| Class / Patent application number | Description | Number of patent applications / Date published |
|---|
| 166300000 | Chemical inter-reaction of two or more introduced materials (e.g., selective plugging or surfactant) | 55 |
| 20090159288 | Chemically enhanced thermal recovery of heavy oil - Described herein are methods for removing heavy oils from underground reservoirs. The methods involve the use of chemical compositions in combination with steam techniques for the efficient removal of heavy oils. | 06-25-2009 |
| 20090159287 | IN-SITU FORMATION OF SOLIDS FOR WELL COMPLETIONS AND ZONAL ISOLATION - A sol of metallic alkoxide is pumped into a desired location in a wellbore and allowed to gel, creating solids in-situ. The sol is either unstabilized, requiring rapid placement before gelling, or the sol is stabilized, permitting off-site mixing. Sols can be stabilized with either surfactant or with interfacial polymers. Large concentrations of surfactant can be placed in the sol to create templates around which gelation occurs, creating porous solids. | 06-25-2009 |
| 20120181027 | Viscosified Fluids for Remediating Subterranean Damage - Method comprising introducing a first remedial fluid into a first portion of a subterranean formation, wherein the first remedial fluid comprises a base fluid and a viscosifying agent, and allowing the first remedial fluid to divert at least a portion of a second remedial fluid that comprises an oxidizer to a second portion of the subterranean formation. Wherein the viscosifying agent comprises at least one viscosifying agent selected from the group consisting of a gelling agent, an emulsifier, or a gas in combination with a foaming agent. Also wherein the polymeric gelling agent, if present, comprises at least one polymer selected from the group consisting of xanthan, diutans, wellans, succinoglycan, clarified biopolymers, scleroglycan, combinations thereof, and derivatives thereof. | 07-19-2012 |
| 20130112414 | Engineered Methods and Materials for Wellbore Strengthening in Subterranean Operations - A method of wellbore strengthening may include providing a wellbore strengthening fluid comprising a drilling fluid, a particulate, and a fiber; introducing the wellbore strengthening fluid into a wellbore penetrating a subterranean formation; and forming a plug comprising the particulate and the fiber in a void near the wellbore, the plug being capable of maintaining integrity at about 1000 psi or greater overbalance pressure. | 05-09-2013 |
| 20130112413 | Controlled Release Breaker Composition for Oil Field Applications - The present invention relates to encapsulated breakers and the use of encapsulated breakers for breaking viscosified treatment fluids. One embodiment of the present invention provides a method of providing a viscosified treatment fluid having a first viscosity having a gelling agent, a crosslinking agent, a proppant, an aqueous-base fluid, and an encapsulated breaker composition having an encapsulant that has a poly(meth)acrylate blend; introducing the viscosified treatment fluid in the subterranean formation; creating or enhancing a fracture in a subterranean formation; and allowing the encapsulated breaker composition to release the breaker so as to reduce the viscosity of the viscosified treatment fluid to a second viscosity. | 05-09-2013 |
| 20090301722 | SYSTEM, METHOD, AND APPARATUS FOR INJECTION WELL CLEAN-UP OPERATIONS - A method for removing drilling damage from a formation in a wellbore that has not been produced includes injecting a chemical-acting cleanup fluid and contacting it with a filtercake on a face of a formation of interest for a period of time sufficient to loosen some of the solids embedded in the filtercake. The method further includes circulating a solids removal fluid at a high rate through the wellbore across the face of the formation of interest, the solids removal fluid including a viscosifier, and positioning a second treatment fluid having a fluid loss control pill in the wellbore at the formation of interest. The method further includes degrading particles of the fluid loss control pill and degrading remaining bridging agent from the drilling fluid. | 12-10-2009 |
| 20090014179 | In Situ Conversion Of Heavy Hydrocarbons To Catalytic Gas - A method of producing natural gas from a heavy hydrocarbon-containing subterranean formation includes: placing a catalyst having at least one transition metal into the formation, injecting an anoxic stimulation gas into the formation, and collecting the natural gas generated in the formation. The method may be performed outside the context of a subterranean formation under controlled conditions. Thus, a method of producing natural gas from bitumen includes: providing an anoxic mixture of heavy hydrocarbons and a catalyst having at least one transition metal, adding an anoxic stimulation gas to the mixture, and heating the mixture in the presence of the stimulation gas. | 01-15-2009 |
