| Entries |
| Document | Title | Date |
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| 20080271888 | Methods of Using Viscoelastic Surfactant Gelled Fluids to Pre-Saturate Underground Formations - Viscoelastic surfactant (VES) based fluid systems are effective to pre-saturate high permeability subterranean formations prior to a treatment operation that would undesirably suffer from high fluid leakoff. The fluid systems may include brine, a viscosity enhancer, as well as the VES, and a high temperature stabilizer. The stabilizer may be an alkaline earth metal oxide, alkaline earth metal hydroxide, alkali metal oxide, alkali metal hydroxide, Al | 11-06-2008 |
| 20090025933 | System, Method, and Apparatus for Acid Fracturing with Scale Inhibitor Protection - A method for treating a subterranean formation includes forming a treatment fluid including a carrier fluid, a solid acid-precursor, and a solid scale inhibitor. The solid acid-precursor includes a material that forms an acid at downhole conditions in the subterranean formation. The method further includes adding a solid acid-responsive material into the treatment fluid, where the solid acid-responsive material enhances formation of acid from the solid acid-precursor in acidic conditions. The method includes performing an acid fracture treatment and inhibiting scale formation within the subterranean formation. The solid scale inhibitor allows for long-term scale inhibition after the treatment. | 01-29-2009 |
| 20090266542 | CAPILLARY INJECTOR - Provided is a mineral extraction system, including a branch having a branch passage, a diverter coupled to the branch passage, and a capillary injection conduit disposed inside to the branch passage. Further provided is a method of injecting chemicals, including injecting a chemical into a capillary injection conduit disposed internal to a production passage, wherein the chemical injection capillary conduit comprises an inlet and an outlet configured to terminate proximate a well formation. | 10-29-2009 |
| 20090272534 | METHODS OF USING VISCOELEASTIC SURFACTANT GELLED FLUIDS TO PRE-SATURATE UNDERGROUND FORMATIONS - Viscoelastic surfactant (VES) based fluid systems are effective to pre-saturate high permeability subterranean formations prior to a treatment operation that would undesirably suffer from high fluid leakoff. The fluid systems may include brine, a viscosity enhancer, as well as the VES, and a high temperature stabilizer. The stabilizer may be an alkaline earth metal oxide, alkaline earth metal hydroxide, alkali metal oxide, alkali metal hydroxide, Al | 11-05-2009 |
| 20100051272 | LIQUIFIED PETROLEUM GAS FRACTURING METHODS - Methods of tailoring a hydrocarbon fracturing fluid for a subterranean formation are disclosed. Fluid in the subterranean formation has a fluid temperature. A first critical temperature of a hydrocarbon fluid is adjusted to a critical temperature above the fluid temperature by adding a liquefied petroleum gas component to the hydrocarbon fluid to produce the hydrocarbon fracturing fluid. The liquefied petroleum gas component has a second critical temperature, and the hydrocarbon fluid comprises liquefied petroleum gas. A hydrocarbon fracturing fluid made by these methods are also disclosed. Methods of treating a subterranean formation are also disclosed. A hydrocarbon fracturing fluid is introduced into the subterranean formation, the hydrocarbon fracturing fluid having a critical temperature that is above a fluid temperature of the hydrocarbon fracturing fluid when the hydrocarbon fracturing fluid is in the subterranean formation. The hydrocarbon fracturing fluid is subjected to pressures above the formation pressure. | 03-04-2010 |
| 20100089578 | Prevention of Water Intrusion Into Particulates - Treatments and compounds useful in subterranean formations are discussed, with particular attention to those where particulates may be subject to water intrusion. Certain methods pertain to providing diffusion barriers for particulates. Of these, certain diffusion barriers may provide hydrophobic coatings to the particulates, certain diffusion barriers may provide fillers that may act to prevent water intrusion into surface features of particulates, and certain diffusion barriers may be initiated with diagenesis source material. | 04-15-2010 |
| 20100186954 | METHODS FOR CONTROLLING WATER AND PARTICULATE PRODUCTION IN SUBTERRANEAN WELLS - Improved methods for stabilizing unconsolidated subterranean formation particulates and reducing permeability of a subterranean formation to water. Some methods describe methods of stabilizing unconsolidated subterranean formation particulates and reducing the permeability of water comprising providing a portion of a subterranean formation that comprises unconsolidated formation particulates; introducing a fluid comprising a relative permeability modifier into at least a portion of the subterranean formation so as to at least partially reduce the permeability of that portion of the subterranean formation to water; and, introducing a fluid comprising a consolidating agent into at least a portion of the subterranean formation so as to at least partially consolidate the unconsolidated formation particulates. | 07-29-2010 |
| 20110048707 | SELECTIVE PLACEMENT OF CONFORMANCE TREATMENTS IN MULTI-ZONE WELL COMPLETIONS - Selective placement of conformance treatments in multi-zone well completions. A method includes injecting a relative permeability modifier into a zone and optimizing a ratio of desired fluid to undesired fluid produced from the zone, including adjusting at least one flow control device between fully open and fully closed configurations. Another method includes injecting a relative permeability modifier into multiple zones, one at a time, via respective flow control devices, and then producing fluid from each of the zones. Another method includes identifying which of the zones to treat by, for each of the zones: a) closing flow control devices corresponding to the other zones, and b) evaluating fluid produced from the zone; and injecting a conformance treatment into the zones identified as the zones to treat. | 03-03-2011 |
| 20110162841 | Continuous Slow Dissolving Chemical Treatment for Oil and Gas Wells - The invention relates to dispensing slow release chemicals for inhibiting the formation of scale, corrosion or other precipitates in hydrocarbon wells. The chemical is provided into a dispenser positioned for at least nearly continuous exposure to liquid preferably in the active water phase. The active water phase is generally just below the inlet into production tubing. | 07-07-2011 |
| 20110162842 | METHOD OF TREATING THE AREA SURROUNDING ACID GAS STORAGE WELLS - Method of treating the area surrounding an acid gas storage well ( | 07-07-2011 |
| 20120067576 | TREATMENT FLUIDS CONTAINING A BIODEGRADABLE CHELATING AGENT AND METHODS FOR USE THEREOF - Of the many methods provided herein, an example is a method including: providing a treatment fluid that comprises: an aqueous base fluid; a hydrofluoric acid source selected from the group consisting of hydrofluoric acid, a hydrofluoric acid generating compound, and a combination thereof; and a biodegradable chelating agent comprising one of the following selected from the group consisting of: glutamic acid diacetic acid, a glutamic acid diacetic acid salt, a derivative thereof, and a combination thereof; and introducing the treatment fluid into at least a portion of a subterranean formation. | 03-22-2012 |
| 20120073811 | IN SITU PROCESS FOR MERCURY REMOVAL - Methods and system relate to in-situ treatment of fluid to remove a heavy metal, such as mercury. The treatment utilizes a sorbent injected into a wellbore and disposed in a flow path of the fluid being produced to above ground. The mercury retained by the sorbent upon contact with the fluid may remain within a reservoir from which the fluid is recovered. | 03-29-2012 |
| 20120080189 | DEGRADABLE COMPOSITIONS, APPARATUS COMPRISING SAME, AND METHODS OF USE - Compositions, apparatus incorporating a composition, and methods of use are described, one composition embodiment consisting essentially of one or more reactive metals in major proportion, and one or more alloying elements in minor proportion, with the provisos that the composition is high-strength, controllably reactive, and degradable under defined conditions. Compositions of the invention may exist in a variety of morphologies, including a reactive metal or degradable alloy processed into an alloy of crystalline, amorphous or mixed structure that may constitute the matrix of other composition, for instance a composite. Methods of using apparatus comprising a composition, particularly in oilfield operations are also described (e.g. flow and displacement control, sensors, actuators). This abstract allows a searcher or other reader to quickly ascertain the subject matter of the disclosure. It will not be used to interpret or limit the scope or meaning of the claims. | 04-05-2012 |
