Entries |
Document | Title | Date |
20080200352 | Degradable Material Assisted Diversion or Isolation - A method for well treatment by forming a temporary plug in a fracture, a perforation, a wellbore, or more than one of these locations, in a well penetrating a subterranean formation is provided, in which the method of well treatment includes: injecting a slurry comprising a degradable material, allowing the degradable material to form a plug in a perforation, a fracture, or a wellbore in a well penetrating a formation; performing a downhole operation; and allowing the degradable material to degrade after a selected time such that the plug disappears. | 08-21-2008 |
20080269083 | Oil Reservoir Treatment Method By Injection of Nanoparticles Containing an Anti-Mineral Deposit Additive - The invention relates to a method of treating permeable rocks wherein the following stages are carried out: producing particles of nanometric size comprising an active anti-mineral-deposit water-soluble polymer encapsulated in either a matrix so as to form a nanocomplex or a nanosphere, or in a membrane so as to form a nanocapsule; maintaining an amount of said particles dispersed in a liquid phase; injecting the dispersion into the permeable rock; and releasing the active polymer upon contact with salt water. | 10-30-2008 |
20090023615 | 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 |
20090062157 | Methods and compositions related to the degradation of degradable polymers involving dehydrated salts and other associated methods - Methods are included herein that include a method comprising: providing a degradable particulate comprising a degradable polymer matrix and an dehydrated salt; and placing the degradable particulate in a subterranean formation. Other methods and compositions are provided as well. | 03-05-2009 |
20090124521 | ADDITIVE FOR INCREASING THE DENSITY OF A FLUID FOR CASING ANNULUS PRESSURE CONTROL - A method of treating a wellbore that includes circulating a wellbore fluid in the wellbore, wherein the wellbore fluid comprises an oleaginous base fluid and a wellbore additive colloidal solid material, and wherein the wellbore additive colloidal solid material is formed by grinding a solid particulate material and a polymeric dispersing agent for a sufficient time so that the polymeric dispersing agent is absorbed to the surface of the resulting colloidal solid particles and less than 10% of the resulting colloidal solid particles have a diameter greater than 10 microns, but not more than five percent of the particles are less than 0.2 micron in diameter, wherein the grinding is carried out in the presence of an oleaginous base fluid and wherein the grinding is carried out so that the wellbore additive colloidal solid material has a weight average particle diameter d | 05-14-2009 |
20090131282 | Solid Zirconium-based cross-linking agent and use in oil field applications - A solid zirconium cross-linking agent and use in a cross-linking composition in oil field applications such as hydraulic fracturing and plugging of permeable zones. The zirconium cross-linking agent is prepared by a process comprising contacting a zirconium complex with an alkanolamine and water at particular mole ratios of alkanolamine and water to zirconium. | 05-21-2009 |
20090137432 | pH Sensitive Emulsion System - An oilfield treatment fluid in the form of an emulsion wherein the emulsion contains at least one treatment agent sequestered within a phase of the emulsion, wherein the emulsion is stable when the pH is maintained within a predetermined range, and breaks to release the at least one treatment agent when the pH is changed to a release pH value outside the predetermined stable pH range. | 05-28-2009 |
20090143257 | Methods and Compositions for Controlling Water Production - A composition for treatment of a subterranean formation, which may be used for water control, is comprised of at least one of 1) a premix of an oleochemical polyol, at least one of polyisocyanate, polycyanate and polyisothiocyanate, and a blocking agent to temporarily block all or a portion of free reactive groups of said at least one of polyisocyanate, polycyanate and polyisothiocyanate. Alternatively, or in addition, the composition may be comprised of a solvent and 2) a polyurethane prepolymer formed by reacting an oleochemical polyol and at least one of polyisocyanate, polycyanate and polyisothiocyanate. A blocking agent may also be used with the polyurethane prepolymer. The composition may be used in a method of treating a subterranean formation penetrated by a wellbore by introducing the composition into the formation through the wellbore. In another embodiment, a method of treating a subterranean formation penetrated by a wellbore is carried out by forming a treatment fluid containing at least one of 1) palmitic acid or its derivatives and 2) palm oil and at least one of an hydrolyzing or oxidizing agent to facilitate formation of palmitic acid or its derivatives. The treatment fluid also includes a source of a monovalent ions. The treatment fluid is introduced into the wellbore for treatment of the subterranean formation. | 06-04-2009 |
20090209438 | LOW RESIDUE FLUID FRACTURING SYSTEM AND METHOD OF USE - A fluid system for hydraulic fracturing operations which comprises a low residue fluid that facilitates the clean up of the wellbore following the treatment is disclosed. The system includes a surfactant compound that forms micelles above a critical concentration. Under certain conditions the addition of an associative thickener compound yields a network based on hydrophobic interactions. The resulting viscous fluid can transport proppants, be applied neat or as a foamed or energized system, or used in an acidizing treatment. The fluid system may further include a breaker additive. | 08-20-2009 |
20090264321 | COMPOSITION AND METHOD FOR RECOVERING HYDROCARBON FLUIDS FROM A SUBTERRANEAN RESERVOIR - This invention is directed to a composition comprising encapsulated expandable polymeric microparticles including expandable base microparticles encapsulated in a shell of at least one layer of a labile or degradable encapsulation material. The encapsulated microparticles have an unexpanded volume average particle size diameter of from about 0.05 to about 5,000 microns. The invention is further directed to the use of the composition for modifying the permeability of subterranean formations and increasing the mobilization and/or recovery rate of hydrocarbon fluids present in the formations. | 10-22-2009 |
