A61K 9/02 - SuppositoriesBougiesBases for suppositories or bougies
A61K 31/437 - Heterocyclic compounds having nitrogen as a ring hetero atom, e.g. guanethidine or rifamycins having six-membered rings with one nitrogen as the only ring hetero atom ortho- or peri-condensed with heterocyclic ring systems the heterocyclic ring system containing a five-membered ring having nitrogen as a ring hetero atom, e.g. indolizine, beta-carboline
A pharmaceutical composition comprising a beta2-agonist selected from indacaterol and formoterol in combination with a corticosteroid selected from fluticasone and ciclesonide, and, optionally, one or more pharmaceutically acceptable excipients.
A61K 31/167 - Amides, e.g. hydroxamic acids having aromatic rings, e.g. colchicine, atenolol, progabide having the nitrogen atom of a carboxamide group directly attached to the aromatic ring, e.g. lidocaine, paracetamol
A61K 31/46 - 8-Azabicyclo [3.2.1] octaneDerivatives thereof, e.g. atropine, cocaine
A61K 31/573 - Compounds containing cyclopenta[a]hydrophenanthrene ring systemsDerivatives thereof, e.g. steroids substituted in position 17 beta by a chain of two carbon atoms, e.g. pregnane or progesterone substituted in position 21, e.g. cortisone, dexamethasone, prednisone or aldosterone
A61K 45/06 - Mixtures of active ingredients without chemical characterisation, e.g. antiphlogistics and cardiaca
A61K 9/00 - Medicinal preparations characterised by special physical form
A composition comprising rifaximin in the form of particles, wherein substantially all the particles have a particle size less than or equal to 2 micrometres.
A61K 47/24 - Organic compounds, e.g. natural or synthetic hydrocarbons, polyolefins, mineral oil, petrolatum or ozokerite containing atoms other than carbon, hydrogen, oxygen, halogen, nitrogen or sulfur, e.g. cyclomethicone or phospholipids
A61J 1/00 - Containers specially adapted for medical or pharmaceutical purposes
A61K 47/48 - Medicinal preparations characterised by the non-active ingredients used, e.g. carriers, inert additives the non-active ingredient being chemically bound to the active ingredient, e.g. polymer drug conjugates
G01N 1/00 - SamplingPreparing specimens for investigation
4.
INHALATION FORMULATIONS COMPRISING CARMOTEROL IN COMBINATION WITH A CORTICOSTEROID
A pharmaceutical composition comprising carmoterol in combination with a corticosteroid selected from fluticasone, ciclesonide or mometasone, and, optionally, one or more pharmaceutically acceptable excipients.
A61K 31/56 - Compounds containing cyclopenta[a]hydrophenanthrene ring systemsDerivatives thereof, e.g. steroids
A61K 31/573 - Compounds containing cyclopenta[a]hydrophenanthrene ring systemsDerivatives thereof, e.g. steroids substituted in position 17 beta by a chain of two carbon atoms, e.g. pregnane or progesterone substituted in position 21, e.g. cortisone, dexamethasone, prednisone or aldosterone
A61K 45/06 - Mixtures of active ingredients without chemical characterisation, e.g. antiphlogistics and cardiaca
A61K 9/00 - Medicinal preparations characterised by special physical form
A pharmaceutical composition for inhalation comprising R (+) budesonide and one bronchodilators, and, optionally, one or more pharmaceutically acceptable excipients.
A61K 31/58 - Compounds containing cyclopenta[a]hydrophenanthrene ring systemsDerivatives thereof, e.g. steroids containing heterocyclic rings, e.g. danazol, stanozolol, pancuronium or digitogenin
A61K 45/06 - Mixtures of active ingredients without chemical characterisation, e.g. antiphlogistics and cardiaca
A61K 31/167 - Amides, e.g. hydroxamic acids having aromatic rings, e.g. colchicine, atenolol, progabide having the nitrogen atom of a carboxamide group directly attached to the aromatic ring, e.g. lidocaine, paracetamol
A61K 31/137 - Arylalkylamines, e.g. amphetamine, epinephrine, salbutamol, ephedrine
A61K 31/4709 - Non-condensed quinolines containing further heterocyclic rings
6.
ACID-SOLUBLE CEMENT COMPOSITIONS COMPRISING CEMENT KILN DUST AND/OR A NATURAL POZZOLAN AND METHODS OF USE
The present invention relates to acid-soluble cement compositions that comprise cement kiln dust ("CKD") and/or a natural pozzolan and associated methods of use. An embodiment includes a method of cementing comprising: placing an acid-soluble cement composition in a subterranean formation, wherein the acid-soluble cement composition comprises a hydraulic cement, a component selected from the group consisting of CKD, pumicite, and a combination thereof, and water; allowing the acid-soluble cement composition to set; and contacting the set acid-soluble cement composition with an acid to dissolve the set acid-soluble cement composition.
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 14/16 - Minerals of vulcanic origin porous, e.g. pumice
C04B 18/16 - Waste materialsRefuse from building or ceramic industry
7.
CRYSTALLINE FORM OF PRULIFLOXACIN AND PROCESSES FOR ITS PREPARATION
The present invention relates to a crystalline polymorphic form of 6-fluoro-1-methyl-7- {4-[(5-methyl-2-oxo-1,3-dioxol-4-yl)methyl]piperazin-1-yl}-4-oxo-4H-[1,3]-thiazeto-[3,2- a]-quinoline-3-carboxylic acid (prulifloxacin). More specifically, the invention relates to a crystalline form of prulifloxacin (herein referred to as Form A), and a method for preparing the crystalline Form A. The present invention further provides a pharmaceutical formulation comprising the novel form of prulifloxacin.
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.
C04B 24/26 - Macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
C04B 24/28 - Macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
C09K 8/48 - Density increasing or weighting additives
9.
METHODS OF PLUGGING AND ABANDONING A WELL USING COMPOSITIONS COMPRISING CEMENT KILN DUST AND PUMICITE
The present invention is directed to plug-and-abandon operations that use plugging compositions comprising cement kiln dust, pumicite, and/or lime. An embodiment includes a method of plugging a well bore for abandonment comprising: placing a plugging composition in the well bore, the plugging composition comprising: cement kiln dust in an amount of about 5% to about 100% by weight of cementitious components, pumicite in an amount of about 5% to about 100% by weight of cementitious components, 0% to about 24% of Portland cement by weight of cementitious components, and water; and allowing the plugging composition to set and form a plug.
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 14/16 - Minerals of vulcanic origin porous, e.g. pumice
C04B 18/16 - Waste materialsRefuse from building or ceramic industry
The present invention provides dexrabeprazole magnesium hydrate and a process for its preparation. The present invention also provides a magnesium, calcium or potassium salt of dexrabeprazole, optionally in amorphous form, and processes for its preparation.
C07D 401/12 - Heterocyclic compounds containing two or more hetero rings, having nitrogen atoms as the only ring hetero atoms, at least one ring being a six-membered ring with only one nitrogen atom containing two hetero rings linked by a chain containing hetero atoms as chain links
A61K 31/4184 - 1,3-Diazoles condensed with carbocyclic rings, e.g. benzimidazoles
A61P 1/04 - Drugs for disorders of the alimentary tract or the digestive system for ulcers, gastritis or reflux esophagitis, e.g. antacids, inhibitors of acid secretion, mucosal protectants
11.
