The present invention relates to pharmaceutical antiretroviral compositions comprising a combination of antiretroviral agents, the manufacturing process thereof and use of the said compositions for the prevention, treatment or prophylaxis of diseases caused by retroviruses, specifically acquired immune deficiency syndrome or an HIV infection.
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
A61K 31/427 - Thiazoles not condensed and containing further heterocyclic rings
A61K 31/513 - PyrimidinesHydrogenated pyrimidines, e.g. trimethoprim having oxo groups directly attached to the heterocyclic ring, e.g. cytosine
A61K 31/535 - 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
This invention provides a low dose pharmaceutical composition comprising deferasirox or a pharmaceutically acceptable derivative thereof and one or more pharmaceutically acceptable excipients.A unit dose of the pharmaceutical composition comprises from about 50mg to about 100mg of deferasirox, from about 150mg to about 200mg of deferasirox or from about 260mg to about 350mg of deferasirox. The pharmaceutical composition of the present invention, wherein the pharmaceutical composition comprises deferasirox, may be used to treat chronic iron over load or to treat lead toxicity. The pharmaceutical composition of the present invention, wherein the pharmaceutical composition comprises deferasirox and deferiprone,may be used to treat lead toxicity. This invention also provides a process for preparing the low dose pharmaceutical composition, the process comprising :dissolving or adsorbing or blending deferasirox and at least one excipient to produce a dispersion of deferasirox; and processing the dispersion to produce a desired dosage form.
A61K 31/41 - Heterocyclic compounds having nitrogen as a ring hetero atom, e.g. guanethidine or rifamycins having five-membered rings with two or more ring hetero atoms, at least one of which is nitrogen, e.g. tetrazole
A61P 7/00 - Drugs for disorders of the blood or the extracellular fluid
4.
PHARMACEUTICAL COMPOSITIONS FOR RECTAL ADMINISTRATION
The present invention relates to pharmaceutical compositions for rectal administration comprising fidaxomicin and to a process for preparing the pharmaceutical compositions for rectal administration. The invention also relates to an aerosol canister comprising a foamable pharmaceutical composition comprising fidaxomicin for rectal administration and to the treatment or maintenance of remission of infections such as diarrhoea caused by Clostridium difficile..
A complex comprises pemetrexed and a coformer. A pharmaceutical composition comprises a complex of pemetrexed and a co-former and one or more pharmaceutically acceptable excipients.
The present invention relates to a process for the control of Ostwald Ripening phenomenon occurring in particle suspensions without the need for addition of stabilizing agents, by using high pressure homogenization at mild conditions in a way that no increase or decrease in particle size occurs, thus allowing the stabilization of the suspension during the isolation step in the form of a dried powder.
F26B 3/12 - Drying solid materials or objects by processes involving the application of heat by convection, i.e. heat being conveyed from a heat source to the materials or objects to be dried by a gas or vapour, e.g. air the gas or vapour carrying the materials or objects to be dried with it in the form of a spray
8.
TETRACYCLINE TOPICAL FORMULATIONS, PREPARATION AND USES THEREOF
The invention relates to a topical suspension formulation that includes a tetracycline, a liquid medium and a polymeric gelling agent. The tetracycline may be in the form of its pharmaceutically acceptable salts, hydrates, or polymorphs and is in a suspended form within the formulation. The liquid medium is selected such that it does not dissolve or substantially minimally dissolves the tetracycline. The gelling agent is a polymeric hydrocarbon gelling agent. Preferably, the tetracycline has a particlesize of less than or equal to about 20microns.
The present invention relates in general to a topical pharmaceutical composition comprising an antiretroviral agent in combination with a bactericidal agent and optionally an antifungal agent, particularly for use as a contraceptive.
A61K 31/4418 - Non-condensed pyridinesHydrogenated derivatives thereof having a carbocyclic ring directly attached to the heterocyclic ring, e.g. cyproheptadine
A61K 31/675 - Phosphorus compounds having nitrogen as a ring hetero atom, e.g. pyridoxal phosphate
The present invention relates to a pharmaceutical composition comprising arformoterol and fluticasone furoate (preferably for once daily administration), to a process for preparing such a composition and to the use of such a composition for the treatment treatment and/or prevention of respiratory, inflammatory or obstructive airway disease.
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
11.
PRODUCTION OF NEAR MONODISPERSE PARTICLES USING MILLING AND MEMBRANE SEPARATION.
The present invention provides a method for producing particles having a reduced particle size distribution, which method comprises the steps of: a) providing a composition comprising particles; b) subjecting the particles in said composition to a size reduction step or to a size growth step; c) feeding said particles to a first membrane separation system to separate said particles according to size; d) recycling those particles that do not meet the size criteria back to step a); e) optionally, collecting in a collection tank the permeate of the first membrane separation system. Particles obtainable according to the method of the invention and characterized by having a near monodisperse particle size distribution are also provided. The particles are preferably characterized by having a particle size distribution with a span of less than 2.0. The invention also provides pharmaceutical compositions comprising particles according to the invention, and also apparatus for carrying out the method of the invention.
B01J 2/00 - Processes or devices for granulating materials, in generalRendering particulate materials free flowing in general, e.g. making them hydrophobic
This invention concerns the delivery of high doses of active pharmaceutical compounds via inhalation. A pharmaceutical formulation in the form of a powder suitable for inhalation comprises one or more active pharmaceutical ingredients and a mucolytic agent and/or a buffer, wherein the formulation is free of carrier.
The invention provides a method comprising: providing a drilling fluid, completion fluid, or workover fluid comprising an aqueous base fluid and a nonionic cellulose ether polymer having hydroxyethyl groups and being further substituted with one or more hydrophobic substituents, and placing the drilling fluid, completion fluid, or workover fluid in a subterranean formation.
The present invention relates to methods and compositions for treating a water- and hydrocarbon-producing subterranean formation with a relative permeability modifier, and more specifically, to improved treatment fluids, methods for preparing treatment fluids, and methods for use thereof in a subterranean formation. Methods of the present invention comprise providing a treatment fluid comprising a relative permeability modifier, at least one surfactant, and an aqueous phase base fluid; and placing the treatment fluid in a subterranean formation. The relative permeability modifier comprises a hydrophobically modified hydrophilic polymer. The at least one surfactant is operable to maintain the relative permeability modifier in a dissolved state in the treatment fluid above a pH of about 8. The at least one surfactant may be an anionic curfactant.
Disclosed herein is a wellbore servicing system, comprising a tubular string, a first sleeve system incorporated within the tubular string, 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 (274) while the first restrictor is enabled, and a first delay system (268,291) configured to selectively restrict movement of the first sliding sleeve relative to the first ported case while the first restrictor is disabled; a second sleeve system incorporated within the tubular string, the second sleeve system comprising a second sliding sleeve at least partially carried within a second ported case, the second sleeve system being selectively restricted from movement relative to the second ported case by a second restrictor while the second restrictor is enabled. The restrictor (274) is held in place by shear pin (284). In order to disable restrictor (274) a drop ball is seated on set (270) and pressure is increased to shear pin (284). Seat (270) is comprised of three or more radial segments. A protective sheath (272) is covering one or more surfaces of the seat to protect the set from contact with well fluid and to retain the segments in the close conformation.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
16.