20090264322 | COMPOSITION AND METHOD FOR RECOVERING HYDROCARBON FLUIDS FROM A SUBTERRANEAN RESERVOIR - This invention is directed to a composition comprising expandable polymeric microparticles comprising hydrophobic polymers having a backbone with labile pendant groups, the microparticles having an unexpanded volume average particle size diameter of from about 0.05 to about 5,000 microns. Labile pendant groups on the backbone are subject to hydrolysis under a change in environmental conditions that results in expansion of the microparticle. The invention is further directed to the use of the composition for modifying the permeability of subterranean formations and increasing the mobilization and/or recovery rate of hydrocarbon fluids present in the formations. | 10-22-2009 |
20090281003 | RECOVERY AND RECYCLING OF CHEMICALS IN CHEMICAL FLOODING PROCESS - A method including a) injecting into the formation an aqueous solution containing a polymer and a surfactant to create a organic phase and a aqueous phase, the surfactant being capable of reducing the interfacial tension between the phases to less than 1 dyne/cm; b) recovering a portion of the organic and aqueous phases containing at least a portion of the polymer and surfactant components and a portion of native petroleum surfactants generated in the porous formation; c) adjusting the conditions of the recovered portions to force a portion of the polymer and surfactant from one phase into the other phase by use of chemical, physical, electrical or gravitational means or a combination of said means; d) separating the polymer- and surfactant-containing phase; e) concentrating the polymer and surfactant components in the separated phase; and f) re-injecting at least a portion of the concentrated polymer and surfactant components into the formation. | 11-12-2009 |
20090281004 | Composition and Method for Fluid Recovery from Well - A well treatment microemulsion for use in a subterranean formation is disclosed, the microemulsion comprises a solvent blend comprising a solvent and a co-solvent; a surfactant blend comprising a surfactant, wherein the surfactant blend is able to give formation intermediate wettability properties; an alcohol; and a carrier fluid; wherein the alcohol, the solvent and surfactant blends are combined with the carrier fluid to produce the well treatment microemulsion. By intermediate wettability it is meant that the water has an advancing contact angle on the surface between 62 and 133 degrees. The associate method of treating a subterranean formation of a well with the microemulsion and the associate method of modifying the wettability of the formation with the microemulsion are also disclosed. | 11-12-2009 |
20090291863 | Methods of Diverting Chelating Agents in Subterranean Treatments - Methods and compositions including a method comprising: providing a treatment fluid comprising an aqueous fluid, a relative permeability modifier, and a chelating agent; introducing the treatment fluid into a well bore that penetrates a subterranean formation; and allowing at least a first portion of the treatment fluid to penetrate into a portion of the subterranean formation so as to substantially divert a second portion of the treatment fluid to another portion of the subterranean formation. | 11-26-2009 |
20100048430 | Delayed crosslinking agents for high-temperature fracturing - Treatment fluids comprising gelling agents and high-temperature, delayed crosslinkers, and methods of use in subterranean operations, are provided. In one embodiment, a method of treating a subterranean formation includes providing a treatment fluid comprising an aqueous base fluid; a gelling agent comprising terpolymer of 2-acrylamido-2-methylpropane sulfonic acid, acrylamide, and acrylic acid or a salt thereof; and a crosslinking agent comprising at least one component selected from the group consisting of zirconyl chloride and zirconium sulfate; and introducing the treatment fluid into a subterranean formation. | 02-25-2010 |
20100048431 | Methods and compositions for treating subterranean formations - Methods and compositions useful in treating subterranean formations, and more particularly, breaker compositions that may be useful in treating subterranean formations wherein synthetic polymers are used, are provided. Of the many methods and compositions provided herein, one composition comprises a source of hydrogen peroxide and an activator. One method comprises providing a polymer breaker composition comprising a source of hydrogen peroxide and an activator; introducing the polymer breaker composition into a well bore which penetrates a subterranean formation; allowing the activator to activate the source of hydrogen peroxide to create an oxidizing species; and allowing the oxidizing species to break synthetic polymers present in the subterranean formation. | 02-25-2010 |
20100062953 | RHEOLOGY MODIFYING AGENTS AND METHODS OF MODIFYING FLUID RHEOLOGY USE IN HYDROCARBON RECOVERY - A method of modifying the rheological properties of a fluid include adding to the fluid at least one polymer that is the reaction product of at least one water soluble, allyic monomer and at least one structure inducing agent. The polymer is adapted to increase the viscosity of the fluid and to impart non-Newtonian characteristic to the fluid. Non-Newtonian characteristics are, for example, evidenced by the fluid exhibiting an n value of less than 1 upon addition of the polymer as determined by the equation τ=Kθ | 03-11-2010 |
20100093565 | SYSTEM, METHOD, AND APPARATUS FOR UTILIZING DIVALENT BRINES IN VISCOSIFIED WELL TREATMENT FLUIDS - A method includes providing a wellbore treatment fluid having a divalent brine and an amount of polymer and lowering a pH value of the treatment fluid. The method further includes retaining the treatment fluid at the lower pH value until the polymer achieves a primary hydration value. The method further includes adding a cross-linking agent and a cross-linking delay agent to the treatment fluid. The cross-linking agent includes zirconium and/or titanium, and the cross-linking delay agent is a polyol. The method further includes performing a wellbore treatment with the treatment fluid. | 04-15-2010 |
20100099586 | 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. | 04-22-2010 |
20100113310 | ELASTIC HOLLOW PARTICLES FOR ANNULAR PRESSURE BUILDUP MITIGATION - The concept involves placing within the annulus, hollow particles that possess material and geometric properties such that the hollow particles buckle at or near a defined pressure. Buckling of the particles increases the available volume within the annulus, thereby decreasing the annular pressure. The elastic hollow particles are designed such that they buckle in a sufficiently elastic manner to allow them to rebound towards their original shape as the pressure decreases. The rebounded particles then remain available to mitigate subsequent instances of APB. | 05-06-2010 |