| 20130126169 | Tight Gas Stimulation by In-Situ Nitrogen Generation - Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include nitrogen generating compounds, which upon activation, react to generate heat and nitrogen gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, heat and nitrogen gas are generated. Upon the generation of nitrogen gas and heat within the formation, microfractures are produced within the formation and the hydrostatic pressure within the reservoir is reduced to less than the reservoir fluid pressure, such that the rate of production of hydrocarbons from the formation is increased. | 05-23-2013 |
| 20120234544 | DEGRADABLE GELS IN ZONAL ISOLATION APPLICATIONS - A method of treating a formation that includes emplacing an oxidizing breaker fluid into a region of the formation occupied by a gel; and allowing sufficient time for the oxidizing breaker fluid to degrade the gel is disclosed. | 09-20-2012 |
| 20120234543 | Organic Acid Compositions and Methods of Use in Subterranean Operations - Methods comprising providing a treatment fluid that comprises using an aqueous base fluid, a synthetic cationic gelling agent, a plurality of particulates, and an organic acid. The treatment fluid is then introduced into at least a portion of a subterranean formation having a temperature of above about 275° F. wherein the particulates are deposited into the subterranean and the treatment fluid form at least one void in the subterranean formation itself. The viscosity of the treatment fluid in the subterranean formation is greater than about 20 cP for at least 20 minutes at temperatures higher than about 275° F. | 09-20-2012 |
| 20080296022 | Method for Treating Subterranean Formation - A method is provided for treating a subterranean formation penetrated by a well bore comprising the steps of:
| 12-04-2008 |
| 20110278008 | WELL TREATMENT FLUID COMPOSITIONS AND METHODS OF USE THAT INCLUDE A DELAYED RELEASE PERCARBONATE FORMULATION - A well treatment fluid and method of use includes water, at least one hydratable polymer, an optional crosslinking agent, and a delayed release percarbonate formulation effective to reduce initial viscosity of the fluid after a period of time. Also disclosed are processes for fracturing a subterranean formation. | 11-17-2011 |
| 20100314113 | Dual-Functional Breaker for Hybrid Fluids of Viscoelastic Surfactant and Polymer - Incorporating water-based polymer breakers, such as oxidizers, enzymes and/or acids, into a mixture of an oil and oil-soluble surfactants creates an emulsion that can then perform as a dual-functional breaker for reducing the viscosity of hybrid fluids gelled with both a viscoelastic surfactant (VES) and a polymer. The outer phase of the dual-functional breaker emulsion is oil, e.g. a mineral oil, containing an oil-soluble surfactant that will, over time and with heat, break the VES portion of the gel. As it does so, the polymer breaker in the internal aqueous phase will be released to then break the polymer portion of the gel. The polymer breaker will not start to break the polymer gel before the oil-soluble surfactant starts to break the VES gel. The overall breaking using the emulsion is slower as compared to introducing the polymer breaker and the oil-soluble surfactant in a non-emulsified form. | 12-16-2010 |
| 20110290489 | METHOD AND COMPOSITION - A method of controlling ingress of water into a production well used to extract fluid hydrocarbons the method comprising the steps of: introducing a composition comprising a polymer, a polar solvent, a cross-linking agent and a base oil into the production well; recovering hydrocarbons from the production well; wherein the polymer comprises an alcohol moiety. The density of the composition is preferably between 0.92 to 1.00 g/cm | 12-01-2011 |
| 20110290488 | Creation of a Hydrate Barrier During In Situ Hydrocarbon Recovery - Certain viscous oil reservoirs are too deep to be commercially mined but lack an adequate top seal to employ in situ recovery methods such as SAGD. Without an adequate top seal, gases from the reservoir can rise into overlying aquifers and potentially to the surface. While ice-like hydrates would not normally form above the oil reservoir during in situ recovery, an additive can be added to promote hydrate formation. In this way, a hydrate barrier can be formed to act as a top seal to contain these gases. | 12-01-2011 |
