Patent application number | Description | Published |
20080305971 | Polysaccharide Treatment Fluid and Method of Treating A Subterranean Formation - A treatment fluid for treating a subterranean formation penetrated by a wellbore is formed from an aqueous medium, a diutan heteropolysaccharide having a tetrasaccharide repeating unit in the polymer backbone and a peroxide breaker. A method of treating a subterranean formation penetrated by a wellbore may be carried out by introducing the treatment fluid into the formation through the wellbore. Breaking aids or catalysts may also be used with the treatment fluid. | 12-11-2008 |
20090023613 | Polysaccharide Treatment Fluid and Method of Treating a Subterranean Formation - A treatment fluid for treating a subterranean formation penetrated by a wellbore is formed from an aqueous medium, a diutan heteropolysaccharide having a tetrasaccharide repeating unit in the polymer backbone and a peroxide breaker. A method of treating a subterranean formation penetrated by a wellbore may be carried out by introducing the treatment fluid into the formation through the wellbore. Breaking aids or catalysts may also be used with the treatment fluid. | 01-22-2009 |
20090281004 | Composition and Method for Fluid Recovery from Well - A well treatment microemulsion for use in a subterranean formation is disclosed, the microemulsion comprises a solvent blend comprising a solvent and a co-solvent; a surfactant blend comprising a surfactant, wherein the surfactant blend is able to give formation intermediate wettability properties; an alcohol; and a carrier fluid; wherein the alcohol, the solvent and surfactant blends are combined with the carrier fluid to produce the well treatment microemulsion. By intermediate wettability it is meant that the water has an advancing contact angle on the surface between 62 and 133 degrees. The associate method of treating a subterranean formation of a well with the microemulsion and the associate method of modifying the wettability of the formation with the microemulsion are also disclosed. | 11-12-2009 |
20090305914 | Phosphorus-Free Gelled Hydrocarbon Compositions and Method for Use Thereof - A method of forming a gelled organic-based fluid is disclosed. The method comprises combining an organic solvent, a viscoelastic surfactant, and a metal carboxylate crosslinker; and forming the gelled organic-based fluid. In a further aspect, the method is used to treat a subterranean formation of a well, for example for a stimulation job as fracturing or the like. | 12-10-2009 |
20090318313 | Slickwater Treatment Fluid and Method - A treatment fluid for treating a subterranean formation penetrated by a wellbore is formed from water, a polyacrylamide in an amount of less than about 0.5% by weight of the fluid for reducing friction of the fluid and a stabilized peroxide breaker. A method of treating a subterranean formation penetrated by a wellbore is carried out by forming treatment fluid comprising water, a polyacrylamide in an amount of less than about 0.5% by weight of the fluid for reducing friction of the fluid and a stabilized peroxide breaker. The treatment fluid is introduced into the formation through the wellbore at a pressure above the fracture pressure of the formation. | 12-24-2009 |
20100056405 | SELF-DIVERTING ACID TREATMENT WITH FORMIC-ACID-FREE CORROSION INHIBITOR - A method of treating a subterranean formation penetrated by a wellbore of a well having iron-containing components is carried out by introducing a treatment fluid into the wellbore of the well. The treatment fluid is formed from an aqueous solution, a mineral acid, a viscoelastic surfactant gelling agent and corrosion inhibitor system containing at least one of an alkyl, alkenyl, alicyclic or aromatic substituted aliphatic ketone and aliphatic or aromatic aldehyde. The treatment fluid is substantially free of any formic acid or precursor formic acid. In certain embodiments, the corrosion inhibitor system comprises a mixture of at least one of an alkenyl phenone or α,β-unsaturated aldehyde, an unsaturated ketone or unsaturated aldehyde other than the alkenyl phenone and α,β-unsaturated aldehyde, a dispersing agent, an extender and an alcohol solvent. A corrosion inhibitor intensifier may also be used in certain embodiments, which may include a mixture of cuprous iodide and cuprous chloride. | 03-04-2010 |
20100093891 | Self-Viscosifying and Self-Breaking Gels - The invention provides a method. The method injects into a wellbore, a fluid comprising at least one of an acrylamide polymer and an acrylamide copolymer, and at least one of an oxidizing agent and a radical initiator; and allows viscosity of the fluid to increase for a first period of time; and subsequently, allows viscosity of the fluid to decrease for a second period of time. In a further aspect the invention provides a fluid for use in a well within a subterranean formation penetrated by a wellbore. The fluid is in a first embodiment, made of an acrylamide polymer and/or copolymer and an oxidizing agent or radical initiator, wherein concentration of the oxidizing agent or radical initiator is such that the fluid increases its viscosity for a period of time and after said period of time decreases its viscosity. The fluid is in a second embodiment, made of an acrylamide polymer and/or copolymer and an oxidizing agent or radical initiator, wherein the oxidizing agent or radical initiator is such that the fluid increases its viscosity for a period of time and after said period of time decreases its viscosity. | 04-15-2010 |
