids, lubrication, wood treatment and decoration, fire-retardant treatment, detergency, oil prospecting and production, water treatment, cosmetics, pharmaceutics, food industry and chemical intermediates. | 02-26-2009 |
| 20090075845 | Degradable Polymers for Wellbore Fluids and Processes - A viscosifying agent for wellbore fluids is described including a polymer polymerized using at least two pre-polymers “A” and “B”, the polymer being capable of essentially fully degrading into soluble fragments after the initiation of a breaking process. | 03-19-2009 |
| 20090131280 | Swelling Inhibitors for Clays and Shales - Hydration of clays and shales may be inhibited during drilling operations by using a clay and shale inhibitor. The inhibitor may be used with a water based drilling fluid. The clay and shale inhibitor includes from 0.2 to 5 % by weight of a reaction product of an epoxy resin with at least one primary or secondary aliphatic or cycloaliphatic amine. | 05-21-2009 |
| 20090192051 | HIGH TEMPERATURE STABILIZER FOR WELL TREATMENT FLUIDS AND METHODS OF USING SAME - A high temperature well treatment fluid comprising an electron donating compound comprising phenothiazine as thermal decomposition reduction additives for gels used in well treatment fluids is provided. The electron donating compound comprising phenothiazine performs as a stabilizer in well treatment fluids at temperatures of up to about 500° F. (260° C.). Methods of treating wells having subterranean formation temperatures of up to about 500° F. (260 ° C.) using such high temperature well treatment fluids are provided. | 07-30-2009 |
| 20090258798 | Methods and compositions using crosslinked aliphatic polyesters in well bore applications - Methods and compositions including a method comprising: providing a treatment fluid comprising a carrier fluid and a solid particle comprising a crosslinked aliphatic polyester; and placing the treatment fluid into a subterranean formation. | 10-15-2009 |
| 20090275487 | ADDITIVE FOR INCREASING THE DENSITY OF AN OIL-BASED FLUID AND FLUID COMPRISING SUCH ADDITIVE - A method of formulating a wellbore fluid that includes grinding a solid particulate material and a polymeric dispersing agent to provide a resulting polymer coated solid material, and suspending the resulting polymer coated solid material in the wellbore fluid. At least a portion of the resulting polymer coated solid material has a particle diameter less than 2.0 microns, wherein the polymeric dispersing agent has a molecular weight greater than 10,000. Exemplary starting materials for the solid material include weighting agents including barite, calcium carbonate, dolomite, ilmenite, hematite or other iron ores, olivine, siderite and strontium sulfate as well as mixture and combinations of these and other similar weighting materials. The dispersant in one illustrative embodiment is a polymeric acrylate ester made from the monomers of stearyl methacrylate, butyacrylate, and acrylic acid. | 11-05-2009 |
| 20100009873 | Thermally Stable Compositions and Use Thereof in Drilling Fluids - A composition is comprised of a mixture of the reaction product of an amine and a poly-functional isocyanate, and the reaction product of (i) a carboxylic acid with at least two carboxylic moieties; (ii) a polyamine having an amine functionality of two or more; and a chemical selected from the group consisting of (i) alkoxylated alkyl amines, (ii) fatty acid amides and (iii) mixtures thereof, and it is used as a drilling fluid additive. | 01-14-2010 |
| 20100056398 | THICKENER COMPOSITION - Thickener systems which are suitable for preparing thickener compositions, and which systems consists of (A) at least one anionic surfactant A and (B) at least one polymer B comprising at least one hydrophobic group and preferably at least one hydrophilic group, wherein the concentration of the polymer B in a thickener composition is below the overlap concentration c* of the polymer, along with processes for preparing such compositions and uses thereof. | 03-04-2010 |
| 20100069267 | Non-damaging manganese tetroxide water-based drilling fluids - A water-based drilling fluid containing Mn | 03-18-2010 |
