Abstract: A method of treating a formation that includes emplacing an oxidizing breaker fluid into a region of the formation occupied by a gel; and allowing sufficient time for the oxidizing breaker fluid to degrade the gel is disclosed.

Abstract: Methods comprising providing a treatment fluid that comprises using an aqueous base fluid, a synthetic cationic gelling agent, a plurality of particulates, and an organic acid. The treatment fluid is then introduced into at least a portion of a subterranean formation having a temperature of above about 275° F. wherein the particulates are deposited into the subterranean and the treatment fluid form at least one void in the subterranean formation itself. The viscosity of the treatment fluid in the subterranean formation is greater than about 20 cP for at least 20 minutes at temperatures higher than about 275° F.

Abstract: Certain emulsions and masses produced using those emulsions exhibited improved permeability and stability. In one embodiment, the methods comprise: providing a composition that comprises a plurality of inorganic particulates, an aqueous component, and an organic component comprising at least one polymerizable monomer and at least one surface active agent in an amount of up to about 10% by volume of the organic component; permitting the composition to form an emulsion that comprises an internal aqueous phase in an amount of at least about 50% by volume of the emulsion and a continuous organic phase; introducing the composition into at least a portion of a subterranean formation; and permitting the composition to form a porous polymer mass in at least a portion of the subterranean formation.

Abstract: The present invention relates to methods useful for isolating a portion of a wellbore. In one embodiment, a method includes preparing a sealant composition containing a set modifier component. The sealant composition is placed into the wellbore and is subjected to ionizing radiation that alters the set modifier component, triggering the thickening of the sealant composition.

Abstract: A method comprising providing a composition with at least one isocyanate including a blocking group able to be unblocked at or above a deblocking temperature, contacting the composition with an inactivated catalyst and at least one active hydrogen compound, exposing the composition to a trigger to activate the catalyst, creating an elastomeric gel composition, and exposing the composition to a temperature above the deblocking temperature with a second downhole tool, wherein the second downhole tool is able to generate microwaves is provided.

Abstract: Structures can be formed downhole by accumulating already existing materials and/or materials introduced into a well to perform a specified function. The formed structures may be used to obstruct fluid flow of production or injection fluids, carry mechanical loads, control electrical or magnetic properties of components, mechanically actuate a component, as well as others. The materials may be induced to form the specified structure, such as by application of a potential downhole. For example, electrical, magnetic, sonic, biological potentials, or a combination thereof may be established downhole to form specified structures in specified locations to perform specified functions.

Abstract: A two part epoxy resin system is surface mixed in a method of remediating an active well. This surface mixed epoxy resin is then placed in the well at the desired remediation depth. Finally, the mixture in situ forms a cement plug.

Abstract: Techniques for preconditioning an oilfield reservoir including heavy oil and/or bitumen prior to production of a petroleum product are described. A preconditioning agent can be injected into a mobile water film included in the oilfield reservoir. The preconditioning agent preconditions the reservoir prior to production of the petroleum product.

Abstract: Method comprising introducing a first remedial fluid into a first portion of a subterranean formation, wherein the first remedial fluid comprises a base fluid and a viscosifying agent, and allowing the first remedial fluid to divert at least a portion of a second remedial fluid that comprises an oxidizer to a second portion of the subterranean formation. Wherein the viscosifying agent comprises at least one viscosifying agent selected from the group consisting of a gelling agent, an emulsifier, or a gas in combination with a foaming agent. Also wherein the polymeric gelling agent, if present, comprises at least one polymer selected from the group consisting of xanthan, diutans, wellans, succinoglycan, clarified biopolymers, scleroglycan, combinations thereof, and derivatives thereof.

Abstract: Of the many methods and compositions provided herein, in one embodiment, the invention provides a method comprising: providing an oil-wet well bore surface; providing a surfactant wash treatment fluid that comprises an acid-compatible surfactant, an acid and/or an acid-generating component, and an aqueous fluid; contacting the oil-wet well bore surface with the surfactant wash treatment fluid; allowing the oil-wet well bore surface to become water-wet; and producing fluids from the formation. In another embodiment, the invention provides a surfactant wash treatment fluid for use in a subterranean formation comprising an aqueous fluid, an acid-compatible surfactant, an acid and/or an acid-generating component.

