Abstract: A method to enhance oil recovery from a fractured carbonate reservoir, the reservoir being accessible via a production well. The method includes injecting a surfactant solution including surfactants into the production well, and injecting a second well treatment process into the production well. The second well treatment process includes a second well treatment solution. The second well treatment solution is selected from the group consisting of a scale inhibition squeeze process, a well acidizing process, a chemical process to reduce water production rate, carbon dioxide injection for stimulation of a production or injection well, an acid fracturing process, and a hydraulic fracturing process. The surfactant solution and the second well treatment solution are injected into the production well within less than about six months from one another.

Abstract: The present invention relates to use of compositions comprising: (a) a copolymer of an unsaturated phosphonic acid (or salt of such an acid) with an unsaturated sulphonic acid (or salt of such an acid) or an unsaturated carboxylic acid (or salt of such an acid); or (b) a terpolymer of an unsaturated phosphonic acid (or salt of such an acid) with an unsaturated sulphonic acid (or salt of such an acid) and an unsaturated carboxylic acid (or salt of such an acid). These compositions are used to control the formation of scale in water systems.

Abstract: Degradable material assisted diversion (DMAD) methods for well treatment, DMAD treatment fluids, and removable plugs for DMAD in downhole operations. A slurry of solid degradable material is injected into the well, a plug of the degradable material is formed, a downhole operation is performed around the plug diverter, and the plug is then degraded for removal. Degradation triggers can be temperature or chemical reactants, with optional accelerators or retarders to provide the desired timing for plug removal. In multilayer formation DMAD fracturing, the plug isolates a completed fracture while additional layers are sequentially fractured and plugged, and then the plugs are removed for flowback from the fractured layers. In DMAD fluids, an aqueous slurry can have a solids phase including a degradable material and a fluid phase including a viscoelastic surfactant. The solids phase can be a mixture of fibers and a particulate material.

Abstract: Non-spherical particulates are useful in the stimulation of subterranean formations. A proppant pack composed of the non-spherical particulates exhibits greater porosity than a corresponding proppant pack composed of spherical particulates. In addition, the non-spherical particulates exhibit higher conductivity at higher stresses than spherical shaped particulates. Non-spherical particulates which are hollow and non-porous may further be at least partially filled with a chemical treatment agent including water-soluble or oil-soluble chemical treatment agents.

Abstract: An oil recovery method employing amphoteric surfactants with the steps of: a) Injecting into one or more injection wells an aqueous solution containing a mixture of amphoteric surfactants containing mixture of amphoteric surfactants having a hydrocarbyl chain length between 8 and 26 and certain degree of unsaturation, and b) recovering the oil from one or more producing wells. The aqueous injection fluid may also contain one or more of the following: a thickening agent, an alkali, a co-solvent.

Abstract: In some embodiments, a method of delivering at least one chemical into an underground well equipped with a reciprocating plunger includes retaining the plunger above the well after the well is unloaded and shut in, dispensing at least one chemical into the well and releasing the plunger so that the plunger may drop in the well after the chemical(s).

Abstract: Provided embodiments relate to introducing a water-drainage-rate-enhancing agent into a subterranean formation to enhance gas production following a relative-permeability-modifier treatment to decrease undesired water production. An exemplary embodiment provides a method of treating a subterranean formation such that initiation of gas production is enhanced following the treatment, the method comprising: introducing a relative-permeability modifier into at least a portion of the subterranean formation such that the relative-permeability modifier reduces permeability of the portion to aqueous fluids; and introducing a water-drainage-rate-enhancing agent into at least a portion of the subterranean formation. Another exemplary embodiment provides a treatment fluid comprising a carrier fluid, a relative-permeability modifier, and a water-drainage-rate-enhancing agent.

Abstract: A method for reducing or eliminating water block around a well bore of a well bore region in a reservoir is provided. The method comprises removing the water from around the well bore, injecting crude oil around the well bore, and injecting precipitants causing surface precipitation of asphaltenes thereby altering formation wettability in the well bore and decreasing capillary forces of retention for water and/or gas condensates and increasing the flow of hydrocarbon fluids from the reservoir.