A FLUID LOSS ADDITIVE CONTAINING A BIODEGRADABLE GRAFTED COPOLYMER FOR A CEMENT COMPOSITION
According to an embodiment, a fluid loss additive comprises a biodegradable grafted copolymer, wherein the copolymer comprises: (i) a first polymer comprising a monomer or monomers selected from the group consisting of acrylamido-2-methylpropane sulfonic acid, N-N dimethyl acrylamide, N-vinyl-N- methylaceamide, N-vinylformamide, N-vinylpyrrolidone, acrylonitrile, acrylamide, acrylomorpholine, vinyl alcohol, maleic anhydride, acrylic acid, and any combination thereof; and (ii) a second polymer, wherein the first polymer is grafted onto the second polymer. According to another embodiment, a method of cementing in a low-temperature subterranean formation comprises: introducing a cement composition into the subterranean formation comprising: (i) cement; (ii) water; and (iii) the fluid loss additive; and allowing the cement composition to set. According to another embodiment, a method of cementing in a high-temperature subterranean formation comprises: introducing a cement composition into the subterranean formation comprising: (i) cement; (ii) water; (iii) a clay; and (iv) the fluid loss additive; and allowing the cement composition to set.
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
C09K 8/487 - Fluid loss control additivesAdditives for reducing or preventing circulation loss
12.
A WATER-BASED FLUID LOSS ADDITIVE CONTAINING AN AMPHIPHILIC DISPERSANT FOR USE IN A WELL
According to an embodiment, a well treatment composition comprises: an aqueous liquid; a fluid loss additive, wherein the fluid loss additive comprises a high molecular weight, water-swellable polymer; and an amphiphilic dispersant, wherein the well treatment composition has an activity of at least 10%. According to another embodiment, a method of cementing in a subterranean formation comprises: introducing a cement composition into the subterranean formation, the cement composition comprising: (i) cement; (ii) water; and (iii) the well treatment composition; and allowing the cement composition to set.
C09K 8/12 - Clay-free compositions containing synthetic organic macromolecular compounds or their precursors
C09K 8/40 - Spacer compositions, e.g. compositions used to separate well-drilling from cementing masses
C09K 8/52 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
C09K 8/66 - Compositions based on water or polar solvents
C09K 8/70 - Compositions for forming crevices or fractures characterised by their form or by the form of their components, e.g. foams
C04B 18/16 - Waste materialsRefuse from building or ceramic industry
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C09K 8/473 - Density reducing additives, e.g. for obtaining foamed cement compositions
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices or the like
The present invention relates to a process for the preparation of substantially pure nateglinide of formula (I), substantially free from the cis-isomer and L-enantiomer and preparation of enantiomerically pure nateglinide form B, directly from the hydrolysis of a (-)-N-(trans-4-isopropylcyclohexyl-1-carbonyl)-D-phenylalanine alkyl ester in a ketonic solvent or water or mixture thereof.
C07C 231/12 - Preparation of carboxylic acid amides by reactions not involving the formation of carboxamide groups
C07C 233/63 - Carboxylic acid amides having carbon atoms of carboxamide groups bound to carbon atoms of rings other than six-membered aromatic rings having the nitrogen atom of at least one of the carboxamide groups bound to a carbon atom of a hydrocarbon radical substituted by carboxyl groups
14.
A STABLE ORGANIC-BASED FLUID LOSS ADDITIVE CONTAINING AN ORGANOPHILIC CLAY-BASED SUSPENDING AGENT FOR USE IN A WELL
The present invention provides a well treatment composition comprising: a water- soluble, organic liquid, wherein the organic liquid comprises the continuous phase of the well treatment composition, and wherein the organic liquid comprises a polyglycol or a derivative of polyglycol; a fluid loss additive, wherein the fluid loss additive is insoluble in the organic liquid, and wherein the fluid loss additive comprises a high molecular weight, water-swellable polymer; and a suspending agent, wherein the suspending agent comprises an organophilic clay, wherein the well treatment composition has an activity of at least 15%. The present invention also provides a method of cementing in a subterranean formation comprising: introducing a cement composition into the subterranean formation, the cement composition comprising: (i) cement; (ii) water; and (iii) the well treatment composition; and allowing the cement composition to set after introduction into the subterranean formation.
C09K 8/40 - Spacer compositions, e.g. compositions used to separate well-drilling from cementing masses
C09K 8/66 - Compositions based on water or polar solvents
C09K 8/70 - Compositions for forming crevices or fractures characterised by their form or by the form of their components, e.g. foams
C04B 18/16 - Waste materialsRefuse from building or ceramic industry
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C09K 8/473 - Density reducing additives, e.g. for obtaining foamed cement compositions
This invention relates to a swellable and degradable sand plug system used in horizontal wellbores and the use of the system in treating horizontal wellbores. The slurry composition comprises a carrier fluid and a granular borate source material, where the borate source material is at least partially dehydrated or anhydrous. The carrier fluid may be a non-aqueous fluid, or when the average size of the granular borate source material is sufficient large, the carrier fluid may also be an aqueous fluid. The slurry composition is allowed to settle in the horizontal wellbore and at least partially fill at least a portion of the horizontal wellbore in a direction vertical to the substantially horizontal wellbore, and is exposed to a sufficient amount of aqueous fluid to expand to the point to substantially fill at least a portion of the horizontal wellbore in a direction vertical to the horizontal wellbore, thereby plugging the substantially horizontal wellbore. The slurry composition may be further exposed to a sufficient amount of aqueous liquid to at least partially dissolve the expanded slurry composition, thereby at least partially removing the plug from the substantially horizontal wellbore.
Downhole orientation sensing with a nuclear spin gyroscope. A downhole orientation sensing system for use in conjunction with a subterranean well can include a downhole instrument assembly positioned in the well, the instrument assembly including an atomic comagnetometer, and at least one optical waveguide which transmits light between the atomic comagnetometer and a remote location. A method of sensing orientation of an instrument assembly in a subterranean well can include incorporating an atomic comagnetometer into the instrument assembly, and installing the instrument assembly in the well.
A method comprises providing a treatment fluid comprising a gelling agent, an aqueous base fluid, a buffer composition comprising a plurality of salts, and a crosslinking agent; and contacting a subterranean formation with the treatment fluid. The method may be used in subterranean formation having a temperature greater than about 200 °F (about 93°C), and the treatment fluid useful with the method may have a high shear recovery greater than 100%.
C09K 8/68 - Compositions based on water or polar solvents containing organic compounds
C09K 8/90 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
Some aspects of the present disclosure include monitoring fluid flow in a subterranean reservoir. In some implementations, a sealant mixture is injected into a subterranean reservoir (105) to form a flow barrier (108) in the subterranean reservoir. The sealant mixture includes a sealant (226) material and a tracer (228). The tracer may be stored in the flow barrier, and the tracer may be displaced from the flow barrier, for example, by fluid flow in the subterranean reservoir. The displaced tracer may be detected, for example, in fluid produced into a well bore (103) in the subterranean reservoir. Fluid flow in the subterranean reservoir may be analyzed based on detection of the tracer.
A method of servicing a wellbore is provided. The method comprises establishing a communication link between a wellsite and a central control site, wherein the communication link carries sensor, audio, and video data to the central control site and carries command parameters to the wellsite to command wellbore servicing equipment on the wellsite. The data transmitted by the wellsite is analyzed at the central control site, stored in a data store at the central control site, and the results of analysis displayed on a display at the central control site.
