Class / Patent application number | Description | Number of patent applications / Date published |
166310000 | Entraining or incorporating treating material in flowing earth fluid | 71 |
20080236833 | Fluid-flow system, device and method - Methods, devices, and systems are disclosed for combining fluids of different pressures and flow rates in, for example, gas gathering systems, gas wells, and other areas in which independently powered compressors or pumps are not desired. | 10-02-2008 |
20080277121 | DUST CONTROL SYSTEM FOR TRANSFERRING DRY MATERIAL USED IN SUBTERRANEAN WELLS - A portable well treating fluid mixing system includes: a supply tank having an inlet receiving pneumatically conveyed dry treating material; a cyclone separator having an inlet coupled to the supply tank and receiving dust laden air from the supply tank, and having a first outlet venting clean air and having a second outlet venting solids; a collection container having a first inlet coupled to the cyclone separator second outlet and receiving solids from the cyclone separator and having an outlet; and, a pump having an inlet coupled to the collection container outlet and a pump outlet coupled to the supply tank. In operation, the system continuously conveys dust from the collection container back into the supply tank to maintain the separator in proper operating condition and minimizes venting of dust during the transfer of material to the supply tank. | 11-13-2008 |
20100018712 | METHOD OF TRANSITIONING TO KINETIC HYDRATE INHIBITORS IN MULTIPLE TIE-IN WELL SYSTEMS - The technical challenges for a smooth transition between using both a thermodynamic hydrate inhibitor (THI) and a kinetic hydrate inhibitor (KHI) to simply using only the KHI in multiple tie-in gas natural gas production systems is solved by adding more THI in a first pipeline leg of the production system while ceasing adding THI in a second pipeline leg of the system. Further, more KHI is added into the second leg of the system, and subsequently THI is gradually and/or slowly reduced in the remaining legs of the system until only KHI is being injected, after which the KHI amount in all legs may be reduced to the equilibrium or steady-state levels. | 01-28-2010 |
20100025041 | PORTABLE WELL TREATING FLUID MIXING SYSTEM AND METHOD - A portable well treating fluid mixing system includes: a supply tank having an inlet receiving pneumatically conveyed dry treating material; a cyclone separator having an inlet coupled to the supply tank and receiving dust laden air from the supply tank, and having a first outlet venting clean air and having a second outlet venting solids; a collection container having a first inlet coupled to the cyclone separator second outlet and receiving solids from the cyclone separator and having an outlet; and, a pump having an inlet coupled to the collection container outlet and a pump outlet coupled to the supply tank. In operation, the system continuously conveys dust from the collection container back into the supply tank to maintain the separator in proper operating condition and minimizes venting of dust during the transfer of material to the supply tank. | 02-04-2010 |
20100108320 | SUBSURFACE SAFETY VALVE FOR CHEMICAL INJECTION - A subsurface safety valve is modified to permit the passage of a downhole treatment chemical through the valve while bypassing a valve closure member which is maintained within the safety valve in operative condition. | 05-06-2010 |
20100270024 | Method and apparatus for the continuous treatment of a water well - An apparatus for the continuous treating of a water well with chlorine or hydrogen peroxide to do away with shock chlorination includes an inlet pipe, which is mounted in the cover on a water well and an elongated tube extending downwardly from the bottom end of the pipe into the well, preferably beyond any pitless adapter, for depositing chlorine pellets or chlorine or hydrogen peroxide solution in the well. The pellets or solution are added roughly on a weekly basis which prevents a chlorine or hydrogen peroxide smell in the water and obviates the need for dechlorination. | 10-28-2010 |
20110000673 | Drilling Fluid and Method for Reducing Lost Circulation - Lost circulation of drilling fluid is one of the most serious and expensive problems facing the drilling industry. The present invention relates to an improved drilling fluid for reducing or preventing lost circulation to an underground formation surrounding a well bore in the process of drilling a well. The drilling fluid comprises a base fluid and wax or waxy substance as a primary seepage loss agent. In a particularly preferred embodiment, the seepage loss agent does not include particles having a blend of natural wax and synthetic wax together in a single particle. The invention also provides a method of reducing or preventing lost circulation to an underground formation surrounding a well bore in the process of drilling a well using the drilling fluid of the invention, wherein the primary seepage loss agent is added to the drilling fluid, either before or during drilling, and the drilling fluid is pumped down hole during drilling. | 01-06-2011 |
20110017459 | APPARATUS FOR FLUIDIZING FORMATION FINES SETTLING IN PRODUCTION WELL - The present invention relates to a method and apparatus for reducing the occurrences of lateral wellbores being occluded by fines such as sand and silt. More specifically, the invention relates to discharging a portion of the output of an electrical submersible pump through nozzles that pass through the sidewalls of tubing, the tubing being located in the lateral wellbore. | 01-27-2011 |