Abstract: The handling, transport and delivery of particulate materials, particularly fine particles, may be difficult. Alkaline earth metal oxide particles such as magnesium oxide (MgO) may be suspended in glycerin and/or alkylene glycols such as propylene glycol up to loadings of 51 wt %. Such suspensions or slurries make it easier to deliver MgO and similar agents into fluids, such as aqueous fluids gelled with viscoelastic surfactants (VES). The MgO serves as stabilizers and/or fluid loss control agents for VES-gelled fluids used to treat subterranean formations, e.g. for well completion or stimulation in hydrocarbon recovery operations. The particle size of the magnesium oxide or other agent may be between 1 nanometer to 0.4 millimeter.

Abstract: The handling, transport and delivery of particulate materials, particularly fine particles, may be difficult. Alkaline earth metal oxide particles such as magnesium oxide (MgO) may be suspended in glycerin and/or alkylene glycols such as propylene glycol up to loadings of 51 wt %. Such suspensions or slurries make it easier to deliver MgO and similar agents into fluids, such as aqueous fluids gelled with viscoelastic surfactants (VES). These concentrated suspensions or slurries may be improved in their stability by the inclusion of minor amounts of a vegetable oil and/or a fish oil. The MgO serves as stabilizers and/or fluid loss control agents for VES-gelled fluids used to treat subterranean formations, e.g. for well completion or stimulation in hydrocarbon recovery operations. The particle size of the magnesium oxide or other agent may be between 1 nanometer to 0.4 millimeter.

Abstract: A process for preparation of synthetic crude from a deposit of heavy crude, comprises: (a) the extraction of heavy crude by technology using steam; (b) the separation of crude extract and water; (c) the separation of crude into at least one light fraction and one heavy fraction; (d) the conversion of the heavy fraction of separation into a lighter product, said converted product, and a residue; (e) optionally, the partial or total hydrotreatment of the converted product and/or the light fraction (or fractions) obtained during the separation c), (f) the combustion and/or gasification of the conversion residue; the converted product and the light fraction (or fractions) for separation, optionally having been subjected to a hydrotreatment e), constituting the synthetic crude; said combustion allowing the generation of steam and/or electricity and said gasification allowing the generation of hydrogen; the steam and/or electricity thus generated being used for the extraction a) and/or the electricity and/or hydrog

Abstract: Adding relatively low molecular weight water-soluble friction loss reduction polymers to an aqueous fluid gelled with a viscoelastic surfactant (VES) increases the critical generalized Reynold's number at which the Fanning friction factor increases and friction pressure starts to increase rapidly. The water-soluble polymeric friction loss reduction additives lower surface pumping pressure in VES-gelled fracturing fluids for a given pump rate, thus lowering hydraulic horsepower (HHP) requirements for pumping fluids downhole, e.g. for hydraulic fracturing or frac packing treatments of subterranean formations.

Abstract: Zero discharge processing methods for the treatment of agricultural drainage water (ADW) are disclosed. The disclosed methods are capable of meeting the three critical issues in treating ADW: (1) selective removal of sulfate scale-prone species and toxic species; (2) production of usable water that at least meets irrigation water quality; and (3) recovery of sodium sulfate and sodium chloride as valuable commodities.

Abstract: Asphaltene control additives are added to base fluids which are introduced directly or indirectly into a hydrocarbon-bearing formation to mitigate asphaltene deposition in the formation which results in improved permeability in the formation and production of hydrocarbons therefrom. The fluids to which the additive is added may be liquid CO2-based, aqueous-based or non-aqueous-based fluids. Further, the fluids are fracturing fluids, drilling fluids and wellbore treatment fluids such as acidizing fluids.

Abstract: A composite of a well treatment agent adsorbed onto a water-insoluble adsorbent is useful in the treatment of oil and gas wells and may be introduced, as a well treatment fluid, with a carrier fluid. The water-insoluble adsorbent may be activated carbon, silica particulate, precipitated silica, zeolite, diatomaceous earth, ground walnut shells, fuller's earth and organic synthetic high molecular weight water-insoluble adsorbents. Suitable as the well treatment agent are scale inhibitors, corrosion inhibitors, paraffin inhibitors, salt inhibitors, gas hydrate inhibitors, asphaltene inhibitors, oxygen scavengers, biocides, foaming agent, emulsion breakers and surfactants.