20100120637 | Composition That Can Form a Gel Comprising a Copolymer, and Useful Copolymers - The invention relates to a composition that can form a gel comprising a copolymer. Said composition is an aqueous composition, and the copolymer is a star copolymer. The invention also relates to useful copolymers, especially for the inventive compositions. | 05-13-2010 |
20100184631 | PROVISION OF VISCOUS COMPOSITIONS BELOW GROUND - A method of providing a viscous emulsion at a subterranean location accessible via a wellbore, begins by providing an aqueous/aqueous emulsion comprising two aqueous solutions which, at surface temperature and pressure, are able to co-exist as separate aqueous phases in contact with each other. The two phases contain respective solutes which are sufficiently incompatible that they cause phase separation. The dispersed phase is rich in one solute, which may be a thickening polymer, while continuous phase is rich in a second solute, which may comprise surfactant. A hydrophobic liquid is dispersed in this emulsion to become the dispersed phase of a viscous emulsion whose continuous phase is provided by the aqueous/aqueous emulsion. The hydrophobic liquid and the aqueous/aqueous emulsion may be pumped separately down the wellbore to the subterranean location, and allowed to mix there so as to form the viscous emulsion at the subterranean location. On mixing, surfactant from the aqueous/aqueous emulsion may migrate to the oil/water interface, allowing the aqueous phases to become one phase with the result that the emulsion is further thickened by any thickening polymer in its composition. Even more thickening can be achieved by crosslinking the thickening polymer. | 07-22-2010 |
20100267593 | CONTROL OF PARTICULATE ENTRAINMENT BY FLUIDS - An aqueous slurry composition for use in industries such as petroleum and pipeline industries that includes: a particulate, an aqueous carrier fluid, a chemical compound that renders the particulate surface hydrophobic, and a small amount of an oil. The slurry is produced by rendering the surface of the particulate hydrophobic during or before the making of the slurry. The addition of the oil greatly enhances the aggregation potential of the hydrophobically modified particulates once placed in the well bore. | 10-21-2010 |
20100285998 | POLYAMIDE BEADS AND METHOD FOR THE PRODUCTION THEREOF - Certain polyamide beads or granules are useful as a sustaining material for underground natural or artificial cracks of the earth's crust essentially employed for the extraction of hydrocarbons such as crude oil or natural gas; such polyamide beads have a spherical or ellipsoidal shape and have a surface free of concave portions, advantageously having a uniform shape, and having a mean diameter lower than or equal to 1.7 mm and a porosity lower than 0.1 ml/g, and are produced using a particular cutting device/extruder. | 11-11-2010 |
20100323931 | STABILISED EMULSIONS - A method and system are described in which a first composition may be delivered to a target location, which target location may include but is not limited to a location in a wellbore penetrating an earth formation. The first composition is dispersed into a second composition to form an emulsion, where the emulsion is stabilized by particles that are responsive to a magnetic field. The emulsion is used to transport the first composition to the target location where the emulsion is subjected to a magnetic field sufficient to interact with the particles and disrupt the emulsion, and thereby change the viscosity of the composition and/or release the first composition at the target location. In some aspects, the first and second composition may react together upon the release of the first composition at the target location. | 12-23-2010 |
20100323932 | METHODS FOR TREATING A WELL OR THE LIKE - A method is disclosed where introducing into a wellbore a degradable material stabilized in a non-aqueous based fluid. | 12-23-2010 |
20110021386 | MICROEMULSION TO IMPROVE SHALE GAS PRODUCTION BY CONTROLLING WATER IMBIBITION - The invention provides a method for treating tight gas sand and shale subterranean formations, the method comprising: forming a solvent-surfactant blend by combining a solvent, a surfactant and a co-surfactant; adding a diluent to the solvent-surfactant blend to form a micro emulsion; wherein the wettability of the formation altered from water-wet to gas-wet, and the amount of water imbibed into the formation is reduced. | 01-27-2011 |
20110028357 | SYSTEM, METHOD AND APPARATUS FOR ENHANCING WELLBORE TREATMENT FLUID FLEXIBILITY - A method includes performing a chemical process to create a chemical product and an amount of heat, and transferring the heat to a first fluid. The method further includes hydrating a polymer in the first fluid, and adding the chemical product from the chemical process to the first fluid to create a treatment fluid. The method further includes diluting the treatment fluid with respect to at least one constituent of the treatment fluid. The method includes treating a formation of interest in a wellbore with the treatment fluid. The method includes changing a formulation of the treatment fluid during the treating. The method also includes extending the treating beyond a design amount, or ending the treatment before the design amount and preserving some reagents of the chemical process. | 02-03-2011 |
20110028358 | Methods of Fluid Loss Control and Fluid Diversion in Subterranean Formations - Improved methods of placing and/or diverting treatment fluids in subterranean formations are provided. In one embodiment, the methods comprise introducing a treatment fluid into a subterranean formation penetrated by a well bore, wherein the treatment fluid comprises: a base fluid, and a plurality of solid particulates comprising at least one selected from the group consisting of: a scale inhibitor, a chelating agent, and a combination thereof, wherein the solid particulates are substantially insoluble in the base fluid; and allowing at least a portion of the solid particulates to form a barrier or at partially divert a subsequent fluid. | 02-03-2011 |
20110053812 | Polymeric Additives for Enhancement of Treatment Fluids Comprising Viscoelastic Surfactants and Methods of Use - Polymeric additives used with viscoelastic surfactants, fluids comprising such additives and viscoelastic surfactants, and associated methods of use, are provided. In one embodiment, the methods comprise: providing a treatment fluid that comprises an aqueous base fluid, a viscoelastic surfactant, and an amphiphilic polymer, the amphiphilic polymer comprising a hydrophobic component, and a hydrophilic component comprising at least 15 monomer units; and introducing the treatment fluid into at least a portion of a subterranean formation. | 03-03-2011 |