IMPROVED ANNULAR ISOLATION WITH TENSION-SET EXTERNAL MECHANICAL CASING (EMC) PACKER
An apparatus comprising a first casing string (320) comprising one or more profiled seats (303a, 303b, 303c) furrowed into the first casing string's inner casing wall, a second casing string (400) comprising an upper casing joint, a lower casing joint, and a tension-set external mechanical casing (EMC) packer (500) positioned between the upper casing joint and the lower casing joint, wherein the tension-set EMC packer (500) comprises a mandrel (510) that is attached to the upper casing joint and to the lower casing joint, wherein the second casing string (400) is disposed within the first casing string (320) such that a casing casing annulus (CCA) is formed between the first casing string's inside diameter (ID) and the second casing string's outside diameter (OD), and wherein the recessed seats (303a, 303b, 303c) are positioned below the tension-set EMC packer (500) prior to any engagement of the tension-set EMC packer with the first casing string (320).
Stabilizing a subterranean formation containing water-sensitive clays with methods including introducing a leading-edge fluid comprising a first base fluid and a first clay stabilizer solution wherein the first clay stabilizer is present in the first base fluid at a first concentration; and then introducing a treatment fluid comprising a second base fluid and a second clay stabilizer solution wherein the second clay stabilizer is present in the second base fluid at a second concentration, wherein the first concentration of clay stabilizer solution is higher than the second concentration of clay stabilizer solution.
A reciprocating apparatus for pumping pressurized fluid. The reciprocating apparatus comprises a plunger (18) disposed within a cylinder (36), wherein the plunger (18) is hollow and ported for enabling fluid within the cylinder (36) to flow into the plunger (18). The plunger (18) includes at least one outlet (70) through which fluid within the plunger (18) flows out of the plunger (18). In operation, the plunger (18) retracts to displace fluid from the hollow body (66) and into a discharge chamber, and the plunger (18) extends towards the discharge chamber to discharge the displaced fluid. As the plunger (18) alternately retracts and extends, fluid within the plunger continuously flows towards the discharge chamber.
F04B 15/02 - Pumps adapted to handle specific fluids, e.g. by selection of specific materials for pumps or pump parts the fluids being viscous or non-homogeneous
Of the many embodiments provided herein, one embodiment includes a method comprising: providing a drilling fluid comprising: an aqueous fluid; and a surfactant; and drilling a well bore in a subterranean formation comprising an oleaginous fluid using the drilling fluid, wherein the surfactant forms a micelle within the well bore; and removing an oil block in the formation.
The present invention relates to a limit collar (200) comprising a limit component (202) coupled to a surface of a wellbore tubular and an interface component (204) engaging the limit component (202), and to methods utilizing the same.
Systems and methods for improved propped fracture geometry for high permeability reservoirs are provided. In one embodiment, a method of determining a pad volume and proppant volume for fracturing a subterranean formation is provided comprising selecting a proppant volume for placement in a fracture to be created in a subterranean formation; determining a desired fracture geometry for the fracture; calculating a pad volume sufficient to create the desired fracture geometry in the subterranean formation at a lower fluid efficiency value; calculating a fracture length that would result from injecting the pad volume into the subterranean formation at an upper fluid efficiency value; calculating a fracture width that corresponds to the calculated fracture length; and calculating a proppant volume sufficient to fill a fracture having the calculated length and width.
Improved methods of placing and/or diverting treatment fluids in subterranean formations are described. The methods include introducing a treatment fluid into a subterranean formation penetrated by a wellbore, 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 least partially divert a subsequent fluid.
C09K 8/03 - Specific additives for general use in well-drilling compositions
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
C09K 8/528 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
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 8/70 - Compositions for forming crevices or fractures characterised by their form or by the form of their components, e.g. foams
C09K 8/80 - Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
C09K 8/92 - Compositions for stimulating production by acting on the underground formation characterised by their form or by the form of their components, e.g. encapsulated material
23.
RADIATION-INDUCED THICKENING AND RADIATION-INDUCED TRIGGERING FOR SET-ON-COMMAND SEALENT COMPOSITIONS AND METHODS OF USE
The present invention includes methods and compositions relating to the setting of fluids or slurries in a wellbore. In one embodiment, a method of isolating a portion a wellbore includes preparing a sealant composition having a fluid component, a polymeric additive constituent, and a set modifier component. The sealant composition is placed into a wellbore and subjected to ionizing radiation. The ionizing radiation can cause bonding between polymeric additive constituents and create a polymer matrix within the sealant composition that increases the mechanical strength of the sealant composition. The ionizing radiation also alters the set modifier component, triggering the thickening of the sealant composition.
The present invention includes methods relating to the setting of fluids or slurries in a wellbore. In one embodiment, a method of isolating a portion a wellbore by preparing a sealant composition cornprising a fluid component and a polymeric additive component, placing the sealant composition into a wellbore and subjecting the sealant composition to ionizing radiation. The ionizing radiation can cause bonding between polymeric additive components and create a polymer matrix within the sealant composition that increases the mechanical strength of the sealant composition.
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 8/467 - 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 8/508 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds
25.
RADIATION-INDUCED TRIGGERING FOR SET-ON-COMMAND COMPOSITIONS AND METHODS OF USE
The present invention relates to methods useful for isolating a portion of a wellbore. In one embodiment, a method includes preparing a sealant composition containing a set modifier component. The sealant composition is placed into the wellbore and is subjected to ionizing radiation that alters the set modifier component, triggering the thickening of the sealant composition.
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 8/508 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds
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 40/02 - Selection of the hardening environment
26.
USE OF MICRO-ELECTRO-MECHANICAL SYSTEMS (MEMS) IN WELL TREATMENTS
A method of servicing a wellbore, comprising placing a wellbore composition comprising a plurality of Micro-Electro-Mechanical System (MEMS) sensors in the wellbore, placing a plurality of acoustic sensors in the wellbore, obtaining data from the MEMS sensors and data from the acoustic sensors using a plurality of data interrogation units spaced along a length of the wellbore, and transmitting the data obtained from the MEMS sensors and the acoustic sensors from an interior of the wellbore to an exterior of the wellbore. A method of servicing a wellbore, comprising placing a wellbore composition comprising a plurality of Micro-Electro-Mechanical System (MEMS) sensors in the wellbore, and obtaining data from the MEMS sensors using a plurality of data interrogation units spaced along a length of the wellbore, wherein one or more of the data interrogation units is powered by a turbo generator or a thermoelectric generator located in the wellbore.
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
27.
A METHOD FOR INDIVIDUALLY SERVICING A PLURALITY OF ZONES OF A SUBTERRANEAN FORMATION
A method of servicing a subterranean formation (102) comprising providing a first sleeve system (200a) comprising a first one or more ports and being transitionable from a first mode to a second mode and from the second mode to a third mode, and a second sleeve system (200b) comprising a second one or more ports and being transitionable from a first mode to a second mode and from the second mode to a third mode, wherein, in the first mode and the second mode, fluid communication via the one or more ports of the first or second sleeve system is restricted, and wherein, in the third mode, fluid may be communicated via the one or more ports of the first or second sleeve system, transitioning the first and second sleeve systems to the second mode, and allowing the first sleeve system to transition from the second mode to the third mode.
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
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
A wellbore servicing system (100), comprising a sleeve system (200) comprising a ported case (208), a sliding sleeve (260) within the case and movable between a first sleeve position in which the sleeve re-stricts fluid communication via the case and a second sleeve position in which the sleeve does not, a radially divided segmented seat (270) movable between a first seat position in which the seat re-stricts movement of the sleeve and a second seat position in which the seat does not, and a sheath (272) covering a portion of the seat, the sleeve system being transitionable from a first, to a second, to a third mode, in the first mode, the sleeve is in its first position and the seat in its first position, in the second mode, the sleeve is in its first position and the seat in its second position, and, in the third mode, the sleeve is in its second position.
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
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
29.
