Abstract: Methods of stabilizing unconsolidated portions of a subterranean formation are provided. In one embodiment, the methods comprise: creating or enhancing at least two slots in an unconsolidated portion of a subterranean formation along a well bore, wherein the slots are positioned about 180 degrees from each other along the inner surface of the well bore; introducing a consolidating agent into the slots in the unconsolidated portion of the subterranean formation; and creating or enhancing at least one fracture in a portion of the subterranean formation.

Abstract: A process is described for replacing at least a portion of the liquid within the annular volume of a casing system within a wellbore with a second liquid. The second liquid is preselected to provide a measure of control of the pressure within the annular volume as the fluid within the volume is being heated.

Abstract: A method is provided for treating a zone of a subterranean formation penetrated by a wellbore. The method includes a step of introducing a treatment fluid into a zone of a subterranean formation through the wellbore, wherein the treatment fluid comprises: (i) water; (ii) a gelling agent comprising a polymer grafted with a vinyl phosphonic acid or derivative thereof; and (iii) a crosslinking agent, and the step of subsequently introducing an oxidizer into a zone of a subterranean formation through the wellbore. According to another aspect the method includes a step of introducing a treatment fluid into a zone of a subterranean formation through the wellbore, wherein the treatment fluid comprises: (i) water; (ii) a gelling agent comprising a polymer grafted with a vinyl phosphonic acid or derivative thereof; and (iii) a magnesium oxide; and the step of: introducing an acid into the zone through the wellbore.

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: Disclosed embodiments relate to methods of completing wells in subterranean formations. An exemplary embodiment comprises forming an artificial barrier to water flow, wherein the artificial barrier is located at or above a hydrocarbon-water interface between a water-bearing formation zone and a hydrocarbon-bearing formation zone. The exemplary embodiment further comprises consolidating a portion of the hydrocarbon-bearing formation zone, wherein the artificial barrier is located between the consolidated portion of the hydrocarbon-bearing formation zone and the water-bearing formation zone.

Abstract: A method for use within a subterranean formation penetrated by a wellbore includes introducing a thixotropic agent into the well and introducing a cement slurry into the well. The method includes forming a thixotropic cement slurry downhole, including mixing the cement slurry and the thixotropic agent downhole.

Abstract: A method is provided for reducing lost circulation when aqueous, oil, or synthetic based drilling fluid is used. The method includes injecting two fluids into the well bore and lost circulation zone. The first fluid is an aqueous liquid containing at least one polymer capable of absorbing water in an alkaline environment. The aqueous liquid has a pH that inhibits at least one polymer from absorbing water. The second fluid contains a hardening composition in a base fluid having a pH sufficient to increase the pH in situ to allow at least one polymer to absorb water and expand with the absorbed water and substantially increase in size to close off the lost circulation zone and allow the hardening composition to create a plug in the well bore and set up.

Abstract: Methods for stabilizing portions of a subterranean formation and controlling the production of water from those subterranean formations. In one embodiment, the methods of the present invention comprise: providing a consolidating agent; introducing the consolidating agent into an unconsolidated portion of a subterranean formation using a fluid diversion tool; allowing the consolidating agent to at least partially consolidate the unconsolidated portion of the subterranean formation; providing a relative permeability modifier; introducing the relative permeability modifier into the subterranean formation using a fluid diversion tool; and allowing the relative permeability modifier to modify the relative permeability of at least a portion of the subterranean formation.

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: A wellbore system is provided including a wellbore formed in an earth formation, the wellbore extending into a salt layer of the earth formation. The wellbore system comprises a tubular conduit arranged in the wellbore whereby at least a portion of the tubular conduit is surrounded by the salt layer whereby an annular space is formed between said portion of the tubular conduit and the wellbore wall. The wellbore system further comprises an annular body of a resilient material arranged in said annular space and extending substantially the length of said portion of the tubular conduit surrounded by the salt layer.

Abstract: Novel well cement compositions are provided. Exemplary embodiments of the well cement compositions comprise water, a cement and a fluid loss control additive comprising a graft polymer. The graft polymer comprises a backbone comprising a lignite. The graft polymer further comprises grafted monomers selected from the group consisting of 2-acrylamido-2-methylpropanesulfonic acid, acrylamide, acrylic acid, vinylphosphonic acid, diallyldimethylammonium chloride and salts thereof.

Abstract: A method for well treatment by forming a temporary plug in a fracture, a perforation, a wellbore, or more than one of these locations, in a well penetrating a subterranean formation is provided, in which the method of well treatment includes: injecting a slurry comprising a degradable material, allowing the degradable material to form a plug in a perforation, a fracture, or a wellbore in a well penetrating a formation; performing a downhole operation; and allowing the degradable material to degrade after a selected time such that the plug disappears.