20100126723 | Fluid Loss Control - A fluid loss control method uses a fluid loss control pill in a well in advance of a completion operation. An embodiment of the fluid loss control pill comprises polyester solids that are hydrolysable and can exhibit plastic deformation at formation conditions. An embodiment of the method comprises spotting the fluid loss control pill in the well adjacent to a formation to form a filtercake to inhibit fluid entry from the well into the formation, performing a completion operation comprising contacting the filtercake with overbalanced wellbore fluid, and degrading the filtercake wherein the polyester particles are hydrolyzed to remove formation damage. | 05-27-2010 |
20100160189 | Method and Composition for Removing Filter Cake - The current disclosure describes a multifunctional fluid that addresses a new concept in the removal of filter cake. A composition is disclosed comprising: a carrier fluid, a surfactant, a fluorine source and an organic stabilizer able to minimize precipitation of fluorine The associated method to remove the filter cake is also described. | 06-24-2010 |
20100163233 | SYSTEM, METHOD AND TREATMENT FLUID FOR CONTROLLING FINES MIGRATION - A method includes providing a treatment fluid that is a viscous fluid. The viscous fluid may be greater than 0.01 Pa-s, greater than 0.1 Pa-s, and/or a cross-linked polymer based fluid. The method further includes determining a fines migration composition soluble in an aqueous phase of the treatment fluid that is compatible with the treatment fluid, and that interacts to secure fines in an earth formation intersecting a wellbore within a fines reaction time. The method further includes adding an amount of the fines migration composition to the treatment fluid, and treating the earth formation with the treatment fluid. The method includes leaking off a portion of the treatment fluid into the earth formation, and providing a residence time of the leaked off portion of the treatment fluid in the earth formation, where the residence time meets or exceeds the fines reaction time. | 07-01-2010 |
20100181065 | Fluid Loss Additive and Breaking Agent - A system includes a hydraulic fracturing fluid including a polymeric constituent and an additive having particles including poly-vinyl acetate in an amount sufficient to control fluid loss. The system includes a formation of interest having a downhole temperature, and the particles including poly-vinyl acetate have a size and/or shape such that the poly-vinyl acetate hydrolyses at the downhole temperature. The particles may have a size and/or shape such that the particles are deformable at the downhole temperature. The poly-vinyl acetate in the particles may be a part of the particle substrate, a coating on the particles, and/or the entire particle may be poly-vinyl acetate. The poly-vinyl acetate may be included in any portion of the hydraulic fracturing fluid, or only the portion of the hydraulic fracturing fluid that is not proppant laden. | 07-22-2010 |
20100190666 | METHOD FOR TREATING FRACTURING WATER - A method of treating a medium for water fracturing is disclosed, the method comprises: introducing at least one biocide and at least one metabolic inhibitor in the medium, using the medium for water fracturing. In another aspect a method of controlling the post-fracture reservoir souring by the metabolic activities of sulfate reducing bacteria of a well is described: at least one biocide and at least one metabolic inhibitor are introduced in a medium made of water, the medium is used for fracturing the well, and the medium remains in the reservoir to kill and/or inhibit growth of sulfate reducing bacteria. | 07-29-2010 |
20100319915 | APPLICATION OF DEGRADABLE FIBERS IN INVERT EMULSION FLUIDS FOR FLUID LOSS CONTROL - A method of treating a subterranean formation including emplacing in a wellbore a fluid, comprising an oleaginous continuous phase, a non-oleaginous discontinuous phase, an emulsifier, at least one degradable material, and at least one bridging material, and contacting the formation with the fluid. A method and apparatus related to an invert emulsion fluid loss pill including an oleaginous continuous phase, a non-oleaginous discontinuous phase, an emulsifier, at least one degradable material, wherein the degradable material hydrolyzes to release an organic acid, and at least one bridging material. | 12-23-2010 |
20100319919 | APPLICATION OF DEGRADABLE FIBERS IN INVERT EMULSION FLUIDS FOR KILL PILLS - A method of treating a subterranean formation includes pumping into a cased, perforated wellbore that intersects the formation an invert emulsion kill fluid, the invert emulsion kill fluid comprising: an oleaginous continuous phase; a non-oleaginous discontinuous phase; an emulsifier; at least one degradable material; and at least one bridging material; contacting the formation with the kill fluid; and allowing the degradable material to at least partially degrade. | 12-23-2010 |