INCREASING FRACTURE COMPLEXITY IN ULTRA-LOW PERMEABLE SUBTERRANEAN FORMATION USING DEGRADABLE PARTICULATE
A method of increasing the fracture complexity in a treatment zone of a subterranean formation is provided. The subterranean formation is characterized by having a matrix permeability less than 1.0 microDarcy (9.869233 x 10-19 m2). The method includes the step of pumping one or more fracturing fluids into a far-field region of a treatment zone of the subterranean formation at a rate and pressure above the fracture pressure of the treatment zone. A first fracturing fluid of the one or more fracturing fluids includes a first solid particulate, wherein: (a) the first solid particulate includes a particle size distribution for bridging the pore throats of a proppant pack previously formed or to be formed in the treatment zone; and (b) the first solid particulate comprises a degradable material. In an embodiment, the first solid particulate is in an insufficient amount in the first fracturing fluid to increase the packed volume fraction of any region of the proppant pack to greater than 73%. Similar methods using stepwise fracturing fluids and remedial fracturing treatments are provided.
A centralizer (200) comprises a first collar (202), a second collar (204), a plurality of bow springs (206) coupling the first collar to the second collar, and a plurality of particulates (220) disposed on an outer surface of at least one bow spring. One or more of the first collar, the second collar, and the bow springs comprises a composite material. In some embodiments, the centralizer comprises a third collar (302), wherein the plurality of bow springs comprise a first portion (304) of bow springs and a second portion (306)of bow springs, and where in the first portion of the bow springs couple the first collar (202) to the third collar (302) and the second portion of the bow springs couple the second collar (204) to the third collar (302).
The present invention relates to a pharmaceutical composition comprising an inhaled corticosteroid and an anticholinergic. In particular, to a pharmaceutical composition comprising tiotropium bromide and fluticasone furoate. The invention also relates to a process for preparing the pharmaceutical composition, therapeutic uses thereof in the treatment and / or prevention of respiratory, inflammatory or obstructive airway disease.
A computerized method and system for determining engine exhaust emissions for a job. Job utilization data is stored for each of a plurality of engines used for the job. An amount of engine exhaust emissions for each engine is determined based on the utilization data. An amount of engine exhaust emissions for the job is determined based on the amount of engine exhaust emissions for each engine. The amount of engine exhaust emissions for the job is stored and may, for example, be used for determining job cost, reporting, or controlling the job in real-time.
An embodiment of the present invention comprises a method of cementing comprising: placing a settable composition into a well bore, the settable composition comprising unexpanded perlite, cement kiln dust, and water; and allowing the settable composition to set. Another embodiment of the present invention comprises a method of cementing comprising: placing a settable composition into a well bore, the settable composition comprising ground unexpanded perlite, Portland cement interground with pumicite, and water; and allowing the settable composition to set. Yet another embodiment of the present invention comprises a settable composition comprising: ground unexpanded perlite; cement kiln dust; and water.
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
C04B 14/16 - Minerals of vulcanic origin porous, e.g. pumice
One method described includes the steps of: providing an HPG concentrate having a polymer load of about 2 to about 25% w/v and being present in a worse-than-theta aqueous solvent, the HPG concentrate comprising HPG polymer and an aqueous based solvent that comprises water and a non-solvent for the HPG that is soluble in the aqueous based solvent; and diluting the HPG concentrate with an aqueous fluid to form a subterranean treatment fluid.
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
B01F 13/00 - Other mixers; Mixing plant, including combinations of dissimilar mixers
A solid oral pharmaceutical composition comprises greater than 100 mg of imatinib, and one or more pharmaceutically acceptable excipients. A process for preparing a pharmaceutical composition comprising than greater than 100 mg of imatinib, and one or more pharmaceutically acceptable excipients comprises manufacturing a solid oral pharmaceutical composition by granulating imatimib with one or more pharmaceutically acceptable excipients. A solid oral pharmaceutical composition for use in medicine comprises greater than 100 mg of imatinib, and one or more pharmaceutically acceptable excipients.
A centralizer comprises a first body portion (204), a second body portion (202), a plurality of bow springs connecting the first body portion to the second body portion, and a window (208) disposed in the first body portion. The centralizer may also have a wellbore tubular disposed longitudinally within the first body portion, the second body portion, and the plurality of bow springs, and an upset (304) disposed on the surface of the wellbore tubular and within the window. Methods using the centralizer with a wellbore tubular and the use of the centralizer with a wellbore tubular are also disclosed.
The invention relates to corrosion inhibitor compositions comprising products of a reaction between aldehydes and amides for use in subterranean applications and methods related thereto. In general, the methods for inhibiting corrosion comprise providing a corrosive environment and adding a composition comprising a corrosion inhibitor to the corrosive environment. The corrosion inhibitor comprises a product of a reaction between at least one aldehyde and at least one amide that is not formamide or a formamide derivative.
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 8/74 - Eroding chemicals, e.g. acids combined with additives added for specific purposes
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
A transportable apparatus (10) may include a bin (12) having a first end (16), a second end (18), and a wall (20) connecting the first end and the second end; a frame (14) configured to support the bin in a transport position; and a base (34) configured to support the bin in a working position. At least a portion of the wall may have a non- circular curved cross - section having a major dimension and a minor dimension. A method may include providing a transportable apparatus, moving a bin of the transportable apparatus from a transport position to a working position, and providing material within the bin.
B65D 88/30 - Hoppers, i.e. containers having funnel-shaped discharge sections specially adapted to facilitate transportation from one utilisation site to another
B65D 88/56 - Large containers characterised by means facilitating filling or emptying by tilting
B60P 1/48 - Vehicles predominantly for transporting loads and modified to facilitate loading, consolidating the load, or unloading using pivoted arms raisable above the load supporting or containing element
B60P 1/64 - Vehicles predominantly for transporting loads and modified to facilitate loading, consolidating the load, or unloading the load supporting or containing element being readily removable
Systems, methods, and instructions encoded in a computer-readable medium can perform operations related to evaluating surface data. Geodetic data for a plurality of surface locations are received. The geodetic data may include surface gradient information and/or surface elevation information for multiple surface locations. A set of constraining relationships is generated based on the geodetic data. The set of constraining relationships relates undetermined values of surface elevation movement and/or undetermined values of surface gradient movement to measured surface elevation changes and/or measured surface gradient changes. Some or all of the constraining relationships include multiple undetermined values. Particular values for surface elevation movements and/or particular values for surface gradient movements are calculated for multiple surface locations based on determining a solution to the set of constraining relationships. In some implementations, a minimum curvature surface may be generated deterministically based on the geodetic data and the particular values identified using the constraining relationships.
An oxygen scavenger for completion brines effective and stable in high temperature subterranean formations. In one embodiment, the scavenger contains erythorbate and alkylhydroxlyamine.
A method of flocculating coal fines from produced water is provided. The method includes the steps of: (A) mixing at least: (i) produced water, wherein the produced water comprises suspended coal fines; (ii) one or more oil-soluble phosphate esters; and (iii) water- immiscible solvent; wherein the mixing is in proportions to obtain an oil-in-water emulsion; (B) allowing or mechanically causing the oil-in-water emulsion to substantially break into: (i) a first fluid having a continuous phase comprising at least some of the water from the produced water; and (ii) a second fluid having a continuous phase comprising at least some of the water-immiscible solvent; and (C) mechanically separating the first fluid and the second fluid. Optionally, the step of mixing further includes mixing with a crosslinker for the one or more phosphate esters to form a gel for suspending the separated coal fines.
Treatments and compounds useful in subterranean formations are discussed, with particular attention to those formations where surfaces may be subject to silica scale build-up. Certain embodiments pertain to utilizing silica scale control additives with remediation and stimulation treatments. One example of a suitable method includes providing an acidic treatment fluid comprising: a base fluid, an acid, and a silica scale control additive; contacting at least a portion of a subterranean formation with the acidic treatment fluid; and allowing the acidic treatment fluid to interact with silica scale buildup in the subterranean formation so that at least a portion of the silica scale buildup is removed.