20110017460 | METHOD OF ENHANCING ADSORPTION OF AN INHIBITOR ONTO A WELLBORE REGION - The instant disclosure is directed to a method of enhancing adsorption of a salt inhibitor onto a wellbore region, wherein the method comprises preconditioning the wellbore region, emplacing the salt inhibitor into the wellbore region, and shutting in the wellbore region for a period of time to at least initiate adsorption of the salt inhibitor onto the wellbore region. The salt inhibitor comprises an at least partially water soluble compound comprising a Group 3 to Group 15 metal and/or an at least partially water soluble compound having any one of the formulae: | 01-27-2011 |
20110017461 | PROCESS FOR CONSOLIDATING SAND - A method of treating a subterranean hydrocarbon-bearing formation comprising unconsolidated or poorly consolidated particulates, the method comprising contacting the formation with a solution or a dispersion of an organosilane, characterised in that the organosilane is a silylated polymer of formula (I): (RO) | 01-27-2011 |
20110017462 | METHOD AND COMPOSITION FOR ENHANCED HYDROCARBONS RECOVERY - A method of treating a hydrocarbon containing formation, comprising (a) providing a composition to at least a portion of the hydrocarbon containing formation, wherein the composition comprises a glycerol sulfonate of a propoxylated primary alcohol having a branched aliphatic group with an average carbon number from 10 to 24 and having an average number of branches per aliphatic group of from 0.7 to 2.5 and having at least 0.5 moles of propylene oxide per mole of primary alcohol; and (b) allowing the composition to interact with hydrocarbons in the hydrocarbon containing formation. | 01-27-2011 |
20110024122 | METHODS AND SYSTEMS OF TREATING A WELLBORE - Embodiments disclosed herein relate to methods of treating a wellbore ( | 02-03-2011 |
20110030961 | Treatment of Fluids that Increase in Viscosity at or Above a Threshold Temperature and Methods of Formulating and Using Such Fluids - A treatment fluid comprising: aqueous base comprising a combination of components effective to viscosify the treatment fluid upon exposure to a temperature at or above a threshold temperature, the treatment fluid having a pH of greater than 7; the combination of components comprising: a concentration of oil emulsified in the aqueous base; a quantity of water soluble polymer comprising one or more polysaccharides having a weight average molecular weight of about 500,000 to about 2,500,000; and, an amount of surfactant. | 02-10-2011 |
20110030962 | AQUEOUS CROSSLINKER SLURRY COMPOSITIONS AND APPLICATIONS - A method and composition for treating a subterranean formation penetrated by a wellbore including preparing an aqueous composition comprising a source of boron, whereby boron is present in the slurry in an amount of about 1.7% or greater, by weight, based upon a total weight of the composition, combining the composition with a mixture comprising a viscosifier and aqueous medium to form a treatment fluid, wherein the composition is added to the mixture in an amount of about 0.5% or less, by volume, based upon a total volume of the treatment fluid, and contacting the formation with the treatment fluid to treat the formation. A method and composition for treating a subterranean formation penetrated by a wellbore including preparing an aqueous composition comprising boric acid and a pH adjusting agent, combining the composition with mixture comprising a viscosifier and aqueous medium to form a treatment fluid, wherein the composition is added to the mixture in an amount of about 0.5% or less, by volume, based upon total volume of the treatment fluid, and contacting the formation with the treatment fluid to treat the formation. | 02-10-2011 |
20110048721 | DI-FUNCTIONAL SURFACTANTS FOR ENHANCED OIL RECOVERY - The present invention describes the synthesis and use of cleavable di-functional anionic surfactants for enhanced oil recovery applications and/or the use of sacrificial surfactants. | 03-03-2011 |
20110056693 | Composition and Method for Inhibiting the Deleterious Effects of Sulfate Reducing Bacteria - A method for reducing the deleterious effects of sulfate reducing bacteria in aqueous environments, particularly those in which metal materials are exposed to the microorganisms. A treatment solution containing rotenone is introduced into the aqueous environment. The rotenone is present in the treatment fluid in an amount which is sufficient to inhibit the growth of sulfate reducing bacteria on the metal material. | 03-10-2011 |
20110067876 | METHOD AND APPARATUS FOR INJECTING FLUID IN A WELLBORE - A chemical injection system for controlling injection of an injection fluid from an injection fluid supply at a surface location into a production tubing assembly having an upper flow path, a first flow zone, and a second flow zone. The chemical injection system comprises a first fluid injection line configured to inject the injection fluid into the first flow zone and a second fluid injection line configured to inject the injection fluid into the second flow zone. A main fluid supply line is configured to fluidly connect both the first fluid injection line and the second fluid injection line to the injection fluid supply. | 03-24-2011 |
20110079392 | ADDITIVES TO SUPPRESS SILICA SCALE BUILD-UP AND METHODS OF USE THEREOF - Treatments and compounds useful in subterranean formations are discussed, with particular attention to those formations where surfaces may be subject to silica scale build-up. Certain embodiments pertain to utilizing silica scale control additives with remediation and stimulation treatments. One example of a suitable method includes providing an acidic treatment fluid comprising: a base fluid, an acid, and a silica scale control additive; contacting at least a portion of a subterranean formation with the acidic treatment fluid; and allowing the acidic treatment fluid to interact with silica scale buildup in the subterranean formation so that at least a portion of the silica scale buildup is removed. | 04-07-2011 |