A method of maintaining a location of a wellbore servicing device includes connecting a pressure activated hold-down tool (PAHT) (100) to the wellbore servicing device, delivering the wellbore servicing device and the PAHT into < wellbore, selectively increasing a curvature (112) of the PAHT in response to change in a fluid pressure, and engaging the PAHT with a feature (146) of a wellbore to prevent longitudinal movement of the wellbore servicing device. A PAHT has pressure actuated elements that selectively provide an unactuated state in which the PAHT lies substantially along a longitudinal axis and the pressure actuated elements selectively lie increasingly deviated from the longitudinal axis in response to a change in pressure applied to the PAHT. At least one of the pressure actuated elements has a tooth (136) configured for selective resistive engagement with a feature of the wellbore.
Methods and systems for integral storage and blending of the materials used in oilfield operations are disclosed. A modular integrated material blending and storage system includes a first module comprising a storage unit, a second module comprising a liquid additive storage unit and a pump for maintaining pressure at an outlet of the liquid additive storage unit. The system further includes a third module comprising a pre-gel blender (206). An output of each of the first module, the second module and the third module is located above a blender and gravity directs the contents of the first module, the second module and the third module to the blender. The system also includes a pump that directs the output of the blender to a desired down hole location. The pump may be powered by natural gas or electricity.
The invention relates to methods and compositions for producing or recovering an aqueous- based fluid to be utilized or injected in a wellbore or surrounding subterranean formation. The method comprises the step of contacting an aqueous-based fluid with an aqueous-soluble breaker composition comprising an oxidizing agent and a catalyst for a time sufficient to reduce or eliminate one or more deleterious substances in the aqueous-based fluid to produce a treated aqueous-based fluid suitable for use or injection in a wellbore or surrounding subterranean formation.
A61K 31/536 - Heterocyclic compounds having nitrogen as a ring hetero atom, e.g. guanethidine or rifamycins having six-membered rings with at least one nitrogen and at least one oxygen as the ring hetero atoms, e.g. 1,2-oxazines ortho- or peri-condensed with carbocyclic ring systems
A method of servicing a wellbore comprising placing an oil-based wellbore servicing fluid comprising an electrical conductivity enhancer into the wellbore and logging the wellbore by resistivity imaging. A method of servicing a wellbore comprising introducing an oil-based drilling fluid to a wellbore, identifying a subsection of the wellbore for imaging, introducing to the subsection of the wellbore a oil-based wellbore servicing fluid comprising a carbon nanotube wherein the servicing fluid comprising the electrical conductivity enhancer mixes with the oil-based drilling fluid; and imaging the subsection of the wellbore.
G01V 3/18 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
A method comprises providing a treatment fluid comprising an aqueous fluid, and a low-leakoff particulate, contacting a subterranean formation with the treatment fluid, and allowing the low-leakoff particulate to de-link so that at least a portion of the low-leakoff particulate enters the liquid phase.
A downhole tool that is capable of isolating communication pressure from below the set downhole tool, and is capable of being converted to a frac plug is provided. The downhole tool includes a packer with a ball seat defined therein. A plug is disposed at a lower end of the downhole tool to isolate the upper well from the lower well. A sealing ball is carried with the packer into the well by a setting tool. The movement of the sealing ball away from the ball seat is limited by isolation of the sealing ball from the lower well. A rod is disposed through the downhole tool contacting the plug. The rod is partially disposed in the ball seat, preventing the sealing ball from sealing. When the packer is set, flow within the well is isolated, thereby allowing treatment of the well above the packer. With the application of sufficient pressure, the sealing ball applies force to the rod which shears the plug from within the tool. The tool is converted to a standard frac plug.
An invert emulsion drilling fluid, and a method for the use thereof in drilling wellbores, with good rheological properties at high temperatures and pressures. One embodiment of the drilling fluids are free of organophilic clays and lignites, free of calcium chloride, and comprise an alcohol in the internal phase, a quaternary ammonium emulsifier, and argillaceous solids. In one embodiment, the alcohol is a glycerol, a polyglycerol, or a mixture thereof. In one embodiment, the base oil for the emulsion is a paraffin and/or mineral oil. The drilling fluids provide good lubricity and high rates of penetration.
A method of servicing a wellbore comprising preparing a wellbore servicing composition having a target water content, placing the wellbore servicing composition in the wellbore, recovering from the wellbore a recovered wellbore servicing fluid having a modified water content, wherein the modified water content is greater than the target water content, vacuum stripping water from the recovered wellbore servicing fluid to form a processed wellbore servicing fluid, wherein the processed wellbore servicing fluid has a water content less than the modified water content, and placing the processed wellbore servicing fluid in the same or a different wellbore.
The present invention relates to fluids useful for treating injection wells to prevent or to reduce migration of particulates therein. Some embodiments of the present invention describe methods of introducing a tackifying treatment fluid through an injection well and into a portion of a subterranean formation surrounding the injection well, wherein the tackifying treatment fluid comprises a base fluid and a tackifying agent. Other embodiments include a stop of introducing a resin treatment fluid to the injection well before the tackifying treatment fluid.
A method comprises providing a fluid source in a subterranean formation; providing a wellbore in the subterranean formation; and providing an in-situ barrier, wherein the in-situ barrier is disposed within the subterranean environment and modifies the flow pattern of at least one fluid within the subterranean formation that is provided by the fluid source and flows towards the wellbore.
C09K 8/588 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
C09K 8/60 - Compositions for stimulating production by acting on the underground formation
31.
INVERT DRILLING FLUIDS HAVING ENHANCED RHEOLOGY AND METHODS OF DRILLING BOREHOLES
An invert emulsion drilling fluid, and a method of drilling with such fluid, having improved rheology at low mud weights and high temperatures. The improved rheology is effected with addition of hydrophobic amines, most preferably dimer diamines.
A cementing tool for cementing a casing in a well has an inner mandrel that defines a central flow passage and has at least one fluid port defined through a wall thereof. An outer mandrel is disposed about the inner mandrel and the inner and outer mandrels define an annular space therebetween. The outer mandrel has at least one sealing element affixed thereto. An opening sleeve is positioned in the inner mandrel and is movable from a closed position to an open position in which the fluid port is uncovered. An expansion cone is positioned in the annular space. Fluid pressure applied through the central flow passage, and the fluid port will pass into the annular space and will urge the expansion cone through the annular space which will plastically deform the outer mandrel so that sealing elements affixed to the outer mandrel engage a previously installed casing in the well to seal thereagainst.
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
System and methods for effectively and efficiently cementing a casing annulus are disclosed. A packer system ( 600) includes an outer case (708), a landing collar within the outer case and a slidable shifting sleeve (726) coupled to the landing collar (704). The landing collar and the shifting sleeve are movable. A connecter (720) coupled to the shifting sleeve and is movable in a movement slot (722) with the shifting sleeve. A rubber element (716) is coupled at one end to the connector and is on an outside surface of the outer case. The displacement of the connector in the movement slot compresses the rubber element.
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes using plugs for isolating cement chargePlugs therefor
34.
PNEUMATIC PARTICULATE MATERIAL FILL SYSTEMS AND METHODS
Pneumatic particulate material fill systems (100, 200) and methods are disclosed. A particulate material fill system (100, 200) includes a cyclone separator (105) having an inlet (110) adapted to receive pneumatically conveyed particulate material. The cyclone separator has a first outlet (115) adapted to vent air and a second outlet (120) adapted to discharge solids. The particulate material fill system includes a tank (135) adapted to receive solids discharged from the cyclone separator (105) via the second outlet (120). The tank is adapted for use at atmospheric pressure.