Abstract: Methods for stabilizing unconsolidated or weakly consolidated portions of a subterranean formation and controlling the production of water in those portions include introducing a consolidating agent into the subterranean formation so as to transform a portion of the subterranean formation surrounding the well bore into a consolidated region; and introducing a relative permeability modifier fluid into the subterranean formation so as to penetrate at least a portion of the consolidated region. Fracturing steps may be used to reconnect the well bore to portions of the formation (e.g., formation reservoirs) in certain embodiments. Optionally, preflush fluids, after-flush fluids, and shutting-in periods may be used as desired.

Abstract: A gas hydrate is produced by injecting guest molecules into voids in a layer of which temperature and pressure condition allows the guest molecules to cause to form hydrate, in a form of emulsion where liquid of the guest molecules is dispersed in water as minute particles having a size of less than a size of voids, and thereby dispersing the guest molecules uniformly into the voids in the layer.

Abstract: A method for treating a subterranean formation includes forming a treatment fluid including a carrier fluid, a solid acid-precursor, and a solid scale inhibitor. The solid acid-precursor includes a material that forms an acid at downhole conditions in the subterranean formation. The method further includes adding a solid acid-responsive material into the treatment fluid, where the solid acid-responsive material enhances formation of acid from the solid acid-precursor in acidic conditions. The method includes performing an acid fracture treatment and inhibiting scale formation within the subterranean formation. The solid scale inhibitor allows for long-term scale inhibition after the treatment.

Abstract: Compositions relating to fluid loss control operations are provided. In some embodiments, fluid loss treatment fluid compositions are provided that may comprise ceramic particulate bridging agents, wherein at least a portion of the ceramic particulate bridging agents comprise chemically bonded particulates, a partially depolymerized starch derivative, and a base fluid are provided. In other embodiments, fluid loss treatment fluid compositions are provided comprising ceramic particulate bridging agents, wherein at least a portion of the ceramic particulate bridging agents are substantially insoluble in water; a partially depolymerized starch derivative, and a base fluid.

Abstract: A fluid injection system is used in a well. Fluid stages are arranged in repeating series within a tubing of the fluid injection system to facilitate control over effects of injection. A sensor system can be used to detect one or more parameters related to the fluids moved downhole through the tubing to further enhance injection procedures.

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, matrix acidizing, and the like.

Abstract: Subterranean treatment operations, and more particularly, methods of treating subterranean formations using treatment fluid compositions including chlorinated carbohydrates, are provided. An example of a method is a method of treating a subterranean formation, including: providing a treatment fluid including water, a hydraulic cement, and a chlorinated carbohydrate; placing the treatment fluid in a subterranean formation; and permitting the treatment fluid to treat the formation. An example of a method is a method that includes providing a cement composition that includes water, a hydraulic cement, and an additive that includes a chlorinated carbohydrate and a tartaric acid; placing the cement composition in a subterranean formation; and permitting the cement composition to set therein.

Abstract: Of the many methods provided, in one aspect, the present invention provides a method comprising: providing a treatment fluid comprising: an aqueous base fluid, a first surfactant, and a surfactant-based fluid loss control agent capable of forming a viscoelastic fluid; and introducing the treatment fluid into a well bore that penetrates the subterranean formation.

Abstract: Methods are provided that include a method comprising providing a treatment fluid comprising a base fluid and a gelling agent that comprises a diutan composition; providing a breaker that comprises an acid composition; allowing the breaker to interact with the treatment fluid; and allowing the viscosity of the treatment fluid to decrease. In some embodiments, the treatment fluid may comprise a base fluid, a gelling agent that comprises a diutan composition, and a breaker that comprises an acid composition. In some embodiments, the treatment fluid may be introduced into a portion of the subterranean formation at or above a pressure sufficient to create or enhance one or more fractures in the portion of the subterranean formation. Additional methods are also provided.

Abstract: Substances to stimulate the extraction of crude oil and a method, of processing them: This invention is about substances to stimulate the extraction of crude oils, especially the ponderous and paraffin one, not clogging the route and the abutting deposits of the oil derrick by changing the deposit's reology and also about solubility of the aggregates which were made from paraffin resins on the oil derrick's circulation route, using a similar chemical vector to the prodrugs from the medicine industry. The substance to stimulate the extraction of crude oil by increasing the fluidization characterized by the fact that 90% from the volume is made by mixing three fractions oil types from the distilled mineral coal: ?20-30% phenol oil (fraction distilled from 170-190° C.); ?20-40% absorption oil (fraction distilled from 250-270° C.); ?20-40% polymerized oil (fraction distilled from 320-350° C.