20110100634 | DOWNHOLE CHEMICAL DELIVERY SYSTEM AND METHOD - A method for delivering a chemical composition downhole into a wellbore includes forming a cylindrical body including a treatment chemical, where the cylindrical body includes a flow channel therethrough. The method further includes positioning the cylindrical body into a fluid conduit of a wellbore, and flowing a release fluid through the flow channel to release at least part of the treatment chemical into the release fluid. The release fluid causes the release of the treatment chemical by dissolving the chemical, and/or by removing a coating on the chemical through dissolution, response to pH adjustment, and/or response to an abrasive material in the release fluid. Examples of a treatment chemical include a cross-linker, breaker, fluid loss pill agent, and an encapsulated chemical. | 05-05-2011 |
20110186298 | Method And System For Treating A Subterranean Formation Using Diversion - A method well treatment includes establishing fluid connectivity between a wellbore and at least one target zone for treatment within a subterranean formation, which is intersected by a wellbore. The method includes deploying coiled tubing into the wellbore and introducing a treatment composition into the wellbore. The method includes contacting a target zone within the subterranean formation with the treatment composition, introducing a diversion agent through the coiled tubing to an interval within a wellbore and repeating the introduction of the treatment, the contacting of the target zone and the introduction of the diversion agent for more than one target zone. | 08-04-2011 |
20110186299 | Low-Toxicity Biodegradable Corrosion Inhibitors - The present invention relates to low-toxicity biodegradable compounds that inhibit metal corrosion, said compounds being salts obtained through the reaction of a carboxylic diacid with an imidazoline derivative. The invention also relates to the use of said corrosion-inhibiting compounds in all types of industries for drilling ore or fossil compounds, such as gas or oil. | 08-04-2011 |
20110198091 | Solvent Separation In A Solvent-Dominated Recovery Process - In solvent-dominated recovery processes for recovering In situ oil, including bitumen, the produced fluid stream includes oil and solvent. The solvent is preferably recovered and reinjected into the reservoir. In previously described methods, solvent is removed from the oil/solvent mixture. In the present method, the oil/solvent mixture is first separated into a heavier stream and a lighter stream from which solvent is independently removed. | 08-18-2011 |
20110214870 | LOST CIRCULATION COMPOSITION - A composition of matter and a method of sealing a permeable formation are provided incorporating the composition to reduce or eliminate lost circulation in permeable formations up to at least 6000 psi. The composition comprises one or more sealing components, a wetting component, a viscosifier component, an activator or flocculant component, and an extender. A dry mixture of the components may be added directly from the bag to the drilling mud up to the rate of 90 pounds per barrel. The mixture will seal the formation in an aqueous or organic environment. The mixture de-waters at a rapid rate without regard to the time and temperature required for curing agents or other additives. The mixture may be weighted and does not require additional agents such as defoamers, accelerators, retarders or spacers to de-water and set as a solid plug. | 09-08-2011 |
20110253374 | Geochemical Control of Fracturing Fluids - Treatments and compounds useful in subterranean formations are discussed, with particular attention to fracturing treatments where particulates and/or surfaces may be subject to water intrusion. Certain methods pertain to utilizing diagenesis source material to create porous structures in a subterranean formation. Such porous structures may be formed of consolidated particulates and/or diagenic product. Certain methods pertain to analyzing and/or quantifying the effects of the other methods disclosed herein. | 10-20-2011 |
20110253375 | APPARATUS AND METHODS FOR REMOVING MERCURY FROM FORMATION EFFLUENTS - An apparatus and related methods for removing hazardous trace elements from hydrocarbon reservoir effluent is implemented by placing an adsorbing volume of material designed to adsorb the hazardous trace elements into the vicinity of a producing formation face at a downhole location; and letting the reservoir effluent flow through the volume of adsorbing material | 10-20-2011 |
20110278011 | MATERIALS AND METHODS FOR TEMPORARILY OBSTRUCTING PORTIONS OF DRILLED WELLS - In various embodiments, provided are materials and methods for controlling the flow of water, steam, drilling fluid, hydraulic stimulation fluid, hydrocarbon (oil or gas), or combinations thereof, in drilled wells (such as enhanced geothermal system wells, oil wells, or natural gas wells) by at least partially and temporarily obstructing one or more of a geologic fracture, perforation, or wellbore in a reversible manner. | 11-17-2011 |
20110284231 | Electromagnetic Wave Treatment Of Oil Wells - A method including exposing a substance to a first type of electromagnetic waves generated by a first device. The frequency of the first type of electromagnetic waves is in the radio frequency range and the device preferably consumes no more than about 1,000 Watts of power. The exposure takes place for a period of time and at a frequency sufficient to detectably alter at least one physical property of the substance as it existed prior to the exposure. The substance is selected from the group consisting of a hydrate, a water and oil emulsion, clay, scale, cement, a completion fluid, tank sediment and iron sulfide. | 11-24-2011 |