| 20120097392 | Treatment Fluids Containing Biodegradable Chelating Agents and Methods for Use Thereof - Treatment fluids containing biodegradable chelating agents and methods for use thereof are described. The methods can comprise providing a treatment fluid that comprises an aqueous base fluid and a chelating agent composition, and introducing the treatment fluid into at least a portion of a subterranean formation. The treatment fluids can also be used for treatment of pipes or tubing such as, for example, well bore pipes or tubing penetrating a subterranean formation and above-ground pipelines. Illustrative biodegradable chelating agents include, but are not limited to, glutamic acid diacetic acid, methylglycine diacetic acid, β-alanine diacetic acid, S,S-ethylenediaminedisuccinic acid, iminodisuccinic acid, hydroxyiminodisuccinic acid, any salt thereof, any derivative thereof, and any combination thereof. The treatment fluids can optionally comprise an acid, which can include hydrofluoric acid or a hydrofluoric acid generating compound. | 04-26-2012 |
| 20120097393 | METHODS FOR TREATING CARBONATE HYDROCARBON-BEARING FORMATIONS WITH FLUORINATED AMPHOTERIC COMPOUNDS - Method of treating a carbonate hydrocarbon-bearing formation. The method includes contacting the hydrocarbon-bearing formation with a composition comprising solvent and a fluorinated amphoteric compound. Carbonate hydrocarbon-bearing formations treated according to the method are also disclosed. | 04-26-2012 |
| 20120111564 | Methods and Compositions for Altering the Viscosity of Treatment Fluids Used in Subterranean Operations - Methods of decreasing the viscosity of a treatment fluid through contact with a cyclodextrin modifier. Such methods include providing a cyclodextrin modifier; providing a treatment fluid that comprises a base fluid and a viscosifying agent wherein the viscosifying agent is selected from the group consisting of a hydrophobically modified polymer, a viscoelastic surfactant, a phosphonate surfactant, or a combination thereof; and, introducing the cyclodextrin modifier and the treatment fluid into a well bore penetrating a subterranean formation wherein the viscosity of the treatment fluid is decreased due to the combination of the hydrophobically modified polymer and the cyclodextrin modifier. | 05-10-2012 |
| 20120132421 | HYDROLYZABLE PARTICLE COMPOSITIONS, TREATMENT FLUIDS AND METHODS - A composition, treatment fluid and method using hydrolyzable fines. A treatment fluid, which may optionally include a high solids content fluid (HSCF) and/or an Apollonianistic solids mixture, includes a fluid loss control agent comprising a dispersion of hydrolyzable fines, optionally with one or more of a surfactant, plasticizer, dispersant, degradable particles, reactive particles and/or submicron particles selected from silicates, γ-alumina, MgO, γ-Fe2O3, TiO2, and combinations thereof. | 05-31-2012 |
| 20120132422 | INTERPOLYMER CROSSLINKED GEL AND METHOD OF USING - Disclosed herein is a gel comprising, polyacrylamide crosslinked with a non-metallic crosslinker, the non-metallic crosslinker comprising a polyamine. A method of making the gel and a method of using the gel are also disclosed. | 05-31-2012 |
| 20120132423 | Compositions and Methods for Treatment of Well Bore Tar - Of the many compositions and methods provided herein, one method includes a method comprising: contacting tar resident in a well bore with a tar stabilizing polymer comprising at least one polymer selected from the group consisting of a styrene polymer, an acrylate polymer, a styrene-acrylate polymer, and any combination thereof; and allowing the tar stabilizing polymer to interact with the tar to at least partially reduce the tendency of the tar to adhere to a surface. | 05-31-2012 |
| 20120138294 | INTERPOLYMER CROSSLINKED GEL AND METHOD OF USING - Disclosed herein is a gel or a gel concentrate comprising, polyacrylamide crosslinked with a non-metallic crosslinker comprising a polylactam. A well treatment fluid comprising the gel or the gel concentrate, a method of making the gel or the gel concentrate, and a method of using the gel or the gel concentrate are also disclosed. | 06-07-2012 |
| 20120160486 | IN-SITU KEROGEN CONVERSION AND RECOVERY - Disclosed herein are methods for extracting a kerogen-based product from subsurface (oil) shale formations. These methods rely on chemically modifying the shale-bound kerogen using a chemical oxidant so as to render it mobile. The oxidant is provided to a formation fluid in contact with the kerogen in the subsurface shale. An alkaline material is also provided to the formation fluid to mobilize organic acids which are produced during oxidation of the kerogen. A mobile kerogen-based product which includes the organic acids is withdrawn from the subsurface shale formation and further processed to isolate the organic acids contained therein. | 06-28-2012 |
| 20120160487 | METHOD AND COMPOSITION FOR ENHANCED HYDROCARBON RECOVERY FROM A FORMATION CONTAINING A CRUDE OIL WITH SPECIFIC SOLUBILITY GROUPS AND CHEMICAL FAMILIES - A method of treating a formation containing crude oil with specific solubility groups and chemical families is described. The method includes (a) providing a hydrocarbon recovery composition to at least a portion of a formation containing crude oil with specific solubility groups and chemical families, wherein the composition comprises a C | 06-28-2012 |
| 20120175114 | IN-SITU KEROGEN CONVERSION AND PRODUCT ISOLATION - Disclosed herein are methods for extracting a kerogen-based product from subsurface (oil) shale formations. These methods rely on chemically modifying the shale-bound kerogen using a chemical oxidant so as to render it mobile. The oxidant is provided to a formation fluid in contact with the kerogen in the subsurface shale. A mobile kerogen-based product which includes the organic acids is withdrawn from the subsurface shale formation and processed to isolate the organic acids contained therein. An exemplary method for isolating the acids includes treating the mobile kerogen-based product such that at least a portion of the organic acids form a separate phase from the mobile kerogen-based product. The organic acids may further be extracted from the mobile kerogen-based product using an organic extraction fluid. | 07-12-2012 |
| 20120175115 | IN-SITU KEROGEN CONVERSION AND PRODUCT UPGRADING - Disclosed herein are methods for extracting a kerogen-based product from subsurface (oil) shale formations. These methods rely on chemically modifying the shale-bound kerogen using a chemical oxidant so as to render it mobile. The oxidant is provided to a formation fluid in contact with the kerogen in the subsurface shale. A mobile kerogen-based product which includes the organic acids is withdrawn from the subsurface shale formation and processed to isolate the organic acids contained therein. The isolated organic acids are upgraded by a reaction process that make the products suitable as refinery feedstocks, fuel or lubricant blendstocks, reaction intermediates, chemical feedstocks, or chemical intermediate blendstocks. | 07-12-2012 |
| 20120175116 | IN-SITU KEROGEN CONVERSION AND RECYCLING - Disclosed herein are methods for extracting a kerogen-based product from subsurface (oil) shale formations. These methods rely on chemically modifying the shale-bound kerogen using a chemical oxidant so as to render it mobile. The oxidant is provided to a formation fluid in contact with the kerogen in the subsurface shale. An alkaline material is also provided to the formation fluid to mobilize organic acids which are produced during oxidation of the kerogen. A mobile kerogen-based product which includes the organic acids is withdrawn from the subsurface shale formation and further processed to isolate the organic acids contained therein. These organic acids are valuable as hydrocarbon products for creating commercial products and a portion of these organic acids can also be used in the process for extracting the kerogen-based product from the subsurface shale formation. | 07-12-2012 |
| 20120181025 | METHOD AND COMPOSITION FOR ENHANCED HYDROCARBONS RECOVERY FROM A VERY HIGH SALINITY, HIGH TEMPERATURE FORMATION - A method of treating a very high salinity high temperature hydrocarbon containing formation is described. The method includes (a) providing a hydrocarbon recovery composition to at least a portion of a hydrocarbon containing formation having a brine salinity of above about 13 wt % and a temperature of above about 7° C., wherein the composition comprises a C | 07-19-2012 |
| 20120186811 | METHODS FOR STIMULATING OIL OR GAS PRODUCTION USING A VISCOSIFIED AQUEOUS FLUID WITH A CHELATING AGENT TO REMOVE CALCIUM CARBONATE AND SIMILAR MATERIALS FROM THE MATRIX OF A FORMATION OR A PROPPANT PACK - A method for treating a portion of a subterranean formation or a proppant pack is provided. In general, the method comprises the steps of: (A) forming or providing a treatment fluid comprising: (i) water; (ii) a chelating agent capable of forming a heterocyclic ring that contains a metal ion attached to at least two nonmetal ions; and (iii) a viscosity-increasing agent; and (B) introducing the treatment fluid into the wellbore under sufficient pressure to force the treatment fluid into the matrix of the formation or the proppant pack. | 07-26-2012 |
