Patent application number | Description | Published |
20080287323 | Treatment and Reuse of Oilfield Produced Water - The invention discloses treatment and reuse of oilfield produced water. A method of inhibiting enzymes/bacteria in an aqueous medium for viscosification comprises contacting the aqueous medium with a denaturant and/or a bactericide and thereafter mixing a gelling agent in the aqueous medium. The viscosified fluid can be used as a well treating fluid for fracturing and other applications. A well treatment fluid comprises a metal denaturant and/or a bactericide and a gelling agent in an amount effective to viscosify the fluid. Also disclosed is oilfield produced water denatured with from 1 to 2000 ppm by weight of a zirconium compound. | 11-20-2008 |
20090078410 | Aggregate Delivery Unit - A delivery unit for providing aggregate to a worksite, such as a wellsite location. The unit may include a mobile chassis for accommodating a plurality of modular containers which in turn house the aggregate. As such, a weight measurement device may be located between each container and the chassis so as to monitor aggregate levels within each container over time. The units may be particularly well suited for monitoring and controlling aggregate delivery during a fracturing operation at an oilfield. The modular containers may be of an interchangeable nature. Furthermore, a preferably wireless control device may be provided for monitoring and directing aggregate delivery from a relatively remote location. | 03-26-2009 |
20090277636 | SYSTEM AND METHOD FOR PERFORATED WELL SAND CONTROL - In one embodiment, a system includes a cased wellbore disposed in a formation of interest. The system includes an emulsion positioned in the wellbore at a depth of the formation of interest. The emulsion includes an oil external phase and an aqueous internal phase. The oil external phase includes particles having calcium hydroxide. The aqueous internal phase includes insoluble silica particles. The system further includes a perforating tool that generates perforation tunnels through the cased wellbore into the formation of interest. The system further includes a well flow control device that shuts in the wellbore for a specified period of time. The emulsion breaks during contact with the formation in the perforation tunnels, and the calcium hydroxide and silica particles form a cementitious material that consolidates the perforation tunnels. | 11-12-2009 |
20100056403 | METAL FREE CROSSLINKING OF GALACTOMANNAN - Methods of treating a subterranean formation are disclosed, using a fluid including an essentially metal-free organic crosslinker selected from amines, diamines, poly amines, polyamino polymers, alcohols, polyols, polyhydroxy polymers, hydroxyl amines, peptides and proteins, combined with a polysaccharide or cellulosic material having oxidized functional groups. The fluid is then introduced into a wellbore penetrating the formation to contact the formation. The polysaccharide or cellulosic material may have aldehyde groups as one example of an oxidized group, or any other suitable oxidized functional group. The polysaccharide or the cellulosic material may be oxidized using at least one of an enzymes, oxidizers, photooxidation, bacteria, catalyst, or other suitable technique. The fluid may also further include an inorganic crosslinker. | 03-04-2010 |
20100096128 | ENHANCING HYDROCARBON RECOVERY - Recovery of hydrocarbon fluid from low permeability sources is enhanced by introduction of a treating fluid. The treating fluid may include one or more constituent ingredients designed to cause displacement of hydrocarbon via imbibition. The constituent ingredients may be determined based on estimates of formation wettability. Further, contact angle may be used to determine wettability. Types and concentrations of constituent ingredients such as surfactants may be determined for achieving the enhanced recovery of hydrocarbons. | 04-22-2010 |
20100096129 | METHOD OF HYDROCARBON RECOVERY - A method is given for treating a wellbore to increase the production of hydrocarbons from a subterranean formation penetrated by a wellbore, involving a period of injecting into the formation an aqueous injection fluid having a different chemical potential than the aqueous fluid in the formation. If there is water blocking, an osmotic gradient is deliberately created to cause flow of water into the injected fluid; hydrocarbon is then produced by imbibition. If the pore pressure in the water-containing pores in the formation is too low, an osmotic gradient is deliberately created so that water flows from the injected fluid into the water-containing pores, increasing the pore pressure and facilitating hydrocarbon production by imbibition. The method may be repeated cyclically. A semipermeable membrane may be created to enhance the osmosis. Wetting agents may be used to influence imbibition. | 04-22-2010 |
20100163225 | System, Method, and Apparatus for Post-Fracture Treatment - A method includes hydraulically fracturing a subterranean formation with a first treatment fluid and allowing the hydraulic fracture to close. The method includes preparing a second treatment fluid having a damage removal agent including carbon dioxide. The second treatment fluid further includes a proppant pack damage removal agent including an oxidizer, a radical initiator, an acid, a solvent, and/or other damage removal agents. The method further includes injecting the second treatment fluid into the subterranean formation at a downhole pressure below a fracturing pressure for the subterranean formation. The method includes holding pressure on the formation while the second treatment fluid enhances formation and proppant pack permeability, and flowing the second treatment fluid back to the surface. | 07-01-2010 |