20110290493 | Compositions And Methods For Completing Subterranean Wells - Disclosed are compositions and methods for providing fluid-loss control in subterranean wells. Well-completion fluids contain fine particulate additives whose glass-transition temperatures are below the anticipated bottomhole temperature. The particles soften upon injection into the well, whereupon they soften and become deformable. The particles then migrate to the borehole wall and form a seal that reduces further fluid flow from the borehole into the formation. The additive may be supplied as a powder or in the form of a liquid suspension. | 12-01-2011 |
20120006552 | METHOD FOR PRE-TREATMENT OF SUBTERRANEAN SITES ADJACENT TO WATER INJECTION WELLS - A method to improve the effectiveness of MEOR or bioremediation processes has been disclosed. In this method toxic chemicals accumulated in subterranean sites adjacent to the water injection wells are either dispersed or removed prior to introduction of microbial inocula for enhanced microbial oil recovery or bioremediation of these sites. | 01-12-2012 |
20120012326 | Shaped Compressed Pellets for Slow Release of Well Treatment Agents Into a Well and Methods of Using Same - Shaped particulates which have been compressed from a composite of a well treatment agent and adsorbent in a matrix may be introduced into horizontal or deviated oil or gas wells. The well treatment agent of the shaped pellets may be used to prevent and/or control the formation of deposits in a production well. | 01-19-2012 |
20120043086 | Zero-Leakoff Emulsified Acid - Disclosed herein are an acid emulsion fluid for use in sealing target portions of a hydrocarbon producing formation penetrated by a wellbore and the method of use thereof for fluid loss control. | 02-23-2012 |
20120061085 | Increasing Enhanced Oil Recovery Value From Waste Gas - A process is presented for selecting a treatment option for enhancing oil recovery from a geological formation in a remote location. The process includes a selection process for identifying a suitable treatment option. | 03-15-2012 |
20120061086 | Method of Preparing Polymer-Water Emulsion and Further Settling a Sticky Polymer Material In Downhole Environment - This invention relates to oil and gas production, more specifically, to the methods of producing polymer emulsion for downhole operations and mixing degradable (hydrolysable) polymer emulsion with the treatment fluid. | 03-15-2012 |
20120073821 | Methods for Reducing Biological Load in Subterranean Formations - Methods of treating subterranean formations to reduce bacteria load are provided. Some methods include the steps of providing a treatment fluid, particulates, and tri-n-butyl tetradecyl phosphonium chloride (TTPC) wherein the TTPC is in liquid form or in solution; coating the TTPC onto the particulates; combining the particulates coated with TTPC with the treatment fluid to create a suspension; and, placing the suspension into the portion of the subterranean formation. Other methods involve the use of TTPC in the form of a solid salt. | 03-29-2012 |
20120111569 | CHEMICAL DELIVERY APPARATUS, SYSTEM, AND METHOD FOR HYDROCARBON PRODUCTION - An apparatus, system and method for delivering a mixture of well treatment chemicals into a well are disclosed. A chemical distribution device includes mixing manifold that receives well treatment chemicals and solvent that are to be mixed. A siphon is positioned within the mixing manifold to control the fluid level. The mixture is not delivered from the chemical distribution device until the fluid level of the mixture is above a crest of the siphon. The mixture is delivered in a batch to the well via a flowline until the fluid level of the mixture is below the inlet of the siphon. | 05-10-2012 |
20120111570 | WELLBORE TREATMENT COMPOSITIONS COMPRISING HYDROPHILICALLY MODIFIED POLYMERS AND NONIONIC SURFACTANTS - The disclosed compositions and methods utilize hydrophilic polymers modified by the incorporation of one or more hydrophilic side groups. The polymers may exhibit physical association in solution at a specific temperature so as to provide a significant increase in viscosity at the specific temperature. The viscosity of such systems is substantially increased by the further inclusion of one or more hydrophilic components that may exhibit physical association in solution at one or more temperature trigger points and also associate with the one or more hydrophilic polymers modified by the incorporation of one or more hydrophilic side groups. | 05-10-2012 |
20120118575 | Thermally Stable Scale Inhibitor Compositions - Methods for scale inhibition treatment of oil or gas production wells generally include injecting a scale inhibition composition into the oil or gas production well, wherein the scale inhibition composition comprises one or more polymers, each polymer comprising recurring units of a first monomer and a second monomer, wherein: (i) the first monomer is selected from maleic acid, maleic anhydride, fumaric acid, acrylic acid, salts thereof, or combinations thereof; and (ii) the second monomer is selected from vinyl sulfonic acid, allyl sulfonic acid, methallylsulfonic acid, salts thereof, or combinations thereof; wherein the concentration of the polymers in the composition is about 10 to about 60 percent of the polymers by weight of the composition; and wherein the composition has a pH of about 7 to about 8.5. | 05-17-2012 |
