Class / Patent application number | Description | Number of patent applications / Date published |
507214000 | Polysaccharide is cellulose or derivative thereof | 34 |
20090023614 | Polymer Delivery in Well Treatment Applications - This invention relates to compositions and methods for treating subterranean formations, in particular, oilfield stimulation compositions and methods using water-in-water polymer emulsions to uniformly dissolve a rheologically active polymer, such as a thickener or friction reducer, in the treatment fluid. The emulsions have a low viscosity and are easily pumped for mixing into a treatment fluid, where upon dilution with an aqueous medium, the polymer is easily hydrated without forming fish-eyes. The partitioning agent in the water-in-water emulsion does not generally affect the rheology of the treatment fluid. The invention also relates to further processing of the emulsion by wet grinding, high shear mixing and/or heating to enhance the hydration rate in the preparation of the well treatment fluid. | 01-22-2009 |
20090111716 | ADDITION OF ZWITTERIONIC SURFACTANT TO WATER SOLUBLE POLYMER TO INCREASE THE STABILITY OF THE POLYMERS IN AQUEOUS SOLUTIONS CONTAINING SALT AND/OR SURFACTANTS - An aqueous fluid composition useful for the recovery of hydrocarbons from a subterranean formation, including a mixture of water, a water soluble polymer, an inorganic salt and at least one zwitterionic surfactant and methods of using same. | 04-30-2009 |
20100056403 | METAL FREE CROSSLINKING OF GALACTOMANNAN - Methods of treating a subterranean formation are disclosed, using a fluid including an essentially metal-free organic crosslinker selected from amines, diamines, poly amines, polyamino polymers, alcohols, polyols, polyhydroxy polymers, hydroxyl amines, peptides and proteins, combined with a polysaccharide or cellulosic material having oxidized functional groups. The fluid is then introduced into a wellbore penetrating the formation to contact the formation. The polysaccharide or cellulosic material may have aldehyde groups as one example of an oxidized group, or any other suitable oxidized functional group. The polysaccharide or the cellulosic material may be oxidized using at least one of an enzymes, oxidizers, photooxidation, bacteria, catalyst, or other suitable technique. The fluid may also further include an inorganic crosslinker. | 03-04-2010 |
20100179076 | Filled Systems From Biphasic Fluids - Methods and apparatus for forming a fluid for use within in a subterranean formation comprising combining a partitioning agent, crosslinkable polymer, and crosslinker into a fluid, wherein more than 50 percent of the crosslinkable polymer crosslinks and less than 10 percent of the partitioning agent crosslinks, and introducing the fluid into the subterranean formation. Methods and apparatus of forming a fluid for use within in a subterranean formation comprising combining a partitioning agent, crosslinkable polymer, and crosslinker into a fluid, wherein a critical polymer concentration for crosslinking the crosslinkable polymer is lower than if the partitioning agent were not in the fluid, and introducing the fluid into the subterranean formation. | 07-15-2010 |
20100323930 | METHOD FOR PRODUCING SOLID MATERIALS ON THE BASIS OF SYNTHETIC POLYMERS AND/OR BIOPOLYMERS AND USE THEREOF - The use of solid materials based on synthetic polymers and/or biopolymers (A) in natural gas and mineral oil extraction technology. The solid materials are produced by solubilizing at least one synthetic polymer and/or biopolymer (A), or at least one synthetic polymer and/or biopolymer (A) and at least one additive (B), in at least one substantially anhydrous chaotropic liquid (C). The solution or dispersion (AC) or (ABC) is contacted with a liquid (D1) which is miscible with the chaotropic liquid (C), but in which at least the synthetic polymer and/or the biopolymer (A) are substantially insoluble, resulting in a phase (E). The chaotropic liquid (C) is removed from phase (E) to result in a gel (G), which is impregnated with a liquid (D2). The two liquids (D1) and (D2) are removed from the gel (G) by evaporating, producing a solid material based on synthetic polymer and/or biopolymer (A). | 12-23-2010 |
20110195875 | ENCAPSULATED REACTANT AND PROCESS - An encapsulated reactant(s) having at least one encapsulant and at least one reactant. An outermost encapsulant is substantially nonreacting, impermeable and nondissolving with water. The reactant(s) contribute to at least one reaction with contaminants in environmental media rendering the environmental media less harmless. Processes for using the encapsulated reactant in environmental media is also hereby claimed. | 08-11-2011 |