The invention provides electrophilic monohalomethylating reagents, methods for their preparation and methods for preparation of monohalomethylated biologically active compounds using such reagents. Typical monohalomethyl groups transferred are FH2C-, CIH2C- and others. The reagents used for transferal of the groups are described by Formulae A-D : wherein: X = F, CI, Br, I, sulfonate esters, phosphate esters or another leaving group; R11 = tetrafluoroborates, inflates, halogen, perchlorate, sulfates, phosphates or carbonates The other variables are as defined in the claims.
Polysaccharides, for example xanthan, diutan, scleroglucan, gums, celluloses, and starches, and derivatives of the foregoing, are reacted with organic carbonates forming products that: (1) have increased viscosifying efficiency, i.e., higher viscosities at reduced concentrations compared to the unmodified polysaccharide; or (2) are insolubilized at temperature ranges for which the unmodified polysaccharide would hydrate fully; or (3) both properties. In some cases, the insolubilized polysaccharides can be activated to dissolve and viscosify at specific temperature ranges by using pH modifiers. A method of treating a well is provided, including the steps of: (a) obtaining a modified polysaccharide characterized by having been made by the process of combining: (i) a water-soluble polysaccharide, wherein the polysaccharide is in a solid form during the combining step; and (ii) a transesterification agent, wherein the transesterification agent is in liquid form; wherein the step of combining is in the presence of less than 10% by weight water relative to the water-soluble polysaccharide and wherein any water present is at a pH of 8 or less; (b) forming a treatment fluid comprising the modified polysaccharide and water; and (c) introducing the treatment fluid into the well.
C09K 8/08 - Clay-free compositions containing natural organic compounds, e.g. polysaccharides, or derivatives thereof
C09K 8/40 - Spacer compositions, e.g. compositions used to separate well-drilling from cementing masses
C09K 8/514 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
C09K 8/90 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
The present invention provides a pharmaceutical composition comprising a low dose of zanamivir and a process for preparing the pharmaceutical composition comprising a low dose of zanamivir. The pharmaceutical composition comprising a low dose zanamivir may be used in the treatment and/or prophylaxis of influenza. The present invention also provides a method of treatment and/or prophylaxis of influenza which comprises administering a dry powder inhaler composition comprising a low dose zanamavir. The pharmaceutical composition of the present invention comprises zanamivir and one or more pharmaceutically acceptable excipients, wherein the total daily dose of the zanamivir is less than 10 mg, preferably for administration at least once a day, and preferably wherein the composition delivers from 3 mg to 8 mg of zanamivir per administered dose.
A61K 31/196 - Carboxylic acids, e.g. valproic acid having an amino group the amino group being directly attached to a ring, e.g. anthranilic acid, mefenamic acid, diclofenac, chlorambucil
A61K 31/351 - Heterocyclic compounds having oxygen as the only ring hetero atom, e.g. fungichromin having six-membered rings with one oxygen as the only ring hetero atom not condensed with another ring
A61P 31/16 - Antivirals for RNA viruses for influenza or rhinoviruses
A61K 9/72 - Medicinal preparations characterised by special physical form for smoking or inhaling
The present invention relates to a pharmaceutical composition comprising deferasirox, a process for preparing such pharmaceutical composition, and its use in the treatment of chronic iron overload. The pharmaceutical composition comprises nanosized deferasirox having improved surface area and solubility. It also relates to a method for treatment of chronic iron overload which comprises administering a pharmaceutical composition comprising nanosized deferasirox.
The invention relates to providing controlled delivery of subterranean fluid additives to a well bore treatment fluid and/or a surrounding subterranean environment using intelligent materials that respond to a magnetic stimulus to release subterranean fluid additives downhole in a subterranean environment. Methods disclosed include a method of releasing a subterranean fluid additive in a subterranean formation comprising: providing a magnetically- sensitive component that comprises a subterranean fluid additive; providing a magnetic source; and releasing the subterranean fluid additive in the subterranean formation from the magnetically-sensitive component using a magnetic force generated from the magnetic source.
E21B 27/00 - Containers for collecting or depositing substances in boreholes or wells, e.g. bailers for collecting mud or sandDrill bits with means for collecting substances, e.g. valve drill bits
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 40/06 - Inhibiting the setting, e.g. mortars of the deferred action type containing water in breakable containers
48.
TETHERED POLYMERS USED TO ENHANCE THE STABILITY OF MICROEMULSION FLUIDS
Of the methods provided in this invention, one method includes: providing a treatment fluid comprising: an aqueous fluid, a microemulsion surfactant, and an amphiphilic polymer, wherein the amphiphilic polymer comprises a hydrophobic component, and a hydrophilic component; and introducing the treatment fluid into a subterranean formation, wherein the microemulsion surfactant forms a microemulsion that comprises the amphiphilic polymer within the subterranean formation.
An apparatus for routing pressurized fluid from a fluid source is disclosed. The apparatus comprises a manifold assembly. The manifold assembly includes a frame, an intake section coupled to the frame, and an articulating arm coupled to the intake section. The intake section is configured to route pressurized fluid to the articulating arm. The articulating arm is configured to route pressurized fluid away from the intake section. The apparatus may further comprise a pre-assembled piping system. The pre-assembled piping system comprises an inlet for receiving fluid, said inlet being in fluid communication with the articulating arm of the manifold assembly, wherein the articulating arm is configured to direct fluid having a first pressure to a pump. The pre-assembled piping system also comprises a second articulating arm proximate to the articulating arm and configured to receive pressurized fluid from the pump, wherein the pressurized fluid has a second pressure greater than the first pressure; and a discharge line in fluid communication with the second articulating arm. A method of routing pressurized fluid from a fluid source is also disclosed.
An inhibitive water-based polymer mud system and method for using the system in drilling and in stabilizing wellbores is disclosed for use in water sensitive formations as an alternative to oil-based muds or water-based muds comprising ferro-chrome lignosulfonates. The system comprises a fresh water or salt water base thinned or dispersed with a sulfonated acrylic copolymer having a hybrid/graft lignosulfonate multipolymer structure containing carboxylate and sulfonate functional groups with synthetic polymer side chains covalently linked to a base lignosulfonate material, having a molecular weight in the range of about 1,000 to about 15,000, and having a high anionic charge density. This system is effective and has stable rheology over a broad pH range, even at a near neutral pH of 8.0. The drilling fluids do not contain heavy metals and are Theologically tolerant to contaminants such as cement, anhydrite and sodium and temperatures as high as about 400°F.
An inhibitive water-based polymer mud system and method for using the system in drilling and in stabilizing wellbores is disclosed for use in water sensitive formations as an alternative to oil-based muds. The system comprises a fresh water or salt water base thinned or dispersed with a water soluble, biodegradable polyamide-based copolymer having at least one grafted side chain formed from ethylenic unsaturated compounds. This system is effective and has stable rheology over a broad pH range, even at a near neutral pH of 8.0. The drilling fluids do not contain heavy metals and are rheologically tolerant to contaminants such as cement, anhydrite and sodium and temperatures as high as about 400°F.
A communication system can include a transmitter (42) which transmits a signal, and at least one sensing device (24) which receives the signal, the sensing device (24) including a line contained in an enclosure, and the signal being detected by the line through a material of the enclosure. A sensing system (12) can include at least one sensor (38) which senses a parameter, at least one sensing device which receives an indication of the parameter, the sensing device including a line contained in an enclosure, and a transmitter (42) which transmits the indication of the parameter to the line through a material of the enclosure.
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
53.