Abstract: A formulation containing a copolymer derived from a cationic monomer effectively inhibits and controls the formation of inorganic scales. Suitable copolymers include those comprising an acrylamide unit and a quaternary ammonium salt group, and optionally an acrylate and/or nitrogen heterocyclic monomer including those wherein the quaternary ammonium salt is a unit of the formula: wherein R is methyl or hydrogen; R4 is a C1 to C6 alkyl group, optionally substituted with halogen, hydroxyl and alkoxy groups, X is halogen; and R1, R2 and R3 are independently selected from the group consisting of alkyl and alkoxy groups. Suitable nitrogen heterocyclic compounds include N-vinylpyrrolidone, N-vinylformamide, N-vinylacetamide, N-vinylcaprolactam, N-vinylimidazole and N-vinylpyridine.

Abstract: Subterranean treatment operations, and more particularly, methods of cementing subterranean formations using cement compositions including maltodextrin, are provided. An example of a method of the present invention is a method of cementing a subterranean formation, comprising: providing a cement composition comprising water, a hydraulic cement, and an additive comprising maltodextrin; placing the cement composition in a subterranean formation; and permitting the cement composition to set in the formation.

Abstract: Methods are disclosed for the selective separation of sulfate from a saline stream such as seawater to produce nearly sulfate-free saline stream for oil-fields water injection operations. The separated sulfate in the form of gypsum from the treated saline stream can be used in different applications.

Abstract: A method for underground treatment of subsurface materials comprises providing an injection pattern and a recovery pattern, the injection pattern and the recovery pattern located proximate to a subsurface treatment zone and at least one of the injection pattern and the recovery pattern comprising a plurality of lateral bores extending from a main bore. A treatment solution is injected through the injection pattern and recovered through the recovery pattern.

Abstract: A method of treatment of subterranean formations in which leakoff through natural fractures is controlled through the use of fibers. The method involves pumping a mixture of a formation treatment fluid and a fiber into the formation for matrix stimulation, fracture stimulation, diversion, and/or water control. In carbonate formations, the formation treatment fluid is preferably an in situ gelled acid. The method optionally also involves pumping the same or a different formation treatment fluid without fiber.

Abstract: Methods of steam flooding for stimulating hydrocarbon production are provided. In general, the methods comprise the steps of: (A) injecting a mutual solvent preflush fluid capable of dissolving oil into the near-wellbore region of at least a portion of a wellbore; (B) injecting an aqueous preflush fluid further comprising a surfactant capable of oil-wetting silica; (C) injecting a treatment fluid into the near-wellbore region, wherein the treatment fluid comprises a curable resin, and wherein: (i) when injected, the curable resin is in an uncured state; and (ii) after being cured, the curable resin is stable up to at least 350° F. (177° C.); and (D) driving steam to break through the near-wellbore region.

Abstract: An aqueous, viscoelastic fluid gelled with a viscoelastic surfactant (VES) is stabilized and improved with an effective amount of an alkali earth metal oxide and/or alkali earth metal hydroxide. These fluids are more stable and have reduced or no tendency to precipitate, particularly at elevated temperatures. The additives may also increase viscosity to the point where less VES is required to maintain a given viscosity. These stabilized, enhanced, aqueous viscoelastic fluids may be used as treatment fluids for subterranean hydrocarbon formations, such as in hydraulic fracturing.

Abstract: Treating fluid production and subterranean formation treating methods as well as treating fluid compositions that reuse at least part of a prior treating fluid, particularly a fluid having one or more constituents that can be relinked. This includes conditioning a selected at least partially delinked flow-back fluid recovered from a first treating fluid pumped into a well, such that the conditioned selected at least partially delinked flow-back fluid provides a constituent for a second treating fluid. Also included are pricing considerations. A composition for a treating fluid includes a treating fluid residual recovered from a well, preferably a conditioned treating fluid residual. Examples of such compositions include fracturing fluids and gravel pack fluids.