20130274153 | ALKALI-ACTIVATED COATINGS FOR PROPPANTS - The present invention relates to proppants and the manufacture of proppants by contacting a substrate with an alkali-activated composition that cures to form a continuous polymer coating. | 10-17-2013 |
20140066342 | LOW DAMAGE SEAWATER BASED FRAC PACK FLUID - Treatment fluids comprising an aqueous fluid and a low-leakoff particulate, wherein the low-leakoff particulate comprises a low molecular weight modified polysaccharide that has been crosslinked with a crosslinking agent wherein the low molecular weight modified polysaccharide contains one or more of the following monosaccharide units: galactose, mannose, glucoside glucose, xylose, arabinose, fructose, glucuronic acid, or pyranosyl sulfate. | 03-06-2014 |
20140106992 | INVERT EMULSION WITH ENCAPSULATED BREAKER FOR WELL TREATMENT - An emulsion including: (a) an external oil phase, wherein the oil phase has a viscosity of less than 200 cP; (b) an internal water phase adjacent the external phase, wherein the internal water phase has a pH in the range of 5 to 9; (c) an emulsifier having a hydrophilic-lipophilic balance in the range of 3 to 7 on the Davies scale; and (d) a Bronsted-Lowry base having a pKb(1) less than 12, wherein the base is encapsulated with an encapsulated breaker composition comprising: an encapsulant that comprises an ether cellulose. A method of treating a well includes the steps of: forming a treatment fluid including the emulsion; and introducing the treatment fluid into the well. In a preferred embodiment, the emulsion has a viscosity greater than 200 cP. | 04-17-2014 |
20140194327 | VISCOUS FLUID SYSTEMS FROM WASTE WATER - By including a chemical additive in the well treatment fluid system design the cost and environmental impact of hydraulic fracturing may be substantially reduced. By adding a weak base to the well treatment fluid, water having a high, heterogeneous concentration of dissolved solids, such as water produced by oil and gas wells, may be utilized as the base fluid for hydraulic fracturing or other stimulation processes without adversely affecting the various components of the well treatment fluid. The well treatment fluid typically includes a base fluid, in this case produced water, a gelling agent, a weak base, and other additives useful for treating a well such as friction reducers, buffering agents, clay control agents, biocides, scale inhibitors, chelating agents, gel-breakers, oxygen scavengers, antifoamers, crosslinkers, wax inhibitors, corrosion inhibitors, de-emulsifiers, foaming agents, or tracers. | 07-10-2014 |
507215000 | Carboxyalkylcellulose (e.g., CMC, CMHEC, etc.) | 13 |
20080234147 | Method of Treating Subterranean Formation with Crosslinked Polymer Fluid - A method of treating a subterranean formation penetrated by a wellbore utilizes a treating fluid formed from an aqueous solution of a water-soluble polymer. The treating fluid further contains a crosslinking agent and an optional delayed release alkaline additive. The delayed release alkaline additive may be at least one of urea, a urea derivative, a solid alkaline earth metal carbonate, a solid alkaline earth metal oxide and combinations of these. The treating fluid further includes an acidic pH adjusting agent used in an amount to provide the treating fluid with a pH of less than about 5. The treating fluid is then introduced into the formation. | 09-25-2008 |
20080300151 | Oil-well cement fluid loss additive compostion - The present invention relates to compositions and use of fluidized polymer suspensions containing allyloxy linkage and its functional derivatives, and water soluble polymers for use in oil field applications as fluid additives for drilling and cementing processes. | 12-04-2008 |
20100016182 | METHOD OF TREATING A WELL WITH A GEL STABILIZER - The present invention relates to the use of chalcogen heterocyclic electron donating compounds as thermal decomposition reduction additives for gels used in well treatment fluids such as drilling fluids, fracturing fluids, and well completion and workover fluids. | 01-21-2010 |
20100130388 | METHOD FOR TREATING WELL BORE IN A SUBTERRANEAN FORMATION WITH HIGH DENSITY BRINES AND COMPLEXED METAL CROSSLINKERS - The invention discloses a method of treating a wellbore by providing an aqueous mixture of a hydrated polysaccharide with a salt; adding to the mixture a cross-linking agent for cross-linking the hydrated polysaccharide, wherein the cross-linking agent comprises a zirconium compound, glutamic acid, and a polyol; pumping the aqueous mixture of the hydrated polysaccharide and the cross-linking agent into the wellbore; and cross-linking the hydrated polysaccharide. | 05-27-2010 |