The present invention relates to low environmental impact treatment fluids comprising a compliant crosslinking agent, and methods of use employing such treatment fluids to treat subterranean formations. The methods include providing a low environmental impact treatment fluid including an aqueous base fluid, a viscosifying agent, and a compliant crosslinking agent that comprises an iron ion and a non-iron crosslinking metal ion; and placing the treatment fluid in a subterranean formation. In some embodiments, the viscosifying agent may be a compliant viscosifying agent.
Treatment fluids comprising an aqueous base fluid, a viscosifying agent, and a compliant dual- functional additive are provided. The present invention provides methods of using the treatment fluids in subterranean formations. One example of a suitable method includes providing a fracturing fluid comprising an aqueous base fluid, a viscosifying agent, and a compliant dual- functional additive that acts as a fluid loss control agent and a breaker and introducing the fracturing fluid into at least a portion of a subterranean formation at a rate and pressure sufficient to create or enhance at least one or more fractures in the subterranean formation.
Treatment fluids comprising an aqueous base fluid, a compliant cellulosic viscosifying agent, a crosslinking agent, and a protective ligand are provided. The present invention provides methods of using the treatment fluids in subterranean formations. One example of a suitable method includes providing a fracturing fluid comprising an aqueous base fluid, a compliant cellulosic viscosifying agent, a crosslinking agent, and a protective ligand and introducing the fracturing fluid into at least a portion of a subterranean formation at a rate and pressure sufficient to create or enhance at least one or more fractures in the subterranean formation.
Compositions and methods according to the invention are directed to a cement composition for use in a subterranean formation. The cement composition comprises: (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 0F 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, wherein the test composition consists of 860 grams of Class-H Portland cement, 325 grams of deionized water, and 0.4% by weight of the cement of the polymer. The method comprises the steps of: (A) introducing the cement composition into the subterranean formation; and (B) allowing the cement composition to set after introduction into the subterranean formation.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 24/32 - Polyethers, e.g. alkylphenol polyglycolether
39.
SYSTEM AND METHOD FOR DETERMINING POSITION WITHIN A WELLBORE
A method of locating a wellbore feature, comprising delivering a mechanical position determination tool (100) into the wellbore, selectively causing an undulating curvature (110, 112, 114) of the mechanical position determination tool in response to a change in a fluid pressure, moving the mechanical position determination tool (100) along a longitudinal length of the wellbore, and sensing a change in resistance to continued movement of the mechanical position determination tool. A mechanical position location tool (100) for a wellbore, comprising pressure actuated elements configured to cooperate to selectively provide an unactuated state in which the mechanical position location tool lies substantially along a longitudinal axis (102) and the pressure actuated elements further configured to cooperate to selectively lie increasingly deviated from the longitudinal axis (102) in response to a change in pressure applied to the mechanical position location tool.
E21B 23/03 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting the tools into, or removing the tools from, laterally offset landing nipples or pockets
E21B 47/09 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes
40.
IMPROVED WEIGHING ASSEMBLY FOR MATERIAL STORAGE UNITS
Methods and systems for accurate measurement of forces to determine the amount of materials in a container are disclosed. A weighing assembly is disclosed which includes a base plate, a plurality of bearing plates coupled to the base plate and a plurality of load sensors. Each of the plurality of load sensors is coupled to one of the plurality of bearing plates. A mounting block is symmetrically supported by the plurality of load sensors and a current measurement device measures a sum of currents output from the plurality of load sensors.
G01G 3/14 - Weighing apparatus characterised by the use of elastically-deformable members, e.g. spring balances wherein the weighing element is in the form of a solid body stressed by pressure or tension during weighing measuring variations of electrical resistance
A downhole tool releasing mechanism which includes a collet 814) for releasably engaging a mandrel (41) of a downhole tool. A retaining band (30) is circumferentially disposed about the fingers (16) of the collet (14) for maintaining engagement of the collet and the mandrel prior to application of a predetermined axially directed force on the releasing mechanism (10). Upon application of such a force the collet fingers (16) expand, breaking the shear band (30), the mandrel (41) is released and the downhole tool is disengaged.
Of the many methods provided herein, one provided is a method comprising: providing a treatment fluid having a first microorganism count as a result of the presence of at least a plurality of microorganisms in the fluid; adding an attenuating agent to the treatment fluid; placing the treatment fluid in a UV light treatment system comprising a UV light source such that a plurality of free radicals are generated by the attenuating agent; allowing the free radicals to interact with the microorganisms in the fluid so as to reduce the microorganism count of the treatment fluid to a second microorganism count; and placing the treatment fluid having the second microorganism count into a subterranean formation.
Of the methods provided herein, one includes a method comprising: providing a turbid treatment fluid having a first microorganism count; placing the turbid treatment fluid in a self- contained, road mobile UV light treatment manifold that comprises a UV light source; irradiating the turbid treatment fluid with the UV light source in the self-contained, road mobile UV light treatment manifold that comprises an attenuating agent so as to reduce the first microorganism count of the turbid treatment fluid to a second microorganism count to form an irradiated treatment fluid, wherein the second microorganism count is less than the first microorganism count; and placing the irradiated treatment fluid having the second microorganism count in a subterranean formation, a pipeline or a downstream refining process.
A61K 31/34 - Heterocyclic compounds having oxygen as the only ring hetero atom, e.g. fungichromin having five-membered rings with one oxygen as the only ring hetero atom, e.g. isosorbide
45.
DELIVERING WATER-SOLUBLE POLYSACCHARIDES FOR WELL TREATMENTS
A method is provided comprising the steps of: (a) providing a dispersion comprising: a water-soluble polysaccharide and a carrier fluid, wherein the carrier fluid comprises: (i) glycerol, and (ii) a mono-hydroxylic alcohol having 1-3 carbons, wherein the mono- hydroxylic alcohol is present in at least 0.1% by weight of the glycerol, wherein the polysaccharide is insoluble in the carrier fluid; (b) mixing the dispersion with at least water to form an aqueous well treatment fluid, wherein the polysaccharide is soluble in the aqueous phase of the aqueous wellbore treatment fluid; and (c) introducing the aqueous treatment fluid into a subterranean formation.
A method of servicing a wellbore comprising placing a composition comprising a surfactant, brine, an oleaginous fluid, and optionally a co-surfactant in an annular space of the wellbore, wherein the composition forms a microemulsion under low shear conditions.
Methods and compositions that comprise sub-micron alumina for accelerating setting of a cement composition. An embodiment includes a method of cementing in a subterranean formation. The method may comprise introducing a cement composition into the subterranean formation, wherein the cement composition comprises hydraulic cement, sub-micron alumina, and water. The method further may comprise allowing the cement composition to set in the subterranean formation. Another embodiment includes a cement composition that may comprise hydraulic cement, sub-micron alumina, and water.
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
A pharmaceutical composition comprising a combination of Withania somnifera extract with at least one anti-retroviral agent and one or more optional pharmaceutically acceptable excipients.
A method of servicing a wellbore is provided. The method comprises running a toolstring (32) into a wellbore (12) to a first depth, actuating a controllably rotating sub-assembly (38) of the toolstring to rotate, and activating a pressure activated bendable sub-assembly (36) of the toolstring to bend, wherein actuating the controllably rotating sub -assembly to rotate and activating the pressure activate bendable sub -assembly are performed in any sequence or concurrently. The method also comprises running the toolstring into the wellbore beyond the first depth and stabbing the toolstring into a window (42) in a wall of the wellbore to enter a lateral wellbore, wherein no whipstock is used to facilitate stabbing into the window. The method further includes running the toolstring into the lateral wellbore and performing a wellbore servicing operation in the lateral wellbore.