Abstract: The invention provides for a composition for treating a subterranean formation, the composition comprising: a) a crosslinkable water-soluble polymer comprising at least one acylated amine unit; and b) a crosslinkable water-soluble polymer comprising a functional group selected from the group consisting of carboxylic acid and carboxylic acid derivative. The invention also provides for a method of treating a subterranean formation penetrated by a wellbore, the method comprising the steps of forming the treatment fluid and introducing the treatment fluid through the wellbore and into contact with the formation.

Abstract: Among many things, compositions and methods relating to the prevention and remediation of surfactant gel damage are provided. In one embodiment, the method includes providing a treatment fluid comprising a carrier fluid; at least one component selected from the group consisting of a chelating agent and a scale control agent; at least one component selected from the group consisting of an alcohol, a glycol, a pH modifier, a hydrocarbon, a mutual solvent, an oxidizer, a reducer, an enzyme, a transition metal, a combination thereof, and a derivative thereof; and at least one component selected from the group consisting of a nonemulsifier, a demulsifier, a combination thereof, and a derivative thereof, and introducing the treatment fluid into a subterranean formation.

Abstract: Methods of acidizing subterranean formations or well bores, and more specifically, to acidizing systems involving acid-generating fluids that comprise acid-generating compounds and associated methods are provided. An example is a method that comprises: providing an acid-generating fluid that comprises an acid-generating compound; placing the acid-generating fluid into a subterranean formation; and allowing an acid to generate from the acid-generating fluid.

Abstract: Among many things, compositions and methods relating to the prevention and remediation of surfactant gel damage are provided. In one embodiment, the method includes providing a treatment fluid comprising a carrier fluid and at least one component selected from the group consisting of a chelating agent and a scale control agent, and introducing the treatment fluid into a subterranean formation that has been treated with a viscoelastic surfactant fluid.

Abstract: Methods of acidizing subterranean formations or well bores, and more specifically, to acidizing systems involving acid-generating fluids that comprise acid-generating compounds and associated methods are provided. An example of a method of the present invention comprises: providing an acid-generating fluid that comprises an acid-generating compound; placing the acid-generating fluid into a well bore penetrating a subterranean formation; and allowing the acid-generating compound to produce an acid that then acidizes at least a portion of the subterranean formation or damage contained in the formation or well bore.

Abstract: In one embodiment, a method of treating a subterranean formation is provided comprising the steps of providing a gelled liquid hydrocarbon treatment fluid comprising a liquid hydrocarbon and a gelling agent that comprises a polyvalent metal salt of an organophosphonic acid ester or a polyvalent metal salt of an organophosphonic acid, and treating the subterranean formation with the gelled liquid hydrocarbon treatment fluid. The gelled liquid hydrocarbon treatment fluids are suitable for use in subterranean treatment operations, such as subterranean stimulation and sand control treatments like fracturing and gravel packing, that may be carried out in subterranean formations for the production of hydrocarbons. The compositions and methods also may be suitable, for example, to be used as plugging agents, well bore cleanup fluids, viscous sweep fluids, or insulating fluids to be used in associated methods.

Abstract: The invention provides a composition for use in a subterranean formation penetrated by a wellbore, the composition comprising: a) a solvent consisting essentially of a water-soluble solvent selected from the group consisting of any solvent that is at least 25% by weight soluble in water and any mixture of two or more thereof in any proportion, wherein the solvent is from about 90% to about 99.9% by weight of the composition; and b) a tackifying compound, wherein the tackifying compound is from about 0.01% to about 10% by weight of the composition; wherein the tackifying compound and the solvent are mutually selected such that, for the ratio of the tackifying compound to the solvent, the tackifying compound is soluble in the solvent. The invention also provides a method for treating a subterranean formation penetrated by a wellbore, the method comprising the steps of: a) forming the composition; and b) introducing the composition through the wellbore into the subterranean formation.

Abstract: Methods of treating a portion of a subterranean formation, comprising: providing an aqueous treatment fluid comprising water, and a friction reducing copolymer that comprises acrylamide and an acrylic acid ester; and introducing the aqueous treatment fluid into the portion of the subterranean formation. Methods of fracturing a subterranean formation comprising: providing an aqueous treatment fluid comprising water, and a friction reducing copolymer that comprises acrylamide and an acrylic acid ester; and introducing the aqueous treatment fluid into the subterranean formation at or above a pressure sufficient to create one or more fractures in the subterranean formation. Aqueous treatment fluids comprising: an aqueous fluid and a friction reducing copolymer that comprises acrylamide and an acrylic acid ester.