| 20090277638 | Methods of pumping fluids having different concentrations of particulate at different average bulk fluid velocities to reduce pump wear and maintenance in the forming and delivering of a treatment fluid into a wellbore - The inventions are for methods of forming and delivering a treatment fluid into a wellbore. In one aspect, methods are provided of pumping a first fluid having a relatively high concentration of a particulate suspended therein and pumping a second fluid having either none of the particulate or a relatively low concentration of the particulate suspended therein, and then merging at least the first and second fluids to form a treatment fluid having a merged concentration of the particulate. According to this aspect, the first and second fluids are pumped at different average bulk fluid velocities through different pumping chambers of fluid pumps. This helps reduce wear on the pumps. | 11-12-2009 |
| 20090255677 | Micro-Crosslinked Gels and Associated Methods - Provided are methods that include a method comprising: providing a micro-crosslinked gel that comprises micro-domains; and placing the micro-crosslinked gel into a subterranean formation via a well bore penetrating the formation at a desired pressure. In another aspect, the invention provides compositions that include a micro-crosslinked gel comprising a jigsaw configuration of micro-domains and particulates. | 10-15-2009 |
| 20110168393 | Methods of Using Fluid Loss Additives Comprising Micro Gels - Methods and fluids are provided that include, but are not limited to, a drilling fluid comprising an aqueous base fluid and a fluid loss control additive that comprises at least one polymeric micro gel and a method comprising: providing an aqueous based treatment fluid comprising a fluid loss control additive that comprises at least one polymeric micro gel; placing the aqueous based treatment fluid in a subterranean formation via a well bore penetrating the subterranean formation; allowing the fluid loss control additive to become incorporated into a filter cake located on a surface within the subterranean formation; allowing the filter cake to be degraded; and producing hydrocarbons from the formation. Additional methods are also provided. | 07-14-2011 |
| 20110203797 | GAS EVOLVING OIL VISCOSITY DIMINISHING COMPOSITIONS FOR STIMULATING THE PRODUCTIVE LAYER OF AN OIL RESERVOIR - The invention is directed to a chemical system of gas evolving oil viscosity diminishing compositions (GEOVDC) for stimulating the productive layer of an oil reservoir, that is to chemical compositions for a thermochemical treatment of an oil reservoir, more specifically for initiating a chemical reaction in the productive layer zone of the oil reservoir to produce heat and evolve gases so that the extraction of oil (petroleum) is improved. The invention is further directed to a method of thermochemically treating an oil reservoir by means of this chemical system, and to an apparatus for performing thermochemical treatment of an oil reservoir. | 08-25-2011 |
| 20080289827 | Viscosified fluids for remediating subterranean damage - Of the many methods and compositions provided herein, one method includes a method comprising introducing a viscosified remedial fluid comprising a base fluid, a viscosifying agent, and an oxidizer into at least a portion of a subterranean formation having damage present therein so as to contact the damage with the viscosified remedial fluid; and allowing the viscosified remedial fluid to at least partially remediate the damage present in the subterranean formation. Another method provided herein includes introducing a viscosified remedial fluid comprising a base fluid, a first viscosifying agent, and an oxidizer into at least a portion of a subterranean formation before a treatment fluid comprising a second viscosifying agent is introduced therein, wherein the oxidizer is available to remediate damage in the subterranean formation. | 11-27-2008 |
| 20100206567 | Gel Capsules for Solids Entrainment - The present invention is a method for treating a subterranean wellbore. More specifically, the invention is a method for removing wellbore solids. A first, polymer containing fluid is placed in the solids bed. A second, viscosifying fluid is then placed into the solids bed thereby agitating the solids in the bed and causing the formation of a gel capsules when mixed with the biopolymer fluid. These gel capsules are capable of trapping or entraining the agitated solids. The gel capsules typically have a relatively high volume and a relatively low density, thereby making their removal from the wellbore easier. | 08-19-2010 |