| 20120193095 | Hydrocarbon Recovery Operations Fluids and Methods For Using the Same - Fluids for use in hydrocarbon recovery operations include a non-aqueous fluid and at least one organo-anionic surfactant. The fluids may be used in methods for conducting hydrocarbon recovery operations, such as drilling operations, completion operations, production operations, injection operations. The fluid may be adapted to remediate a NAF filter cake. Exemplary organo-anionic surfactants may include one or more of monoethanol ammonium alkyl aromatic sulfonic acid, monoethanol ammonium alkyl carboxylic acid, and mixtures thereof. | 08-02-2012 |
| 20120211227 | Well Treatment Compositions and Methods Utilizing Nano-Particles - Disclosed embodiments relate to well treatment fluids and methods that utilize nano-particles. Exemplary nano-particles are selected from the group consisting of particulate nano-silica, nano-alumina, nano-zinc oxide, nano-boron, nano-iron oxide, and combinations thereof. Embodiments also relate to methods of cementing that include the use of nano-particles. An exemplary method of cementing comprises introducing a cement composition into a subterranean formation, wherein the cement composition comprises cement, water and a particulate nano-silica. Embodiments also relate to use of nano-particles in drilling fluids, completion fluids, simulation fluids, and well clean-up fluids. | 08-23-2012 |
| 20120247763 | BIOMASS-BASED OIL FIELD CHEMICALS - Microbial biomass from oleaginous microbes provides a cost-efficient, biodegradable additive for use in well-related fluids. The biomass is useful as a fluid loss control agent, viscosity modifier, emulsifier, lubricant, or density modifier. | 10-04-2012 |
| 20120255732 | ULTRAFINE GRINDING OF SOFT MATERIALS - Compositions and methods pertaining to the ultrafine grinding of soft materials are disclosed. In one embodiment, a method comprises the step of mixing a soft material with an additive to form a mixture. The method further comprises raising the temperature of the mixture to at least the glass transition temperature of the soft material. The method further comprises cooling the temperature of the mixture. The method further comprises grinding the mixture to form ultrafine particles that comprise at least a portion of the soft material. | 10-11-2012 |
| 20120261125 | Horizontal In-Well Treatment System and Source Area Bypass System and Method For Groundwater Remediation - The application relates to a sustainable and green remedial approach for in situ remediation. The system and method use directionally drilled horizontal wells filled with granular reactive media generally installed in the direction of groundwater flow for groundwater remediation. “Flow-focusing” behavior is leveraged to capture and passively treat proportionally large volumes of groundwater in situ. The system and method perform well in low hydraulic conductivity environments where the success of other in situ remediation methods is controlled by aquifer injectability. Reactive media are selected according to the contaminants to be treated and site characteristics. Energy conservation and other considerations result in considerable cost savings compared to current in situ remediation systems. Also disclosed is a source area bypass system comprising one or more horizontal wells, constructed in a manner to allow unimpacted or cleaner groundwater to bypass a nonaqueous phase liquid zone or high-concentration source area of contamination and discharge downgradient. Reactive media may or may not be used in a source area bypass system. In some configurations, groundwater pumps may be installed to enhance performance. Core elements of green remediation according to the United States Environmental Protection Agency are achieved. | 10-18-2012 |
| 20120267102 | Nano-Sized Particles for Formation Fines Fixation - A treating fluid may contain an effective amount of a particulate additive to fixate or reduce fines migration, where the particulate additive is an alkaline earth metal oxide alkaline earth metal hydroxide, alkali metal oxides, alkali metal hydroxides transition metal oxides, transition metal hydroxides, post-transition metal oxides, post-transition metal hydroxides piezoelectric crystals and pyroelectric crystals. The particle size of the magnesium oxide or other agent may be nanometer scale, which scale may provide unique particle charges that help fixate the formation fines. These treating fluids may be used as treatment fluids for subterranean hydrocarbon formations, such as in hydraulic fracturing, completion fluids, gravel packing fluids and fluid loss pills. The carrier fluid used in the treating fluid may be aqueous, brine, alcoholic or hydrocarbon-based. | 10-25-2012 |
| 20120267103 | DEGRADABLE FIBER SYSTEMS FOR STIMULATION - A method for minimizing the amount of metal crosslinked viscosifier necessary for treating a wellbore with proppant or gravel is given. The method includes using fibers to aid in transporting, suspending and placing proppant or gravel in viscous carrier fluids otherwise having insufficient viscosity to prevent particulate settling. Fibers are given that have properties optimized for proppant transport but degrade after the treatment into degradation products that do not precipitate in the presence of ions in the water such as calcium and magnesium. Crosslinked polymer carrier fluids are identified that are not damaged by contaminants present in the fibers or by degradation products released by premature degradation of the fibers. | 10-25-2012 |
| 20120298357 | Compositions and systems for combatting lost circulation and methods of using the same - A method of servicing a wellbore in a subterranean formation comprising placing a first stream comprising a dilute solution of a metal acrylate into a lost circulation zone in the subterranean formation; placing a second stream comprising an activator into the lost circulation zone; and forming a lost circulation material upon contacting of the metal acrylate and the activator, wherein the lost circulation material forms in from about 0 to about 60 minutes. A method of servicing a wellbore in a subterranean formation comprising placing a composition comprising a dilute solution of a cross-linkable material and an encapsulated activator into a lost circulation zone in the subterranean formation; and allowing the composition to set. | 11-29-2012 |
| 20120305245 | METHODS TO IMPROVE STABILITY OF HIGH SOLID CONTENT FLUID - A method of treating a subterranean formation of a well bore comprises providing a treatment fluid comprising a carrier fluid, a particulate material, a viscosifying agent and fumed silica, wherein fumed silica is in such concentration to reduce the settling rate of the particulate material in the treatment fluid; and introducing the treatment fluid into the wellbore. | 12-06-2012 |
| 20120305246 | SHEAR-ACTIVATED VISCOELASTIC SURFACTANT FLUID AND METHOD - A well treatment composition is formed from a fluid mixture of a viscoelastic surfactant and a liquid carrier fluid. The fluid mixture has rheological properties wherein the mixture exhibits shear-thickening behavior when the shear rate is increased from a first shear rate to a second higher shear rate. The fluid mixture may further include a shear activation additive that interacts with the viscoelastic surfactant to facilitate the shear-thickening behavior. The method is accomplished by introducing the fluid mixture into a wellbore formed in a subterranean formation. In certain applications, the fluid mixture may be recycled by bringing the fluid mixture to the surface and reintroducing the fluid into the same or a different wellbore. | 12-06-2012 |
| 20120325471 | ENCAPSULATED MATERIALS AND THEIR USE IN OIL AND GAS WELLS - A subterranean formation penetrated by a wellbore is treated by introducing into the wellbore an encapsulated material comprising an encapsulating component formed from a regenerated ionic-liquid-dissolved compound and an active component that is encapsulated by the encapsulating component. The encapsulating material is then allowed to release the active component into the formation. In another treatment method, an encapsulated material comprising an encapsulating component and an active component that is encapsulated by the encapsulating component are introduced into the wellbore. The encapsulating component is degradable when subjected to electromagnetic radiation having a frequency of from about 300 MHz to about 300. The encapsulated material is then subjected to electromagnetic energy in the frequency range of from about 300 MHz to about 300 GHz to degrade the encapsulating component and facilitate the release the active component into the formation. | 12-27-2012 |