MONITORING OF OBJECTS IN CONJUNCTION WITH A SUBTERRANEAN WELL
Objects (14) are monitored in a subterranean well (16). A well system can include at least one object (14) having a transmitter (42), and at least one sensing device (24) which monitors displacement of the object along a wellbore. A method of monitoring at least one object in a subterranean well can include positioning at least one sensing device in a wellbore of the well, and then displacing the object through the wellbore, the sensing device monitoring the object as it displaces through the wellbore.
A method of cementing in a subterranean formation comprising the steps of: (A) introducing a cement composition into the subterranean formation, the cement composition comprising: (i) cement; (ii) water; and (iii) a high-density additive selected from the group consisting of silicon carbide, sintered bauxite, and any combination thereof, wherein the cement composition has a density of at least 16 pounds per gallon; and (B) allowing the cement composition to set. According to an embodiment, the high-density additive is in a concentration of at least 30 % by weight of the cement. A cement composition for use in an oil or gas well comprises: (A) cement; (B) water; and (C) a high- density additive selected from the group consisting of silicon carbide, sintered bauxite, and a combination thereof, wherein the high-density additive is in a concentration of at least 30 % by weight of the cement, and wherein the cement composition has a density of at least 16 pounds per gallon.
Methods and compositions for the treatment of subterranean formations, and more specifically, treatment fluids containing vitrified shale and methods of using these treatment fluids in subterranean formations, are provided. A method of displacing a fluid in a wellbore comprises providing a wellbore having a first fluid disposed therein; and placing a second fluid into the wellbore to at least partially displace the first fluid therefrom; wherein the second fluid comprises a base liquid; vitrified shale; a clay weighting agent present in the range of about 5% to about 20% by weight of the second fluid; and a viscosiiying agent present in the range of about 1% to about 10% by weight of the second fluid.
A method of treating a subterranean formation is disclosed, wherein the method comprises providing a treatment fluid comprising: an aqueous fluid; a gelling agent, and a multifunctional boronic crosslinker comprising two or more boronic functional groups; and introducing the treatment fluid into a subterranean formation. A composition, comprising an aqueous fluid; a gelling agent; and a multifunctional boronic crosslinker comprising two or more boronic functional groups is also disclosed.
A method of treating a subterranean formation is disclosed, wherein the method comprises: providing an aqueous-based fracturing fluid; placing the aqueous-based fracturing fluid into a subterranean formation; placing an erosion agent in the aqueous-based fracturing fluid and/or the subterranean formation; allowing a channel to form within a fracture network in the subterranean formation; providing a plasticity modification fluid that comprises an embrittlement modification agent; placing the plasticity modification fluid into the subterranean formation; and embrittling rock surrounding the fracture network.
The present invention relates to a method, wherein the method comprises providing a drilling fluid comprising: an aqueous fluid, a microemulsion surfactant and optionally a non- polar fluid; and drilling a well bore in a subterranean formation comprising an oleaginous fluid or a pore throat or both using the drilling fluid, wherein the microemulsion surfactant forms a microemulsion with the oleaginous fluid within the well bore or wherein the microemulsion surfactant forms a microemulsion with at least the non-polar fluid. Optionally, the method comprises providing a drilling fluid comprising an aqueous base fluid and a microemulsion surfactant; and drilling a well bore in a subterranean formation that comprises a pore throat; and allowing the surfactant to remove an oil block, a water block, or both from the pore throat. In accordance with the method, the subterranean formation may have a retained producibility greater than about 50%.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
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
59.
A WATER-BASED GROUTING COMPOSITION WITH AN INSULATING MATERIAL
According to an embodiment, a method for thermally insulating a portion of a tubular located inside an enclosed conduit comprises the steps of: (A) introducing a grouting composition into an annulus between the tubular and the enclosed conduit, the grouting composition comprising: (i) a water-swellable binding material comprising water-swellable clay; (ii) an aqueous liquid, wherein the aqueous liquid is the continuous phase of the grouting composition; and (iii) an insulating material; and (B) allowing the grouting composition to set after the step of introducing, wherein after setting the grouting composition has a thermal conductivity of less than 0.3 BTU/hr.ft. °F (0.5 w/m °C). According to another embodiment, a grouting composition for use in insulating a portion of a tubular located inside an enclosed conduit comprises: (A) a water-swellable binding material comprising water-swellable clay; (B) an aqueous liquid, wherein the aqueous liquid is the continuous phase of the grouting composition; and (C) an insulating material, wherein after the grouting composition has set, the grouting composition has a thermal conductivity of less than 0.3 BTU/hr.ft.°F (0.5 w/m °C).
C04B 28/00 - 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
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
E21B 36/00 - Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
60.
AN OIL-BASED GROUTING COMPOSITION WITH AN INSULATING MATERIAL
According to an embodiment, a method for thermally insulating a portion of a tubular located inside an enclosed conduit comprises the steps of: (A) introducing a grouting composition into an annulus between the tubular and the enclosed conduit, the grouting composition comprising: (i) an oil-swellable binding material; and (ii) a hydrocarbon liquid, wherein the hydrocarbon liquid is the continuous phase of the grouting composition; and (iii) an insulating material comprising a hollow microsphere; and (B) allowing or causing the grouting composition to set after the step of introducing, wherein after setting the grouting composition has a thermal conductivity of less than 0.3 BTU/hr-ft-°F (0.5 w/m° C). According to another embodiment, a grouting composition for use in insulating a portion of a tubular located inside an enclosed conduit comprises: (A) an oil-swellable binding material comprising a organophilic clay; and (B) a hydrocarbon liquid, wherein the hydrocarbon liquid is the continuous phase of the grouting composition; and (C) an insulating material comprising a hollow microsphere, wherein after the grouting composition has set, the grouting composition has a thermal conductivity of less than 0.3 BTU/hrft-°F (0.5 w/m° C).
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 28/00 - 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
E21B 36/00 - Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
61.
CONTROLLING WELL OPERATIONS BASED ON MONITORED PARAMETERS OF CEMENT HEALTH
A method of controlling a well operation can include monitoring at least one parameter of cement lining a weilbore, the monitoring being performed via at least one optical waveguide, and modifying the well operation in response to the parameter being outside of a predetermined acceptable range. A well monitoring system can include at least one optical waveguide which is used to sense at least one parameter of cement lining a weilbore, an optical interrogation system optically connected to the at least one optical waveguide, and a control system which controls operation of at least one item of well equipment in response to information received from the optical interrogation system.
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
62.
WELLBORE SERVICING COMPOSITIONS AND METHODS OF MAKING AND USING SAME
A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising cement, water and a polyuronide polymer, placing the wellbore servicing fluid in the wellbore, and allowing the wellbore servicing fluid to set. A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a highly methylated pectin, cementitious material and water into the wellbore, placing the wellbore servicing fluid in the wellbore, and allowing the wellbore servicing fluid to set. A wellbore servicing fluid comprising cement, water and a polyuronide polymer.
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
The present invention describes a process for the preparation of monofluoromethylated organic biologically active compounds using monofluoromethylated reagents. Fluticasone Propionate and Fluticasone Furoate can be prepared using, for example, S-monofluoromethyl-S-phenyl-2,3,4,5- tetramethylphenylsulfonium tetrafluoroborate as monofluoromethylating reagent instead of bromofluoromethane.
The present invention describes processes for the preparation of, monofluoromethylated organic biologically active compounds, such as Fluticasone Propionate and Fluticasone Furoate, in the presence of fluorodecarboxylating reagents such as XeF2 and BrF3.
New particles comprising a tetracycline or one of its pharmaceutically acceptable salts and an antioxidant, formulations comprising the same and their use in the treatment of infectious diseases. Methods of encapsulation of a tetracycline or one of its pharmaceutically acceptable salts and an antioxidant are also disclosed.