| 20120067579 | PROCESS FOR ENHANCED OIL RECOVERY USING THE ASP TECHNIQUE - The present invention relates to a process for the enhanced recovery of oil in a deposit owing to the introduction, into the deposit, of an alkaline aqueous solution of a water-soluble polymer containing a surfactant, characterized in that the aqueous solution of water-soluble polymer introduced is prepared with an aqueous solution initially containing Ca | 03-22-2012 |
| 20100175880 | Method of Using Crosslinkable Brine Containing Compositions - A method of enhancing the productivity of a subterranean formation penetrated by a gas, oil or geothermal well consists of introducing into the formation and/or well a pumpable polymerizable fluid comprising a crosslinkable, mono functional alkene, multi-functional alkene (such as a difunctional alkene), a heat inducible free radical initiator and brine. The fluid may be used in the thermal insulation of production tubing or transfer pipes and hydraulic fracturing. | 07-15-2010 |
| 20100186957 | FLUID PRESSURE TRANSMISSION PILL - A pill for wellbore operations, that includes a base fluid; and at least two polymers that interact to form a gelatinous structure characterized as isolating and controllably transmitting hydrostatic pressure between a first wellbore fluid above the pill in a wellbore and a second wellbore fluid below the pill in the wellbore is disclosed. | 07-29-2010 |
| 20100258313 | INVERT SILICATE FLUIDS FOR WELLBORE STRENGTHENING - A wellbore fluid that includes an oleaginous continuous phase; a non-oleaginous discontinuous phase comprising a water-soluble silicate therein; and an emulsifier to stabilize the non-oleaginous phase dispersed in the oleaginous phase is disclosed. A setting agent, including organic or inorganic setting agent may optionally be included to trigger gelation or precipitation of the silicate downhole. | 10-14-2010 |
| 20110232907 | LAMINAR PHASE RING FOR FLUID TRANSPORT APPLICATIONS - 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. | 09-29-2011 |
| 20100126726 | ALKALINE BETA-MANNANASE CONTAINING COMPOSITIONS USEFUL FOR THE HYDROLYSIS OF GUAR IN HIGH pH ENVIRONMENTS AND METHODS RELATED THERETO - Methods and compositions of fracturing formations are provided. The fracturing fluid includes an enzyme breaker that decreases the viscosity of the fracturing fluid over time. The enzyme breaker can be used in environments having a pH value ranging from about 7 to about 12. | 05-27-2010 |
| 20100252266 | Organic Acid Treating Fluids With Viscoelastic Surfactants and Internal Breakers - An aqueous fluid system that contains an aqueous dicarboxylic acid solution, a viscoelastic surfactant as a gelling agent to increase the viscosity of the fluid, and an internal breaker such as mineral oil and/or fish oil to controllably break the viscosity of the fluid provides a self-diverting acid treatment of subterranean formations. The internal breaker may be at least one mineral oil, a polyalphaolefin oil, a saturated fatty acid, and/or is an unsaturated fatty acid. The VES gelling agent does not yield viscosity until the organic acid starts to spend. Full viscosity yield of the VES gelling agent typically occurs at about 6.0 pH. The internal breaker allows the VES gelling agent to fully viscosify the spent organic acid at 6.0 pH and higher, but as the spent-acid VES gelled fluid reaching reservoir temperature, controllable break of the VES fluid viscosity over time can be achieved. | 10-07-2010 |
| 20100038086 | Conformance Control Through Stimulus-Responsive Materials - A method, apparatus and production well system that utilize stimulus-responsive materials for “conformance control” and profile control along the fluid flow path in a well as part of a gravel pack or a coating on a well tool. The stimulus-responsive materials are also known as intelligent or smart polymers and are typically polymeric materials that reversibly or irreversibly swell or collapse in the presence of stimulus such as changes in concentration of a fluid media in contact with the stimulus-responsive material, pH or polarity of the media the stimulus-responsive material is in contact with, salinity, current; or temperature. The stimulus-responsive materials may swell upon contact with a rust stimulus and shrink or collapse upon contact with a second stimulus or vice-versa The changes between production and injection profiles may be automatic with the application of the stimulus-responsive materials and may occur without user intervention. | 02-18-2010 |