20110003720 | CONTROLLING THE STABILITY OF WATER IN WATER EMULSIONS - This invention relates to compositions and methods of treating a surface in contact with a wellbore and/or a subterranean formation penetrated by a well bore, comprising forming a treatment composition comprising a rheological polymer, a partitioning agent, and a liquid medium; and injecting the treatment fluid into the well bore, wherein the treatment composition forms a heterogeneous mixture comprising a dispersed rheological polymer-rich phase and a partitioning agent-rich phase, and wherein the stability of the heterogeneous mixture is controlled by introducing a stability control agent. This invention relates to compositions and methods for forming a water in water emulsion, comprising a rheological polymer, a partitioning agent, a liquid medium; and a stability control agent, wherein the emulsion is a heterogeneous mixture comprising a dispersed rheological polymer-rich phase and a partitioning agent-rich phase. | 01-06-2011 |
20120245060 | CROSS-LINKERS FOR HYDRAULIC FRACTURING FLUID - A method of forming a wellbore fluid, the method including introducing a hydratable polymer and introducing a crosslinker comprised of at least a silica material, the crosslinker having a dimension of from about 5 nm to about 100 nm. | 09-27-2012 |
20120270760 | Boron Crosslinkers For Fracturing Fluids With Appreciably Lower Polymer Loading - Fracturing fluid compositions and methods of fracturing subterranean formations using polyboronic compounds as crosslinking agents are provided. The compositions and methods of the present invention allow for lower polymer loadings because achieving higher fracturing fluid viscosities can be achieved using less polymer than in traditional crosslinked systems. | 10-25-2012 |
20130130948 | METALLIC PARTICLE ACTIVATED OXIDATIVE BREAKING METHOD AND SYSTEM - A method for breaking the viscosity of an aqueous fluid gelled with a water soluble polymer or a VES is disclosed. The method includes providing an aqueous fluid. The method also includes adding to the aqueous fluid, in any order: a water soluble polymer in an amount sufficient to form a gelled aqueous fluid having a viscosity, a water soluble oxidizing agent configured to generate free radicals and a plurality of metallic particles to produce a mixture comprising dispersed metallic particles dispersed within the gelled aqueous fluid, the metallic particles configured to dissolve in the gelled aqueous fluid and provide a reducing agent to accelerate the generation of free radicals. The method further includes dissolving the metallic particles in the gelled aqueous fluid to provide a source of at least one transition metal ion in an amount effective accelerate the generation of free radicals and reduce the viscosity. | 05-23-2013 |
20130150268 | GEL HYDRATION UNIT - A fracking fluid hydration unit is provided that has a plurality of hydration tank sections wherein shear is added to the hydrated fluid flow via a recirculation hydrated fluid jetting system. | 06-13-2013 |
20140038858 | ENHANCED OIL RECOVERY FLUID CONTAINING A SACRIFICIAL AGENT - An enhanced oil recovery formulation composition containing a sacrificial agent and a surfactant dispersed in a fluid is provided. The sacrificial agent reduces the amount of surfactant required to enhance oil recovery from a petroleum-bearing formation. The sacrificial agent is selected from the group consisting of a compound comprising a single carboxylic acid, a single carboxylic acid derivative, or a single carboxylate salt, or a compound lacking a carboxylic acid group, a carboxylate group, a sulfonic acid group, or a sulfonate group that is a pheol, a sulphonamide, or a thiol, or a compound having a molecular weight of 1000 or less that comprises one or more hydroxyl groups. | 02-06-2014 |