A method of servicing a subterranean formation with a servicing fluid, the method comprising providing a first component of the servicing fluid to a first high-pressure pump (50A) at a first pressure, providing a second component of the servicing fluid to a second high-pressure pump (50B) at a second pressure, increasing the pressure of the first component of the servicing fluid at the first high-pressure pump to a third pressure, wherein the third pressure is greater than the first pressure, increasing the pressure of the second component of the servicing fluid at the second high-pressure pump to a fourth pressure, wherein the fourth pressure is greater than the second pressure, communicating the first component of the servicing fluid to a high-pressure manifold (300), communicating the second component of the servicing fluid to the high-pressure manifold, communicating the first component of the servicing fluid from a first high-pressure manifold outlet to a wellhead (60) located at a wellbore, communicating the second component of the servicing fluid from a second high-pressure manifold outlet to the wellhead, and mixing the first component of the servicing fluid and the second component of the servicing fluid at the wellhead to form the servicing fluid.
Of the many embodiments presented herein, one is a subterranean treatment fluid comprising: an aqueous fluid; and a water-soluble degradable synthetic vinyl polymer having a labile link in its backbone. Also provided in one instance is a water-soluble degradable synthetic vinyl polymer with labile group in its backbone made by a redox polymerization, the redox polymerization reaction comprising these reactants: a macroinitiator that comprises a labile link, an oxidizing metal ion, and a vinyl monomer.
A process for reducing the particle size of an active pharmaceutical ingredient (API) while maintaining its polymorphic form, comprises the step of processing the active pharmaceutical ingredient by cavitation at elevated pressure. The process preferably comprises the step of isolating the processed active ingredient in the form of powder, wherein the isolation step comprises filtration or spray drying. Particles produced by the process of the invention typically have a span value of less than 2.5.
A61K 31/137 - Arylalkylamines, e.g. amphetamine, epinephrine, salbutamol, ephedrine
A61K 31/46 - 8-Azabicyclo [3.2.1] octaneDerivatives thereof, e.g. atropine, cocaine
A61K 31/56 - Compounds containing cyclopenta[a]hydrophenanthrene ring systemsDerivatives thereof, e.g. steroids
A61K 9/00 - Medicinal preparations characterised by special physical form
A61K 31/58 - Compounds containing cyclopenta[a]hydrophenanthrene ring systemsDerivatives thereof, e.g. steroids containing heterocyclic rings, e.g. danazol, stanozolol, pancuronium or digitogenin
An aspect encompasses a method of testing a subsea umbilical (160, 165, 170) where a first portion of testing is performed on the subsea umbilical, the testing comprising hydraulic testing and at least one of electrical or optical testing, and a second portion of the testing is performed independent of a diver or an ROV.
Of the many methods provided herein, one method comprises: providing at least one fracture in a subterranean formation that comprises tight gas, a shale, a clay, and/or a coal bed; providing a plasticity modification fluid that comprises an aqueous fluid and an alkaline embrittlement modification agent; placing the plasticity modification fluid into the fracture in the subterranean formation; and embrittling at least one fracture face of the fracture to form an embrittled fracture face.
Methods for creating and using multi-phase fluid flows are disclosed. In one embodiment, such a method includes introducing an inner fluid into a tubular conduit. The method further includes introducing a ring fluid into the tubular conduit. In this embodiment, the ring fluid is disposed annularly between the inner fluid and the interior of the tubular conduit, and the flow of the ring fluid is laminar.
This invention is generally related to using treatments fluids having additives that modify rheological characteristics. Some embodiments of the present invention provide methods of using treatment fluids comprising an aqueous fluid and an associative polymer additive, wherein the associative polymer additive increases the PV of the treatment fluid by more at least 50% and wherein the associative polymer additive increases the yield point by no more than about 30% of the corresponding increase in the PV relative to a treatment fluid without the associative polymer additive in a portion of a subterranean formation.
A method of controlling operation of multiple valves interconnected in a tubular string in a subterranean well can include opening each of the valves, and then closing the valves in response to an application of pressure to the tubular string. A well system can include multiple valves interconnected in a tubular string, each of the valves including an actuator, and a valve control device interconnected in the tubular string. The valve control device may be connected to each of the valve actuators via multiple flow paths, whereby a pressure differential generated between the flow paths is also generated in each of the valve actuators.
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
A well bore in a subterranean formation includes a signaling subsystem (114) communicably coupled to injection tools (212) installed in the well bore. Each injection tool controls a flow of fluid into an interval (118a, 118b, 118c, 118d)of the formation based on a state of the injection tool. Stresses in the subterranean formation are altered by creating fractures (302a, 302b) in the formation. Control signals are sent from the well bore surface through the signaling subsystem (114) to the injection tools (212) to modify the states of one or more of the injection tools. Fluid is injected into the stress - altered subterranean formation through the injection tools to create a fracture network in the subterranean formation. In some implementations, the state of each injection tool can be selectively and repeatedly manipulated based on signals transmitted from the well bore surface, hi some implementations, stresses are modified and/or the fracture network is created along a substantial portion and/or the entire length of a horizontal well bore.
According to one embodiment, a treatment fluid for a well includes: (a) a water- soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non- acidic ethylenically unsaturated polar monomer; (b) an organic crosslinker comprising amine groups, wherein the organic crosslinker is capable of crosslinking the water-soluble polymer; (c) a weak organic acid; and (d) water; wherein the treatment fluid is a crosslinkable polymer composition. According to another embodiment, a method for blocking the permeability of a portion of a subterranean formation penetrated by a wellbore is provided, the method including the steps of: (a) selecting the portion of the subterranean formation to be treated; (b) selecting estimated treatment conditions, wherein the estimated treatment conditions comprise temperature over a treatment time; (c) forming a treatment fluid that is a crosslinkable polymer composition comprising: (i) a water-soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non-acidic ethylenically unsaturated polar monomer; (ii) an organic crosslinker comprising amine groups, wherein the organic crosslinker is capable of crosslinking the water-soluble polymer; (iii) a weak organic acid; and (iv) water; (d) selecting the water-soluble polymer, the crosslinker, the weak organic acid, and the water, and the proportions thereof, such that the gelation time of the treatment fluid is at least 1 hour when tested under the estimated treatment conditions; and (e) injecting the treatment fluid through the wellbore into the portion of the subterranean formation.
According to one embodiment, a treatment fluid for a well includes: (a) a water- soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non- acidic ethylenically unsaturated polar monomer; (b) an organic crosslinker comprising amine groups, wherein the organic crosslinker is capable of crosslinking the water-soluble polymer; (c) a salt of a weak Bronsted base and a Bronsted acid; and (d) water; wherein the treatment fluid is a crosslinkable polymer composition. According to another embodiment, a method for blocking the permeability of a portion of a subterranean formation penetrated by a wellbore is provided, the method including the steps of: (a) selecting the portion of the subterranean formation to be treated; (b) selecting estimated treatment conditions, wherein the estimated treatment conditions comprise temperature over a treatment time; (c) forming a treatment fluid that is a crosslinkable polymer composition comprising: (i) a water-soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non-acidic ethylenically unsaturated polar monomer; (ii) an organic crosslinker comprising amine groups, wherein the organic crosslinker is capable of crosslinking the water-soluble polymer; (iii) a salt of a weak Bronsted base and a Bronsted acid; and (iv) water; (d) selecting the water-soluble polymer, the crosslinker, the salt of a weak Bronsted base and a Bronsted acid, and the water, and the proportions thereof, such that the gelation time of the treatment fluid is at least 1 hour when tested under the estimated treatment conditions; and (e) injecting the treatment fluid through the wellbore into the portion of the subterranean formation.