Abstract: The invention discloses a method of creating a polymerized composition in a well bore: providing a polymerizable composition made of a polymerization initiator and a monomer polymerizable by frontal polymerization; introducing the polymerizable composition into the wellbore; exposing the polymerizable composition to a trigger to activate the frontal polymerization; and creating the polymerized composition.

Abstract: A depolymerized-carboxyalkyl polysaccharide formed by de polymerizing a polysaccharide having from 0.5 to 3.0 degrees of substitution and reducing the molecular weight of said polysaccharide before or after said depolymerizing provides a biodegradable scale inhibitor useful to prevent deposition of scale comprising, for example, calcium, barium, sulfate and salts thereof. The depolymerized carboxyalkyl polysaccharide is particularly useful in off shore oil production squeeze treatments and in the treatment of scale formed in industrial water treatment.

Abstract: Disclosed herein is a well treatment fluid comprising an aqueous solution comprising greater than or equal to about 1 wt % boron, at least 5 wt % of a co-solvent, and greater than or equal to about 5 wt % sodium hydroxide, potassium hydroxide, or a combination thereof, wherein the co-solvent comprises glycerol, ethylene glycol, propylene glycol, or a combination thereof. Methods of using the well treatment fluid are also disclosed.

Abstract: A method and apparatus for the management of injection and production of well fluids in a subterranean well is described to optimize the use of stimulation fluids to enhance their compatibility with subterranean reservoirs and the surface environment and thereby reducing the damage said fluids induce in subterranean reservoirs and upon flow back to the surface reduce their damage to the environment is described. More specifically, this method is directed to the subterranean treatment of injection fluids.

Abstract: Methods of controlling fluid loss, providing fluid diversion, or plugging a portion of a well bore using a treatment fluid including relatively insoluble borate material particulates that are placed into a subterranean formation to provide the desired action and then degrade over time in the subterranean formation in the presence of an aqueous fluid such as water.

Abstract: The current application discloses 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. The current application also discloses 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.

Abstract: 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.

Abstract: Methods comprising providing a polymerizable treatment fluid that comprises furfuryl alcohol monomer dispersed in an aqueous base fluid; introducing the polymerizable treatment fluid to a portion of a subterranean formation; and allowing the polymerizable treatment fluid to polymerize in the subterranean formation. The methods may include the use of contacting the furfuryl alcohol with an initiator to begin polymerization.

Abstract: One apparatus for releasing a chemical in a well bore includes a casing collar configured to couple to a casing string. A chemical container is disposed within the casing collar, and the casing collar is configured to release the chemical from the chemical reservoir.

Abstract: 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.

Abstract: The present invention includes methods relating to the setting of fluids or slurries in a wellbore. In one embodiment, a method of isolating a portion a wellbore by preparing a sealant composition comprising a fluid component and a polymeric additive component, placing the sealant composition into a wellbore and subjecting the sealant composition to ionizing radiation. The ionizing radiation can cause bonding between polymeric additive components and create a polymer matrix within the sealant composition that increases the mechanical strength of the sealant composition.

Abstract: Disclosed are processes for improving recovery of product from a subterranean carbonaceous deposit wherein there has been a reduction in product recovery from a production well, the processes comprising treating the deposit with a liquid that contains at least one of an oxoacid ester of phosphorous or an oxoacid acid ester of sulfur.

Abstract: A method to enhance oil recovery from a subterranean reservoir, the reservoir being accessible via a production well. The method includes injecting a surfactant solution that includes surfactants into the production well. The surfactant solution selected to increase an oil-to-water ratio of oil recovery from a porous matrix portion of the reservoir. The method also includes injecting a well-servicing volumetric solution into the production well to perform a second well treatment process. The second well treatment process is selected from the group consisting of a scale inhibition squeeze process, a well acidizing process, a chemical process to reduce water production rate, an acid fracturing process, and a hydraulic fracturing process. In the method, the surfactant solution and the second well treatment solution are injected into the production well within less than about six months of one another.