Abstract: The prevention of latex inversion in saltwater cement compositions for use in subterranean formations by inclusion of a combination of latex stabilizers and associated methods of cementing. Saltwater cement compositions comprising saltwater, a cement, a latex, a first latex stabilizer comprising a surfactant having the formula: R—O—(OCH2CH2)mXM wherein R is an alkyl group having in the range of from about 10 carbons to about 20 carbons, m is an integer in the range of from about 10 to about 40, X is OSO3 or SO3, and M is a compatible cation, and a second latex stabilizer comprising an alcohol ether sulfate having the formula: R1—O—(OCH2CH2)nOSO3M wherein R1 is an alkyl group having in the range of from about 4 carbons to about 12 carbons, n is an integer in the range of from about 1 to about 10, and M is a compatible cation.

Abstract: Novel uses of reactive surfactants in treating subterranean formations and/or proppant particulates are provided. In one embodiment, the present invention provides a method comprising: providing a treatment fluid that comprises a base fluid and a reactive surfactant; introducing the treatment fluid into a subterranean formation; and allowing the reactive surfactant to interact with a surface in the subterranean formation.

Abstract: Methods of retarding the setting of a cement composition comprise including one or more secondary amines substituted with a carboxyl group or salts thereof (e.g., 3-hydroxy N,N?-iminodisuccinic acid) in the cement composition. The inclusion of such materials in cement compositions may be highly beneficial. In wellbores having BHCT's of less than or equal to about 250° F., the use of the secondary amine as the set retarder ensures that the thickening time of the cement composition is sufficient to allow the cement composition to be pumped to its desired downhole location. Further, the secondary amine may be used in combination with conventional set retarders to enhance the ability of those retarders to increase the thickening time of the cement composition at higher BHCT's, e.g., from about 250° F. to about 525° F.

Abstract: Methods for using rapid setting plugging compositions comprising oil, clay, magnesium chloride, and magnesium oxide powder to seal permeable zones in subterranean formations are provided. The permeable zones may be sealed by passing the plugging composition and water to the subterranean formation. While being exposed to downhole temperatures in a range of from about 0° F. to about 500° F., the plugging composition quickly thickens to form a sealing mass that is substantially impermeable to fluid in less than about 1 minute after contacting the water. It then usually develops an effective amount of compressive strength to prevent it from being washed away within a period ranging from about 5 minutes to about 2 hours at temperatures ranging from about 0° F. to about 500° F.

Abstract: A high temperature blocking gel contains a blend of an aqueous fluid and carboxymethyl guar and a crosslinking agent. The gel exhibits excellent hydration capability in brines and positive viscosity generation and controls fluid loss from an oil well during drilling, completion and/or workover operations.

Abstract: A composition includes water having a salinity of at least 1 ppt, at least one hydrophilic polymer containing primary (—NH2) and/or secondary (—NHR) amine groups and at least one saccharide containing a reducible function. A method of changing the permeability of a subterranean formation includes the step of injecting into a subterranean formation a composition comprising water, at least one hydrophilic polymer containing at least two groups which are independently the same or different a primary amine group or a secondary amine group and at least one saccharide containing a reducible function.

Abstract: A method of controlling the physical interface between two wellbore servicing fluids during the displacement of one wellbore servicing fluid by another, the method comprising selecting a liquid plug having a viscosity greater than the viscosity of the two wellbore servicing fluids, introducing a first wellbore servicing fluid into the wellbore, introducing a volume of the liquid plug into the wellbore, and introducing a second wellbore servicing fluid into the wellbore, wherein the liquid plug is selected such that the mixing between the two wellbore servicing fluids is minimized.

Abstract: A sealant composition and methods for using the same are disclosed. In an embodiment, a method of servicing a wellbore in contact with a subterranean formation is disclosed. The method comprises placing a sealing agent and a nonaqueous carrier fluid in the wellbore. The method further comprises placing a nonaqueous activating fluid in the wellbore. In addition, the method comprises contacting the sealing agent with the nonaqueous activating fluid to form a sealant composition.