| 20100210480 | USE OF INVERT EPOXY EMULSIONS FOR WELLBORE STABILIZATION - An invert emulsion wellbore fluid, including: a continuous oleaginous phase; a discontinuous non-oleaginous phase; a stabilizing agent; an oil-immiscible epoxy-based resin; and a hardening agent; wherein the wellbore fluid is a stable emulsion having a viscosity greater than 200 cps. In some embodiments, the hardening agent is an oil-miscible hardening agent; in other embodiments, the hardening agent is an oil-immiscible hardening agent. | 08-19-2010 |
| 20100210481 | Drilling Fluids With Redispersible Polymer Powders - A drilling fluid has a redispersible polymer powder introduced as a water dispersion that is capable of providing a deformable latex film on at least a portion of a subterranean sand formation and which inhibits or controls fluid loss and acts as a sealing agent when used to drill in sand formations for hydrocarbon recovery operations. The redispersible polymer powder may be made by drying the emulsion in which they are formed and then grinding into a powder or by spray drying. The polymer particles of suitable size precipitate or collect or assemble onto the pores of a subterranean sand formation to at least partial seal the formation with a deformable polymer film. | 08-19-2010 |
| 20100216671 | MICROEMULSIONS TO CONVERT OBM FILTER CAKES TO WBM FILTER CAKES HAVING FILTRATION CONTROL - Single phase microemulsions improve the removal of filter cakes formed during drilling with oil-based muds (OBMs). The single phase microemulsion removes oil and solids from the deposited filter cake. Optionally, an acid capable of solubilizing the filter cake bridging particles may also be used with the microemulsion. In one non-limiting embodiment the acid may be a polyamino carboxylic acid. Skin damage removal from internal and external filter cake deposition can be reduced. In another optional embodiment, the single phase microemulsion may contain a filtration control additive for delaying the filter cake removal, destruction or conversion. | 08-26-2010 |
| 20100248996 | WELLBORE FLUID - The invention provides an oil-based wellbore fluid in the form of an emulsion which comprises a continuous phase comprising an oil and, dispersed therein, a first dispersed liquid phase and a second separate dispersed liquid phase, the first dispersed liquid phase being a brine phase, and the second dispersed liquid phase comprising a polar organic liquid, said polar organic liquid being insoluble or sparingly soluble in the brine comprising said first dispersed liquid phase, but being soluble in pure water. There is also provided a method of carrying out a wellbore operation, which includes the steps of (a) introducing into a wellbore a wellbore fluid of the invention; (b) allowing a filter-cake to form; and subsequently (c) allowing a further fluid to come into contact with the filter-cake, said further fluid having a level of salinity which is lower than the level of salinity of said first dispersed liquid phase, and being such that said polar organic liquid is soluble therein. The fluid of the invention may be used in a variety of drilling operations where a low-permeability filter-cake is required initially, but where higher permeability is required at a later stage. | 09-30-2010 |
| 20100292108 | AGGREGATING COMPOSITIONS, MODIFIED PARTICULATE METAL-OXIDES, MODIFIED FORMATION SURFACES, AND METHODS FOR MAKING AND USING SAME - A method for treating solid materials is disclosed, where the treating compositions coats surfaces or portions of surfaces of the solid materials changing an aggregation or agglomeration propensity of the materials. Treating composition and treated solid materials are also disclosed. The methods and treated materials are ideally suited for oil field applications. | 11-18-2010 |
| 20100323927 | EQUIVALENT CIRCULATING DENSITY CONTROL IN DEEP WATER DRILLING - A method of providing a substantially constant rheological profile of a drilling fluid over a temperature range of about 120° F. to about 40° F. includes adding a drilling fluid additive to the drilling fluid, wherein the drilling fluid additive includes the reaction product of a carboxylic acid with at least two carboxylic moieties; and a polyamine having an amine functionality of two or more. A composition, such as an oil based drilling fluid, includes the reaction product of a carboxylic acid with at least two carboxylic moieties and a polyamine having an amine functionality of two or more. | 12-23-2010 |