According to one embodiment, a treatment fluid for a well includes: (a) a water- soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non- acidic ethylenically unsaturated polar monomer; (b) an organic crosslinker comprising amine groups, wherein the organic crosslinker is capable of crosslinking the water-soluble polymer; (c) a Lewis acid; and (d) water; wherein the treatment fluid is a crosslinkable polymer composition. According to another embodiment, a method for blocking the permeability of a portion of a subterranean formation penetrated by a wellbore is provided, the method including the steps of: (a) selecting the portion of the subterranean formation to be treated; (b) selecting estimated treatment conditions, wherein the estimated treatment conditions comprise temperature over a treatment time; (c) forming a treatment fluid that is a crosslinkable polymer composition comprising: (i) a water-soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non-acidic ethylenically unsaturated polar monomer; (ii) an organic crosslinker comprising amine groups, wherein the organic crosslinker is capable of crosslinking the water-soluble polymer; (iii) a Lewis acid; and (iv) water; (d) selecting the water-soluble polymer, the crosslinker, the Lewis acid, and the water, and the proportions thereof, such that the gelation time of the treatment fluid is at least 1 hour when tested under the estimated treatment conditions; and (e) injecting the treatment fluid through the wellbore into the portion of the subterranean formation.
According to one embodiment, a treatment fluid for a well includes: (a) a water- soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non- acidic ethylenically unsaturated polar monomer; (b) an organic crosslinker capable of crosslinking the water-soluble polymer; (c) an ammonium halide; and (d) water. According to another embodiment, a method for blocking the permeability of a portion of a subterranean formation penetrated by a wellbore is provided, the method including the steps of: (a) selecting the portion of the subterranean formation to be treated, wherein the bottomhole temperature of the portion of the subterranean formation is equal to or greater than 250 °F (121 °C); (b) selecting estimated treatment conditions, wherein the estimated treatment conditions comprise temperature over a treatment time; (c) forming a treatment fluid that is a crosslinkable polymer composition comprising: (i) a water-soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non-acidic ethylenically unsaturated polar monomer; (ii) an organic crosslinker capable of crosslinking the water- soluble polymer; (iii) an ammonium halide; and (iv) water; (d) selecting the water-soluble polymer, the crosslinker, the ammonium halide, and the water, and the proportions thereof, such that the gelation time of the treatment fluid is at least 2 hours when tested under the estimated treatment conditions; and (e) injecting the treatment fluid through the wellbore into the portion of the subterranean formation.
A method of cementing a wellbore (200), comprising delivering a diversion and movable isolation tool (100) into the wellbore and thereby at least partially isolating a first wellbore volume (212) from a second wellbore volume (214), the second wellbore volume being uphole relative to the first wellbore volume, passing fluid through the diversion and movable isolation tool (100) into the first wellbore volume (212), substantially discontinuing the passing of fluid through the diversion and movable isolation tool into the first wellbore volume, passing fluid through the diversion and movable isolation tool into the second wellbore volume (214). A diversion and movable isolation tool (100) for a wellbore, comprising a body comprising selectively actuated radial flow ports (108), and a fluid isolation assembly (116), comprising one or more segments (118), each segment comprising a central ring (130) and at least one tab (132) extending from the central ring.
The present invention provides a method for optimizing rate of penetration when drilling into a geological formation comprising the steps of: gathering real-time PWD (pressure while drilling) data; acquiring modeled ECD (equivalent circulating density) data; calculating the standard deviation of the differences of said real-time PWD and said modeled ECD data; calculating a predicted maximun tolerable ECD based on the calculated deviation; and determining the rate of penetration of a drill string based on the maximum tolerable ECD of a drilling process. In another aspect the present invention provides a system for optimizing rate of penetration, which system can be used to control the rate of penetration of a drill string based on the maximum tolerable ECD of a drilling process.
Embodiments of the hybrid tool string include coiled tubing (80) and jointed tubing, as well as a means typically located at the connection of the coiled and jointed tubing for sealing the fluid flowpath through the bore of the hybrid tool string. Embodiments of the hybrid tool string may use a pressure - activated valve tool (50) attached in series between the coiled tubing and the jointed tubing, which allows for sealing of the bore by application of pressure. Embodiments of the pressure - activated valve tool may use a flapper (53) in conjunction with a sleeve (55) to seal the bore. The novel hybrid tool string may be used to service a well.
E21B 17/04 - CouplingsJoints between rod and bit, or between rod and rod
E21B 19/22 - Handling reeled pipe or rod units, e.g. flexible drilling pipes
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
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
A tubing sheave apparatus is disclosed. A circular member has a grooved circumference. A hub is coupled to the circular member via one or more radial support members. The circular member and the hub have a rotational axis. A roller is disposed near the grooved circumference. An actuator is coupled to the roller and configured to move the roller at least toward the grooved circumference. The roller and the grooved circumference are configured to contact tubing disposed therebetween.
Improved methods of oil and/or gas production by employing mixed surfactants to treat formations comprising multiple rocks. In one embodiment the methods comprise: providing a treatment fluid comprising: an aqueous base fluid, a first surfactant having a charge, a second surfactant having an opposite charge, and a compatibilizer; and introducing the treatment fluid into at least a portion of the subterranean formation.
Improved methods of oil and/or gas production by reducing the occurrence of water blocks and/or gas condensates in the treated portion of the formation are provided. In one embodiment, the methods comprise: providing a treatment fluid comprising: an aqueous base fluid, a friction reducing agent, and a quaternary ammonium surfactant described by at least the following formula: wherein R1 is either a saturated or unsaturated, branched or straight chain alkyl comprising about 12 carbons to about 22 carbons, and R2, R3 and R4 are independently selected from the group consisting of either a saturated or unsaturated, branched or straight chain alkyl or aryl comprising about 1 to about 14 carbons, and any combination thereof; and introducing the treatment 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.
Improved treatment fluids and methods for use in subterranean operations including the treatment of low permeability shale formations. In one embodiment the methods comprise: providing a treatment fluid comprising an aqueous base fluid and a controlled wetting system that comprises: a water soluble polymer having a charge, a surfactant having an opposite charge, and a compatibilizer; and introducing the treatment fluid into a subterranean formation.
Systems and methods for direct and indirect measurement of the density of a fluid which exhibits sag characteristics is disclosed. The sag measurement system (100) includes a test container (102) for holding a fluid mixture to be analyzed and a suction port (104) on the test container. A pump (108) is coupled to the suction port for circulating the fluid mixture from the test container through a circulation loop (110). A measurement device (112) is coupled to the circulation loop and a return port (106) directs the fluid mixture from the circulation loop back to the test container at substantially the same vertical location as the suction port. The fluid mixture flowing through the circulation loop passes through the measurement device before returning to the test container through the return port. The measurement device is operable to monitor the particle distribution of the fluid mixture as it changes due to gravity.
Methods are provided including methods comprising providing a drill-in fluid, a reaming fluid, and a consolidating agent; drilling at least a portion of a subterranean formation with the drill-in fluid whereby a filter cake is formed on a surface of the subterranean formation; reaming at least a portion of the subterranean formation with the reaming fluid whereby at least a portion of the filter cake is removed; and consolidating at least a portion of the subterranean formation with the consolidating agent. Other methods are also provided.
C09K 8/38 - Gaseous or foamed well-drilling compositions
C09K 8/575 - Compositions based on water or polar solvents containing organic compounds
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutterDrill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
A subsea coiled tubing injector apparatus is disclosed. The subsea coiled tubing injector apparatus includes a linear actuator (170) and a pair of carriages (140) coupled via the linear actuator (170). The linear actuator is electrically powered and is configured to apply lateral force to the carriages (140). The carriages are configured to move substantially laterally with respect to one another. Each carriage includes a tubing engagement assembly (130) configured to engage tubing (115) interposed between the carriages..