Abstract: According to various embodiments, methods of increasing a shelf life of a gas-generating material comprise: including a C8-C18 hydrocarbon in a mixture used to coat the gas-generating material. This gas-generating material may be used in a cement composition to generate gas therein after the composition has been placed in a wellbore. The coating surrounding the gas-generating material serves to delay the reaction for producing the gas until desired. The gas may serve to inhibit gas migration from an adjacent subterranean formation into and through the cement composition before it sets into a hard mass. Coating the gas-generating material with the mixture may ensure that it can be stored for a relatively long period of time (e.g., up to 1 year or longer) without being concerned that it might experience sintering and thus react prematurely.

Abstract: A method for sealing a subterranean zone is disclosed. The method includes the steps of preparing a wellbore fluid, placing the wellbore fluid into at least a portion of an annular space between the sidewalls of a wellbore and the exterior of a casing string disposed in the wellbore, and allowing the wellbore fluid to solidify therein, wherein the wellbore fluid includes an oleaginous fluid as the continuous phase of the wellbore fluid, a non-oleaginous fluid as the discontinuous phase of the wellbore fluid, and about 5 to about 50 pounds per barrel of a thermally activated hydrocarbon gellant.

Abstract: A clayish subterranean formation, such as may be encountered in rock surrounding a well bore during hydrocarbon recovery operations may be stabilized with relatively high molecular weight polyamine salts of an imide of polymaleic anhydride. The salts may be unneutralized or partially neutralized. The invention is particularly relevant to hydraulic fracturing fluids used in enhanced oil recovery. The compositions herein are made in the presence of a reactive solvent, such as a polyalkylene glycol, e.g. polyethylene glycol. The compositions of this invention are more environmentally friendly than some current technology.

Abstract: Crosslinkable-polymer compositions that comprise a chitosan-based compound and a phenol source, and associated methods, are provided. Various methods of use are also provided. In one embodiment, the methods comprise providing a crosslinkable-polymer composition comprising an aqueous fluid, a chitosan-based compound, a chitosan-reacting polymer, and a phenol source; introducing the crosslinkable-polymer composition into the portion of the subterranean formation; and allowing the crosslinkable-polymer composition to form a crosslinked gel in the portion of the subterranean formation.

Abstract: A well service fluid comprising one or more anionic viscoelastic surfactants and one or more polymers is described. The fluids can contain an aqueous or non-aqueous fluid and/or a buffer for adjusting the pH of the fracturing fluid. The well service fluid can be used as a fracturing fluid in order to control water production from a well, while simultaneously increasing the oil production from the well.

Abstract: Crosslinkable-polymer compositions are provided that may be useful for, among other things, reducing, stopping, or diverting the flow of fluids in subterranean formations. The crosslinkable-polymer compositions may comprise an aqueous fluid, a chitosan-reacting polymer, chitosan, and a gelation-retarding additive comprising an acid derivative. Various methods of use are also provided.

Abstract: The present invention is a composition for forming seals. The composition includes a base material and a hydrogel. The base materials is preferably an elastomer or a thermoplastic. Seals formed with the composition are particularly suited for use in a wellbore environment. The inclusion of hydrogel in the seals allows the seals to be manipulated or altered through certain environmental factors. For instance, temperature, oil/water ratio, pH and the electronic field may all be used to alter the characteristics of the hydrogel. In this way, the seal may be caused to swell in response to a specific stimulus, thereby preventing or sealing a leak without requiring additional work or input from the operator.

Abstract: The invention provides a method of treating a subterranean formation penetrated by at least one injection well and at least one production well, the method comprising the steps of a) analyzing the injection well, the production well, and reservoir contained in the subterranean formation; b) selecting at least one fluid and at least one permeability reducer to be placed in flow ways contained within the formation; and c) performing a formation permeability modification using the selected fluids and at least one permeability reducer, whereby the flow of injected driving fluid between the injection well and production well is substantially reduced. In one embodiment, the method of analyzing the injection well, the production well, and reservoir contained in the subterranean formation includes the steps of evaluation of completion information, reservoir data, or both.

Abstract: The invention discloses an additive for weighted aqueous slurries to reduce lost circulation during well drilling operations, a method of preparing the additive, and a method of reducing lost circulation utilizing the additive. The additive comprises a hardenable alkaline composition comprising mixtures of diatomaceous earth, finely ground paper, a hydrophobic liquid, micronized cellulose and lime. The hydrophobic liquid decreases the time required to prepare the weighted aqueous slurries, i.e., pills, containing the additive.

Abstract: The invention provides a method of forming packs in a plurality of perforations in a casing of a wellbore, the method comprising the steps of: (a) forming a plug of a plugging particulate material in the wellbore of the casing, wherein the plug covers at least one perforation in the casing; (b) forming a pack of a first packing particulate material in at least one perforation located above the plug in the casing; (c) removing at least an upper portion of the plug to expose the at least one perforation in the casing that had been previously covered by at least the upper portion of the plug; and (d) forming a pack of a second packing particulate material in the at least one perforation exposed by removing at least the upper portion of the plug, wherein the second packing particulate material can be the same or different from the first packing particulate material.