| 20130000900 | DOWN-HOLE PLACEMENT OF WATER-SWELLABLE POLYMERS - Methods and fluids are provided for the placement of a water-swellable polymer into a subterranean formation. The methods and fluids include a placement fluid that has an acidic aqueous phase. The water-swellable polymer does not substantially swell in the acidic aqueous phase. The acid is allowed or caused to be spent downhole, whereby the water-swellable polymer can then swell in the formation. In an embodiment, an oil-external emulsion having an internal acidic water phase is provided for placement of a water-swellable polymer into a subterranean formation. Preferably, the oil-external emulsion is adapted to break as the acid contained in the internal water phase is allowed or caused to be spent downhole. | 01-03-2013 |
| 20130020081 | 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 | 01-24-2013 |
| 20130020082 | METHOD AND COMPOSITIONS FOR ENHANCED OIL RECOVERY - A flooding fluid for use in petroleum recovery from a petroleum-bearing formation is prepared by mixing an oxygen scavenger consisting essentially of an alkaline aqueous solution of at least one water-soluble borohydride with an aqueous or nonaqueous input fluid having oxygen dissolved therein to reduce the level of dissolved oxygen. | 01-24-2013 |
| 20130025860 | Composite Particulates and Methods Thereof for High Permeability Formations - Composite particulates for use in high permeability subterranean formations may contain, at least, a gel particulate having a solid particulate incorporated. Some methods of using the diverting agent may include introducing a treatment fluid comprising a base fluid and a diverting agent into at least a portion of a subterranean formation and allowing the diverting agent to bridge fractures, provide fluid loss control, seal the rock surfaces for fluid diversion, or plug an area along the annulus of a wellbore. | 01-31-2013 |
| 20130025861 | Methods and Systems for In-Situ Extraction of Bitumen - A method for carrying out in-situ bitumen extraction can include a step of forming one or more vertical freeze walls within or around a deposit of bituminous material and establishing a laterally confined deposit of bituminous material; a step of injecting a solvent within the laterally confined deposit of bituminous material; a step of withdrawing a mixture of dissolved bitumen and solvent from within the laterally confined deposit of bituminous material; a step of injecting water within the laterally confined deposit of bituminous material; and a step of withdrawing a mixture of solvent and water from within the laterally confined deposit of bituminous material. | 01-31-2013 |
| 20130032344 | METHODS FOR MONITORING FLUIDS WITHIN OR PRODUCED FROM A SUBTERRANEAN FORMATION USING OPTICOANALYTICAL DEVICES - In or near real-time monitoring of fluids can take place using an opticoanalytical device that is configured for monitoring the fluid. Fluids can be monitored prior to or during their introduction into a subterranean formation using the opticoanalytical devices. Produced fluids from a subterranean formation can be monitored in a like manner. The methods can comprise providing a treatment fluid comprising a base fluid and at least one additional component; introducing the treatment fluid into a subterranean formation; allowing the treatment fluid to perform a treatment operation in the subterranean formation; and monitoring a characteristic of the treatment fluid or a formation fluid using at least a first opticoanalytical device within the subterranean formation, during a flow back of the treatment fluid produced from the subterranean formation, or both. | 02-07-2013 |
| 20130032345 | METHODS FOR MONITORING FLUIDS WITHIN OR PRODUCED FROM A SUBTERRANEAN FORMATION DURING ACIDIZING OPERATIONS USING OPTICOANALYTICAL DEVICES - In or near real-time monitoring of fluids can take place using an opticoanalytical device that is configured for monitoring the fluid. Fluids can be monitored prior to or during their introduction into a subterranean formation using the opticoanalytical devices. Produced fluids from a subterranean formation can be monitored in a like manner. The methods can comprise providing an acidizing fluid comprising a base fluid and at least one acid; introducing the acidizing fluid into a subterranean formation; allowing the acidizing fluid to perform an acidizing operation in the subterranean formation; and monitoring a characteristic of the acidizing fluid or a formation fluid using at least a first opticoanalytical device within the subterranean formation, during a flow back of the acidizing fluid produced from the subterranean formation, or both. | 02-07-2013 |
| 20130048282 | Fracturing Process to Enhance Propping Agent Distribution to Maximize Connectivity Between the Formation and the Wellbore - A method of treating a subterranean formation may include placing a first treatment fluid into a subterranean formation through an access conduit connecting the subterranean formation to a wellbore at a pressure sufficient to form at least a portion of a fracture network; pumping a second treatment fluid comprising a propping agent into the fracture network such that the propping agent forms a proppant pack in at least a portion of the fracture network; placing a third treatment fluid comprising a secondary diverting agent into the fracture network so as to substantially inhibit fluid flow through at least a portion of the fracture network without substantially inhibiting fluid flow through the access conduit; and placing a fourth treatment fluid comprising a primary diverting agent into the wellbore such that the primary diverting agent substantially inhibits fluid flow through the access conduit. | 02-28-2013 |
| 20130056203 | REDUCING SULFIDE IN OIL RESERVOIR PRODUCTION FLUIDS - Methods are provided for treating production fluid in an oil reservoir to reduce the amount of sulfide in the production fluid. The production fluid is treated with nitrate and/or nitrite ions in an aqueous solution that is added to an injection well that is in contact with the production well. | 03-07-2013 |
| 20130081811 | IN SITU FLUID RESERVOIR STIMULATION PROCESS - Methods and processes for in-situ stimulation of hydrocarbon containing formations using energy to expand in-situ liquid hydrocarbons, thus rejuvenating naturally occurring fractures. In some embodiments, the energy is supplied as heat from injection of an oxygen containing fluid. | 04-04-2013 |
| 20130087330 | LOST-CIRCULATION MATERIAL MADE FROM A RECYCLED MATERIAL CONTAINING ASHPALT - A composition comprises: a treatment fluid comprising a lost-circulation material, wherein the lost-circulation material comprises asphalt, and wherein the lost-circulation material has a median particle size in the range from about 0.001 millimeters to about 25.4 millimeters. According to another embodiment, the composition comprises: a treatment fluid comprising a lost-circulation material, wherein the lost-circulation material comprises asphalt, and wherein the median particle size and the concentration of the lost-circulation material is selected such that the treatment fluid has a sealing pressure of at least 30 psi (0.2 MPa). A method of eliminating or reducing lost circulation from a well comprises: introducing the treatment fluid into at least a portion of the well. | 04-11-2013 |
| 20130087331 | LOST-CIRCULATION MATERIAL MADE FROM A RECYCLED CERAMIC - A composition comprises: a treatment fluid comprising a lost-circulation material, wherein the lost-circulation material comprises a ceramic, and wherein the lost-circulation material has a median particle size in the range from about 0.001 millimeters to about 25.4 millimeters. According to another embodiment, a composition comprises: the treatment fluid comprising a lost-circulation material, wherein the lost-circulation material comprises a ceramic, and wherein the median particle size and the concentration of the lost-circulation material is selected such that the treatment fluid has a sealing pressure of at least 50 psi (0.3 MPa). A method of eliminating or reducing lost circulation from a well comprises: introducing the treatment fluid into at least a portion of the well. | 04-11-2013 |
| 20130098612 | PROCESS FOR PRODUCING MINERAL OIL USING SURFACTANTS BASED ON A MIXTURE OF C24 GUERBET-, C26 GUERBET-, C28-GUERBET CONTAINING HYDROCARBYL ALKOXYLATES - The present invention relates to a surfactant mixture comprising at least three ionic surfactants which differ in terms of the hydrocarbyl moiety (R | 04-25-2013 |
| 20130118739 | Real Time Downhole Sensor Data for Controlling Surface Stimulation Equipment - A system, method and apparatus for stimulating a reservoir is disclosed. A slurry is supplied to the work string at the surface, which work string extends from the surface location to a downhole location adjacent the reservoir. A parameter of the slurry is measured at the downhole location and transmitted to the surface location. A control unit at the surface location receives the measured parameter of the slurry and estimates a fracture conductivity of the reservoir using the measured parameter of the slurry. The control unit may alter the parameter of the slurry at the surface location to obtain a selected fracture conductivity to stimulate the reservoir. | 05-16-2013 |