20140073538 | Fluid Loss Control Composition and Method of Using the Same - Fluid loss materials including carboxymethylcellulose and zirconium-based crosslinkers may be employed as fluid loss materials in methods of treating subterranean formations. One method includes providing a treatment fluid including carboxymethylcellulose (CMC) and a crosslinker including zirconium, wherein the carboxymethylcellulose has a degree of substitution in a range of from about 0.5 to about 2.5, wherein the crosslinker including zirconium includes one selected from the group consisting of ammonium zirconium fluoride, zirconium 2-ethylhexanoate, zirconium acetate, zirconium neodecanoate, zirconium acetylacetonate, tetrakis(triethanolamine) zirconate, zirconium carbonate, ammonium zirconium carbonate, zirconyl ammonium carbonate, zirconium complex of hydroxyethyl glycine, zirconium malonate, zirconium propionate, zirconium lactate, zirconium acetate lactate, and zirconium tartrate, and placing the treatment fluid in a subterranean formation, wherein the treatment fluid controls fluid loss in a permeable portion of the subterranean formation penetrated by a wellbore. | 03-13-2014 |
20140315766 | Methods and Compositions of Treating a Subterranean Formation with an Optimized Treatment Fluid - Methods of treating a subterranean formation including providing a treatment fluid comprising a brine base fluid and an anionic carboxylated polysaccharide, wherein the brine base fluid comprises a concentration of salt in the range of from about 30,000 ppm to saturation and a pH in the range of from about 4 to about 8, and wherein the anionic carboxylated polysaccharide is present in the range of from about 0.05% to about 2% by weight of the treatment fluid; and introducing the treatment fluid into the subterranean formation. | 10-23-2014 |
20170233642 | Well Treatment Fluids and Methods | 08-17-2017 |
507216000 | Hydroxyalkylcellulose (e.g., HEC, etc.) | 11 |
20090149353 | Polysaccharide Containing Well Treatment Compositions and Methods of Using Same - Loss of wellbore fluids (such as drilling fluids, completion fluids and workover fluids) into the flow passages of a subterranean formation during well drilling, cementing, completion and workover operations may be reduced or eliminated by introducing into the wellbore in communication with the formation a suspension of a polysaccharide in a aqueous fluid. The aqueous fluid contains water and a delayed viscosification material or agent. Hydration of the polysaccharide may be delayed until after introduction of the composition into the formation. A fluid-impermeable barrier is thereby formed. | 06-11-2009 |
20090203554 | Well Treatment Compositions Containing Nitrate Brines and Method of Using Same - Brine-based well treatment compositions containing alkali nitrate exhibit greater thermal stability when used in deep wells than substantially similar brine-based well treatment compositions which do not contain an alkali nitrate. The brine is thickened with a water-soluble crosslinkable polymer and crosslinking agent. The enhanced thermal stability of the well treatment compositions allows use of the fluids at elevated temperatures, for instance as high as 400° F. | 08-13-2009 |
20100184630 | BREAKING THE RHEOLOGY OF A WELLBORE FLUID BY CREATING PHASE SEPARATION - Embodiments of this invention relate to compositions and methods of treating a subterranean formation penetrated by a well bore including introducing a Theological polymer into a subterranean formation, introducing a partitioning agent into a subterranean formation and forming a heterogeneous mixture comprising a dispersed Theological polymer-rich phase and a partitioning agent-rich phase, wherein the viscosity of the mixture is lower than the viscosity of the mixture when no partitioning agent is present. Embodiments of this invention relate to compositions and methods of treating a surface in contact with a wellbore and/or a subterranean formation penetrated by a well bore including forming a heterogeneous mixture comprising a dispersed Theological polymer-rich phase and a partitioning agent-rich phase at the surface of the subterranean formation, and introducing the mixture into a subterranean formation, wherein the viscosity of the mixture within the subterranean formation is lower than the viscosity of the mixture when no partitioning agent is present and wherein the viscosity of the mixture within the subterranean formation is lower than the viscosity of the mixture when the mixture is formed at the surface of the subterranean formation. | 07-22-2010 |
20110028356 | ANNULAR FLUIDS AND METHOD OF EMPLACING THE SAME - An annular fluid or packer fluid, and methods of making the same, that includes a water-miscible solvent, a viscosifying additive, a crosslinking agent, a crosslinking inhibitor having the facility to inhibit crosslinking between the viscosifying additive and the crosslinking agent, and an initiating agent having the facility to overcome an action of the crosslinking inhibitor and to initiate crosslinking between the viscosifying additive and the crosslinking agent, is shown and described. The fluid has a thermal conductivity of no more than about 0.25 btu/(hr·ft·° F.) and a potential to substantially increase its viscosity upon sitting for a selected period of time. | 02-03-2011 |