| 20110100628 | METHODS OF DELAYING THE CURING OF MOISTURE SENSITIVE CURABLE ELASTOMERS - A method of treating a formation that includes injecting gelling components curable by a moisture cure into a selected region of the formation; and controlling the onset of curing of the gelling components by contacting the gelling components with a drying agent is disclosed. | 05-05-2011 |
| 20110048716 | Treatment Fluids Comprising Transient Polymer Networks - The invention relates to compositions and methods relating to treatment fluids that comprise transient polymer networks in subterranean applications. In one aspect, the invention provides a method comprising: providing a treatment fluid comprising an aqueous base fluid and a transient polymer network, and placing the treatment fluid in a subterranean formation. In another aspect, the invention provides a subterranean treatment fluid comprising: an aqueous-base fluid and a transient polymer network. | 03-03-2011 |
| 20090126932 | REVERSIBLE POLYMERIC GELATION FOR OILFIELD APPLICATIONS - This invention relates to the synthesis and use in oilfield applications of copolymers which can undergo the Diels-Alder reaction to form a gel. Under appropriate conditions, the retro Diels-Alder reaction can take place to provide for decreasing the viscosity of the aforementioned gel. | 05-21-2009 |
| 20080223578 | Polyelectrolyte Complexes as Delayed Gelling Agents for Oil and Gas Applications - A polyelectrolyte complex for the controlled or delayed gelation of a water and hydrocarbon producing subterranean formation. | 09-18-2008 |
| 20100319920 | METHODS FOR IMPROVING THE PRODUCTIVITY OF OIL PRODUCING WELLS - Methods for treating formations bearing brine and at least one of black oil or volatile oil using a composition containing a nonionic polymer and solvent. The solvent at least one of solubilizes or displaces at least one of brine or oil in the formation. Methods for making a composition for treating a formation bearing brine an at least one of black oil or volatile oil are also disclosed. | 12-23-2010 |
| 20110132609 | FORMATION FLUID SAMPLING TOOLS AND METHODS UTILIZING CHEMICAL HEATING - A formation fluid sampling tool is provided with reactants which are carried downhole and which are combined in order to generate heat energy which is applied to the formation adjacent the borehole. By applying heat energy to the formation, the formation fluids are heated, thereby increasing mobility, and fluid sampling is expedited. | 06-09-2011 |
| 20090183877 | Mesophase Fluids with Extended Chain Surfactants for Downhole Treatments - Mesophase fluids may be pre-formed or formed in situ and may be used downhole for various treatments including, but not limited to, cleaning up and removing non-polar materials from reservoir production zones, removing wellbore damage, releasing stuck pipe, components in spacers and pills and the like in oil and gas wells. These treatments involve solubilization of the non-polar material into the emulsion when the treatment fluid contacts non-polar materials. These mesophase fluids use extended chain surfactants having propoxylated/ethoxylated spacer arms. The extended chain surfactants are intramolecular mixtures containing hydrophilic and lipophilic portions. They attain high solubilization in the mesophase fluids (e.g. single phase microemulsions), are in some instances insensitive to temperature and are useful for a wide variety of oil types. | 07-23-2009 |
| 20080217012 | Gelled emulsions and methods of using the same - Gelled emulsions contain (i.) an external phase of an aqueous water-soluble solvent solution, polymeric viscosifying agent and, optionally, an oxidative and/or acidic breaker; and (ii.) an internal phase of a dispersed organic fluid. The aqueous water-soluble solvent solution constitutes between from about 15 to about 50 volume percent of the gelled emulsion and the dispersed organic fluid is presented in the gelled emulsion in amounts ranging from about 50 to about 85 volume percent. The gelled emulsions are useful in a variety of applications including, but not limited to, oil field, pipeline and processing facility applications. | 09-11-2008 |
| 20080217013 | TUNABLE SURFACTANTS FOR OIL RECOVERY APPLICATIONS - The systems and methods described herein provide for modified lignins and other compositions that may be useful as surfactants. These compositions have particular utility for energy-related applications. In embodiments, they may be useful for enhanced oil recovery. In embodiments, they may be useful for extracting bitumen from oil sands. In embodiments, they may be useful for environmental remediation. | 09-11-2008 |