| 20130118740 | Well Completion Methods Using Gellable Treatment Fluids Having Long Term Thermal Stability of the Gelled State - Gellable treatment fluids containing a terpolymer that comprises 2-acrylamido-2-methylpropanesulfonic acid, acrylamide, acrylic acid monomer units can be used in various subterranean operations where it is necessary for the treatment fluid to remain in a gelled state for extended periods of time at high formation temperatures. Methods for treating a subterranean formation can comprise providing a treatment fluid comprising an aqueous carrier fluid, a crosslinking agent, a gel stabilizer, and a terpolymer that comprises 2-acrylamido-2-methylpropanesulfonic acid, acrylamide, and acrylic acid monomer units, or any salt thereof; introducing the treatment fluid into a subterranean formation; allowing the treatment fluid to form a gel in the subterranean formation; and breaking the gel after it has been in the subterranean formation for at least about one day. | 05-16-2013 |
| 20130126159 | METHOD AND COMPOSITION FOR CEMENTING A CASING IN A WELLBORE - Methods and compositions for treating a formation, proximate a wellbore, prior to primary cementing, by reacting an activating agent and a silicate to provide a barrier between the wellbore and the formation to reduce the contamination of cement by ingress of formation fluids or leakage of cement from the wellbore during cement transitional phases. The activating agent may be provided while the wellbore is being drilled or may be provided subsequent to drilling or may be at least partially naturally occurring in the formation prior to drilling. The silicate may be provided during or subsequent to drilling. | 05-23-2013 |
| 20130133886 | Time-delay Fluids for Wellbore Cleanup - A method for delaying the removal of a majority of an oil-based mud (OBM) filter cake from a hydrocarbon reservoir wellbore that utilizes a multiple phase composition is described. The use of the multiple phase composition allows for a microemulsion, a miniemulsion, or a nanoemulsion to form in situ downhole at a controllable time. The method includes pumping the multiple phase composition comprising an additive into the wellbore. The multiple phase composition may be broken thereby releasing the additive. The broken multiple phase composition and the additive may contact the OBM filter cake particles to form an in situ emulsion selected from the group consisting of a nanoemulsion, a miniemulsion, a microemulsion, a multiple emulsion, a water-continuous emulsion and mixtures thereof. The in situ emulsion may incorporate more of the external oil from the OBM filter cake in order to more easily remove the OBM filter cake. | 05-30-2013 |
| 20130161001 | PRECONDITIONING A SUBSURFACE SHALE FORMATION BY REMOVING EXTRACTIBLE ORGANICS - Disclosed herein are methods for extracting an organics component from subsurface shale formations comprising kerogen and an extractible organics component in an inorganic matrix. Among other factors, these processes are based on the discovery that to more easily access the kerogen in oil shale, it is helpful to first remove the extractible organics component from the subsurface shale formation. The methods utilize a hydrocarbon solvent to at least partially solubilize the extractible organics component. The extractible organics component can be isolated and upgraded to produce useful products. The presently disclosed processes are more environmentally benign, more economical, and more efficient in producing commercial products and in providing access to kerogen. | 06-27-2013 |
| 20130161002 | In-Situ Kerogen Conversion and Oxidant Regeneration - Disclosed herein are methods for extracting a kerogen-based product from subsurface shale formations. The methods utilize in-situ reactions of kerogen involving liquid phase chemistry at formation temperatures and pressures. These methods rely on chemically modifying the shale-bound kerogen to render it mobile, using chemical oxidants. In the methods disclosed herein an oxidant is provided to the subsurface shale formation comprising kerogen in an inorganic matrix, the oxidant converting the kerogen to form organic acids, and forming a mobile kerogen-based product. The spent oxidant is regenerated in-situ to restore at least some of the original oxidation activity. At least a portion of the mobile kerogen-based product is recovered. The kerogen-derived product can be upgraded to provide commercial products. | 06-27-2013 |
| 20130180713 | IN-SITU CROSSLINKING WITH ALUMINUM CARBOXYLATE FOR ACID STIMULATION OF A CARBONATE FORMATION - A method of treating a zone of a subterranean carbonate formation penetrated by a wellbore is provided. The method includes the steps of: According to an embodiment, a method of treating a zone of a subterranean carbonate formation penetrated by a wellbore is provided, the method including the steps of: (a) forming a treatment fluid comprising: (i) water; (ii) a water-soluble polymer having at least one functional group that can be crosslinked with aluminum(III); and (iii) a water-soluble aluminum carboxylate; wherein the pH of the treatment fluid is less than 1; (b) introducing the treatment fluid through the wellbore into the zone; and (c) allowing time for the strong acid in the treatment fluid to spend in the formation such that the pH of the fluid increases sufficiently for the aluminum of the aluminum carboxylate to crosslink the polymer. | 07-18-2013 |
| 20130192826 | COMPOSITION AND METHOD FOR RECOVERING HYDROCARBON FLUIDS FROM A SUBTERRANEAN RESERVOIR - A composition comprising crosslinked expandable polymeric microparticles capable of hydrolysis at or below neutral pH and a method of modifying the permeability to water of a subterranean formation by introducing such compositions into the subterranean formation is disclosed and claimed. This invention further relates to compositions and methods for the recovery of hydrocarbon fluids from a subterranean reservoir or formation subjected to CO | 08-01-2013 |
| 20130220607 | METHODS OF USING CELLULOSE IN VARIOUS OILFIELD APPLICATIONS - Described herein is a method of well treatment that includes providing a well treatment composition containing a non-functionalized cellulose material and a halide salt composition containing at least zinc halide, calcium halide or a mixture thereof, and placing the well treatment composition within a wellbore or a subterranean formation, and wherein the halide salt composition dissolves at least a portion of the non-functionalized cellulose material. | 08-29-2013 |
| 20130233542 | SYSTEM AND METHOD FOR DELIVERING TREATMENT FLUID - The current application discloses methods and systems for preparing a pump-ready treatment fluid, delivering the pump-ready treatment fluid to a location operationally coupled to a wellsite, providing the pump-ready treatment fluid to a pump; and pumping the pump-ready treatment fluid into a wellbore. In some embodiments, the treatment fluid is a fracturing fluid for conducting a hydraulic fracturing operation on a subterranean formation penetrated by a wellbore. | 09-12-2013 |
| 20130233543 | Nitrogen-containing compounds as corrosion inhibitors - The present invention relates to nitrogen-containing hydroxyethyl substituted compounds to be used as corrosion inhibitors for metal surfaces, for example in aqueous systems and in particular in oil-field applications, e.g. in oil or gas wells, and which could be used under sweet-well conditions as well as under sour-well conditions. It may also be used in oil-field acidizing and fracture-acidizing well stimulation treatment. The compounds belong to the group of partly ethoxylated fatty alkylamines, partly ethoxylated alkyletheramines and partly or fully hydroxyethyl substituted alkylamidopropylamines. The corrosion inhibitors have the formula (I) where R is a hydrocarbyl or an acyl group having 14-24 carbon atoms, or the group R′OCH | 09-12-2013 |
| 20130233544 | SYSTEM AND PROCESS FOR INHIBITOR INJECTION - A method for introducing inhibitor into a fluid to be treated by forming a dispersion comprising droplets, particles, or gas bubbles of inhibitor dispersed in a continuous phase of a carrier, wherein forming the dispersion comprises subjecting a mixture of the inhibitor and the carrier to a shear rate of greater than about 20,000 s | 09-12-2013 |