20100331223 | Acidic Viscosity Enhancer for Viscoelastic Surfactant Fluids - The invention discloses method of treating a subterranean formation of a well bore, the method comprising: providing a treatment fluid comprising: an aqueous base fluid; a viscosity enhancer; and a viscoelastic surfactant, wherein the enhancer is acid in the aqueous base fluid and co-operates with the viscoelastic surfactant to enhance viscosity compared to viscoelastic surfactant alone in the aqueous base fluid; and introducing the treatment fluid into the well bore. | 12-30-2010 |
20110017464 | WELLBORE DEBRIS CLEANOUT WITH COILED TUBING USING DEGRADABLE FIBERS - Embodiments of this invention relate to a method of removing debris from a wellbore including contacting debris in a wellbore with a treatment fluid, wherein the fluid contains degradable fibers, collecting at least a portion of the treatment fluid, and allowing the degradable fibers to degrade. Embodiments of this invention also relate to a method of removing debris from a wellbore including contacting debris in a wellbore with a treatment fluid, wherein the fluid contains degradable fibers, collecting the treatment fluid, and exposing the fluid to a composition to encourage the degradable fibers to degrade. | 01-27-2011 |
20110034352 | RHEOLOGY MODIFIER FOR POLYMER FLUIDS - Embodiments of this invention relate to a composition and a method for tailoring the rheology of a fluid for use in the oil field services industry including forming a fluid comprising a tetrakis(hydroxyalkyl) phosphonium salt and a polymer, and exposing the fluid to a temperature of about 20° C. to about 200° C., wherein a viscosity is observed that is at least about 5 percent different than if no salt were present. Embodiments of this invention also relate to a composition and a method for tailoring the rheology of a fluid for use in the oil field services industry including forming a fluid comprising a tetrakis(hydroxyalkyl) phosphonium salt and diutan and/or guar and/or guar derivatives and/or a combination thereof, and exposing the fluid to a temperature of about 20° C. to about 163° C., wherein a viscosity is observed that is at least about 5 percent lower than if no salt were present. Embodiments of this invention also relate to a composition and a method for tailoring the rheology of a fluid for use in the oil field services industry including forming a fluid comprising a tetrakis(hydroxyalkyl) phosphonium salt and xanthan, and exposing the fluid to a temperature of about 20° C. to about 200° C., wherein a viscosity is observed that is at least about 5 percent higher than if no salt were present. | 02-10-2011 |
20110036582 | Solid incorporated reversible emulsion for a fracturing fluid - Embodiments of this invention relate to an apparatus and a method for treating a subterranean formation permeated by a wellbore including forming a fluid comprising a reverse emulsion and a degradable material, introducing the fluid into a wellbore, and allowing the degradable material to degrade. Embodiments of this invention relate to an apparatus and a method for treating a subterranean formation permeated by a wellbore including forming a fluid comprising a reverse emulsion and a fluid loss additive, introducing the fluid into a wellbore, and allowing the fluid loss additive to degrade. | 02-17-2011 |
20120103609 | COMPOSITIONS AND METHODS FOR WELL COMPLETIONS - Cement retarders for well cements are based on hydrophobins. Hydrophobins are proteins or polypeptides that form hydrophobic coatings on surfaces. The size of the hydrophobins is preferably between about 100 and 350 amino acids, and the preferred hydrophobin concentration is between about 0.001% and 1.0% by weight of cement. Portland cement is the preferred well cement. Cement slurries containing hydrophobins are useful for both primary and remedial cementing applications. | 05-03-2012 |
20120202717 | APPLICATION OF DEGRADABLE FIBERS IN INVERT EMULSION FLUIDS FOR FLUID LOSS CONTROL - A method of treating a subterranean formation including emplacing in a wellbore a fluid, comprising an oleaginous continuous phase, a non-oleaginous discontinuous phase, an emulsifier, at least one degradable material, and at least one bridging material, and contacting the formation with the fluid. A method and apparatus related to an invert emulsion fluid loss pill including an oleaginous continuous phase, a non-oleaginous discontinuous phase, an emulsifier, at least one degradable material, wherein the degradable material hydrolyzes to release an organic acid, and at least one bridging material. | 08-09-2012 |
20120241155 | COMPOSITIONS AND METHODS FOR CLEANING A WELLBORE PRIOR TO CEMENTING - Wellbore-cleaning compositions comprising microemulsions are useful during cementing operations. The microemulsion solvent may be selected from the group comprising methyl esters and ethoxylated alcohols. The microemulsion surfactants comprise a water-wetting surfactant, a cleaning surfactant, an emulsifying surfactant, a non-ionic surfactant and a non-ionic co-surfactant. The wellbore-cleaning compositions may be pumped alone, ahead of a conventional spacer fluid or scavenger slurry and behind a conventional spacer fluid or scavenger slurry. In addition, the wellbore-cleaning composition may be incorporated into a carrier fluid such as (but not limited to) a conventional spacer fluid or scavenger slurry. The resulting fluid mixture may be pumped as a spacer fluid. | 09-27-2012 |