20110059872 | COMPOSITIONS AND METHODS FOR CONTROLLING THE STABILITY OF ETHERSULFATE SURFACTANTS AT ELEVATED TEMPERATURES - The present invention describes the method of making an ether sulfate surfactant solution hydrolytically stable by adding one or more alkalinity generating agents at levels greater than 0.05%. The surfactant solutions of the present invention have half-lives >8 months at 100° C. and find uses in EOR applications, environmental cleanups, detergent industry, and any other surfactant based high temperature applications. | 03-10-2011 |
20110071057 | METHOD OF MANUFACTURE AND USE OF LARGE HYDROPHOBE ETHER SULFATE SURFACTANTS IN ENHANCED OIL RECOVERY (EOR) APPLICATIONS - The present invention describes the method of making anionic ether sulfate surfactants by alkoxylation of a GA using PO and/or EO followed by a sulfation reaction. The GA of the present invention is made by a facile and inexpensive method that involves high temperature base catalyzed dimerization of a linear alcohol. The ether sulfate surfactants of the present invention find uses in EOR applications where it is used for solubilization and mobilization of oil and for environmental cleanup. | 03-24-2011 |
20110111990 | STRONG LOW DENSITY CERAMICS - A synthetic ceramic proppant composition contains an aluminate-borate phase or an aluminate-borate-silicate phase or both and at least one additional phase that adds strength and decreases apparent specific gravity and is formed because of the inclusion of certain inorganic salts and/or metallic oxides in the precursor mixture either as separate components or as impurities in the starting materials. Compositions, methods of manufacture, and uses are given. | 05-12-2011 |
20110118152 | NOVEL METHOD FOR THE TREATMENT OF ROCK FORMATIONS AND NOVEL POLYAMPHOLYTES - A method for the treatment of rock formations which may or may not be underground and, more particularly, of oil or gas production wells, water-injection wells intended to flood hydrocarbon (oil or gas) reservoirs or gas mines or gas storage wells includes a step of injecting, into the rock formation or well, a microgel obtained by dilution in water of a self-invertible inverse latex or of a self-invertible inverse microlatex of a crosslinked polyelectrolyte, obtained by copolymerization, in the presence of a crosslinking agent of partially- or totally-salified free 2-methyl-2-[(1-oxo-2-propenyl)amino]-1-propanesulfonic acid, with at least one cationic monomer chosen from: 2,N,N,N-tetramethyl-2-[(1-oxo-2-propenyl)amino]propanammonium chloride; N,N,N-trimethyl-3-[(1-oxo-2-propenyl)amino]propanammonium chloride; diallyldimethylammonium chloride; N,N,N-trimethyl-2-[(1-oxo-2-propenyl)]ethanammonium chloride; N,N,N-trimethyl-2-[(1-oxo-2-methyl-2-propenyl)]ethanammonium chloride; or N,N,N-trimethyl-3-[(1-oxo-2-methyl-2-propenyl)amino]propanammonium chloride; and with at least one neutral monomer chosen from: acrylamide; N,N-dimethylacrylamide; N-[2-hydroxy-1,1-bis(hydroxymethyl)-ethyl]propenamide; or 2-hydroxyethyl acrylate. | 05-19-2011 |
20110152134 | METHOD FOR BINDING NON-SOLID OXIDIC INORGANIC MATERIALS WITH ETHERIFIED AMINOPLAST RESINS AND CURED COMPOSITIONS OF SAID MATERIALS AND ETHERIFIED AMINOPLAST RESINS - The present invention relates to a process for binding non-consolidated oxidic inorganic materials with curable formulations which comprise etherified amino resins, and to cured compositions obtainable by the process. A preferred embodiment of the invention comprises a process for stabilizing underground formations composed of oxidic inorganic materials, wherein the curable composition is injected into the underground formation and cured at the temperatures which exist in the formation. | 06-23-2011 |
20110177984 | Tagged Propping Agents and Related Methods - A proppant particle comprising a sintered proppant composition that comprises a non-radioactive, detectable tracer uniformly distributed throughout a ceramic composition, wherein the tracer is one or more tracer metal oxides and the tracer metals are selected from a group consisting of lanthanides, strontium, barium, gallium, germanium, tantalum, vanadium, and manganese. | 07-21-2011 |
20110218127 | POLYCARBONATE BLOCK COPOLYMERS - The disclosure pertains to amphiphilic block copolymers comprising an aliphatic polycarbonate chain coupled to a hydrophilic polymer. Such amphiphilic polymers may have the formula A-L-B, where A- is a polycarbonate or polyethercarbonate chain having from about 3 to about 500 repeating units, L is a linker moiety and —B is a hydrophilic oligomer having from about 4 to about 200 repeating units. Provided copolymers are useful as surfactants capable of emulsifying aqueous solutions and supercritical carbon dioxide. Provided copolymers also have utility as additives for use in enhanced oil recovery methods. | 09-08-2011 |
20110237467 | NANOPARTICLE-DENSIFIED COMPLETION FLUIDS - The present invention is directed to completion fluid compositions and methods of making same. Such completion fluids are unique in that they utilize nanoparticles as weighting (densification) agents that increase the specific gravity (or density) of the fluid into which they are dispersed. Depending on their properties, such nanoparticulate weighting agents can vastly broaden the types of base fluid used in the completion fluid, permitting the use of non-aqueous and even hydrocarbon base fluids. Additionally, such nanoparticle-densified completion fluids can provide reduced environmental risks, and the nanoparticle weighting agents used therein can be more easily recovered from the based fluids into which they are dispersed. | 09-29-2011 |
20120122741 | 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. The mixture may also contain a multivalent ion and the particulates may be coated with a coating material in an amount from about 0.1% to about 40% coating material by weight of the scale inhibiting particulate to delay the release of the scale inhibitor. | 05-17-2012 |
20120157356 | Hydraulic fracturing with slick water from dry blends - A “slick water” fluid for hydraulic fracturing of wells is provided that is mixed by adding solid polymer and solid additives to water. The fluid may be batch mixed or mixed in a continuous process using standard blending equipment. Components are selected that are environmentally preferred. Lower cost and environmental benefits are realized. | 06-21-2012 |
20120208728 | WELL TREATMENT - The present invention provides a method for inhibiting scale formation within a hydrocarbon producing system (e.g. a subterranean formation), said method comprising contacting said system with a clay mineral, an organosilane and a scale inhibitor. | 08-16-2012 |