Abstract: Solid material required at a subterranean location is supplied from the surface suspended in a carrier liquid and agglomerated below ground by means of a binding liquid. To achieve agglomeration, the binding liquid and the particulate solid are similar to each other but opposite to the carrier liquid in hydrophilic/hydrophobic character. The solid and the binding liquid may both be hydrophobic while the carrier liquid is hydrophilic, or vice versa. The solid may be hydrophobically surface modified to render it hydrophobic. The binding liquid may be provided as a precursor which converts to the binding liquid below ground to trigger agglomeration after arrival at the subterranean location. The agglomerates may function as proppant heterogeneously placed in a fracture of a reservoir, or may serve to block an unwanted path of flow. The binding liquid may polymerise after agglomeration so as to stabilise and strengthen the agglomerates.

Abstract: A method and apparatus for fracturing a formation containing a wellbore comprising the steps of (a) injecting a gel into the wellbore; (b) permitting the gel to increase in viscosity and (c) fracturing the formation in the vicinity of the gel.

Abstract: The present invention relates to a process for the enhanced recovery of oil in a deposit owing to the introduction, into the deposit, of an alkaline aqueous solution of a water-soluble polymer containing a surfactant, characterized in that the aqueous solution of water-soluble polymer introduced is prepared with an aqueous solution initially containing Ca2+ and Mg2+ ions treated with an alkaline agent and a dispersant, so as, prior to the introduction of the polymer and of the surfactant into the aqueous solution, to precipitate, under the action of the alkaline agent and of the CO2 optionally dissolved in the aqueous solution, the Ca2+ and Mg2+ ions, especially in the form of precipitates of calcium carbonate and of magnesium hydroxide, and to disperse said precipitates owing to the dispersant, chosen in order to limit the size of the calcium carbonate and magnesium hydroxide precipitates formed.

Abstract: A method of servicing a wellbore in contact with a subterranean formation, comprising: placing a wellbore servicing fluid comprising a crosslinkable polymer system and a filler into a lost circulation zone within the wellbore. A method of blocking the flow of fluid through a lost circulation zone in a subterranean formation comprising placing a first composition comprising a packing agent into the lost circulation zone, placing a second composition comprising a crosslinkable polymer system and a filler into the lost circulation zone, and allowing the compositions to set into place.

Abstract: The invention relates to the use of one or more water-soluble reactive liquid component capable of subsequent polymerization or cross-linking to form a solid to improve the zonal isolation and alleviate the impacts of cracks and fissures in the cement sheath around a completed subterranean well. It includes the steps of injecting a wellbore fluid carrying the reactive component or additive into the wellbore, injecting a cementitious composition as slurry into the wellbore and letting said reactive liquid component pass through at least one of the interfaces between cement and formation, cement and filter cake, and filter cake and formation before forming a solid of said reactive liquid component that traverses said at least one of the interfaces.

Abstract: Materials are delivered into oil well reservoirs. Highly sensitive, mechanical, biological and chemical agents can be delivered to subterranean formations with rigid, impermeable capsules. A variety of treatments may be delivered to a subterranean formation.

Abstract: The methods described herein generally relate to preparing and delivering a fluid mixture to a confined volume, specifically an annular volume located between two concentrically oriented casing strings within a hydrocarbon fluid producing well. The fluid mixtures disclosed herein are useful in controlling pressure in localized volumes. The fluid mixtures comprise at least one polymerizable monomer and at least one inhibitor. The processes and methods disclosed herein allow the fluid mixture to be stored, shipped and/or injected into localized volumes, for example, an annular volume defined by concentric well casing strings.

Abstract: Methods and compositions of fracturing formations are provided. The fracturing fluid includes an enzyme breaker that decreases the viscosity of the fracturing fluid over time. The enzyme breaker can be used in environments having a pH value ranging from about 7 to about 12.

Abstract: A method of stimulating production from a subterranean formation penetrated by a wellbore, comprising pumping a fluid from the well into the formation so as to create a hydraulic fracture. The fluid contains one or more reactive species that destabilize cohesive forces in the formation matrix. The method allows the fluid to leak of into the formation and react with the formation matrix so as to produce a destabilized zone in the formation around the location of the fracture such the formation fluids and sand particles can be produced from the formation through the zone and into the well.

Abstract: A method of selectively blocking fractures in a subterranean formation by injecting a diversion agent into the well is disclosed. According to one embodiment, the method comprises injecting a diversion agent into a subterranean formation to form an alkaline-earth carbonate precipitate from decomposition of a carbonyl compound, wherein the diversion agent includes the carbonyl compound and an alkaline-earth halide salt.