There is provided a process for preparing febuxostat of formula (I) or a pharmaceutically acceptable salt thereof, the process comprising: condensing a compound of formula (A) with a compound of formula (B) to form an ester of febuxostat; hydrolyzing the ester of febuxostat to febuxostat, and optionally converting the febuxostat to a pharmaceutically acceptable salt thereof, wherein: R' is an activating group selected from boronic acid or lithium; R is selected from optionally substituted C1-4 alkyl or optionally substituted aryl; L is a leaving group selected from diazo, halo, -OSO2R", -OCOR" or -O-Si(R")3; and R" is selected from optionally substituted C1-4 alkyl or optionally substituted aryl.
Compositions and methods are directed to a cement composition for use in a subterranean formation. In an embodiment the cement composition comprises: (A) cement; (B) water; and (C) a polymer, wherein the polymer: (i) consists essentially of a monomer or monomers selected from the group consisting of acrylic acid, esters of acrylic acid, maleic acid, methacrylic acid, esters of methacrylic acid, itaconic acid, tumeric acid, citraconic acid, mesoconic acid, and any alkali metal, alkaline earth metal, 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 maintained under a temperature condition of 190 0F and a pressure of 5,160 psi; and (b) an initial setting time of less than 24 hours for the test composition maintained under a temperature condition of 217 °F and a pressure of 3,000 psi, wherein the test composition consists of 860 grams of Class-H Portland cement, 325 grams of deionized water, and 0.4 % by weight of the cement of the polymer. In another embodiment the method comprises the steps of: (A) introducing the cement composition into the subterranean formation; and (B) allowing the cement composition to set after introduction into the subterranean formation.
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 24/26 - Macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
C04B 40/06 - Inhibiting the setting, e.g. mortars of the deferred action type containing water in breakable containers
Systems, methods, and instructions encoded in a computer-readable medium can perform operations related to generating a model of a subterranean formation based on a probabilistic earth model. An earth model including a probability distribution for a property of a subterranean region is received. A subterranean formation model is generated based on sampling the probability distribution for the property. The subterranean formation model includes information on boundaries of rock blocks of a formation in the subterranean region. The subterranean formation model may be used for simulating an injection treatment applied to the formation, for example, to predict fracture propagation in the formation, hi some implementations, the subterranean formation model may be used for designing an injection treatment for the formation.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
Systems, methods, and instructions encoded in a computer-readable medium can perform operations related to refining information on characteristics of natural fractures of a subterranean formation. Fracture pattern models are generated based on sampling an initial distribution of values for a fracture parameter. Each fracture pattern model may include, for example, a model of natural fractures in a subterranean formation. Each fracture pattern model is compared to microseismic event data for a subterranean region. A refined distribution for the fracture parameter is generated based on the comparison. Generating the refined distribution may include, for example, selecting values of the fracture parameter from fracture pattern models that correlate with the microseismic event data. In some implementations, an injection treatment may be simulated and/or designed based on the refined distribution.
The invention relates to a pharmaceutical composition comprising liposomes and at least one pharmaceutically acceptable excipient, wherein the liposomes comprise a lipid core containing voriconazole. The invention also relates to a method of making pharmaceutical compositions and to their use as a medicament.
Systems, methods, and instructions encoded in a computer-readable medium can perform operations related to stochastic simulation of subterranean fracture propagation. A plurality of subterranean formation models, each representing a subterranean formation, are analyzed to obtain information on predicted results of applying an injection treatment to the subterranean formation. Each of the analyzed subterranean formation models is generated by simulating forces acting on rock blocks of the subterranean formation during the injection treatment. Each simulation has an input parameter value determined for that simulation based on sampling a distribution of values for a characteristic of the subterranean formation. The characteristic may include, for example, a natural fracture parameter. The information on the predicted results of applying the injection treatment may include, for example, an output probability distribution. In some implementations, the information may be used to design an injection treatment for the subterranean formation.
Systems, methods, and instructions encoded in a computer-readable medium can perform operations related to simulating injection treatments applied to a subterranean formation from multiple well bores in the subterranean formation, and controlling injection treatments. A subterranean formation model representing rock blocks of a subterranean formation is received. Information on multiple injection treatments for multiple well bores in the subterranean formation is received. The subterranean formation model and the information on the injection treatments is used to predict a response of each of the rock blocks to forces acting on the rock block during the injection treatments. The injection treatments may include, for example, multiple fracture treatments for simultaneous application to the subterranean formation. In some implementations, injection treatments may be designed for a multiple-well bore system based on the predicted response of the rock blocks.
Systems, methods, and instructions encoded in a computer-readable medium can perform operations related to simulating subterranean fracture propagation. A subterranean formation model representing rock blocks of a subterranean formation is received. The subterranean formation model is used to predict a response of each rock block to one or more forces acting on the rock block during an injection treatment for the subterranean formation. The predicted responses of the rock blocks may include, for example, a fracture, a rotation, a displacement, a dilation of an existing fracture, and/or another type of response. In some implementations, an injection treatment may be designed for a subterranean formation based on the predicted response of the rock blocks.
A method of making a connection in hydrocarbon production equipment comprising positioning at least a portion of a receiving component (320) about at least a portion of an insertable component (301), providing a swellable element (330) within a circumferential space (340) substantially defined by the at least a portion of the receiving component and the at least a portion the insertable component, and allowing the swellable element to expand. A hydrocarbon production equipment apparatus comprising an insertable component positioned within a receiving component, and a swellable element positioned between at least a portion of the insertable component and at least a portion of the receiving component, wherein the insertable component, the receiving component, or both is coupled to a hydrocarbon production equipment member, wherein the swellable element swells in response to contact with a swelling agent.
A inhaler for an inhalation formulation, comprising a canister containing a pharmaceutical composition under pressure; a metering valve for measuring a metered dose of the composition from the canister for administration to a patient in need thereof; and an actuator for actuating discharge of the metered dose to the patient; wherein the actuator includes a discharge orifice having a diameter in the range 0.2 to 0.4 mm; and wherein the pharmaceutical composition comprises an anticholinergic agent and a pharmaceutically acceptable propellant.
A topical foam pharmaceutical composition for rectal administration comprising rifaximin is described. Also described is a method of making the composition and the use of the composition to as a medicament.
A61K 47/24 - Organic compounds, e.g. natural or synthetic hydrocarbons, polyolefins, mineral oil, petrolatum or ozokerite containing atoms other than carbon, hydrogen, oxygen, halogen, nitrogen or sulfur, e.g. cyclomethicone or phospholipids
61.
IMPROVED METHODS AND SYSTEMS FOR MATERIAL TRANSFER
A storage unit (100) is disclosed. A first feed (115) is disposed at least partially within the storage unit (100), and a second feed (145) is coupled to the first feed (115). The second feed (145) is configured to receive one or more materials and to transfer the one or more materials to the first feed. The first feed is configured to elevate the one or more materials to the storage unit.
A topical foam pharmaceutical composition for rectal administration comprising rifaximin in the form of nanosized particles is described. Also described is a method of making the composition and the use of the composition to as a medicament.