Abstract: Treating fluid production and subterranean formation treating methods as well as treating fluid compositions that reuse at least part of a prior treating fluid, particularly a fluid having one or more constituents that can be relinked. This includes conditioning a selected at least partially delinked flow-back fluid recovered from a first treating fluid pumped into a well, such that the conditioned selected at least partially delinked flow-back fluid provides a constituent for a second treating fluid. Also included are pricing considerations. A composition for a treating fluid includes a treating fluid residual recovered from a well, preferably a conditioned treating fluid residual. Examples of such compositions include fracturing fluids and gravel pack fluids.

Abstract: Embodiments of the present invention are directed to defoaming methods and compositions for well treatment fluids. An exemplary embodiment of the present invention provides a method of treating a subterranean formation, comprising introducing a treatment fluid comprising a liquid and a defoaming composition into a subterranean formation, the defoaming composition comprising an amide of carboxylic acid, a polypropylene glycol, an ethoxylated and propoxylated fatty alcohol, an ethoxylated alcohol comprising from 3 carbons to 6 carbons, and a hydrophobic silica in an amount of up to about 3% by weight of the defoaming composition.

Abstract: A well treating fluid useful in slickwater fracturing processes contains polyacrylamide friction reducer and a viscosity breaker capable of reducing the viscosity of the well treating fluid to about the viscosity of water at ambient temperatures of typical underground formations. The viscosity breaker is selected from the group consisting of hydrogen peroxide, calcium peroxide, magnesium peroxide, and zinc peroxide and is present in an amount above about 0.002% by weight.

Abstract: A method of introducing an oil field or gas field production chemical into a hydrocarbon-bearing porous subterranean formation penetrated by a wellbore comprising: injecting a gelling composition comprising an aqueous liquid, an oil field or gas field production chemical, and a gellable polymer through the wellbore into the porous subterranean formation wherein the gellable polymer forms a gel within the pores of the subterranean formation thereby encapsulating the production chemical in the gel; and controllably releasing the production chemical from the gel into a formation fluid.

Abstract: A method is described for treating a subterranean formation with a low viscosity fluid system that contains a surfactant or mixture of surfactants that does not divert fluid flow in the formation, but that develops the ability to divert flow as the fluid flows through the formation. The fluid optionally contains a formation-dissolving agent. The fluid is used in matrix acidizing, acid fracturing, and diversion.

Abstract: A method to enhance oil recovery from a fractured carbonate reservoir, the reservoir being accessible via a production well. The method includes injecting a surfactant solution including surfactants into the production well, and injecting a second well treatment process into the production well. The second well treatment process includes a second well treatment solution. The second well treatment solution is selected from the group consisting of a scale inhibition squeeze process, a well acidizing process, a chemical process to reduce water production rate, carbon dioxide injection for stimulation of a production or injection well, an acid fracturing process, and a hydraulic fracturing process. The surfactant solution and the second well treatment solution are injected into the production well within less than about six months from one another.

Abstract: A formulation containing a copolymer derived from a cationic monomer effectively inhibits and controls the formation of inorganic scales. The formulation has particular application in the removal of zinc sulfide and iron sulfide scales formed when zinc bromide brines are used as completion fluids. The copolymer exhibit high solubility in high-density brines, such as zinc bromide brines. The polymers may be introduced into an oil or gas well as a portion of a carrier fluid or with brine. The preferred copolymer for use in the invention contains an acrylamide unit and a diallyldimethylammonium salt and, optionally, an acrylic acid or a salt thereof. The weight average molecular weight of such inhibitor copolymers is generally between from about 500,000 to about 5,000,000.

Abstract: The invention provides a method of well treatment comprising introducing into the matrix surrounding a hydrocarbon well bore hole an emulsion the discontinuous phase of which comprises a non-polymerizable, water or oil miscible liquid carrier, a polymerizable monomer and a thermally activated polymerization initiator, said monomer constituting from 2 to 40% wt. of said discontinuous phase.

Abstract: Methods are provided including a method of treating a portion of a subterranean formation comprising: providing a treatment fluid comprising a plurality of self-degrading fibers, the self-degrading fibers comprising an outer shell and a core liquid; placing the treatment fluid into a subterranean formation; and treating a portion of the subterranean formation. Additional methods are also provided.