20120168166 | Methods Useful for Diverting Aqueous Fluids in Subterranean Operations - Method of diverting fluids in a subterranean formation including the steps of providing a first fluid comprising an aqueous fluid and a hydrophobically modified water-soluble relative permeability modifier; introducing the first fluid into a well bore such that the first treatment fluid penetrates into a portion of the subterranean formation in a sufficient amount so as to substantially divert a second treatment fluid to another portion of the subterranean formation. Then, a second aqueous fluid is introduced into the well bore and substantially diverted from the portion of the subterranean formation penetrated with the first treatment fluid. In some cases, a well treatment operation, such as acid stimulation operation, a clay stabilization operation, or a scale inhibition operation, is performed using the second fluid. | 07-05-2012 |
20120181034 | HIGH TEMPERATURE TEMPORARY DIVERTER AND LOST CIRCULATION MATERIAL - A method can include introducing a particulate diverting agent into a first fracture within an underground reservoir formation. The particulate diverting agent can at least partially hydraulically isolate the first fracture. The particulate diverting agent can also be a temporary material which substantially degrades over an extended time. The underground reservoir formation can be stimulated with a stimulation fluid sufficient to expand a second fracture within the underground reservoir formation. The particulate diverting agent can then be allowed to substantially degrade. | 07-19-2012 |
20120181035 | Methods of Preparing Degradable Materials - Methods of creating degradable particulates in a subterranean environment. The methods provide a degradable material supercritical fluid mixture that comprises degradable material into a wellbore penetrating a subterranean formation and provide an orifice between the wellbore and the subterranean formation wherein the pressure in the subterranean formation is less than the pressure in the wellbore. The degradable material supercritical fluid is then fed through the orifice into the subterranean formation such that the degradable material supercritical fluid mixture expands through an orifice into the lower subterranean formation and particulates are formed. | 07-19-2012 |
20120186819 | VARYING PORE SIZE IN A WELL SCREEN - A method can include applying a magnetic field to a well screen, thereby varying sizes of pores via which fluid flows through the well screen. A well screen can include a magnetic shape memory material having a dimension which changes in response to application of a magnetic field. Restriction to flow through the well screen can vary in response to the change in dimension of the magnetic shape memory material. | 07-26-2012 |
20120199357 | METHOD OF CORROSION MITIGATION USING NANOPARTICLE ADDITIVES - A method of mitigating corrosion of downhole articles includes mixing a plurality of nanoparticles into a first downhole fluid to form a nanoparticle fluid. The method also includes exposing a surface of a downhole article in a wellbore to the nanoparticle fluid. The method further includes disposing a barrier layer comprising a portion of the nanoparticles on the surface of the article and exposing the surface of the downhole article to a second downhole fluid, wherein the barrier layer is disposed between the second downhole fluid and the surface of the article. | 08-09-2012 |
20120247777 | METHODS FOR SUPPLYING A CHEMICAL WITHIN A SUBTERRANEAN FORMATION - The method comprises deploying through a well a substantially longitudinal body comprising at least in part a degradable material able to release a chemical; positioning the longitudinal body at a downhole location from the well; and allowing the degradable material to degrade and the chemical to be released. | 10-04-2012 |
20120247778 | Completion Fluid with Friction Reduction - A method for reducing the friction forces between tubulars, for example coiled tubing in casing, is disclosed. The method includes mixing a selected surfactant and particles of TEFLON in oil, then adding the oil to water and pumping the mixture down the tubing. The mixture is particularly useful in coiled tubular drilling inside casing. The formulation has also been found to reduce corrosion on metal surfaces. | 10-04-2012 |
20120247779 | INHIBITING LIQUID LOADING, CORROSION AND/OR SCALING IN OILFIELD TUBULARS - Liquid loading, corrosion and scaling in an oilfield tubular, such as a production tubing in a natural gas production well, is inhibited by treating the inner surface of the oilfield tubular ( | 10-04-2012 |
20120261129 | Electromagnetic Wave Treatment Method And Promoter - A method involving exposing a substance to a promoter, the promoter being made from a liquid carrier and a metal salt component, the metal salt component, having at least (i) a magnetic susceptability above 1000 or (ii) an ionization potential below about 500 volts, or (iii) both (i) and (ii), and applying electromagnetic wave energy to the substance while the substance is in the presence of the promoter, for a period of time and at a frequency and amplification sufficient to promote the modification of at least one physical property of the substance. A related method of treating a well in a subterranean formation, a tank or a pipeline, and the well treatment promoter composition, are also described. | 10-18-2012 |