| 20130255944 | HYDRATED SHEET SILICATE MINERALS FOR REDUCING PERMEABILITY IN A WELL - A method of treating a treatment zone in a well is provided. The method includes the step of introducing into the treatment zone: (a) a hydrated sheet silicate mineral; and (b) a chemical activator for expanding the hydrated sheet silicate mineral. According to an embodiment, a method of treating a treatment zone in a well, where the method includes the steps of, in any order: (a) introducing into the treatment zone a first treatment fluid, wherein the first treatment fluid includes: (i) a hydrated sheet silicate mineral; and (ii) water; and (b) introducing into the zone a second treatment fluid including a chemical activator for expanding the hydrated sheet silicate mineral in the treatment zone. | 10-03-2013 |
| 20130269936 | Treatment Fluids Comprising a Silicate Complexing Agent and Methods for Use Thereof - Treatment fluids comprising a silicate complexing agent can be used in conjunction with acidizing a subterranean formation that contains a siliceous material. Inclusion of the silicate complexing agent in the treatment fluids may eliminate or reduce the production of insoluble fluorosilicates and aluminosilicates that can occur when an acidizing operation is conducted. Methods for treating a subterranean formation can comprise: providing a treatment fluid that comprises a silicate complexing agent comprising a tertiary amine compound, a functionalized pyridine compound, any salt thereof, or any combination thereof; and hydrofluoric acid, a hydrofluoric acid-generating compound, or any combination thereof; and introducing the treatment fluid into a subterranean formation. | 10-17-2013 |
| 20130269937 | Acidizing Fluids Comprising a Salt Block Inhibitor and Methods for Use Thereof - Treatment fluids comprising hydrofluoric acid, a hydrofluoric acid-generating compound, or any combination thereof can be used in conjunction with acidizing a subterranean formation that contains a siliceous material. Inclusion of a salt block inhibitor in the treatment fluids may eliminate or reduce the formation of insoluble fluorosilicates and aluminosilicates that can occur when an acidizing operation is conducted. Methods for treating a subterranean formation can comprise: providing a treatment fluid that comprises a salt block inhibitor comprising a fructan, and hydrofluoric acid, a hydrofluoric acid-generating compound, or any combination thereof; and introducing the treatment fluid into a subterranean formation. | 10-17-2013 |
| 20130306314 | Methods for Protecting a Hydrocarbon-Producing Zone of a Subterranean Formation Using a Relative Permeability Modifier - A relative permeability modifier may be used to protect a hydrocarbon-producing zone of a subterranean formation without detrimentally affecting its ability to produce hydrocarbons. Methods for protecting a hydrocarbon-producing zone of a subterranean formation can comprise: introducing a first treatment fluid comprising a relative permeability modifier to a hydrocarbon-producing zone of a subterranean formation also comprising a water-producing zone; concurrently with or after introducing the first treatment fluid to the hydrocarbon-producing zone, introducing a second treatment fluid comprising a sealant composition to the water-producing zone; and allowing the relative permeability modifier to substantially prevent the sealant composition from entering the hydrocarbon-producing zone. | 11-21-2013 |
| 20130312961 | Biomimetic Adhesive Compositions Comprising a Phenolic Polymer and Methods for Use Thereof - Biomimetic adhesive compositions can be used in various aspects of subterranean treatment operations. Methods for treating a subterranean formation can comprise: providing an adhesive composition that comprises a first polymer comprising a plurality of monomers that comprise a phenolic moiety, a biopolymer that is crosslinkable with the first polymer, a crosslinking agent, and an oxidizing agent; introducing the adhesive composition into a subterranean formation; and forming a coacervate-bound surface in the subterranean formation by crosslinking the first polymer. | 11-28-2013 |
| 20130333888 | SELF-DEGRADING IONICALLY CROSS-LINKED BIOPOLYMER COMPOSITION FOR WELL TREATMENT - A method of treating a well including the steps of: (A) forming a treatment fluid comprising: (i) water; (ii) a water-soluble β-polysaccharide selected from the group consisting of a β-galactomannan, a water-soluble derivative thereof retaining β-O-glycosidic linkages and a mannose:galactose of at least 5:1; and any combination thereof; (iii) a borate cross-linker; (iv) a base to adjust the pH of the water in the treatment fluid to be at least 8.5; and (v) a water-soluble α-polysaccharide or water-soluble derivative thereof retaining α-O-glycosidic linkages; and (B) introducing the treatment fluid into the well. | 12-19-2013 |
| 20130341022 | Methods of Using Nanoparticle Suspension Aids in Subterranean Operations - Methods of drilling wellbores, placing proppant packs in subterranean formations, and placing gravel packs in wellbores may involve fluids, optionally foamed fluids, comprising nanoparticle suspension aids. Methods may be advantageously employed in deviated wellbores. Some methods may involve introducing a pad treatment fluid into at least a portion of the subterranean formation at a pressure sufficient to create or extend at least one fracture in the subterranean formation; introducing a proppant slurry treatment fluid into at least a portion of a subterranean formation, the treatment fluid comprising a base fluid, proppant particles, and a nanoparticle suspension aid; and forming a proppant pack in the fracture. | 12-26-2013 |
| 20140000889 | WIRELINE FLOW THROUGH REMEDIATION TOOL | 01-02-2014 |
| 20140000890 | Fracturing Fluids and Methods For Treating Hydrocarbon-Bearing Formations | 01-02-2014 |
| 20140034308 | METHOD AND APPARATUS FOR REMOTE ZONAL STIMULATION WITH FLUID LOSS DEVICE - Methods and apparatus for running a completion string with sand screen assemblies through multiple zones are presented allowing sequential stimulation of zones, and production without multiple trips. An exemplary method includes running a completion string and isolating target zones. If desired, the formation can be produced prior to stimulation. To stimulate the zones, a first tubing valve is closed, for example by ball-drop, forcing fluid through the first screen assembly. After stimulating the zone is complete, a first screen valve is closed by increased tubing pressure. The first work string valve is re-opened by further increasing tubing pressure. A subsequent tubing valve is then closed, for example, by flowing the ball to the next ball seat. The process is repeated until all zones are stimulated. Valves are then opened at each screen assembly to allow production flow through the screen assemblies. | 02-06-2014 |
| 20140048260 | Hydration Acceleration Surfactants in Conjunction with High Molecular Weight Polymers, and Methods and Compositions Relating Thereto - A hydration acceleration surfactant may be utilized in conjunction with high molecular weight polymers in forming high viscosity, aqueous based treatment fluids. Forming such fluids may involve mixing an aqueous base fluid, a hydration acceleration surfactant, a crosslinker polymer, and a base polymer, thereby yielding a treatment fluid, wherein the base polymer is provided in the form of a first polymeric emulsion before mixing and/or the crosslinker polymer is provided in the form of a second polymeric emulsion before mixing. Further, such fluids may be useful in subterranean operations to perform for at least one function within the wellbore and/or the subterranean formation including bridge a fracture, provide fluid loss control, seal a rock surface, enable fluid diversion, plug a void, reduce formation permeability, control water production, and any combination thereof. | 02-20-2014 |
| 20140048261 | Treatment Fluids Comprising a Stabilizing Compound Having Quaternized Amine Groups and Methods for Use Thereof - Methods for mitigating precipitation during matrix acidizing of a subterranean formation. The methods generally comprise introducing a treatment fluid into a subterranean formation. The treatment fluid comprises a chelating agent; a hydrofluoric acid source; and a stabilizing compound. The stabilizing compound has two or more quaternized amine groups. In some cases the treatment fluid further comprises alkali metal ions. | 02-20-2014 |
| 20140090841 | METHODS AND COMPOSITIONS FOR ENHANCED OIL RECOVERY - A method of recovering crude oil from a subterranean hydrocarbon-containing formation, comprises the steps: i) injecting into said formation an enhanced oil recovery composition comprising a) a surfactant having the general formula: R1-X—R2, wherein R1 is an open chain sugar alcohol, wherein X is one selected from NH, NCH | 04-03-2014 |
| 20140096964 | NANOPARTICLE MODIFIED FLUIDS AND METHODS OF MANUFACTURE THEREOF - Disclosed herein is a nanoparticle modified fluid that comprises nanoparticles; and a liquid carrier; where the nanoparticles have their surfaces modified so as to increase the viscosity of the nanoparticle modified fluid above that of a comparative nanoparticle modified fluid that contains the same nanoparticles whose surfaces are not modified, when both nanoparticle modified fluids are tested at the same shear rate and temperature. | 04-10-2014 |