20120165232 | Methods of Controlling the Degradation Rate of Hydrolytically Degradable Materials - Methods of affecting the rate at which a hydrolytically degradable material degrades comprising: providing a hydrolytically degradable material, the degradable material having an intrinsic degradation rate; providing a modifier, the modifier being capable of affecting the intrinsic degradation rate of the hydrolytically degradable material; placing the hydrolytically degradable material and the modifier into a subterranean formation; and allowing the modifier to affect the intrinsic degradation rate of the hydrolytically degradable material so that the hydrolytically degradable material degrades at a second degradation rate. | 06-28-2012 |
20120322698 | TREATMENT FLUIDS COMPRISING PUMICITE AND METHODS OF USING SUCH FLUIDS IN SUBTERRANEAN FORMATIONS - Methods and compositions for the treatment of subterranean formations, and more specifically, treatment fluids containing pumicite and methods of using these treatment fluids in subterranean formations, are provided. An example of a method is a method of displacing a fluid in a well bore. Another example of a method is a method of separating fluids in a well bore in a subterranean formation. An example of a composition is a spacer fluid comprising pumicite and a base fluid. | 12-20-2012 |
20130096037 | THERMOSET NANOCOMPOSITE PARTICLES, PROCESSING FOR THEIR PRODUCTION, AND THEIR USE IN OIL AND NATURAL GAS DRILLING APPLICATIONS - Use of two different methods, either each by itself or in combination, to enhance the stiffness, strength, maximum possible use temperature, and environmental resistance of thermoset polymer particles is disclosed. One method is the application of post-polymerization process steps (and especially heat treatment) to advance the curing reaction and to thus obtain a more densely crosslinked polymer network. The other method is the incorporation of nanofillers, resulting in a heterogeneous “nanocomposite” morphology. Nanofiller incorporation and post-polymerization heat treatment can also be combined to obtain the benefits of both methods simultaneously. The present invention relates to the development of thermoset nanocomposite particles. Optional further improvement of the heat resistance and environmental resistance of said particles via post-polymerization heat treatment; processes for the manufacture of said particles; and use of said particles in the construction, drilling, completion and/or fracture stimulation of oil and natural gas wells are described. | 04-18-2013 |
20130130949 | WELLBORE SERVICING FLUID COMPRISING A CELLULOSE ETHER - A cellulose ether having (i) one or more substituents selected from the group consisting of methyl, hydroxyethyl and hydroxypropyl, (ii) one or more hydrophobic substituents, and (iii) one or more cationic, tertiary amino, or anionic substituents, and having a retained dynamic viscosity, % η | 05-23-2013 |
20130210685 | Consolidating Spacer Fluids and Methods of Use - Disclosed are spacer fluids and methods of use in subterranean formations. Embodiments may include use of consolidating spacer fluids in displacement of drilling fluids from a well bore annulus. | 08-15-2013 |
20140206583 | WELLBORE SERVICING FLUID HAVING HYDROPHOBICALLY MODIFIED POLYMERS - Embodiments of the present disclosure include a wellbore servicing fluid that includes a diluent, a hydrophobically modified polymer, and a base. The base provides the wellbore servicing fluid with a pH of greater than 10. The presence of the base in the wellbore servicing fluid helps to minimize changes in the viscosity of the wellbore servicing fluid when a deposit, or a kick, of salt is encountered during the drilling operation. | 07-24-2014 |
20150011441 | Mutual Solvent for Downhole Use - A mutual solvent for use in oil and gas well operations comprising an ethoxylated alcohol surfactant, having a six carbon backbone chained to three ethylene oxide groups with a hydrophilic lipophilic balance between 11 and 12 but more preferably of about 11.3. Such a mutual solvent may be used in an oil and gas well as a spacer system, in acid treatments to remove the spent acid, and in solvent systems to remove asphaltenic or paraffinic compounds. | 01-08-2015 |