20100175877 | METHOD OF DESIGNING AND EXECUTING A WELL TREATMENT - An apparatus and a method for treating a subterranean formation comprising designing a treatment that comprises a composition, wherein the design comprises a pressure influence on a viscosity of the composition, and performing the treatment, wherein the composition is not an energized fluid. An apparatus and a method wherein the viscosity is at least partially estimated based on experimental rheological data collected at pressures below about 500 psi and/or at a pressure that is about 1 atm to about 2,000 atm. | 07-15-2010 |
20110021386 | MICROEMULSION TO IMPROVE SHALE GAS PRODUCTION BY CONTROLLING WATER IMBIBITION - The invention provides a method for treating tight gas sand and shale subterranean formations, the method comprising: forming a solvent-surfactant blend by combining a solvent, a surfactant and a co-surfactant; adding a diluent to the solvent-surfactant blend to form a micro emulsion; wherein the wettability of the formation altered from water-wet to gas-wet, and the amount of water imbibed into the formation is reduced. | 01-27-2011 |
20110048719 | RATE INDUCED DIVERSION FOR MULTI-STAGE STIMULATION - The invention provides a method of stimulation a subterranean formation to improve formation fluid production, the method comprising: providing a wellbore which penetrates the subterranean formation, wherein the wellbore comprises at least two perforation cluster zones; injecting a treatment fluid into the wellbore at a fluid pressure equal to or greater than the fracture initiate pressure of the subterranean formation; contacting the subterranean formation with the treatment fluid through a first perforation cluster zone; performing a shutin by stopping injection of the treatment fluid; waiting for a determined period of time, wherein no physical material is introduced into the wellbore and no significant reverse flow from the subterranean formation to the wellbore occurs during said period of time; resuming the introduction of the treatment fluid into the wellbore at a fluid pressure equal to or greater than the fracture initiate pressure of the subterranean formation; and contacting the subterranean formation with the treatment fluid through a second perforation cluster zone. | 03-03-2011 |
20110108271 | ENHANCING HYDROCARBON RECOVERY - Recovery of hydrocarbon fluid from low permeability sources enhanced by introduction of a treating fluid is described. The treating fluid may include one or more constituent ingredients designed to cause displacement of hydrocarbon via imbibition. The constituent ingredients may be determined based on estimates of formation wettability. Further, contact angle may be used to determine wettability. Types and concentrations of constituent ingredients such as surfactants may be determined for achieving the enhanced recovery of hydrocarbons. The selection can be based on imbibition testing on material that has been disaggregated from the source formation. | 05-12-2011 |
20110166050 | TREATMENT AND REUSE OF OILFIELD PRODUCED WATER - The invention discloses treatment and reuse of oilfield produced water. A method of inhibiting enzymes/bacteria in an aqueous medium for viscosification comprises contacting the aqueous medium with a denaturant and/or a bactericide and thereafter mixing a gelling agent in the aqueous medium. The viscosified fluid can be used as a well treating fluid for fracturing and other applications. A well treatment fluid comprises a metal denaturant and/or a bactericide and a gelling agent in an amount effective to viscosify the fluid. Also disclosed is oilfield produced water denatured with from 1 to 2000 ppm by weight of a zirconium compound. | 07-07-2011 |
20110259588 | METHODS OF STABILIZING SHALE SURFACE TO MINIMIZE PROPPANT EMBEDMENT AND INCREASE PROPPANT-PACK CONDUCTIVITY - Embodiments of the invention relate to a method of treating a subterranean formation comprising shale comprising forming a fluid comprising potassium acetate, and introducing the fluid to a surface of the subterranean formation comprising shale, wherein geomechanical weakening of the formation is lower than if the formation were not in contact with the fluid. Embodiments of the invention relate to a method of treating a subterranean formation comprising shale, comprising forming a fluid comprising potassium chloride and ammonium acetate; and introducing the fluid to a surface of the subterranean formation comprising shale, wherein geomechanical weakening of the formation is lower than if the formation were not in contact with the fluid. | 10-27-2011 |
20110284214 | METHODS AND TOOLS FOR MULTIPLE FRACTURE PLACEMENT ALONG A WELLBORE - The invention discloses a tool for use in a wellbore, comprising: a tubular elongated member; openings on the tubular member able to be close with a valve or a sleeve; swellable packers positioned between said opening on the tubular member; and a control unit; the control unit operating the valve or sleeve for fracturing a subterranean formation in a wellbore, in the stages: a. fracturing the subterranean formation through a first stage at predefined first locations; and b. fracturing the subterranean formation through a second stage at second location(s) wherein each location from the second location(s) is localized between the predefined first locations. | 11-24-2011 |