| 20140102703 | Pressure Actuated Ported Sub for Subterranean Cement Completions - A shifting sleeve has differential piston areas so that applied pressure displaces the sleeve against spring bias, which preferably is a series of Belleville washer stacks associated with modular mandrel components, to obtain the desired opposing force to the movement initiated with pressure applied to differential piston areas. An indexing feature is located between the sleeve and the mandrel passage wall and on a predetermined number of cycles disables the Belleville washer stacks from biasing the sleeve in an opposed direction as when pressure is applied. At this time the pressure in the mandrel acting on the differential piston area simply shifts the sleeve to open a lateral port so that fracturing through the cement that was earlier placed with the port closed can take place. | 04-17-2014 |
| 20140116695 | EMULSIFIED ACID WITH HYDROPHOBIC NANOPARTICLES FOR WELL STIMULATION - A composition in the form of an emulsion having: (i) a continuous oil phase comprising: (a) an oil; (b) an emulsifier; and (c) a particulate comprising an oxide selected from the group consisting of metal oxides, metalloid oxides, and any combination thereof, wherein the particulate is hydrophobically modified, would not dissolve in oil or 28% hydrochloric acid, and has a surface area in the range of 700 m | 05-01-2014 |
| 20140116696 | Compositions And Methods Related To Mitigating Aluminum And Ferric Precipitates In Subterranean Formations After Acidizing Operations - Trivalent-ion chelating agents may be useful in mitigating the formation aluminum and ferric precipitates in subterranean formations during acidizing operations. An acidizing operation may include introducing an acidizing fluid into a wellbore penetrating a subterranean formation, the acidizing fluid comprising an aqueous fluid, an acid source, and a trivalent-ion chelating agent, e.g., hydroxamates, 6,7-dihydroxyquinoline, 3-hydroxy-4-pyridinones, and any combination thereof. In some instances, trivalent-ion chelating agents with a pKa of less than about 7 may be particularly useful in acidizing operations. | 05-01-2014 |
| 20140166282 | FUNCTIONALIZED HYDROGEN SULFIDE SCAVENGERS - Functionalized alpha-hydroxy alkyl ethers have been found to perform as non (or anti-) scaling hydrogen sulfide scavengers. A method of scavenging hydrogen sulfide includes contacting a fluid containing hydrogen sulfide with a treatment fluid including a functionalized alpha-hydroxy alkyl ether. Accordingly, the alpha-hydroxy alkyl ether reacts with the hydrogen sulfide to reduce the amount of hydrogen sulfide in the fluid. The functionalized alpha-hydroxy alkyl ether is functionalized with a phosphate group, phosphonate group, sulfate group, or sulfonate group. A broad range of alpha-hydroxy alkyl ethers are disclosed. | 06-19-2014 |
| 20140190692 | PRODUCTION-TREATING CHEMICALS ADDED TO POLYMER SLURRIES USED IN TREATMENT OF OIL AND GAS WELLS - Production-treating chemicals, such as paraffin inhibitors, corrosion inhibitors and scale inhibitors are provided along with water-soluble polymers in a base oil phase to be used in a well treatment. The mixture may be provided as a separate product or mixed at a well site when performing a well treatment, such as hydraulic fracturing, acidizing or gravel packing. | 07-10-2014 |
| 20140196897 | OXIDATIVE INTERNAL BREAKER SYSTEM WITH BREAKING ACTIVATORS FOR VISCOELASTIC SURFACTANT FLUIDS - Compositions and methods are given for delayed breaking of viscoelastic surfactant gels inside formation pores, particularly for use in hydraulic fracturing. Breaking inside formation pores is accomplished without mechanical intervention or use of a second fluid. Bromate oxidizing agents are used along with selected breaking activators for the bromate breaking compounds. Useful bromate breaking activators include acid-generating breaking activators, oxidizing sulfur containing breaking activators, and reducing agent breaking activators. | 07-17-2014 |
| 20140209306 | Wellbore Treatment Tool And Method - A wellbore treatment tool for setting against a constraining wall in which the wellbore treatment tool is positionable, the wellbore treatment tool including: a tool body including a first end formed for connection to a tubular string and an opposite end; a no-go key assembly including a tubular housing and a no-go key, the tubular housing defining an inner bore extending along the length of the tubular housing and an outer facing surface carrying the no-go key, the no-go key configured for locking the no-go key and tubular housing in a fixed position relative to the constraining wall, the tubular housing sleeved over the tool body with the tool body installed in the inner bore of the tubular housing; and a sealing element encircling the tool body and positioned between a first compression ring on the tool body and a second compression ring on the tubular housing, the sealing element being expandable to form an annular seal about the tool body by compression between the first compression ring and the second compression ring. | 07-31-2014 |
| 20140262261 | METHODS AND COMPOSITIONS FOR STIMULATING THE PRODUCTION OF HYDROCARBONS FROM SUBTERRANEAN FORMATIONS - Methods and compositions for stimulating of the production of hydrocarbons (e.g., formation crude oil and/or formation gas) from subterranean formations are provided. In some embodiments, the compositions are emulsions or microemulsions, which may include water, a terpene, and a surfactant. In some embodiments, methods of selecting a composition for treating an oil or gas well are provided. | 09-18-2014 |
| 20140284053 | METHODS AND COMPOSITIONS FOR USE IN OIL AND/OR GAS WELLS - Methods and compositions comprising an emulsion or a microemulsion for use in various aspects of the life cycle of an oil and/or gas well are provided. In some embodiments, the emulsion or the microemulsion comprises water, a solvent, and a surfactant, and optionally, one or more additives. | 09-25-2014 |
| 20140332212 | COMPOSITIONS AND METHODS FOR ENHANCED HYDROCARBON RECOVERY - Compositions of and methods of using a fluid formulation for increasing flow, production, and/or recovery of oil and gas hydrocarbons from a subterranean formation. | 11-13-2014 |
| 20140338902 | POLYSACCHARIDE DELIVERY UNIT FOR WELLBORE TREATMENT AGENT AND METHOD - A method of treating a subterranean formation. The method may include providing a well treatment including a treatment complex formed of a treatment agent encapsulated, entrapped, or embedded in a polysaccharide, introducing the treatment complex into a wellbore through a subterranean formation, and allowing the treatment complex to release the treatment agent over a release time period. The method may include allowing the treatment complex to release the treatment agent after a delay time period from the introduction of the treatment complex into the wellbore. | 11-20-2014 |
| 20140338903 | METHOD FOR ENHANCED OIL RECOVERY BY IN SITU CARBON DIOXIDE GENERATION - The method for enhanced oil recovery by in situ carbon dioxide generation utilizes a chelating fluid injected into an oil reservoir through a fluid injection system. The chelating fluid is a low pH solution of a polyamino carboxylic acid chelating agent. The polyamino carboxylic acid chelating agent may have a concentration of about 5 wt %. The polyamino carboxylic acid chelating agent is preferably either an aqueous solution of H | 11-20-2014 |
| 20140338904 | SYSTEMS AND METHOD FOR SEPARATING DIMETHYL ETHER FROM OIL AND WATER - A system is provided for removing dimethyl ether (DME) from oil, water or brine and gas that includes a gas-oil-water separation module, a DME absorber, a water stripper, a liquid-liquid extractor, a water source, and an oil stripper, and a process is provided for separating DME from a mixture of DME, crude oil, water or brine, and a gas containing alkane hydrocarbons. A DME lean oil containing at most 1 ppmwt may be produced by the process. | 11-20-2014 |
| 20140360719 | ENHANCED OIL RECOVERY METHOD - A method for producing oil from a fractured oil bearing formation is provided in which an oil recovery formulation comprising water and dimethyl ether is introduced into a fracture in the formation to mobilize oil, the mobilized oil is contacted with water or brine, and the mobilized oil is produced from the formation at a location positioned upwards from the fracture. | 12-11-2014 |
| 20150007989 | VISCOELASTIC SURFACTANTS CROSSLINKED WITH DIVALENT IONS AND METHODS FOR MAKING AND USING SAME - Viscoselastic surfactant systems including at least one viscoelastic surfactant and at least one divalent metal compound, where the systems are useable for enhancing oil production in oil wells that coproduce high volumes of gas and/or water and for enhancing gas injection uniformity into injection formations and methods including treating producing or injecting formations with the systems to enhance oil production in treated producing zones or enhance injection efficiency in injection zones. | 01-08-2015 |