20120208729 | Polymeric Acid Precursor Compositions And Methods - A composition is formed from a polymeric acid precursor, such as polylactic acid (PLA), that is a least partially dissolved within a polymer dispersing solvent. An emulsion may be from polymeric acid precursor that is at least partially dissolved within a solvent and a liquid that is substantially immiscible with the solvent. In certain cases, the molecular weight of the polymeric acid precursor may be reduced in forming the solution. The solution may be used in treating a formation penetrated by a wellbore. | 08-16-2012 |
20120283153 | COATED AND CURED PROPPANTS - Solid proppants are coated with a coating that exhibits the handling characteristics of a precured coating while also exhibiting the ability to form particle-to-particle bonds at the elevated temperatures and pressures within a wellbore. The coating includes a substantially homogeneous mixture of (i) at least one isocyanate component having at least 2 isocyanate groups, and (ii) a curing agent. The coating process can be performed with short cycle times, e.g., less than about 4 minutes, and still produce a dry, free-flowing, coated proppant that exhibits low dust characteristics during pneumatic handling but also proppant consolidation downhole for reduced washout and good conductivity. | 11-08-2012 |
20120329683 | DEGRADABLE FIBER SYSTEMS FOR WELL TREATMENTS AND THEIR USE - A method for treating a subterranean formation penetrated by a wellbore is carried out introducing a treatment fluid into the formation through the wellbore wherein the formation has a formation temperature of at least 70° C. A composition for such treatment is also provided. The composition and treatment fluid for the method is formed from water and an amount of fibers formed from high temperature polymers of at least one of a polyester, polyamide, polyurethane, polyurea polymers, and copolymers of these. Each of said high temperature polymers is characterized by the property of not substantially degrading in water at a pH of from 5 to 9 at temperatures below 80° C. A fiber degrading accelerant that facilitates degrading of the fibers at the formation temperature is also included in the treatment fluid. | 12-27-2012 |
20130029883 | GAS GENERATING SYSTEM FOR STIMULATION AND DELIQUIFICATION - A gas generating system for use in stimulation or in deliquification/dewatering includes a foam generating agent, a foam enhancing agent and a gas generating additive. The foam generating agent is absorbed or adsorbed on a first plurality of substrates and the foam boosting agent is absorbed or adsorbed on a second plurality of substrates. The gas generating additive preferably includes an acidic component contained within a releasing mechanism container and a carbonate or bicarbonate contained within a releasing mechanism container. The use of encapsulated substrate permits the staged and targeted delivery of treatment chemicals in fractures extending from the wellbore or in the wellbore itself. | 01-31-2013 |
20130029884 | BIOCIDE FORMULATIONS - Biocide compositions comprising biocide, surfactant, and solubilizing agent. The preferred biocide is parachlorometaxylenol. The biocide composition is useful in oil and gas drilling operations, such as hydraulic fracturing, as well as treating aqueous slurries in ore mining operations. The biocide compositions are effective in controlling microorganisms even in the presence of high salt content water and at high temperatures. | 01-31-2013 |
20130065800 | COATED AND CURED PROPPANTS - Solid proppants are coated with a coating that exhibits the handling characteristics of a pre-cured coating while also exhibiting the ability to form particle-to-particle bonds at the elevated temperatures and pressures within a wellbore. The coating includes a substantially homogeneous mixture of (i) at least one isocyanate component having at least 2 isocyanate groups, and (ii) a curing agent comprising a monofunctional alcohol, amine or amide. The coating process can be performed with short cycle times, e.g., less than about 4 minutes, and still produce a dry, free-flowing, coated proppant that exhibits low dust characteristics during pneumatic handling but also proppant consolidation downhole for reduced washout and good conductivity. Such proppants also form good unconfined compressive strength without use of an bond activator, are substantially unaffected in bond formation characteristics under downhole conditions despite prior heat exposure, and are resistant to leaching with hot water. | 03-14-2013 |
20130123151 | METALLIC PARTICLE MEDIATED VISCOSITY REDUCTION OF VISCOELASTIC SURFACTANTS - A method for breaking the viscosity of an aqueous fluid gelled with a viscoelastic surfactant (VES) is disclosed. The method includes providing an aqueous fluid and adding to the aqueous fluid, in any order: at least one VES comprising a non-ionic surfactant, cationic surfactant, amphoteric surfactant or zwitterionic surfactant, or a combination thereof, in an amount sufficient to form a gelled aqueous fluid comprising a plurality of elongated micelles and having a viscosity, and a plurality of metallic particles to produce a mixture comprising dispersed metallic particles dispersed within the gelled aqueous fluid. The method also 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 to reduce the viscosity. | 05-16-2013 |
20130165353 | STABLE SUSPENSIONS OF CARBON NANOPARTICLES FOR NANO-ENHANCED PDC, LBL COATINGS, AND COOLANTS - A nanocomposite comprises a matrix; and a nanoparticle comprising an ionic polymer disposed on the surface of the nanoparticle, the nanoparticle being dispersed in and/or disposed on the matrix. A method of making a nanocomposite, comprises combining a nanoparticle and an ionic liquid; polymerizing the ionic liquid to form an ionic polymer; disposing the ionic polymer on the nanoparticle; and combining the nanoparticle with the ionic polymer and a matrix to form the nanocomposite. | 06-27-2013 |
20140073539 | AQUEOUS DISPERSION AND ADDITIVES FOR FRACTURING WORK - The aqueous dispersion of the present invention is an aqueous dispersion in which a biodegradable resin composition (C) in the form of a fine solid is dispersed in an aqueous medium, and the biodegradable resin composition (C) comprises a copolymer (A) comprising a constituent unit (a-1) derived from a polyvalent carboxylic acid and a constituent unit (a-2) derived from a hydroxycarboxylic acid, and a biodegradable resin (B), and wherein the mass composition ratio [(A)/(B)] of the copolymer (A) to the biodegradable resin (B) is 1/99 to 100/0 provided that the total amount of the copolymer (A) and the biodegradable resin (B) is 100. | 03-13-2014 |