Abstract: The invention provides a method made of steps of injecting into a wellbore, a composition comprising a solvent, a crosslinkable polymer, a crosslinking agent capable of crosslinking the polymer or forming a polymer, and a gelling accelerator selected from the group consisting of carbon dioxide, polylactic acid, encapsulated acid and latent acid; and allowing viscosity of the composition to increase and form a gel more quickly with the gelling accelerator than without.

Abstract: According to an embodiment, a method for thermally insulating a portion of a tubular located inside an enclosed conduit comprises the steps of: (A) introducing a grouting composition into an annulus between the tubular and the enclosed conduit, the grouting composition comprising: (i) an oil-swellable binding material; and (ii) a hydrocarbon liquid, wherein the hydrocarbon liquid is the continuous phase of the grouting composition; and (iii) an insulating material comprising a hollow microsphere; and (B) allowing or causing the grouting composition to set after the step of introducing, wherein after setting the grouting composition has a thermal conductivity of less than 0.3 BTU/hr·ft·° F.

Abstract: This invention relates to a swellable and degradable sand plug system used in horizontal wellbores and the use of the system in treating horizontal wellbores. The slurry composition comprises a carrier fluid and a granular borate source material, where the borate source material is at least partially dehydrated or anhydrous. The carrier fluid may be a non-aqueous fluid, or when the average size of the granular borate source material is sufficient large, the carrier fluid may also be an aqueous fluid. The slurry composition is allowed to settle in the horizontal wellbore and at least partially fill at least a portion of the horizontal wellbore in a direction vertical to the substantially horizontal wellbore, and is exposed to a sufficient amount of aqueous fluid to expand to the point to substantially fill at least a portion of the horizontal wellbore in a direction vertical to the horizontal wellbore, thereby plugging the substantially horizontal wellbore.

Abstract: A method of controlling ingress of water into a production well used to extract fluid hydrocarbons the method comprising the steps of: introducing a composition comprising a polymer, a polar solvent, a cross-linking agent and a base oil into the production well; recovering hydrocarbons from the production well; wherein the polymer comprises an alcohol moiety. The density of the composition is preferably between 0.92 to 1.00 g/cm3 thus naturally being directed to the interface between lower density oil and higher density water. Moreover the viscosity of the composition is preferably between 200 to 500 sec?1 centipoise at a shear rate of 113 sec?1 and at a temperature of 20° C. and so can flow preferentially into water bearing regions of the reservoir thus further aiding water shut-off. Embodiments of the present invention are particularly suitable for use in recovering unconventional hydrocarbon reservoirs such as tar sands.

Abstract: Certain viscous oil reservoirs are too deep to be commercially mined but lack an adequate top seal to employ in situ recovery methods such as SAGD. Without an adequate top seal, gases from the reservoir can rise into overlying aquifers and potentially to the surface. While ice-like hydrates would not normally form above the oil reservoir during in situ recovery, an additive can be added to promote hydrate formation. In this way, a hydrate barrier can be formed to act as a top seal to contain these gases.

Abstract: Methods for treating a formation penetrated by a wellbore which improves fluid loss control during treatment. In some aspects, the treatments include preparing an aqueous fluid including one or more water inert polymers and an optional viscosifier, injecting the aqueous fluid into the wellbore at a pressure equal to or greater than the formation's fracture initiation pressure, and thereafter injecting into the wellbore a proppant laden fluid at a pressure equal to or greater than the formation's fracture initiation pressure. The water inert polymer may be a polymer such as an emulsion polymer or a latex polymer. Some methods of the invention use a fluid which may have a normalized leak off coefficient (Cw/sqrt(K)) equal to or less than about 0.0022, 0.0014, or 0.0010. A conventional fluid loss additive may or may not be used in conjunction with the treatment fluid and/or the proppant laden fluid. The water inert polymer may or may not substantially enter formation pores.