| 20150027702 | METHODS OF TREATMENT OF A SUBTERRANEAN FORMATION WITH POLYMERIC STRUCTURES FORMED IN SITU - Methods of treating a subterranean formation are disclosed that include placing a treatment fluid into a subterranean formation, the treatment fluid containing a one or more polymers capable of consolidating to form a polymeric structure at a downhole location. Also disclosed are treatment fluids including a polymeric structure for treating a subterranean formation. | 01-29-2015 |
| 20150041131 | METHODS AND COMPOSITIONS FOR USING TEMPORARY, SLOW DEGRADING, PARTICULATE AGENTS IN A SUBTERRANEAN FORMATION - Methods, fluids, and compositions are provided for treating subterranean formations. The fluids can be servicing or drilling fluids including a base fluid and a particulate agent or biocide precursor particulate agent. The particulate agent can seal flow paths in the subterranean formation and subsequently can be degraded to allow flow to resume. The particulate agent may be a reaction product of a urea containing compound and an aldehyde containing compound. An example of such a reaction product is a methylene urea. | 02-12-2015 |
| 20150053402 | FIBER PASTE AND METHODS FOR TREATING A SUBTERRANEAN FORMATION WITH THE FIBER PASTE - Methods of treating a subterranean formation are disclosed that include contacting a paste including a liquid chemical and a lightweight fiber having a high aspect ratio with a treatment fluid, and placing the treatment fluid into a subterranean formation. Also disclosed is an additive for treating a subterranean formation comprising a paste including a liquid chemical and a lightweight fiber having a high aspect ratio. | 02-26-2015 |
| 20150060062 | METHOD FOR ENHANCING PRODUCTIVITY OF HYDROCARBON FORMATIONS USING FLUID CONTAINING ORGANOMETALLIC CROSSLINKING AGENT AND SCALE INHIBITOR - Scales are prevented or inhibited from forming in a well or in a formation penetrated by a well by pumping into the well a fluid comprising a hydratable polymer, a crosslinking agent, such as an organometallic crosslinking agent containing a polyvalent metal and a scale inhibitor selected from the group consisting of polyvinyl sulfonates, a polyacrylamidomethylpropane sulfonic acid, carboxymethyl inulin and sulfonated polyacrylates and mixtures thereof. | 03-05-2015 |
| 20150060063 | Well Treatment - Using in situ channelization treatment fluids in multistage well treatment is disclosed. Also disclosed are methods, fluids, equipment and/or systems for treating a subterranean formation penetrated by a wellbore, relating to in situ channelization treatment fluids. | 03-05-2015 |
| 20150068744 | FLUID MOBILITY MODIFIERS FOR INCREASED PRODUCTION IN SUBTERRANEAN FORMATIONS - Embodiments including methods comprising providing a treatment fluid comprising a first aqueous base fluid and a polymeric gelling agent, wherein the treatment fluid comprises a first surface tension; introducing a fluid mobility modifier into the treatment fluid, wherein the fluid mobility modifier comprises: a first surfactant selected from the group consisting of a non-ionic surfactant; a cationic surfactant; and any combination thereof, and a solvent-surfactant blend comprising a second aqueous base fluid, a second surfactant, a solvent, and a co-solvent, wherein the ratio of the first surfactant to the solvent-surfactant blend is in the range of between about 1:5 to about 5:1, wherein the fluid mobility modifier causes the treatment fluid to adopt a second surface tension that is less than the first surface tension; and introducing the treatment fluid into a subterranean formation. | 03-12-2015 |
| 20150075790 | OILFIELD BIOCIDE - A well treatment fluid comprising a 2-oxo-aldehyde having 3 or more carbon atoms is disclosed herein. Methods to prepare and to utilize the fluid, and to inhibit biological degradation of a well treatment fluid, are also disclosed. | 03-19-2015 |
| 20150083416 | METHOD OF USING SURFACE MODIFYING TREATMENT AGENTS TO TREAT SUBTERRANEAN FORMATIONS - A well treatment fluid contains a surface modifying treatment agent having an anchor and a hydrophobic tail. The surface modifying treatment agent is an organophosphorus acid derivative. After the well treatment fluid is pumped into a well penetrating the subterranean formation, the anchor binds to the surface of the formation. The subterranean formation is a siliceous formation or a metal oxide-containing subterranean formation. The anchor bonds to a Si atom when the formation is a siliceous formation and to the metal of the metal oxide when the formation is a metal oxide-containing formation. After being bound to the surface of the formation, frictional drag within the well is reduced. This allows for faster recovery of formation fluids. The bonding of the surface modifying treatment agent onto the formation may further be enhanced by first pre-treating the formation with a non-aqueous fluid. By increasing the number of sites for the surface modifying treatment agent to bind onto the surface of the subterranean formation, productivity is improved. | 03-26-2015 |
| 20150083417 | METHOD OF USING SURFACE MODIFYING METALLIC TREATMENT AGENTS TO TREAT SUBTERRANEAN FORMATIONS - A method of treating a subterranean formation comprises pumping into a well penetrating the formation a surface modifying treatment agent having a metallic anchor and at least one hydrophobic tail attached to the metal of the anchor. The surface modifying treatment agent is covalently bound to the surface of the subterranean formation through the metal of the anchor. | 03-26-2015 |
| 20150122493 | FRAC SLEEVE SYSTEM AND METHOD FOR NON-SEQUENTIAL DOWNHOLE OPERATIONS - A downhole communication and control system configured for use in a non-sequential order of treating a borehole, the system includes a string having at least three ports including first, second, and third longitudinally spaced ports arranged sequentially in a downhole to uphole manner in the string; at least three frac sleeve systems including first, second, and third frac sleeve systems arranged sequentially in a downhole to uphole manner in the string and arranged to open and close the first, second, and third ports, respectively, each frac sleeve system having self-powered, electronically triggered first and second sleeves; and, communication signals to trigger the first, second, and third frac sleeve systems into moving the first and second sleeves to open and close the ports. Also included is a method of completing downhole operations in a non-sequential order. | 05-07-2015 |
| 20150315456 | METHODS FOR TREATING A SUBTERRANEAN WELL - Fluid compositions comprising water, an acid or an acid source, a chelating agent and a relative permeability modifier have utility in the context of matrix acidizing of oil bearing sandstone formations. Acidizing treatments with these compositions may improve the formation permeability to oil with respect to the permeability to water. The relative permeability modifier is a cationic polyacrylamide. | 11-05-2015 |
| 20150376968 | Synchronic Dual Packer - A downhole tool having a first packing element and a second packing element configured to synchronically set to selectively hydraulically isolate a portion of the wellbore. The movement of a pin along a j-slot track on a second sleeve sets the second packer in compression and the movement of a pin along a j-slot track on a first sleeve the first packer in tension after the second packer has been set. The j-slot track on the first sleeve has six different pin positions and the j-slot track on the second sleeve has four different pin positions. The pin positions and direction of travel of the j-slot tracks are adapted to permit the synchronized setting of the two packing elements to hydraulically isolate a portion of the wellbore. The wellbore may then be treated by flowing fluid out of a ported sub positioned between the packing elements. | 12-31-2015 |
| 20160075935 | ELECTROLYTE-CONTAINING AQUEOUS POLYMER SOLUTION AND METHOD FOR TERTIARY RECOVERY OF PETROLEUM - An electrolyte-containing aqueous polymer solution is described with a salt content of 5% to 35% by weight with respect to the total weight of the polymer solution, containing at least one dissolved synthetic copolymer which contains structural units which are derived from (i) at least one amide of an ethylenically unsaturated carbonic acid and from (ii) at least one ethylenically unsaturated sulphonic acid or their alkali metal salts and/or ammonium salts, and containing at least one non-ionic surfactant selected from the group formed by alkoxylated fatty alcohols, alkoxylated alkylphenols and/or alkoxylated fatty acids, with the proviso that the mean degree of alkoxylation of said surfactants is 8-10. | 03-17-2016 |
| 20160168965 | COMPOSITIONS AND METHODS FOR TREATING A SUBTERRANEAN FORMATION | 06-16-2016 |