| 20110003719 | POLYMER-CONTAINING COMPOSITION, ITS PREPARATION AND USE - Process for the preparation of a polymer-containing composition comprising the steps of: a) preparing a mixture of at least one cyclic monomer selected from glycolide and lactide and a layered double hydroxide comprising as charge-balancing anions 10 to 100% of an organic anion and 0 to 90% of hydroxide, based on the total amount of charge-balancing anions, and b) polymerising said monomer, optionally in the presence of a polymerisation initiator or catalyst. | 01-06-2011 |
| 20110053808 | Suspension Characteristics in Invert Emulsions - Among the methods provided is a method of drilling a subterranean well with an invert emulsion fluid comprising: providing an invert emulsion fluid formed by combining components that comprise: an oil-based continuous phase; an aqueous discontinuous phase; and a polar hydrophobic additive that comprises a polar hydrophobe, wherein the polar hydrophobic additive may substantially increases the yield point, the low-shear yield point, or both of the invert emulsion fluid relative to a fluid without a polar hydrophobic additive while limiting the change in the plastic viscosity to no more than about 35% of the change in the property with the largest increase; and placing the invert emulsion fluid in a subterranean formation. | 03-03-2011 |
| 20110053809 | DEGRADABLE NON-AQUEOUS GEL SYSTEMS - A method of treating a formation that includes exposing a region of the formation occupied by a hydrolysable gel to a hydrolyzing agent; and allowing sufficient time for the hydrolyzing agent to hydrolyze the gel. Various methods may also include the use of a swelling agent to allow for expansion of the gel. | 03-03-2011 |
| 20110136702 | Wellbore Fluid Additives and Methods of Producing the Same - Disclosed herein is a polymer useful in a method of forming a wellbore fluid additive. This polymer comprises a polyethylene backbone comprising pendant aminoalkylsulfonic acid amides which comprise a carbonyl directly attached to a backbone carbon, and an amide formed via the amine group from the aminoalkylsulfonic acid. Methods of preparing these polymers by addition of the aminoalkylsulfonic acid to a polymeric anhydride are disclosed. Methods related to oil extraction using the wellbore fluid with the additive are also disclosed. | 06-09-2011 |
| 20110160097 | VISCOSIFYING POLYMERS AND METHODS OF USE - Fluids for use within a wellbore are provided, comprising amorphous polyalphaolefins and/or amorphous polyisobutylene in an oil-based hydrocarbon solvent. Novel properties of such fluids are described, and the fluids may be used, for example, during drilling or fracturing operations. | 06-30-2011 |
| 20110177981 | WELLBORE FLUIDS COMPRISING POLY(TRIMETHYLENE ETHER) GLYCOL POLYMERS - Wellbore fluids containing poly(trimethylene ether)glycols are provided. The wellbore fluids can provide enhanced functionality, improved cost effectiveness, and reduced environmental impact as compared to conventional wellbore fluids. | 07-21-2011 |
| 20110183871 | Method and composition for curing lost circulation - The invention provides a system made of fibers and a material able to exhibit reverse solubility. The invention preferably is used in a well and as a method to cure lost circulation. | 07-28-2011 |
| 20110183872 | METHODS FOR GAS WELL TREATMENT - Methods for using a microemulsion system are disclosed which comprises a solvent subsystem, a co-solvent subsystem and a surfactant subsystem comprises at least one monoalkyl branched propoxy sulfate anionic surfactant, where the microemulsion system are useful in drilling, producing, remediation, and fracturing application to reduce water blocks and water blocking in formation of a producing formation. | 07-28-2011 |