20140100142 | TRACEABLE POLYMERIC SCALE INHIBITORS AND METHODS OF USING SUCH SCALE INHIBITORS - A traceable polymeric scale inhibitor comprises a traceable phosphinate moiety and a scale inhibiting moiety including carboxylate functionality. The polymeric scale inhibitor may be derived from polymerization of a mixture comprising a phosphinate compound and a vinyl-carboxylate monomer. The traceable polymeric scale inhibitor may be used for oilfield applications. A method of reducing scale formation comprises treating the fluid subjected to scale formation with the traceable polymeric scale inhibitor. The method provides a means to determine when additional treatment of scale inhibitors is needed, which conduit or wellbore needs additional treatment of scale inhibitor, and how much additional scale inhibitor is needed in the repeat treatment to provide effective inhibition of scale formation. | 04-10-2014 |
20140274819 | Proppant With Polyurea-Type Coating - Proppants for hydraulic fracturing of oil and gas wells are coated with a polyurea-type coating. In a preferred embodiment, the polyurea-type coating is formed by contacting a polymeric isocyanate with an amount of water and a blowing catalyst at a rate and quantity sufficient to generate a reactive amine in situ on the outer surface of the proppant which thereby reacts with unconverted polymeric isocyanate to form a thin polyurea-type surface coating that is substantially solid and lacks foam or substantial porosity. Alternatively, the polyurea-type can be produced by selecting reactive amine compounds and isocyanates to develop the coated proppant. The coated proppants retain the discrete, free-flowing character of the original core solids but with the beneficial effects of the polyurea-type coating of the present invention. | 09-18-2014 |
20140274820 | DEGRADABLE POLYMERS AND METHOD FOR FRACKING APPLICATIONS - The present disclosure is directed degradable polymers. The polymers are solid when maintained under substantially dry conditions at a temperature of up to about 90 degrees C. When contacted with water at a temperature of up to about 90 degrees C., however, the polymers initially remain solid for a period of up to about 6 to about 24 hours, then depolymerize to provide a liquid having a viscosity of from about 1 to about 200,000 centipoise after a period of time from about 8 hours to about 3 days and then further depolymerizes to water-soluble components after a period of time at least about 3 days. Also disclosed are sand screen coatings made with the polymers and hydraulic and acid fracturing methods using the polymers. | 09-18-2014 |
20140309149 | Dual Function Proppants - Proppants for use in fractured or gravel packed/frac packed oil and gas wells are provided with a contaminant removal component to remove one or more of the contaminants found in subterranean water/hydrocarbon from a production well. The water/hydrocarbon cleaning proppant solids may be used as discrete particles in a proppant formulation, as a coating on proppant solids in pores of a porous proppant solid or as part of the proppant's internal structure. The contaminant removal component removes contaminants, especially dissolved contaminants, in the subterranean water or hydrocarbon before the water/hydrocarbon leaves the well. For those contaminant removal components that can be regenerated, such as ion exchange resins, a measured quantity of an acidic regeneration solution can be injected into the fractured stratum for regeneration and recovered when the well resumes production. | 10-16-2014 |
20140323363 | NANOTRACERS FOR LABELING OIL FIELD INJECTION WATERS - This invention relates to the development of nanoparticles, which can be used as tracers, in order to track the movement of fluids injected into an oil reservoir. The injected fluids diffuse through a solid geological medium which constitutes the oil reservoir, thus making it possible to study this latter by following the path of the injected fluids. The objective is in particular to monitor the flows between the injection well(s) and the production well(s) and/or to evaluate the volumes of oil in reserve and water in the reservoir and ultimately to optimize oil exploration and exploitation. | 10-30-2014 |
20140323364 | High Strength Low Density Synthetic Proppants for Hydraulically Fracturing and Recovering Hydrocarbons - There is provided synthetic proppants, and in particular polysilocarb derived ceramic proppants. There is further provided hydraulic fracturing treatments utilizing these proppants, and methods of enhance hydrocarbon recovery. | 10-30-2014 |
20140323365 | Polylactide Fibers - Polylactide fibers are made from a blend of polylactides. One of the polylactides has a ratio of R-lactic and S-lactic units from 8:92 to 92:8. The second polylactide has a ratio of the R-lactic and S-lactic units of >97:3 or <3:97. The ratio of the R-lactic units to S-lactic units in the blend is from 7:93 to 25:75 or from 75:25 to 93:7. The polylactide fiber contains at least 5 Joules of polylactide crystallites per gram of polylactide resin in the fiber. | 10-30-2014 |
20140336088 | LIQUEFIED POLYMER FRACTURING FLUID THICKENER AND PREPARATION METHOD THEREOF - The present invention relates to a liquefied polymer fracturing fluid thickener, which has evaluation indexes as: a density of 1.0-1.3 g/cm | 11-13-2014 |
20140357535 | 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 a resin material, a silane coupling agent, and an aqueous base fluid, placing the wellbore servicing fluid in the wellbore and/or subterranean formation, and allowing the wellbore servicing fluid to harden therein. | 12-04-2014 |
20140357536 | INVERT EMULSION FLUID CONTAINING A HYGROSCOPIC LIQUID, A POLYMERIC SUSPENDING AGENT, AND LOW-DENSITY SOLIDS - An invert emulsion treatment fluid comprises: (A) an external phase, wherein the external phase comprises a hydrocarbon liquid; (B) an internal phase, wherein the internal phase comprises a hygroscopic liquid; (C) a suspending agent, wherein the suspending agent is a polymer, and wherein the polymer comprises urea linkages; and (D) a particulate, wherein the particulate has a density less than 3.5 g/cm | 12-04-2014 |
20140364344 | HYDRATION SYSTEM AND METHOD THEREOF - A hydration system configured to selectively enable a continuous process or a batch process of an additive for a hydraulic fracturing fluid, the hydration system including a hydration tank having a plurality of compartments, wherein the hydration tank is configured to enable movement of a material through the plurality of compartments in the continuous process. The hydration tank is configured to substantially restrict movement of the material between the plurality of compartments in the batch process. Also included is a method of selectively hydrating an additive in a batch process or a continuous process using a hydration system configured to enable both the batch process and the continuous process, | 12-11-2014 |