Abstract: A method of servicing a wellbore that penetrates a subterranean formation includes displacing a cement composition comprising an aromatic sulfonated polymer into the wellbore and allowing the cement composition to set. In an embodiment, a transition time of the cement composition is less than or equal to about 60 minutes, alternatively less than or equal to about 50 minutes, less than or equal to about 40 minutes, less than or equal to about 30 minutes, less than or equal to about 20 minutes, or less than or equal to about 10 minutes. Thus, the transition time may be short enough to inhibit a substantial amount of gas migration into the cement composition before it sets. In yet another embodiment, the cement composition exhibits a viscosity that increases from a value of 35 Bc (Bearden units) to about 100 Bc in about 10 minutes or less when the cement composition sets.

Abstract: Crosslinkable polymer compositions comprising an aqueous fluid; a water-soluble polymer comprising carbonyl groups; an organic crosslinking agent capable of crosslinking the water-soluble polymer comprising carbonyl groups; and a water-soluble carbonate retarder. Methods comprising: providing a crosslinkable polymer composition; introducing the crosslinkable polymer composition into a portion of a subterranean formation; and allowing the crosslinkable polymer composition to form a crosslinked gel in the portion of the subterranean formation.

Abstract: A clayish subterranean formation, such as may be encountered in rock surrounding a well bore during hydrocarbon recovery operations may be stabilized with a polyamine salt of an imide of polymaleic anhydride. The salt may be unneutralized or partially neutralized. The invention is particularly relevant to hydraulic fracturing fluids used in enhanced oil recovery. The compositions of this invention are more environmentally friendly than some current technology.

Abstract: Improved casing strings, and methods of using improved casing strings in subterranean operations, are provided. An example of a method is a method of cementing a pipe string in a subterranean formation. Another example of a method is a method of cementing a pipe string in a well bore. An example of an apparatus is an improved pipe string comprising at least one pipe section; and a delivery system of an activator; wherein the delivery system of an activator is disposed adjacent an outer surface of the at least one pipe section.

Abstract: A method for stimulation of gas production from coal seams is described using a permeability modifier, such as a coal swelling agent, injected into the coal seams via a wellbore to reduce the permeability of the coal seams prior to a fracturing treatment.

Abstract: A method of stimulating a production interval adjacent a well bore having a casing disposed therein, that comprises introducing a carrier fluid comprising first particulates into the well bore, packing the first particulates into a plurality of perforations in the casing, perforating at least one remedial perforation in the casing adjacent to the production interval, and stimulating the production interval through the at least one remedial perforation. Also provided are methods of stimulating multiple production intervals adjacent a well bore.

Abstract: Methods of cementing in a subterranean formation may include the steps of: providing a cement composition comprising a cement, water, and a dispersant comprising a low molecular weight starch that comprises anionic groups; placing the cement composition in the subterranean formation; and allowing the cement composition to set therein. In certain embodiments, improved biodegradable dispersants may include low molecular weight starches having anionic groups.

Abstract: A liquid gel concentrate for forming a high viscosity treating fluid is provided which can be premixed and stored before being used. The concentrate is comprised of an aqueous formate solution, at least one hydratable polymer which yields viscosity upon hydration and optionally an inhibitor having the property of reversibly reacting with the hydratable polymer in a manner whereby the rate of hydration of the polymer is retarded. Upon the selective reversal of the hydration inhibiting reaction the polymer is hydrated and high viscosity yielded thereby. The concentrate can be diluted with water to hydrate the hydratable polymer and form a large volume of high viscosity treating fluid.

Abstract: An under-balanced drilling fluid additive is disclosed which reduces reactive shale and/or clay swelling during under-balanced drilling operations, where the additive includes an effective amount of a choline salt. A method for under-balanced drilling is also disclosed including the step of circulating a drilling fluid including an effective amount of a choline salt to reduce reactive shale and/or clay swelling during under-balanced drilling operations.

Abstract: The present invention relates to settable compositions that comprise magnesium oxide and at least one divalent salt and associated methods of use. In some embodiments, the present invention discloses methods of a forming a hardened mass comprising providing a settable composition comprising magnesium oxide, and a brine comprising water and a divalent salt; placing the settable composition into a desired location; and allowing the settable composition to set to form the hardened mass. In other embodiments, the present invention discloses methods of forming a hardened mass in a subterranean formation comprising placing a brine comprising water and a divalent salt into the subterranean formation; contacting the brine with magnesium oxide; and allowing the brine and the magnesium oxide to react to form the hardened mass. In other embodiments, the present invention discloses methods forming a casing in a well bore, and converting a drilling fluid to a settable composition.