| 20110303412 | 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. 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/hr·ft·° F. | 12-15-2011 |
| 20110303411 | SWELLABLE/DEGRADABLE "SAND" PLUG SYSTEM FOR HORIZONTAL WELLS - This invention relates to a swellable and degradable sand plug system used in horizontal wellbores and the use of the system in treating horizontal wellbores. The slurry composition comprises a carrier fluid and a granular borate source material, where the borate source material is at least partially dehydrated or anhydrous. The carrier fluid may be a non-aqueous fluid, or when the average size of the granular borate source material is sufficient large, the carrier fluid may also be an aqueous fluid. The slurry composition is allowed to settle in the horizontal wellbore and at least partially fill at least a portion of the horizontal wellbore in a direction vertical to the substantially horizontal wellbore, and is exposed to a sufficient amount of aqueous fluid to expand to the point to substantially fill at least a portion of the horizontal wellbore in a direction vertical to the horizontal wellbore, thereby plugging the substantially horizontal wellbore. The slurry composition may be further exposed to a sufficient amount of aqueous liquid to at least partially dissolve the expanded slurry composition, thereby at least partially removing the plug from the substantially horizontal wellbore. | 12-15-2011 |
| 20120037368 | CONTROLLED RELEASE PROPPANT - Materials are delivered into oil well reservoirs. Highly sensitive, mechanical, biological and chemical agents can be delivered to subterranean formations with rigid, impermeable capsules. A variety of treatments may be delivered to a subterranean formation. | 02-16-2012 |
| 20110315383 | GELATION ACCELERATION - The invention provides a method made of steps of injecting into a wellbore, a composition comprising a solvent, a crosslinkable polymer, a crosslinking agent capable of crosslinking the polymer or forming a polymer, and a gelling accelerator selected from the group consisting of carbon dioxide, polylactic acid, encapsulated acid and latent acid; and allowing viscosity of the composition to increase and form a gel more quickly with the gelling accelerator than without. | 12-29-2011 |
| 20110005756 | USE OF ZETA POTENTIAL MODIFIERS TO DECREASE THE RESIDUAL OIL SATURATION - Compositions and methods for their use are disclosed, where the compositions comprise an amine component, an amine/phosphate ester component and optionally a solvent component. The compositions are adapted to coat solid materials, substrates and/or surfaces of producing of reservoirs and formations and methods for making and using same, where the coating agents modify surface properties of the solid materials, substrates and/or surfaces of producing formations decreasing residual oil saturation. | 01-13-2011 |
| 20120152544 | COLD WEATHER COMPATIBLE CROSSLINKER SOLUTION - Disclosed herein is a well treatment fluid comprising an aqueous solution comprising greater than or equal to about 1 wt % boron, at least 5 wt % of a co-solvent, and greater than or equal to about 5 wt % sodium hydroxide, potassium hydroxide, or a combination thereof, wherein the co-solvent comprises glycerol, ethylene glycol, propylene glycol, or a combination thereof. Methods of using the well treatment fluid are also disclosed. | 06-21-2012 |
| 20110088902 | DIVERTING AGENTS FOR WATER SHUT OFF - A method of retarding the flow of water in a subterranean formation that includes injecting a gelling pill into the formation, the gelling pill comprising: brine; a crosslinkable polymer; and a crosslinkant; and allowing the crosslinkable polymer to crosslink to form a gel in the subterranean formation is disclosed. A water absorbing polymer is optionally included. | 04-21-2011 |
| 20120247772 | Method for Isolating and Completing Multi-Zone Gravel Packs - A gel barrier may be created within an annulus in a one-step operation by combining two or more solutions within the annulus. The two solutions may include a first solution, such as a silicate solution, and a second solution that may be an aqueous hardener solution. Once the two solutions are combined and subsequently reacted together, the forming of a gel barrier may occur between a plurality of zones along the annulus. The gel barrier may then prevent a fluid from traveling between adjacent zones of the wellbore annulus. | 10-04-2012 |