A61K 47/24 - Organic compounds, e.g. natural or synthetic hydrocarbons, polyolefins, mineral oil, petrolatum or ozokerite containing atoms other than carbon, hydrogen, oxygen, halogen, nitrogen or sulfur, e.g. cyclomethicone or phospholipids
A61J 1/00 - Containers specially adapted for medical or pharmaceutical purposes
63.
DOWNHOLE PROGRESSIVE PRESSURIZATION ACTUATED TOOL AND METHOD OF USING THE SAME
A method of servicing a subterranean formation comprising positioning a wellbore servicing tool comprising an axial flowbore within a wellbore, making a first application of pressure to the axial flowbore of the wellbore servicing tool; wherein the pressure within the wellbore servicing tool is at least a first upper threshold during the first application of pressure, allowing the pressure within the axial flowbore following the first application of pressure to fall below a first lower threshold, making a second application of pressure to the axial flowbore of the wellbore servicing tool, wherein the pressure within the wellbore servicing tool is at least a second upper threshold during the second application of pressure, allowing a second subsiding of pressure within the axial flowbore following the second application of pressure to fall a second lower threshold, and communicating a fluid to the wellbore, the subterranean formation, or both via one or more ports of the wellbore servicing tool.
The present invention includes methods of cementing in subterranean formations using cement kiln dust in compositions having reduced Portland cement content. An embodiment of a method comprises placing a sealant composition that comprises cement kiln dust and is essentially free of Portland cement in a subterranean formation; and allowing the sealant composition to set.
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
C09K 8/473 - Density reducing additives, e.g. for obtaining foamed cement compositions
Devices and methods for testing cement include: a pressure vessel with a sample container inside an interior working volume of the pressure vessel, the pressure vessel configured to supply a first pressurized fluid to control a pore pressure of a cement sample and to supply a second pressurized fluid to lateral exterior surfaces of the sample container to provide a confining pressure that can be different than the pore pressure.
The invention is directed to methods for treating a portion of a well. The methods include the steps of: (A) forming a viscoelastic treatment fluid, wherein the treatment fluid comprises: (i) water; (ii) a viscoelastic surfactant ("VES"), wherein the VES is soluble in the water and wherein the VES is in the form of micelles; and (iii) a cross-linking agent for the VES molecules, wherein: (a) the cross-linking agent comprises cross-linking agent molecules having at least one complexed transition metal, wherein the transition metal has a valence state of at least three; and (b) the cross-linking agent is soluble in the water; and (B) introducing the treatment fluid into a portion of the well. According to a first aspect of the invention, (a) the VES comprises VES molecules having an alkyl group of greater than 14 carbon atoms and (b) the VES comprises VES molecules having at least one functional group selected from a carboxylate group, an amino group, an alcohol group, and an ether group. According to a second aspect of the invention, the VES comprises VES molecules having both an alkyl group of greater than 14 carbon atoms and at least one functional group selected from a carboxylate group, an amino group, an alcohol group, and an ether group.
The present invention includes methods and compositions that include a latex, and at least one of a natural pozzolan or cement kiln dust. An embodiment includes a method comprising: placing a latex composition in a subterranean formation, wherein the latex composition comprises: latex, a component selected from the group consisting of a natural pozzolan, cement kiln dust, and a combination thereof, and water; and allowing the latex composition to set. Another embodiment of the present invention includes a latex composition comprising: latex, a component selected from the group consisting of a natural pozzolan, cement kiln dust, and a combination thereof.
Methods and systems for stimulating a wellbore. A coil tubing bottom hole assembly is disclosed which includes a jetting tool. A non-caged ball sub is coupled to the jetting tool and a ported sub is coupled to the non-caged ball sub. Additionally, a caged ball sub is coupled to the ported sub.
Distributed acoustic, vibration, density and/or strain sensing is utilized for downhole monitoring. A method of tracking fluid movement along a wellbore of a well includes: detecting vibration, density, strain (static and/or dynamic) and/or Brillouin frequency shift in the well using at least one optical waveguide installed in the well; and determining the fluid movement based on the detected vibration, density, strain and/or Brillouin frequency shift. Another method of tracking fluid movement along a wellbore of a well includes: detecting a change in density of an optical waveguide in the well; and determining the fluid movement based on the detected density change.
Distributed density, temperature and/or strain sensing is utilized for downhole monitoring. A method and system for monitoring a rapidly changing parameter in a well includes: detecting gain-based stimulated Brillouin backscattering due to light transmitted through at least one optical waveguide (26) installed in the well (12), the Brillouin backscattering being dependent upon temperature and strain experienced by the waveguide in the well. The method can include measuring at least one of temperature and strain in the well, with the measurement being performed separately from the step of detecting Brillouin backscattering.
G01K 11/32 - Measuring temperature based on physical or chemical changes not covered by group , , , or using changes in transmittance, scattering or luminescence in optical fibres
G01V 9/00 - Prospecting or detecting by methods not provided for in groups
A downhole tool for use in a well has a mandrel (32) with an expandable sealing element (102) disposed thereabout. The mandrel has a head portion (62) threadedly connected thereto. A shoulder in the head portion and an upper end of the mandrel define an annular space (80). A sleeve with a bore therethrough may be positioned in the annular space. The head portion may be removed and a solid plug installed so that it fits within the annular space and so that the downhole tool will act as a bridge plug. The downhole tool has slip rings (92, 96) made up of a plurality of individual slip segments (114) that are adhesively bonded to one another at the sides thereof.
The invention provides a composition comprising a corrosion inhibitor, and a corrosion inhibitor intensifier composition comprising an intensifier compound that corresponds to the following formula (I): wherein R1 is a methyl or ethyl group, and R2 is H or an alkyl, aryl, alkyl aryl, alkylthio aryl, alkyloxy aryl, halogenated aryl, phenyl, alkyl phenyl, alkylthio phenyl, alkyloxyphenyl, or a halogenated phenyl group. The invention also provides a method comprising: contacting a metal surface with an acidic fluid comprising an aqueous base-fluid, an acid, and the corrosion inhibitor composition.
C23F 11/04 - Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in markedly acid liquids
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
C09K 8/74 - Eroding chemicals, e.g. acids combined with additives added for specific purposes
73.
WELLBORE SERVICING FLUID COMPOSITIONS AND USE THEREOF
A method of servicing a wellbore in contact with a subterranean formation comprising placing a wellbore servicing fluid comprising a polyuronide polymer within the wellbore, contacting the wellbore servicing fluid with a divalent ion source, and allowing the wellbore servicing fluid to form a gel within the wellbore wherein the divalent ion source is located within the wellbore. A method of servicing a wellbore in contact with a subterranean formation comprising (a) placing a wellbore servicing fluid comprising a polyuronide polymer into the wellbore wherein the wellbore servicing fluid contacts a calcium ion source, (b) shutting the wellbore and allowing the servicing fluid to set into place for a period of time, and (c) repeating steps (a) and (b) until the permeability of a structure within the wellbore is reduced by about 50%.
The present invention includes well treatment fluids and methods utilizing nano-particles and, in certain embodiments, to sealant compositions and methods utilizing nano-particles. The nano-particles may be incorporated into the sealant composition in different forms, including as discrete nano-particles, encapsulated nano-particles, agglomerated nano-particles, or in a liquid suspension.