Abstract: Methods for performing wellbore operations using a treating fluid that includes zeolite, an activator, and an organic acid or salt thereof. The treating fluid used in the methods includes a zeolite having a mean particle size that is less than or equal to 100 microns.

Abstract: The present invention provides a method of cementing in a subterranean formation that includes providing a cement composition that includes water, cement, and a fluid loss control additive that includes a water-soluble hydrophobically modified polymer or a hydrophilically modified water-soluble polymer; placing the cement composition into the subterranean formation; and allowing the cement composition to set therein. In certain embodiments, the water-soluble hydrophobically modified polymer or the hydrophilically modified water-soluble polymer may include a polymer backbone that comprises polar heteroatoms. In another embodiment, the water-soluble hydrophobically modified polymer may be a reaction product of a hydrophobic compound with a polyvinylamine, a poly(vinylamine/vinyl alcohol), or an alkyl acrylate polymer.

Abstract: A novel microorganism producing a nontoxic, non-antigenic exopolysaccharide is taught. The exopolysaccharide has neutral sugars migrating at the same rate as mannose, fucose, fructose and galactose, acidic sugars migrating at the same rate as fucose and amine sugars migrating at the same rate as glucose and fucose, and wherein the ratio of galactose:fucose:glucose:mannose is about 1:2:3:6. The microbe and the exopolysaccharide have uses as a biofilm in geologic applications and have several consumer uses as food and drug polymers and use as a plasma extender.

Abstract: A fluid-loss pill that includes a brine solution and an effective amount of a viscoelastic surfactant is disclosed. The viscoelastic surfactant preferably includes at least one compound selected from the family of compounds described by where R1, R2, R3, R4 and R5 are carbon atom or carbon chains, saturated or unsaturated, single or multiple unsaturation, straight chain, branched chain or cyclic including aromatic or alicyclic groups, and R1 contains 16–26 carbon atoms, R2 contains 2–10 carbon atoms, R3, R4 and R5 contains 1–6 carbon atoms. Methods of treating a well that include injecting fluid-loss pill into a well to control lost-circulation or to kill a well.

Abstract: Subterranean fluids, and more particularly, subterranean fluids comprising a hydraulic cement in an invert emulsion, and methods of using such fluids in subterranean operations, are provided. An example of these methods is a method of cementing a well bore. Another example of these methods is a method of reducing the cost to cement a well bore in a subterranean formation.

Abstract: A process is described for reducing the production of water in oil wells which comprises the injection into the formation around the well of an aqueous solution of one or more polymers selected from those having general formula (I), wherein: n ranges from 0.70 to 0.98; m ranges from 0.30 to 0.02; n+m=1; X1 and X2, the same or different, are selected from H and CH3; R1, R2, R3, the same or different, are selected from C1–C10 monofunctional hydrocarbyl groups; and x ranges from 2 to 5.

Abstract: Methods of temporarily reducing the permeability of one or more selected sections of a subterranean formation penetrated by a horizontal well bore and the flow of water or water and hydrocarbons or hydrocarbons therefrom are provided. The methods comprise the steps of preparing or providing an aqueous treating fluid comprising water and a water-soluble formation permeability reducing agent, introducing the aqueous treating fluid into one or more selected sections and when required, contacting the one or more selected sections with an aqueous treating fluid comprising water and a formation permeability restoring chemical.

Abstract: Cement compositions including environmentally compatible defoamers and methods of using such cement compositions are provided herein. An example of a method is a method of cementing in a subterranean formation. Another example of a method is a method of reducing foam generation in a cement composition. An example of a composition is a cement composition including water, hydraulic cement, and a defoamer. Another example of a composition is a defoamer.

Abstract: The present invention provides subterranean fluids comprising a hydraulic cement in an invert emulsion, and methods of using such fluids in subterranean well cementing operations. The fluids comprise a hydraulic cement and an invert emulsion of oil, water, and a surfactant. Optionally, other ingredients may be included in the fluids.

Abstract: Methods and cement compositions for sealing a subterranean zone penetrated by a wellbore. The cement compositions include cementitious material, a polymer emulsion and a mixing fluid. The polymer emulsion includes at least one polar monomer and at least one elasticity enhancing monomer.