| 20110237466 | EQUIVALENT CIRCULATING DENSITY CONTROL IN DEEP WATER DRILLING - A method of providing a substantially constant rheological profile of a drilling fluid over a temperature range of about 120° F. to about 40° F. includes adding a drilling fluid additive to the drilling fluid, wherein the drilling fluid additive includes the reaction product of a carboxylic acid with at least two carboxylic moieties; and a polyamine having an amine functionality of two or more. A composition, such as an oil based drilling fluid, includes the reaction product of a carboxylic acid with at least two carboxylic moieties and a polyamine having an amine functionality of two or more. | 09-29-2011 |
| 20120190594 | Organoclay Materials for Environmentally Sensitive Regions - Fluids comprising oil; and an organophilic clay comprising a smectite clay modified by reaction with a protonated amphoteric surfactant. The smectite clay may be montmorillonite, beidellite, nontronite, or a combination thereof. The protonated amphoteric surfactant may be cetyl/myristyl amine oxide, a stearyl amine oxide, a stearyl betaine, or a combination thereof. In some cases, the fluid may also include water and/or a solid reactive metal. | 07-26-2012 |
| 20120225799 | Systems and Methods For Forming High Performance Compressible Objects - The present systems and methods utilize a polyamic acid solution as a precursor to form a polyimide bead having desired properties. The polyamic acid solution may be formed into a polyamic acid droplet. The polyamic acid droplet is then processed to form a polyamic acid bead, such as by extraction of solvent to concentrate the polyamic acid or by partial chemical imidization of the polyamic acid. The polyamic acid bead is then better able to retain its shape during subsequent processing steps, such as drying and pressurizing, before final thermal imidization. | 09-06-2012 |
| 20120231979 | Systems and Methods For Forming High Performance Compressible Objects - The present systems and methods utilize a polyamic acid solution as a precursor to form a polyimide bead having desired properties. The polyamic acid solution may be formed into a polyamic acid droplet. The polyamic acid droplet is then processed to form a polyamic acid bead, such as by extraction of solvent to concentrate the polyamic acid or by partial chemical imidization of the polyamic acid. The polyamic acid bead is then better able to retain its shape during subsequent processing steps, such as drying and pressurizing, before final thermal imidization. | 09-13-2012 |
| 20120258893 | Oil Based Drilling Fluids With Enhanced Stability at High Temperatures - Ester based drilling fluids with enhanced stability at high temperatures for drilling, running casing in, and/or cementing a borehole in a subterranean formation. The drilling fluids comprise a monomeric or polymeric carbodiimide hydrolysis inhibitor. | 10-11-2012 |
| 20120277124 | High Performance Drilling Fluids with Submicron-Size Particles as the Weighting Agent - Methods and compositions utilizing a drilling fluid comprising sub-micron precipitated barite having a weight average particle diameter below about 1 micron. Methods include a method comprising circulating a drilling fluid in a well bore, wherein the drilling fluid comprises: a carrier fluid; and a weighting agent that comprises sub-micron precipitated barite having a weight average particle diameter below about 1 micron are disclosed. In some embodiments, the drilling fluid may comprise an invert emulsion. In some embodiments, the sub-micron precipitated barite has a particle size distribution such that at least 10% of particles in the sub-micron precipitated barite have a diameter below about 0.2 micron, at least 50% of the particles in the of the sub-micron precipitated barite have a diameter below about 0.3 micron and at least 90% of the particles in the sub-micron precipitated barite have a diameter below about 0.5 micron. | 11-01-2012 |
| 20120283150 | Polymeric Additives for Enhancement of Treatment Fluids Comprising Viscoelastic Surfactants and Methods of Use - A subterranean treatment additive comprising a viscoelastic surfactant and an amphiphilic polymer. Wherein the amphiphilic polymer comprises a hydrophobic component, and a hydrophilic component, the hydrophilic component itself comprising at least 15 monomer units. The subterranean treatment additive may be used as part of a treatment fluid with an aqueous base fluid that may be a brine. | 11-08-2012 |