The present invention includes well treatment fluids and methods utilizing nano- particles. An embodiment of a method of the present invention may comprise introducing a treatment fluid comprising nano-clay into a subterranean formation. The treatment fluid may be selected from the group consisting of a cement composition, a drilling fluid, a spacer fluid, and a lost circulation control composition. Another embodiment of the present invention may comprise a method of cementing. The method of cementing may comprise introducing a cement composition comprising a hydraulic cement, nano-clay, and water into a subterranean formation. The method further may comprise allowing the cement composition to set in the subterranean formation. Yet another embodiment of the present invention may comprise a treatment fluid, the treatment fluid comprising nano-clay. The treatment fluid may be selected from the group consisting of a cement composition, a drilling fluid, a spacer fluid, and a lost circulation control composition.
C09K 8/40 - Spacer compositions, e.g. compositions used to separate well-drilling from cementing masses
C09K 8/487 - Fluid loss control additivesAdditives for reducing or preventing circulation loss
C09K 8/516 - Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
C09K 8/504 - Compositions based on water or polar solvents
76.
IMPROVED METHODS AND SYSTEMS FOR INTEGRAL BLENDING AND STORAGE OF MATERIALS
Methods and systems for integral storage and blending of the materials used in oilfield operations are disclosed. An integrated material blending and storage system (100) is disclosed with a storage unit (102), a blender (108) located under the storage unit, a liquid additive storage module (110) having a pump (210) to maintain constant pressure at an outlet of the liquid additive storage module and a pre gel blender. Gravity directs a first input from the storage unit, a second input from the liquid additive storage module and a third input from the pre-gel blender (106) to the blender.
Improved methods of placing and/or diverting treatment fluids in subterranean formations are provided. In one embodiment, the methods comprise: introducing a diverting material into a subterranean formation penetrated by a well bore to reduce or prevent the flow of fluid into a first portion of the subterranean formation; introducing a first fluid into a second portion of the subterranean formation having a higher fluid flow resistance than the first portion of the subterranean formation; allowing the diverting material to be removed from the subterranean formation after at least a portion of the first fluid has been introduced into the second portion of the subterranean formation; and introducing a second fluid into the first portion of the subterranean formation.
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.
A method of servicing hydrocarbon production equipment comprising locating at least a portion of a hydrocarbon flow conduit experiencing a loss of functionality; creating a port to access an interior flow bore of the hydrocarbon flow conduit; installing at least one piece of equipment proximate the access port, wherein the equipment has access to the interior flow bore via the access port; and placing a servicing composition into the conduit via the access port, wherein the servicing composition prevents the loss of materials from the interior of the hydrocarbon flow conduit to the surrounding environment.
Methods and compositions are provided that relate to cement compositions and methods comprising sub-micron calcium carbonate and latex. An embodiment includes a method of cementing in a subterranean formation. The method may comprise introducing a cement composition into the subterranean formation, wherein the cement composition comprises cement, water, sub-micron calcium carbonate, and latex. The method further may comprise allowing the cement composition to set in the subterranean formation. Another embodiment includes a cement composition that may comprise cement, water, a sub-micron calcium carbonate, and latex.
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C09K 8/487 - Fluid loss control additivesAdditives for reducing or preventing circulation loss
The invention relates to compositions and methods relating to treatment fluids that comprise transient polymer networks in subterranean applications. In one aspect, the invention provides a method comprising: providing a treatment fluid comprising an aqueous base fluid and a transient polymer network, and placing the treatment fluid in a subterranean formation. In another aspect, the invention provides a subterranean treatment fluid comprising: an aqueous-base fluid and a transient polymer network.
Polymeric additives used with viscoelastic surfactants, fluids comprising such additives and viscoelastic surfactants, and associated methods of use, are provided. In one embodiment, the methods comprise: providing a treatment fluid that comprises an aqueous base fluid, a viscoelastic surfactant, and an amphiphilic polymer, the amphophilic polymer comprising a hydrophobic component, and a hydrophilic component comprising at least 15 monomer units; and introducing the treatment fluid into at least a portion of a subterranean formation.
Methods and apparatuses for releasing a chemical in a well bore are disclosed. One apparatus includes a curved member configured for coupling to a casing, and a hollow member is connected to the curved member. A chemical container is disposed, at least in part, within the hollow space, and the hollow member extends at least partially around a hollow space.
The invention relates to compositions and methods relating to treatment fluids that comprise entangled equilibrium polymer networks in subterranean applications. In one aspect, the invention provides a method comprising: providing a treatment fluid comprising at least one entangled equilibrium polymer network, and placing the treatment fluid in a subterranean formation.
The invention relates to various new polymorphic forms of manidipine and pharmaceutically acceptable salts thereof. The invention also relates to processes for the preparation of the polymorphic forms of manidipine and pharmaceutically acceptable salts thereof.
C07D 211/90 - Carbon atoms having three bonds to hetero atoms with at the most one bond to halogen
A61K 31/4422 - 1,4-Dihydropyridines, e.g. nifedipine, nicardipine
A61K 31/444 - Non-condensed pyridinesHydrogenated derivatives thereof containing further heterocyclic ring systems containing a six-membered ring with nitrogen as a ring hetero atom, e.g. amrinone
The present invention is directed to a method of hydrocarbon production from a hydrocarbon reservoir. The method includes providing a substantially horizontal wellbore having at least one productive interval within a hydrocarbon reservoir and forming at least one non- conductive transverse fracture in the reservoir along the substantially horizontal wellbore. An injection well is also provided. A fluid is injected into the reservoir through the injection well to displace hydrocarbons within the reservoir toward a production portion of the substantially horizontal wellbore. Hydrocarbons are drained from the reservoir into at least one production interval of the substantially horizontal wellbore. Fluid production from the at least one production interval into the substantially horizontal wellbore flows through an inflow control device that can restrict the fluid flow. A non-conductive transverse fracture can form a barrier within the reservoir to divert injected fluids to increase sweep efficiency and reduce the influx of injected fluids into the production interval.
An anchoring device for stopping movement of a sliding component in a mandrel or case is disclosed. The anchoring device includes an elastically deformable anchor seat and an elastically deformable anchor retainer insertable into the anchor seat. The anchor seat has a groove profile thereon which will mate with a groove profile on the mandrel in an anchoring position. The retainer is insertable into the anchor seat and will hold the anchor seat in the anchoring position.
The present invention relates to a process for preparing naratriptan or a salt thereof, the process comprising: (a) reacting a compound of formula (3) with a compound of the formula HCCR wherein Z is a protecting group, Y is a leaving group and R is a trialkyl silyl group, a trialkylstannyl group or a zinc (II) halide, to obtain the compound of formula (4); (b) converting the compound of formula (4) to a compound of formula (5) wherein Z' is hydrogen or a benzyl group; (c) converting the compound of formula (5) to naratriptan; and (d) optionally converting naratriptan to a salt thereof. The present invention also provides novel compounds (3) and (4) and processes for their preparation.
C07D 401/04 - Heterocyclic compounds containing two or more hetero rings, having nitrogen atoms as the only ring hetero atoms, at least one ring being a six-membered ring with only one nitrogen atom containing two hetero rings directly linked by a ring-member-to-ring- member bond
A method is provided for swelling water-swellable elements located in a portion of a well. The method comprises the steps of: (A) introducing an oil-in-water emulsion into the portion of the well, wherein the oil-in-water emulsion comprises: (i) an aqueous liquid, wherein the aqueous liquid is the external phase of the oil-in-water emulsion; (ii) a hydrocarbon liquid, wherein the hydrocarbon liquid is an internal phase of the oil-in-water emulsion, and wherein the hydrocarbon liquid is adjacent to the external phase of the oil-in-water emulsion; and (iii) a surfactant; and (B) allowing the oil-in-water emulsion to contact the water-swellable element for a sufficient length of time to cause the thickness of the water-swellable element to expand by a desired percentage, wherein the desired percentage is at least 5%.