An anchor tool having a housing, a one-way restrictor device in fluid communication with the housing, and a stabilizer affixed to the housing. The one-way restrictor device is configured to allow restricted flow in a first direction, and to allow flow in a second direction.
Methods and systems for using force measurements to determine the amount of material in a container and/or the rate at which material is discharged from a container are disclosed. A container for storing a desired material is positioned so that the center of gravity of the container shifts horizontally with changes in level of the material in the container. A plurality of load sensors are symmetrically arranged at a base of the container and are used to monitor the amount of materials in the container.
G01F 23/20 - Indicating or measuring liquid level or level of fluent solid material, e.g. indicating in terms of volume or indicating by means of an alarm by measurement of weight, e.g. to determine the level of stored liquefied gas
91.
COMPOSITIONS AND SYSTEMS FOR COMBATTING LOST CIRCULATION AND METHODS OF USING THE SAME
A method of servicing a wellbore in a subterranean formation comprising preparing a composition comprising a base fluid, a thixotropic viscosifier, a gellable composition and a bridging material, applying a shear force to the composition such that the composition viscosity decreases, introducing the composition into a lost circulation zone in the subterranean formation, wherein the lost circulation zone comprises cavities greater than about 200 microns in diameter, decreasing the shear force applied to the composition, and allowing the composition to set in the lost circulation zone. A method of servicing a wellbore in a subterranean formation comprising placing a first stream comprising a dilute solution of a metal acrylate into a lost circulation zone in the subterranean formation, placing a second stream comprising an activator into the lost circulation zone, and forming a lost circulation material upon contacting of the metal acrylate and the activator, wherein the lost circulation material forms in from about 0 to about 60 minutes.
A method comprising placing a Micro-Electro-Mechanical System (MEMS) sensor in a subterranean formation, placing a wellbore composition in the subterranean formation, and using the MEMS sensor to detect a location of the wellbore composition. A method comprising placing a Micro-Electro-Mechanical System (MEMS) sensor in a subterranean formation, placing a wellbore composition in the subterranean formation, and using the MEMS sensor to monitor a condition of the wellbore composition. A method comprising placing one or more Micro-Electro-Mechanical System (MEMS) sensors in a subterranean formation, placing a wellbore composition in the subterranean formation, using the one or more MEMS sensors to detect a location of at least a portion of the wellbore composition, and using the one or more MEMS sensors to monitor at least a portion of the wellbore composition. A method comprising placing one or more Micro-Electro-Mechanical System (MEMS) sensors in a subterranean formation using a wellbore composition, and monitoring a condition using the one or more MEMS sensors.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
93.
SCALE INHIBITING PARTICULATES AND METHODS OF USING SCALE INHIBITING PARTICULATES
Scale-inhibiting particulates formed from a mixture of fly ash and a phosphonic acid curing agent wherein the fly ash is cured into a solid material by the contact with the phosphonic acid curing agent. Methods of using scale-inhibiting particulates to inhibit scale formation in a subterranean formation.
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 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
94.
METHODS AND APPARATUS FOR DESIGNING A CEMENT COMPOSITION
A method comprising preparing a baseline cement slurry comprising a cement, water, and one or more additives, placing a sample of the baseline cement slurry into a sample container having a vertical height, and measuring time of flight of energy through the sample at one or more locations along the vertical height to determine a settling property of the baseline cement slurry. A method comprising providing a settling test apparatus comprising a column having a vertical height and at least one pair of transducers positioned opposite each other with the column there between, placing a cement slurry sample within the column, and measuring time of flight of ultrasonic energy through the sample at one or more locations along the vertical height to determine a settling property of the cement slurry.
G01N 29/024 - Analysing fluids by measuring propagation velocity or propagation time of acoustic waves
G01N 29/07 - Analysing solids by measuring propagation velocity or propagation time of acoustic waves
G01N 29/22 - Investigating or analysing materials by the use of ultrasonic, sonic or infrasonic wavesVisualisation of the interior of objects by transmitting ultrasonic or sonic waves through the object Details
95.
RADIATION-INDUCED THICKENING FOR SET-ON-COMMAND SEALANT COMPOSITIONS AND METHODS OF USE
The present invention includes methods relating to the setting of fluids or slurries in a wellbore. In one embodiment, a method of isolating a portion of a wellbore by preparing a sealant composition comprising a fluid component and a polymeric additive component, placing the sealant composition into a wellbore and subjecting the sealant composition to ionizing radiation. The ionizing radiation can cause bonding between polymeric additive components and create a polymer matrix within the sealant composition that increases the mechanical strength of the sealant composition. The present invention also includes compositions relating to the setting of fluids or slurries in a wellbore. In one embodiment, a sealant composition having a fluid component and a polymeric additive component can be subjected to ionizing radiation.
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 8/508 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds
C04B 24/26 - Macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
96.
RADIATION-INDUCED TRIGGERING FOR SET-ON-COMMAND COMPOSITIONS AND METHODS OF USE
The present invention relates to methods and compositions useful for isolating a portion of a wellbore. In one embodiment, a method includes preparing a sealant composition containing a set modifier component. The sealant composition is placed into the wellbore and is subjected to ionizing radiation that alters the set modifier component, triggering the thickening of the sealant composition. In another embodiment, a composition includes a sealant composition containing a wellbore treatment fluid and a set modifier component.
C09K 8/508 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds
C09K 8/00 - Compositions for drilling of boreholes or wellsCompositions for treating boreholes or wells, e.g. for completion or for remedial operations
97.
SONICALLY ACTIVATING SETTABLE COMPOSITIONS AND METHODS OF ACTIVATING THEM
The present disclosure is directed to a system and method for sonically activating cement slurries. In some implementations, a method of treating a subterranean formation includes positioning a settable composition including a capsule in a wellbore. The capsule is used to increase a setting rate in response to at least sonic signals. A sonic signal is transmitted to at least a portion of the settable composition to release an activator from the capsule. In some implementations, a composition for treating a subterranean formation includes a settable composition and an activator. The activator is released in response to a sonic signal to initiate setting of the settable composition.
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
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 40/02 - Selection of the hardening environment
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells
E21B 41/00 - Equipment or details not covered by groups
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
The present disclosure is directed to a system and method for managing cement in a subterranean zone. In some implementations, a method of cementing in a subterranean formation includes positioning a cement slurry including a plurality of activation devices in a wellbore. The activation devices configured to release an activator that increases a setting rate of the cement slurry. A signal is transmitted to at least a portion of the cement slurry to activate the activation devices. The activation device releases the activator in response to at least the signal.
The present disclosure is directed to a system and method for managing cement in a subterranean zone. In some implementations, a method of cementing in a subterranean formation includes positioning a cement slurry including a plurality of activation devices in a wellbore. The activation devices configured to release an activator that increases a setting rate of the cement slurry. A signal is transmitted to at least a portion of the cement slurry to activate the activation devices. The activation device releases the activator in response to at least the signal.
An expansion device (48) for a wellbore servicing tool (10), comprising a wedge (52) comprising a frusto-conical wall having a tip end (88), the wedge being configured coaxially along a central axis, a plurality of slip segments (50), each slip segment comprising an inner surface having an incline surface, and at least one bridge (94) joining each of the incline surfaces to the frusto conical wall. A method of operating a wellbore servicing tool, comprising longitudinally compressing an expansion device along a central axis, upon sufficient compression, separating plural slip segments from a wedge, moving the wedge relative to the slip segments, upon sufficient movement of the wedge relative to the slip segments, separating at least two slip segments from each other.
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