20120267113 | TREATMENT OF OIL - A method of treating crude oil which comprises contacting the oil with a treatment fluid formulation comprising a polymeric material which comprises vinylalcohol repeat units, wherein said polymeric material is of a type which has a weight average molecular weight in the range 5,000 to 50,000 and/or wherein the viscosity of a 4 wt % aqueous solution of the polymeric material at 2° C. is in the range 1.5-7 cP. The oil may be contacted with the treatment fluid formulation underground by, for example, injection of the fluid formulation into an injection well or production well and the mobility of the oil contacted thereby is significantly improved. | 10-25-2012 |
20120267114 | Methods and Compositions for Consolidating Particulate Matter in a Subterranean Formation - Methods of treating a subterranean formation comprising first introducing a pre-flush fluid into a subterranean formation having particulate matter therein. Then introducing a curable adhesive composition comprising a silane coupling agent and a polymer, the polymer having a reactive silicon end group into the subterranean formation subsequent to the pre-flush fluid. Then introducing an aqueous post-fluid fluid into the subterranean formation subsequent to the curable adhesive composition. Then allowing the curable adhesive composition to at least partially consolidate particulate matter within the subterranean formation. | 10-25-2012 |
20120273208 | Chemical Diversion Technique - A method includes treating a first formation intersecting a wellbore, preparing a diversion fluid including an inactivated viscosifier and an inactivated thinning agent, and positioning an amount of the diversion fluid to isolate the first formation. The method further includes delivering an activator to the diversion fluid, thereby activating the inactivated viscosifier and triggering a thinning agent activation process. The method further includes treating a second formation intersecting the wellbore. The method further includes providing a residence time until the thinning agent activation process completes and the thinning agent breaks the viscosified diversion fluid. The method further includes flowing fluid back from the first formation and the second formation. | 11-01-2012 |
20120285695 | DESTRUCTIBLE CONTAINERS FOR DOWNHOLE MATERIAL AND CHEMICAL DELIVERY - A method of treating a downhole region penetrated by a wellbore with a treatment agent is given, including delivering the treatment agent to the wellsite enclosed in one or more destructible containers, inserting the one or more destructible containers into the fluid being pumped down the well, and mechanically breaking the one or more destructible containers in the wellbore or in the formation to release the treatment agent. A method is also given for treating a downhole region penetrated by a wellbore with a special solid diverting material, which includes special shapes such as fibers or flakes and/or blends of specially sized particles, including delivering the special solid diverting material to the wellsite enclosed in one or more containers, inserting the one or more containers into fluid being pumped down the well, and allowing the one or more containers to release the special solid diverting material in the wellbore. | 11-15-2012 |
20120292032 | WELLBORE TREATMENT APPARATUS AND METHOD - A method for wellbore treatment includes running a liner into a wellbore, the liner including a wall, an inner bore defined by the wall, a first port through the wall, a second port though the wall spaced axially from the first port, a first removable closure for the first port and a second removable closure for the second port; positioning the liner in an open hole section of the wellbore to create an annulus between the liner and a portion of the wellbore wall and with the second port downhole of the first port; inserting a treatment string assembly into the liner, the treatment string assembly including a tubing string and an annular seal about the tubing string and being insertable into the inner bore of the liner; setting the annular seal to create a seal between the tubing string and the liner downhole of the second port; and while the first port is closed to fluid flow therethrough, pumping wellbore treatment fluid into an annular area between the tubing string and the liner such that the fluid passes through the second port and into the annulus to treat the open hole section of the wellbore adjacent the second port. The treatment string assembly may further include a port-opening tool and a fluid communication port permitting fluid communication between the tubing string outer surface and a fluid conduit through the tubing string adjacent an upper side of the annular seal. | 11-22-2012 |
20120318515 | METHOD OF INHIBITING OR CONTROLLING RELEASE OF WELL TREATMENT AGENT - A microemulsion delivery system containing a well treatment agent in a water-in-oil microemulsion may be used for well remediation as well as in other treatment operations including stimulation, acidizing, and drilling. In addition, the water-in-oil microemulsion delivery system may be used to clean surface equipment and downhole equipment. | 12-20-2012 |
20130000916 | RECYCLABLE CLEANOUT FLUIDS - A method for treating a wellbore or a subterranean formation penetrated by a wellbore includes preparing a gelled oil at the surface, introducing the gelled oil into the wellbore, recovering the gelled oil at the surface, adding a base to the gelled oil to reduce the viscosity, allowing entrained solids to settle out, adding an acid to increase the viscosity, and re-injecting the gelled oil. | 01-03-2013 |
20130025870 | WELL SERVICING FLUID AND METHOD OF SERVICING A WELL WITH THE FLUID - A well servicing fluid is disclosed. The well servicing fluid is formulated by combining ingredients comprising: an aqueous based fluid comprising sulfate ions at a concentration greater than 50 mg/l; a chelating agent; and an acid in an amount sufficient to result in the well servicing fluid having a pH of 4.5 or less. A method of servicing a well is also disclosed. | 01-31-2013 |