| 20120289437 | NON-AQUEOUS DRILLING ADDITIVE USEFUL TO PRODUCE A FLAT TEMPERATURE-RHEOLOGY PROFILE - The present application, at least in part, is directed to a method of providing a substantially constant rheological profile of an oil-based drilling fluid over a temperature range of about 120° F. to about 40° F. In some embodiments, the method comprises adding a drilling fluid additive to the drilling fluid, wherein the drilling fluid additive consists essentially of a polyamide and a set of at least one or more mono-carboxyl units. The polyamide has (a) repeat units of (i) a poly-carboxyl unit with at least two carboxylic moieties; and (ii) a polyamine unit having an amine functionality of two or more and the one or more mono-carboxyl units being positioned on the polyamide at a position selected from the group consisting of: an end position, a pendant position and combinations thereof. | 11-15-2012 |
| 20130045897 | AMPHIPHILIC NANOPARTICLE, COMPOSITION COMPRISING SAME AND METHOD OF CONTROLLING OIL SPILL USING AMPHIPHILIC NANOPARTICLE - An amphiphilic nanoparticle comprises a nanoparticle having a hydrophilic region comprising a hydrophilic functional group bonded to a first portion of a surface of the nanoparticle, and a hydrophobic region of a surface of the nanoparticle. A downhole fluid comprises the amphiphilic nanoparticle, and a method of controlling an oil spill using the downhole fluid are also disclosed. | 02-21-2013 |
| 20130130943 | MONO- AND POLYENOIC ACID AND METAL PARTICLE MIXTURES FOR BREAKING VES-GELLED FLUIDS - A method for breaking the viscosity of an aqueous fluid gelled with a viscoelastic surfactant (VES) includes: providing an aqueous fluid; adding to the aqueous fluid, in any order, components comprising: a VES comprising a non-ionic surfactant, cationic surfactant, amphoteric surfactant or zwitterionic surfactant, or a combination thereof, in an amount sufficient to form a gelled aqueous fluid comprising a plurality of elongated micelles, an unsaturated fatty acid comprising a monoenoic acid or a polyenoic acid; or a combination thereof; and a plurality of metallic particles to produce a mixture comprising dispersed metallic particles in the gelled aqueous fluid. The method also includes dissolving the metallic particles in the gelled aqueous fluid to provide a source of metal ions and heating the gelled aqueous fluid to a temperature sufficient to cause the unsaturated fatty acid to auto-oxidize to products present in an amount effective to reduce the viscosity. | 05-23-2013 |
| 20130252854 | OIL DRILLING AUXILIARY DISPERSION - A dispersion liquid for supporting oil drilling, including: an aqueous medium and a particulate solid polyglycolic acid resin dispersed in the aqueous medium; wherein the particulate polyglycolic acid resin has a weight-average molecular weight of at least 70,000 and at most 500,000, and exhibits weight retentivities in water at 80° C. of at least 85% after 12 hours, at most 80% after 72 hours, and at most 45% after 168 hours. The particulate solid polyglycolic acid resin included in the above-mentioned dispersion liquid for supporting oil drilling, functions as a fluidity control material exhibiting ideal degradation characteristics in the drilling operation for expansion of oil production capacity, demanded for suppressing the liquid permeability in the early stage and recovery of the liquid permeability after completion of the operation of the formation around the oil well. | 09-26-2013 |
| 20130267444 | Wellbore Servicing Fluid System and Methods of Use - A wellbore servicing composition comprising a filter cake positioned within a wellbore, the filter cake comprising an invert emulsion fluid, the invert emulsion fluid comprising an oleaginous fluid, a non-oleaginous fluid, and an acid-sensitive surfactant, and an emulsion reversing fluid positioned within the wellbore in contact with the filter cake, the emulsion reversing fluid comprising an acid precursor, wherein the acid precursor is not an acid. | 10-10-2013 |