20150024977 | METHOD FOR INHIBITING THE PLUGGING OF CONDUITS BY GAS HYDRATES - A method for inhibiting the plugging of a conduit containing a flowable mixture comprising at least an amount of hydrocarbons capable of forming hydrates in the presence of water and an amount of water, which method comprises adding to the mixture an amount of a functionalized dendrimer effective to inhibit formation and/or accumulation of hydrates in the mixture at conduit temperatures and pressures; and flowing the mixture containing the functionalized dendrimer and any hydrates through the conduit wherein the functionalized dendrimer comprises at least one polyalkylene glycol end group. | 01-22-2015 |
20150080273 | Foam control formulations - The invention provides a foam control formulation in the form of a microemulsion, the formulation comprising: (a) from S to 70% w/w of primary surfactant, this surfactant having an HLB of from 1 to 12 and/or a cloud point of from 20 to 70° C.; (b) from 2 to 40% w/w of water-insoluble organic carrier liquid; and (c) water. Also provided is the use of this formulation to prevent and/or reduce foam in a fluid system, or as a processing aid to control foam production in a fluid system. The formulation may be used in an aqueous fluid system, such as an oilfield. | 03-19-2015 |
20150080274 | Low-Density Composite Propping Agents - Composite propping agents of low density and of high mechanical strength are based on a thermoplastic polymer matrix, in particular having low compressive deformation at high temperatures are especially useful in the field of well fracturing for the recovery of sludges, liquids and gases present in underground reservoirs, and in particular in the field of the extraction of hydrocarbons, such as crude oil or natural gas. | 03-19-2015 |
20150126417 | Surfactant composition - The invention provides a synergistic surfactant composition comprising: (a) from 5 to 95 wt % of a first surfactant which is selected from derivatives of alkyl polyglucosides and mixtures thereof; and (b) from 5 to 95 wt % of a second surfactant which is selected from: amphoteric surfactants, cationic surfactants, anionic surfactants, non-ionic surfactants, and mixtures thereof. This surfactant composition may be used to generate foam that is used for unloading a liquid from a hydrocarbon reservoir. It may be that the liquid unloading of foam generated using the surfactant composition is greater than that of foam generated from the first and second surfactants when they are foamed individually. | 05-07-2015 |
20150133349 | SYNERGISTIC CHEMISTRY TO PREVENT SILICATE SCALING - Two intermediates that have known separate efficacy for preventing scales such as calcium carbonate, magnesium carbonate and barite (barium sulfate) were discovered to have a synergistic effect for preventing or inhibiting silicate scaling when used together. Each of these intermediates is ineffective at preventing silicate scaling when used alone; however, when used in combination, they have a synergistic benefit. In one non-limiting embodiment the components include a polyamine phosphonate and a lysine tetra(alkylene)phosphonate. | 05-14-2015 |
20150329766 | METHOD OF CONTACTING HYDROCARBON-BEARING FORMATIONS WITH FLUORINATED IONIC POLYMERS - A method is disclosed that includes contacting a hydrocarbon-bearing formation with a treatment composition comprising solvent and a fluorinated polymer. The fluorinated polymer includes: a first divalent unit represented by formula (I): wherein Rf represents a fluoroalkyl group having from 1 to 8 carbon atoms; each R | 11-19-2015 |
20150337078 | POLY(ACRYLATED POLYOL) AND METHOD FOR MAKING AND USING THEREOF AS ASPHALT RUBBER MODIFIERS, ADHESIVE, FRACKING ADDITIVES, OR FRACKING FLUIDS - The present invention relates to a thermoplastic copolymer, block copolymer, and statistical copolymer comprising plural acrylated polyol monomeric units having different degrees of acrylation of hydroxyl groups. The acrylated polyol monomeric units have an average degree of acrylation greater than 1 and less than the number of the hydroxyl groups of the polyol. The present invention also relates to a method of making the thermoplastic copolymer, block copolymer, and statistical copolymer, and using them in various applications, such as asphalt rubber modifiers, adhesives, or an additive in a fracking fluid for oil fracking. | 11-26-2015 |
20150361326 | WELL TREATMENT FLUID MATERIAL AND WELL TREATMENT FLUID COMPRISING THE SAME - A well treatment fluid material comprising 100 parts by mass of polyester resin containing 50% by mass or more of a lactic acid resin and at least one of the degradation accelerators of 0.01 to 10 parts by mass of an organophosphorus compound and 10 to 50 parts by mass of a carboxylic acid anhydride. | 12-17-2015 |
20150368549 | DELAYED WATER-SWELLING MATERIALS AND METHOD OF USE - A water absorbing composition includes a particle having a core of a water-swelling material. A coating substantially surrounds the core that temporarily prevents contact of water with the water-swelling material. The coating may be formed from a layer of water degradable material or a non-water-degradable, non-water absorbent encapsulating layer. A quantity of particles including delayed water-swelling particles formed at least in part from a water-swelling material and, optionally, non-water-swelling particles of the same or different size distributions can be used in treating a formation penetrated by a wellbore. A slurry of the particles is formed with a carrier fluid. The slurry of particles is introduced into the wellbore of the formation to facilitate treatment. | 12-24-2015 |
20160032179 | A Proppant - A proppant includes a particle present in an amount of from 90 to 99.5 percent by weight and a polymeric coating disposed about the particle and present in an amount of from 0.5 to 10 percent by weight, based on the total weight of the proppant. The polymeric coating is formed from a curable composition comprising an isocyanate, an acrylate, and a polyol. A method of forming the proppant includes the steps of combining the isocyanate, the acrylate, and the polyol to form the curable composition, coating the particle with the curable composition, and curing the curable composition to form the polymeric coating. | 02-04-2016 |