20130056214 | REDUCING SULFIDE IN PRODUCTION FLUIDS DURING OIL RECOVERY - Methods are provided for treating production fluid in a production well 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 the well casing. | 03-07-2013 |
20130056215 | Disintegrative Particles to Release Agglomeration Agent for Water Shut-Off Downhole - Disintegrative particles having a disintegrative coating surrounding a disintegrative core may be pumped within an aqueous treatment fluid downhole to a subterranean formation. With time and/or change in wellbore or environmental condition, these particles will either disintegrate partially or completely, in non-limiting examples, by contact with downhole wellbore fluid, formation water, or a stimulation fluid (e.g. acid or brine). Once disintegrated, metals or compounds are released which raises the fluid pH and forms a structure that selectively inhibits or shuts-off the production of water from water-producing zones. The disintegrative particles may be made by compacting and/or sintering metal powder particles, for instance magnesium or other reactive metal or their alloys. Alternatively, particles coated with nanometer-sized or micrometer sized coatings may be designed where the coatings disintegrate faster or slower than the core in a changed downhole environment. | 03-07-2013 |
20130062068 | Use of Sensors Coated with Elastomer for Subterranean Operations - A method comprising placing a composition comprising a wellbore servicing fluid and a Micro-Electro-Mechanical System (MEMS) sensor in a subterranean formation, whereby the MEMS sensor is coated with an elastomer. The elastomer-coated MEMS sensor is used to detect one or more parameters, including a compression or swelling of the elastomer, an expansion of the elastomer, or a change in density of the composition. | 03-14-2013 |
20130075100 | AGGREGATING REAGENTS AND METHODS FOR MAKING AND USING SAME - Composition and methods using the compositions are disclosed, where the compositions include heterocyclic aromatic amines, substituted heterocyclic aromatic amines, poly vinyl heterocyclic aromatic amines, co-polymers of vinyl heterocyclic aromatic amine and non amine polymerizable monomers (ethylenically unsaturated mononers and diene monomers), or mixtures or combinations thereof in the absence of phosphate esters, optionally ethoxylated alcohols, and optionally, which form alter self-aggregating properties and/or aggregation propensities of the particles, surfaces, and/or materials. | 03-28-2013 |
20130098623 | Low Dosage Kinetic Hydrate Inhibitors for Natural Gas Production Systems - Copolymers containing acryloylmorpholine and vinylimidazole, and optionally vinylcaprolactam and/or n-vinyl pyrrolidone, have shown superior results in hydrate inhibition tests at conditions of 7° C. subcooling dosed at 1 vol % based on the water cut of the system fluids. The copolymer product has also passed high TDS (total dissolved solids) brine compatibility tests and secondary property tests including foaming and hot injection tests which make it useful as a kinetic hydrate inhibitor in gas production systems susceptible to the formation of natural gas hydrates. | 04-25-2013 |
20130126177 | METHOD FOR IMPROVING ISOLATION OF FLOW TO COMPLETED PERFORATED INTERVALS - A method for building a plug in a horizontal wellbore using a fluid pill containing a suspended well treatment agent. The well treatment agent contains an ultra lightweight (ULW) deformable core and a viscosifying polymer and crosslinking agent coated onto the core. The fluid pill is pumped into the wellbore at the end of a fracturing treatment. The fluid pill is displaced by a displacement fluid and the fluid pill transforms to a thickened gel. The thickened gel is formed by the in-situ reaction of the viscosifying polymer and crosslinking which become disassociated from the ULW deformable core. The gelled fluid containing the ULW deformable core assists in the bridging of the ULW deformable core and forming the bridge plug. | 05-23-2013 |
20130133892 | BREAKING DIUTAN WITH OXALIC ACID AT 180F to 220F - A method of treating a portion of a well of a well is provided. The method includes the step of forming a treatment fluid comprising: (i) a continuous aqueous phase; (ii) a viscosity-increasing agent selected from the group consisting of diutan, clarified diutan, water-soluble derivative of diutan, and any combination thereof, wherein the viscosity-increasing agent is dissolved in the aqueous phase; and (iii) a breaker comprising oxalic acid, wherein the oxalic acid is dissolved in the aqueous phase. The viscosity of the treatment fluid breaks to less than 3.0 cP in less than 72 hours when in a temperature range of 180° F. (82.2° C.) to 220° F. (104.4° C.). The method also includes the steps of introducing the treatment fluid into the portion of the well and flowing back from the portion of the well. | 05-30-2013 |
20130186631 | SYSTEM AND METHOD FOR TREATMENT OF WELL COMPLETION EQUIPMENT - An apparatus for controlling a flow of a fluid between a wellbore tubular having an opening and a formation includes a particulate control device and a flow control device positioned adjacent to the particulate control device. A flow path is formed between the opening of the wellbore tubular and the formation and that is internal to the particulate control device and the flow control device. The apparatus may include an additive supply line having an outlet positioned to dispense at least one additive into the flow path. A related method for controlling a flow of a fluid between a wellbore tubular having an opening and a formation may include positioning a flow control device adjacent to a particulate control device in the wellbore and dispensing at least one additive into a flow path internal to the particulate control device and the flow control device. | 07-25-2013 |