| 20140024561 | Absorbent Polymers, and Related Methods of Making and Using the Same - Compositions used in subterranean operations include absorbent polymers useful in controlling fluids within a subterranean formation; a method includes the steps of providing a treatment fluid having an absorbent polymer, the absorbent polymer including an aminoalcohol or polyamine-modified water-soluble polymer which includes a carboxylic acid derivative group, the method further includes placing the treatment fluid in at least a portion of a subterranean formation. | 01-23-2014 |
| 20140045731 | Equipment and Methods for Preparing Curved Fibers - 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. | 02-13-2014 |
| 20140087975 | TREATMENT FLUID CONTAINING A CORROSION INHIBITOR OF A POLYMER INCLUDING A SILICONE AND AMINE GROUP - A treatment fluid comprises: water; a carboxylate; and a corrosion inhibitor, wherein the corrosion inhibitor is a polymer, wherein the polymer comprises silicone, an ether monomer residue, and an amine functional group; wherein a test fluid consisting essentially of the water, the carboxylate, and the corrosion inhibitor, and in the same proportions as in the treatment fluid, is capable of providing a corrosion weight loss to a metal plate of less than 0.05 pounds per square feet (lb/ft | 03-27-2014 |
| 20140148367 | NANOPARTICLE BIOCIDE IN INDUSTRIAL APPLICATIONS - A method includes providing a measured dose amount of manufactured metallic nanoparticle material and adding the measured dose amount of the manufactured metallic nanoparticle material to a sub-surface earth activity material to a sub-surface earth activity material for treatment corresponding to the sub-surface earth activity. A composition of silver in the form of silver nanoparticles in suspension having an interior of non-metallic material and a surface of silver dioxide, a maximum diameter less than about 100 nanometers, a minimum diameter of greater than about 2 nanometers, and biocidal properties. | 05-29-2014 |
| 20140349895 | INVERT EMULSION DRILLING FLUID CONTAINING A HYGROSCOPIC LIQUID AND A POLYMERIC SUSPENDING AGENT - An invert emulsion drilling fluid comprises: an external phase, wherein the external phase of the drilling fluid comprises a hydrocarbon liquid; an internal phase, wherein the internal phase of the drilling fluid comprises a hygroscopic liquid; and a suspending agent, wherein the suspending agent is a polymer comprising urea linkages or urea and urethane linkages. The hygroscopic liquid comprises a salt and a suitable solvent or comprises an alcohol. The drilling fluid can exclude an organophilic clay or organophilic lignite. A method of using the invert emulsion drilling fluid comprises: introducing the drilling fluid into at least a portion of a subterranean formation. | 11-27-2014 |
| 20140371113 | DRILLING FLUID PROCESSING - A method of processing a return oil-based drilling fluid includes centrifuging a primarily fluids phase at a first speed and separating the primarily fluids phase into a first effluent and a first residual, centrifuging the first effluent at a second speed and separating the first effluent into a second effluent and a second residual, and centrifuging the second effluent at a third speed and separating the second effluent into a third effluent and a third residual. A surfactant, a polymer, combinations of surfactant(s) and polymer(s) and/or a wash water may be added to one or more of the return oil-based drilling fluid, the primarily fluids phase, the primarily solids phase, the first effluent, the second effluent, and the third effluent. | 12-18-2014 |
| 20150024975 | INVERT EMULSION FLUIDS - Invert emulsion fluids comprising a fatty dimer diamine having 28 to 48 carbon atoms per molecule and an acid or an acid derivative and methods of using such invert emulsion fluids for the treatment of at least a portion of a subterranean formation are provided. The invert emulsion fluids can be suitable for use as, for example, packer fluids and drilling fluids. | 01-22-2015 |