20160032180 | Antimicrobial Resin Coated Proppants - The invention relates to polymeric coatings on proppants. These coatings have antimicrobial materials incorporated within these coatings. Preferably the antimicrobial materials have low water solubility. These antimicrobial agents are incorporated as particles whose surfaces are modified or these may also be incorporated within porous particles which are then added to the coating formulations. The antimicrobially active agents are incorporated in a fashion so that they can be released from these coatings in the environment of the proppants. | 02-04-2016 |
20160040060 | TREATMENT FLUIDS COMPRISING AN ALKALI METAL COMPLEXING AGENT AND METHODS FOR USE THEREOF - Alkali metal ions may lead to the production of insoluble materials during the course of stimulating a subterranean formation, particularly when acidizing a siliceous formation or a formation containing a siliceous material. Alkali metal ions may be sequestered using an alkali metal complexing agent in order to reduce their propensity toward forming insoluble materials in a subterranean formation. Methods for stimulating a subterranean formation can comprise: providing a treatment fluid that comprises an alkali metal complexing agent comprising a cyclic polyether having between 3 and 6 ether oxygen atoms present therein, and hydrofluoric acid, a hydrofluoric acid-generating compound, or any combination thereof; and introducing the treatment fluid into a subterranean formation. | 02-11-2016 |
20160068745 | SLICK-WATER FRACTURING USING TIME RELEASE METAL-COMPLEXING AGENT - In a slick-water fracturing operation, a composition is used to prevent the interaction between a polymer in a water-based fracturing fluid and naturally-occurring metal ions. The composition includes a metal-complexing agent, such as a chelating agent. The chelating agent can also be biodegradable and is citric acid in embodiments. The metal-complexing agent can be coated with one or two coatings to create a time-released form. The time-released form prevents loss of the agent prior to delivery at the shale. | 03-10-2016 |
20160090524 | ASPHALTENE INHIBITION - The technology disclosed herein provides compositions and methods for asphaltene control in a hydrocarbon fluid, such as crude oil, by employing a thiophosphonate ester compound. | 03-31-2016 |
20160102244 | DEGRADABLE FIBER FOR USE IN WELL TREATMENT FLUID, METHOD FOR MANUFACTURING SAME, AND WELL TREATMENT METHOD - A fiber formed from a resin that degrades in treatment fluid for hydrocarbon resource recovery, an oligomer component content of a resin forming an outer surface of the fiber being not greater than 1 mass %, and a birefringence of the fiber being not less than 0.02; a method for manufacturing a degradable fiber for use in well treatment fluid, the oligomer component content of a resin that forms an outer surface of an undrawn yarn obtained in a spinning step being not greater than 1 mass %, and a birefringence of a drawn yarn before heat treatment in a drawing step being not less than 0.02; and a well treatment method using the well treatment fluid containing the degradable fiber for use in well treatment fluid and a proppant. | 04-14-2016 |
20160122617 | DEGRADABLE BALLS FOR USE IN SUBTERRANEAN APPLICATIONS - Degradable balls for downhole use may include an incompliant degradable polymer and a compliant filler material, the incompliant degradable polymer having an elastic modulus of about 2 GPa or greater, and the compliant filler material having an elastic modulus of less than about 2 GPa. Such degradable balls may be useful in sealing segments of a wellbore and actuating wellbore tools. | 05-05-2016 |
20160137904 | PROPPANTS AND METHODS OF USE THEREOF - Proppants for use in fractured or gravel packed/frac packed oil and gas wells are provided with a treatment agent component that provides the proppant with one or more additional chemical, functions, and/or mechanical functions that can be used, for example, in oil and gas well production. | 05-19-2016 |
20160145486 | WELLBORE SERVICING COMPOSITIONS AND METHODS OF MAKING AND USING SAME - A wellbore servicing foam comprising a reducible material and a wellbore servicing material, wherein the wellbore servicing material is uniformly dispersed throughout the foam, and wherein the foam has (i) equal to or greater than 5% reticulated structure and (ii) a specific surface area of from about 0.1 m | 05-26-2016 |
20160160118 | FRACTURING FLUID FOR PREVENTION OF SHALE FRACTURE HYDRATION DURING WELL STIMULATION BY HYDRAULIC FRACTURING - Friction reducers for hydraulic fracturing fluids, hydraulic fracturing fluids containing the friction reducers, and methods of making and using same are disclosed. The friction reducers comprise ethylene oxide polymers, propylene oxide polymers, ethylene oxide-propylene oxide co-polymers, and combinations thereof, and can further comprise a dispersant, such as polypropylene glycol. The friction reducer formulations can be active across a wide range of brine salinities, and tolerant of high levels of divalent cations in solution. The friction reducers can have a cloud point temperature, above which temperature they can precipitate out of solution and deposit on a surface of a hydrocarbon-bearing formation to inhibit hydration of the shale formations lining the fractures. | 06-09-2016 |
20160168450 | ACID CURING AGENT INCLUSION AND METHOD FOR PRODUCING ACID CURING AGENT INCLUSION | 06-16-2016 |
20160186049 | COATED PROPPANTS CONTAINING HYPERBRANCHED POLYURETHANE COATINGS AND METHODS FOR USING SAME - Coated proppants that include hyperbranched polyurethane coatings and methods for making and using same. The coated proppant can include a particle and a polyurethane coating at least partially encasing the particle. The polyurethane coating can include a reaction product of a hyperbranched polyol and a polyisocyanate. The hyperbranched polyol can include a reaction product of a chain extender and a polyol monomer. The coated proppant can have a dry crush strength of about 0.1 wt % to about 5 wt % at a pressure of about 96.5 MPa, based on the Proppant Crush Resistance Test Procedure under ISO 13503-2:2011. | 06-30-2016 |
20160251571 | Resin Coated Proppants with Antimicrobial additives | 09-01-2016 |
20160376496 | A PROPPANT - A proppant includes a particle present in an amount of from 90 to 99.5 percent by weight based on the total weight of the proppant, and a polyurethane coating disposed about the particle and present in an amount of from 0.5 to 10 percent by weight based on the total weight of the proppant. The polyurethane coating comprises the reaction product of an isocyanate component and an isocyanate-reactive component comprising a polydiene polyol. | 12-29-2016 |