20130341031 | INSENSITIVE EXPLOSIVE COMPOSITION AND METHOD OF FRACTURING ROCK USING AN EXTRUDABLE FORM OF THE COMPOSITION - Insensitive explosive compositions were prepared by reacting di-isocyanate and/or poly-isocyanate monomers with an explosive diamine monomer. Prior to a final cure, the compositions are extrudable. The di-isocyanate monomers tend to produce tough, rubbery materials while polyfunctional monomers (i.e. having more than two isocyanate groups) tend to form rigid products. The extrudable form of the composition may be used in a variety of applications including rock fracturing. | 12-26-2013 |
20140060843 | Wellbore Servicing Compositions and Methods of Making and Using Same - A method of servicing a wellbore in a subterranean formation comprising placing a wellbore servicing fluid comprising a lost-circulation composite material into a wellbore, wherein the lost-circulation composite material comprises a swellable component and a reinforcing component. A wellbore servicing fluid comprising a reinforcing component disposed within a swellable component wherein the swellable component comprises a crosslinked polymer. | 03-06-2014 |
20140151053 | HYDROCARBONS - An oil well includes a wellbore ( | 06-05-2014 |
20140182857 | SYSTEM AND METHOD FOR INJECTING A TREATMENT FLUID INTO A WELLBORE AND A TREATMENT FLUID INJECTION VALVE - The present invention provides a valve and method for injecting a treatment fluid into a production zone of a hydrocarbon production well. The valve comprises a tubular housing comprising a housing axial fluid passage, a fluid inlet being in fluid communication with the housing axial fluid passage, and a lateral fluid outlet; a sleeve member having a sleeve axial fluid passage and at least one lateral fluid opening, the sleeve member being fixedly arranged within the tubular housing, wherein the sleeve axial fluid passage is aligned with the housing axial fluid passage, and wherein the at least one lateral fluid opening is aligned with the lateral fluid outlet; and a piston member being moveably disposed within the sleeve axial fluid passage between a closed position and an open position, wherein the piston member in the closed position blocks treatment fluid flow from the housing axial fluid passage toward the sleeve axial fluid passage, and wherein the piston member in the open position permits treatment fluid flow from the fluid inlet through the housing axial fluid passage, the sleeve axial fluid passage, and the at least one lateral fluid opening in the sleeve member toward the lateral fluid outlet of the tubular housing. | 07-03-2014 |
20140202703 | Method of Reducing Corrosion on Metal Surfaces - A method for reducing corrosion on the exterior or interior surface, for example coiled tubing and casing, is disclosed. The method includes mixing a selected surfactant and particles of a polymer in oil, then adding the oil to water and contacting the surfaces of the tubing with the mixture. | 07-24-2014 |
20140246200 | System and Method for Fluid Treatment - A method of treating a wellbore servicing fluid includes disposing an ultraviolet treatment chamber in fluid communication with an inlet of a pump, operating the pump, and drawing a wellbore servicing fluid through the ultraviolet treatment chamber in response to operating the pump. A wellbore servicing fluid treatment system has a first ultraviolet treatment chamber and a first pump in selective fluid communication with the first ultraviolet treatment chamber. The pump is downstream relative to the first ultraviolet treatment chamber and the pump is configured to selectively draw a wellbore servicing fluid through the first ultraviolet treatment chamber. A method of servicing a wellbore includes connecting an ultraviolet fluid treatment system to a blender, operating a pump of the blender, drawing a wellbore servicing fluid through the ultraviolet treatment system in response to operating the pump of the blender, and delivering the wellbore servicing fluid into the wellbore. | 09-04-2014 |
20140345871 | Henna Corrosion Inhibitor for Acid in a Well - A method of treating a portion of a well including the steps of: (A) forming a fluid comprising: (i) an aqueous liquid phase; and (ii) a corrosion inhibitor selected from the group consisting of: (a) the leaves of henna, jewelweed, or any combination thereof; (b) an extract of the leaves of henna, jewelweed, or any combination thereof; (c) a plant source of a hydroxynaphthoquinone; (d) a hydroxynaphthoquinone; and (e) any combination an any of the foregoing; and (B) introducing the fluid into the portion of the well. | 11-27-2014 |
20140374110 | Engineering Plastic / Inorganic Fiber Blends as Lost Circulation Materials - A method is disclosed for reducing lost circulation in drilling wells, employing composite materials containing an engineering thermoplastic polymer and mineral fibers. Optionally the composites may also include other components such as calcium carbonate and blending agents. | 12-25-2014 |
20150013988 | Mitigating Annular Pressure Buildup Using Temperature-Activated Polymeric Particulates - A variety of methods and compositions are disclosed, including, in one embodiment, a method that comprises providing a treatment fluid comprising a carrier fluid and temperature-activated polymeric particulates, wherein a compressible gas is trapped in the polymeric particulates; and introducing the treatment fluid into a well bore annulus. | 01-15-2015 |