| 20150051119 | POLYESTER RESIN COMPOSITION AND MOLDED ARTICLE OF SAME - A polyester resin composition comprising: 100 parts by mass of a polyester resin having at least 50% by mass of a glycolic acid resin; and from 0.5 to 50 parts by mass of a carboxylic acid anhydride. | 02-19-2015 |
| 20150072903 | OIL DRILLING AUXILIARY DISPERSION - A dispersion liquid for supporting oil drilling, including: an aqueous medium and a particulate solid polyglycolic acid resin dispersed in the aqueous medium; wherein the particulate polyglycolic acid resin has a weight-average molecular weight of at least 70,000 and at most 500,000, and exhibits weight retentivities in water at 80° C. of at least 85% after 12 hours, at most 80% after 72 hours, and at most 45% after 168 hours. The particulate solid polyglycolic acid resin included in the above-mentioned dispersion liquid for supporting oil drilling, functions as a fluidity control material exhibiting ideal degradation charateristics in the drilling operation for expansion of oil production capacity, demanded for suppressing the liquid permeability in the early stage and recovery of the liquid permeability after completion of the operation of the formation around the oil well. | 03-12-2015 |
| 20150099674 | Method and Composition for Curing Lost Circulation - The invention provides a composition made of fibers and a material able to exhibit reverse solubility. The invention preferably is used in a well and as a method to cure lost circulation. | 04-09-2015 |
| 20150126414 | POLYGLYCOLIC ACID RESIN SHORT FIBERS AND WELL TREATMENT FLUID - PGA short fibers having the following characteristics of (a) to (c): (a) strength of 1 to 20 gf/D; (b) a mass loss of at least 10% after 14 days in water at a temperature of 60° C.; and (c) a pH of 1 to 5 after 3 days in water at a temperature of 60° C. with a solid content concentration of 2 mass %. The PGA short fibers preferably further having (d1) an outside diameter of 1 to 120 μm, (e1) a fiber length of 2 to 30 mm, and (f1) a fineness of 0.1 to 25 D, or the PGA short fibers preferably further having (d2) an outside diameter of 1 to 200 μm, (e2) a fiber length of less than 2 mm, and (f2) an aspect ratio of 2 to 1,200. Also, a well treatment fluid containing the PGA short fibers. | 05-07-2015 |
| 20150353807 | POLYAMINOPOLYAMIDE-EPICHLOROHYDRIN RESINS FOR USE AS CLAY AND SHALE INHIBITION AGENTS FOR THE DRILLING INDUSTRY - The hydration of clays and shale in drilling operations may be inhibited by employing an aqueous based drilling fluid comprising a shale hydration inhibition agent comprising a polyaminopolyamide-epichlorohydrin resin, preferably the polyamino polyamide-epichlorohydrin resin is a reaction product of an aliphatic polyamine, an aliphatic polycarboxylic acid, and epichlorohydrin. The shale hydration inhibition agent should be present in the aqueous based drilling fluid in sufficient concentration to reduce the reactivity, such as swelling, of clays and shale when exposed to water-based drilling fluids. | 12-10-2015 |
| 20150376490 | Non-Aqueous Drilling Additive Useful To Stabilize Viscosity Over Change In Temperature - A composition and method to control viscosity with respect to temperature for an oil-based drilling fluid by adding a polyamide drilling fluid additive to the oil based drilling fluid. In some embodiments, a polyamide drilling fluid additive includes a reaction product of (i) a carboxylic acid with a single carboxylic moiety; (ii) a carboxylic acid with two carboxylic moieties, a carboxylic acid with three carboxylic moieties and combinations thereof; and (iii) a polyamine having an amine functionality of two or more; and placing the placing the oil based drilling fluid into the subterranean formation. | 12-31-2015 |
| 20160053157 | CURABLE CROSS-LINKABLE COMPOSITIONS FOR USE AS LOST CIRCULATION MATERIAL - The present invention relates to compositions and methods for reducing or preventing the loss of drilling fluids and other well servicing fluids into a subterranean formation during drilling or construction of boreholes in said formation. Specifically, this invention comprises a curable cross-linkable composition capable of free radical polymerization for creating lost circulation material. The curable cross-linkable composition comprises a mixture of:
| 02-25-2016 |