| 20100012323 | BEAD PACK BRAZING WITH ENERGETICS - A method of making porous shapes from unit structures such as beads involves coating the beads with two or more layers of material deposited such that it forms an energetic material. These bi-layer energetic materials are formed from a variety of materials including, but not limited to: Ti & B, Zr & B, Hf & B, Ti & C, Zr & C, Hf & C, Ti & Si, Zr & Si, Nb & Si, Ni & Al, Zr & Al, or Pd & Al, all of which can be deposited from vapor. Pressure is applied to prevent the components from moving and the solid-state reaction between the alternating layers produces exothermic heat. Heat from the reaction alone or in conjunction of an applied brazing compound joins the beads forming a porous shape that is desired. The reaction in the materials may be activated with a small pulse of local energy that can be applied using optical, electrical, or thermal sources. Common examples include an electrical pulse, spark, hot filament, a laser beam, etc. The method reduces energy consumption and the need for specialized equipment. The reactive materials and optional brazing material are preferably applied in a fluidized CVD furnace. | 01-21-2010 |
| 20100270017 | DELAYED BREAKER - A process that includes pumping a first wellbore fluid comprising an oxidative degradable polymer into a wellbore through a subterranean formation; pumping a second wellbore fluid comprising a pH-activated oxidative breaker into the wellbore; pumping a third wellbore fluid comprising a delayed acid source into the wellbore; and allowing the delayed acid source to acidify at least a portion of the wellbore to a pH of less than 7 so as to activate the pH-activated oxidative breaker at the lower pH and degrade the oxidative degradable polymers is disclosed. | 10-28-2010 |
| 20100326660 | USE OF DIRECT EPOXY EMULSIONS FOR WELLBORE STABILIZATION - A direct emulsion wellbore fluid, including: a continuous non-oleaginous phase; a discontinuous oleaginous phase; a stabilizing agent; an oil-miscible epoxy-based resin; and a hardening agent; wherein the wellbore fluid is a stable emulsion having a viscosity greater than 200 cps. In some embodiments, the hardening agent is an oil-miscible hardening agent; in other embodiments, the hardening agent is an oil-immiscible hardening agent. | 12-30-2010 |
| 20120267109 | METHOD OF TREATING A FRACTURED WELL - This invention relates to a method of treating a tight gas well that has been fractured with a gel solution to increase the production of hydrocarbons. The gel solutions used for fracturing typically include an aqueous portion and a polymer material. Generally, the first step of the method is to apply a soak solution to the fractured formation to mix with the aqueous portion of the gel solution to increase the volatility of the aqueous portion. The next step is to apply a dry gas treatment to the tight gas well to remove the aqueous portion of the gel solution after the volatility has been increased. | 10-25-2012 |
| 20120318510 | METHODS OF GENERATING MAGNETIC PARTICLES IN A SUBTERRANEAN ENVIRONMENT - The subject disclosure relates to methods of generating magnetic particles in a wellbore. More particularly, the subject disclosure relates to a fluid system which comprises two or more fluids which react chemically to generate magnetic particles in a wellbore. | 12-20-2012 |
| 20120279711 | Environmentally Friendly Low Temperature Breaker Systems and Related Methods - An embodiment of the present invention includes a method comprising: (a) providing a filter cake on a surface in a subterranean formation, the filter cake comprising a polymer and a bridging agent; (b) providing a filter cake clean-up fluid that comprises an aqueous fluid and L-glutamic acid N,N-diacetic acid; and (c) contacting the filter cake with the filter cake clean-up fluid so that a portion of the subterranean formation neighboring the filter cake has a regain permeability of at least about 86%. | 11-08-2012 |
| 20120285685 | Method of Using Asparaginase as a Polyacrylamide Enzyme Breaker - Asparaginase, such as asparaginase derived from | 11-15-2012 |
| 20120138303 | Methods of Providing Fluid Loss Control or Diversion - Methods of controlling fluid loss, providing fluid diversion, or plugging a portion of a well bore using a treatment fluid including relatively insoluble borate material particulates that are placed into a subterranean formation to provide the desired action and then degrade over time in the subterranean formation in the presence of an aqueous fluid such as water. | 06-07-2012 |
| 20100132948 | Delayed Breaking of Well Treatment Fluids - An embodiment of a downhole method of breaking of a well treatment fluid relates to overcrosslinking a polymeric thickener with an overcrosslinking agent such as an excess crosslinking agent and/or an excess alkaline material, wherein either or both the agent and/or material may be encapsulated. | 06-03-2010 |