Methods and compositions including a method comprising introducing a hydrophobically and cationically modified relative permeability modifier into a portion of a subterranean formation, wherein the hydrophobically and cationically modified relative permeability modifier comprises a hydrophilic polymer backbone with a hydrophobic modification and a cationic modification.
A wellbore servicing system, comprising a first sleeve system (200), the first sleeve system comprising a first sliding sleeve (260) at least partially carried within a first ported case (208), the first sleeve system being selectively restricted from movement relative to the first ported case by a first restrictor (284) while the first restrictor is enabled, and a first delay system configured to selectively restrict movement of the first sliding sleeve relative to the ported case while the restrictor is disabled.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
Improved methods of placing and/or diverting treatment fluids in subterranean formations are provided. In one embodiment, the methods comprise introducing a treatment fluid into a subterranean formation penetrated by a well bore, wherein the treatment fluid comprises: a base fluid, and a plurality of solid particulates comprising at least one selected from the group consisting of: a scale inhibitor, a chelating agent, and a combination thereof, wherein the solid particulates are substantially insoluble in the base fluid; and allowing at least a portion of the solid particulates to form a barrier or at partially divert a subsequent fluid.
C09K 8/03 - Specific additives for general use in well-drilling compositions
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells
C09K 8/536 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
C09K 8/56 - Compositions for consolidating loose sand or the like around wells without excessively decreasing the permeability thereof
C09K 8/60 - Compositions for stimulating production by acting on the underground formation
A method of inducing fracture complexity within a fracturing interval of a subterranean formation (102) comprising characterizing the subterranean formation, defining a stress anisotropy- altering dimension, providing a wellbore servicing apparatus (106) configured to alter the stress anisotropy of the fracturing interval of the subterranean formation, altering the stress anisotropy within the fracturing interval, and introducing a fracture (150) in the fracturing interval in which the stress anisotropy has been altered. A method of servicing a subterranean formation comprising introducing a fracture into a first fracturing interval (2), and introducing a fracture into a third fracturing interval (6), wherein the first fracturing interval and the third fracturing interval are substantially adjacent to a second fracturing interval (4) in which the stress anisotropy is to be altered.
In an embodiment, the present invention provides a process for preparing (-)-6-(4- aminophenyl)-5-methylpyridazin-3-(2H)-one, which process comprises: a) reacting racemic 6-(4-aminophenyl)-4,5-dihydro-5-methyl-3-(2H)-pyridazinone of formula (Il) with a chiral tartaric acid derivative to obtain a diastereomeric salt of (-)-6-(4- aminophenyl)-4,5-dihydro-5-methyl-3-(2H)-pyridazinone and the chiral tartaric acid derivative; and b) reacting the diastereomeric salt with a base to obtain (-)-6-(4- aminophenyl)-4,5-dihydro-5-methyl-3-(2H)-pyridazinone. The (-)-6-(4-aminophenyl)-4,5- dihydro-5-methyl-3-(2H)-pyridazinone may be used to prepare levosimendan.
C07D 237/04 - Heterocyclic compounds containing 1,2-diazine or hydrogenated 1,2-diazine rings not condensed with other rings having less than three double bonds between ring members or between ring members and non-ring members
95.
PROCESS FOR THE PREPARATION OF O-DESMETHYL VENLAFAXINE AND INTERMEDIATE FOR USE THEREIN
The present invention relates to a compound of formula (A), wherein R is alkyl. Compound A may be used as an intermediate in the preparation of O-desmethyl venlafaxine or a salt thereof, and the present invention provides such a preparation, as well as a process for preparing the compound of formula (A).
C07C 215/64 - Compounds containing amino and hydroxy groups bound to the same carbon skeleton having hydroxy groups bound to carbon atoms of at least one six-membered aromatic ring and amino groups bound to acyclic carbon atoms or to carbon atoms of rings other than six-membered aromatic rings of the same carbon skeleton with rings other than six-membered aromatic rings being part of the carbon skeleton
C07C 229/34 - Compounds containing amino and carboxyl groups bound to the same carbon skeleton having amino and carboxyl groups bound to acyclic carbon atoms of the same carbon skeleton the carbon skeleton containing six-membered aromatic rings
A61K 31/135 - Amines, e.g. amantadine having aromatic rings, e.g. methadone
Methods and compositions that include a method comprising: providing a treatment fluid comprising at least a plurality of degradable diverting agents that comprise at least one degradable material selected from the group consisting of a fatty alcohol, a fatty acid salt, a fatty ester, a proteinous material, and a combination thereof; and introducing the treatment fluid into a subterranean formation during a subterranean operation via a well bore.
According to one aspect of the invention, emulsion compositions are provided. Emulsions according to this aspect include: (a) a water-insoluble resinous material; (b) water; and (c) an emulsifier, wherein the emulsifier comprises a non-ionic, a cationic, or a zwitterionic emulsifier; wherein the continuous phase of the emulsion comprises the water; wherein a dispersed phase of the emulsion comprises the resinous material; wherein the dispersed phase is in the form of droplets having a size distribution range such that at least 50% of the droplets have a size of 0.5 micrometers - 500 micrometers; wherein the resinous material of the droplets is in a concentration of at least 5% by weight of the water; and wherein the composition of the droplets has a viscosity of less than 2,000 Poise (2,000 g/(cm.s)) measured at 20°F (-6.6°C). According to another aspect of the invention, methods are provided for treating a portion of a subterranean formation. Methods according to this aspect include the steps of: (a) forming an emulsion according to the composition described above; and (b) introducing the emulsion into a portion of a subterranean formation.
The present invention relates to a method of degrading a filter cake in a subterranean formation comprising: contacting at least a portion of a filter cake with a filter cake degradation fluid comprising a relative permeability modifier; and allowing the filter cake to degrade. The present invention also relates to a method of treating a subterranean formation including providing a well bore that includes a filter cake on at least a portion of the well bore and contacting at least a portion of the filter cake with a filter cake degradation fluid comprising a relative permeability modifier. The method also includes allowing the relative permeability modifier to retain at least a portion of the filter cake degradation fluid in the well bore for a time sufficient to contact the filtercake and allowing the filter cake to degrade.
The present invention provides a stabilized emulsion composition comprising: an oleaginous fluid, a fluid that is at least partially immiscible with the oleaginous fluid, and an emulsion stabilizing agent, wherein the emulsion stabilizing agent comprises a first ionic compound soluble in the oleaginous fluid or the fluid that is at least partially immiscible with the oleaginous fluid, and a second ionic compound with a charge of opposite sign of the first ionic compound and that is at least partially soluble in the opposite fluid as the first ionic compound. The present invention also provides methods involving the use of the stabilized emulsion composition and methods of preparing the stabilized emulsion composition.
Methods and systems for integrally processing the materials used in oilfield operations are disclosed. An integrated material processing system is disclosed with a storage unit (102, 202, 302) resting on a leg (104, 203, 304). A feeder (108, 212, 314) couples the storage unit to a first input of a mixer(106, 210, 312) and a pump (110, 214, 316) is coupled to a second input of the mixer. The storage unit contains a solid component of a well treatment fluid. The feeder supplies the solid component of the well treatment fluid to the mixer and the pump supplies a fluid component of the well treatment fluid to the mixer. The components are mixed in the mixer and the mixer outputs a well treatment fluid.
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