Abstract: Sealant compositions comprising a colloidally stabilized latex and methods of using the same to service a wellbore are provided. The sealant compositions may include: an aliphatic conjugated diene monomer; an additional monomer comprising a non-aromatic unsaturated mono- or di- carboxylic ester monomer, an aromatic unsaturated monomer, a nitrogen-containing monomer, or combinations thereof; and a protective colloid. The foregoing sealant composition may be displaced into the wellbore to isolate the subterranean formation from a portion of the wellbore, to support a conduit in the wellbore, to plug a void or crack in the conduit, to plug a void or crack in a cement sheath disposed in an annulus of the wellbore, to plug an opening between the cement sheath and the conduit, or combinations thereof. The colloidally stabilized latex remains substantially stable when exposed to salt, which may be present in the wellbore and/or in the sealant composition itself.

Abstract: A well treatment fluid and method of use includes water, at least one hydratable polymer, an optional crosslinking agent, and a delayed release percarbonate formulation effective to reduce initial viscosity of the fluid after a period of time. Also disclosed are processes for fracturing a subterranean formation.

Abstract: 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, Al2O3, and mixtures thereof. The viscosity enhancer may include pyroelectric particles, piezoelectric particles, and mixtures thereof. The fluid system is easy to pump into the formation, and after initial pumping, the fluid system will soak into and occupy or “pre-saturate” the pores of the formation prior to pumping of a second treating fluid for fracturing, gravel packing, frac-packing, and the like. The methods are practiced in the absence of acids typically used in acidizing operations, such as hydrochloric acid and hydrofluoric acid.

Abstract: The subject matter relates to an apparatus for insertion of a conduit into a well system bore to introduce a reactant fluid over a subterranean catalyst to initiate decomposition of the reactant fluid which resultant energy release may be utilized to perform work or perform heating of the subterranean environment. The energy released from the catalytic reaction and subsequent combustion of fuels may also be used for cutting, welding, powering pumps, compressors, turbines, generators, or to heat well system fluids, pipes, subterranean reservoir fluids, subterranean solids, and completion devices in the well system.

Abstract: Among the methods described herein are methods using low-specific gravity particulates wherein the particulates comprise silica and an aluminum oxide in an amount of about 0.1% to about 25% by weight and having at least one void, a specific gravity of less than about 2.2, a particle sized of 8 U.S. Mesh or smaller, and a substantially spherical shape.

Abstract: An apparatus for controlling fluid flow in a borehole in an earth formation includes: a carrier configured to be deployed in the borehole; and a shape memory device disposed at the carrier, the shape memory device including a shape memory material having a glass transition temperature, the shape memory material configured to modify the glass transition temperature to a temperature lower than a borehole temperature in response to a trigger, and change from a glass state to a rubber state in response to the borehole temperature to prevent fluid flowing through the shape memory device.

Abstract: The present invention relates to aqueous oilfield treatment fluids containing a gas component and fibers, wherein the fluids may further include a viscosifying agent and/or proppant. The fluids have good proppant suspension and transport properties as well as excellent gas phase stability. Use of fluids comprising an aqueous medium, a gas component, viscosifying agent, and fibers for hydraulically fracturing a subterranean formation, cleanup operations, and gravel packing a wellbore, are also disclosed.

Abstract: Methods for creating and using multi-phase fluid flows are disclosed. In one embodiment, such a method includes introducing an inner fluid into a tubular conduit. The method further includes introducing a ring fluid into the tubular conduit. In this embodiment, the ring fluid is disposed annularly between the inner fluid and the interior of the tubular conduit, and the flow of the ring fluid is laminar.

Abstract: Solid latex powders are employed as additives to control gas migration during the cementation of subterranean wells. Preferably, the latex additives are based on vinyl-acetate or styrene-butadiene based polymers. The additives are particularly useful in low-temperature applications. Methods to prepare cement slurries comprising the latex additives, and methods pertaining to the cementation of subterranean wells are also presented.

Abstract: A downhole annealing system includes a component to be annealed; a steam generating catalyst in proximity to the component; and a reactant fuel selectively communicative with the catalyst to produce an exothermic reaction and method.

Abstract: A method of treating a formation with a well treatment fluid comprising a clay stabilizer comprising a polyamine ether before or during a well treatment such as cleanup, gravel packing, fracturing, or the like. The stabilizer can continue to inhibit fines migration in the treatment zone even after an aqueous fluid without the stabilizer, e.g. a production fluid or injection fluid, displaces the original treatment fluid. When the stabilizer is used in a viscoelastic system (VES) with an acid blend component, the viscosity of the VES is essentially unchanged relative to the VES alone without the stabilizer.