20110287983 | TREATMENT FLUIDS MADE OF HYDANTOIN DERIVATIVES FOR OPERATIONS IN A WELL - The invention discloses a method comprising providing a fluid comprising a viscosifying agent in an aqueous medium; contacting the fluid with a N-halogenated derivative of hydantoin; whereby the viscosity of the fluid with the N-halogenated derivative of hydantoin is reduced compared to the viscosity of the fluid alone; and introducing the fluid into a well. The N-halogenated derivative of hydantoin can be dichlorodimethylhydantoin (DCDMH), bromochlorodimethylhydantoin (BCDMH), or dibromodimethylhydantoin (DBDMH). The N-halogenated derivative of hydantoin can be 1,3-Dichloro-5,5-dimethylhydantoin or 1,3-Dibromo-5,5-dimethylhydantoin. | 11-24-2011 |
20110287984 | TREATMENT FLUIDS MADE OF HALOGENISOCYANURIC ACID AND ITS SALTS FOR OPERATIONS IN A WELL - The invention discloses a method comprising providing a fluid comprising a viscosifying agent in an aqueous medium; contacting the fluid with a halogenisocyanuric acid or halogenisocyanurate component; whereby the viscosity of the fluid with the halogenisocyanuric acid or halogenisocyanurate component is reduced compared to the viscosity of the fluid alone; and introducing the fluid into a well. The halogenisocyanuric acid component can be mono chloroisocyanuric acid, dichloroisocyanuric acid or trichloroisocyanuric acid. The halogenisocyanurate component can be an alkali metal monochloroisocyanurate, alkali metal dichloroisocyanurate or alkali metal trichloroisocyanurate. | 11-24-2011 |
20110319302 | METHOD OF TREATING A WELLBORE AT HIGH TEMPERATURE IN CONTACT WITH CARBON DIOXIDE - A method for treating a subterranean formation is made of steps of providing a composition comprising a carrier fluid, a polymer viscosifying agent, carbon dioxide and a formate salt or formic acid; injecting into a wellbore, the composition; contacting the composition with the subterranean formation, wherein the temperature is above 100 degrees Celsius at this contact; and allowing the composition to treat the subterranean formation. | 12-29-2011 |
20120111563 | METHODS TO DELIVER FLUIDS ON A WELL SITE WITH VARIABLE SOLIDS CONCENTRATION FROM SOLID SLURRIES - The invention discloses a storable composition for oilfield application including a slurry of a carrier fluid and a particulate blend made of proppant; the particulate blend comprising at least a first amount of particulates having a first average particle size between about 100 and 5000 μm and at least a second amount of particulates having a second average particle size between about three and twenty times smaller than the first average particle size; such that a packed volume fraction of the particulate blend exceeds 0.74 and the particulate blend volume is sufficient to substantially avoid settling of the particulate in the carrier fluid. | 05-10-2012 |
20130140031 | SYSTEM AND METHOD FOR PERFORMING OPTIMIZED DOWNHOLE STIMULATION OPERATIONS - A method of performing a stimulation operation for an unconventional wellsite having natural fractures and hydraulic fractures. The method involves providing at least one treatment parameter with a corresponding objective function value and performing a fracture operation based on the treatment parameter. The fracture operation involves defining a treatment schedule, conducting a hydraulic fracture operation, and estimating production. The objective function value is based on an objective function. The method also involves modifying the treatment parameter and performing the fracture operation based on the modified treatment parameter. The modified treatment parameter has a corresponding modified objective function value based on the objective function. The method continues with optimizing the treatment operation by comparing the objective function value with the modified objective function value, and repeating the modifying and optimizing for new modified treatment parameters until convergence about a desired outcome whereby an optimized parameter is defined at convergence. | 06-06-2013 |
20130146293 | Methods for Unconventional Gas Reservoir Stimulation With Stress Unloading For Enhancing Fracture Network Connectivity - The invention discloses a method for use in a wellbore in a tight gas shale formation, comprising: providing a hydraulic fracturing fluid to initiate at least a fracture in the shale; injecting a treatment fluid in the fracture to at least partially destabilize and remove the shale; and repeating the step of fracturing the shale. | 06-13-2013 |
20140069645 | METHODS TO DELIVER FLUIDS ON A WELL SITE WITH VARIABLE SOLIDS CONCENTRATION FROM SOLID SLURRIES - The application discloses a storable composition for oilfield application including a slurry of a carrier fluid and a particulate blend made of proppant; the particulate blend comprising at least a first amount of particulates having a first average particle size between about 100 and 5000 μm and at least a second amount of particulates having a second average particle size between about three and twenty times smaller than the first average particle size; such that a packed volume fraction of the particulate blend exceeds 0.74 and the particulate blend volume is sufficient to substantially avoid settling of the particulate in the carrier fluid. | 03-13-2014 |
20140321950 | AGGREGATE DELIVERY UNITY - A delivery unit for providing aggregate to a worksite, such as a wellsite location. The unit may include a mobile chassis for accommodating a plurality of modular containers which in turn house the aggregate. As such, a weight measurement device may be located between each container and the chassis so as to monitor aggregate levels within each container over time. The units may be particularly well suited for monitoring and controlling aggregate delivery during a fracturing operation at an oilfield. The modular containers may be of an interchangeable nature. Furthermore, a preferably wireless control device may be provided for monitoring and directing aggregate delivery from a relatively remote location. | 10-30-2014 |