Abstract: Expansive cements for use in cementing subterranean wells contain an encapsulated gas-generating substance. The gas-generating substance comprises one or more materials that release hydrogen, nitrogen or both. The gas-generating substance is encapsulated by a coating comprising a polymer. The coating prevents premature gas release at the surface during slurry mixing, and promotes gas release at a desired location in the subterranean well. The released gas may also control the internal pore pressure of the cement slurry, thereby inhibiting the invasion of formation fluids into the borehole.

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: Cement compositions containing biowaste ash and methods of cementing in subterranean formations using such cement compositions. Examples of suitable biowaste ash include agricultural waste ash, municipal waste ash, waste-water treatment waste ash, animal waste ash, non-human-non-animal industrial waste ash, and combinations thereof.

Abstract: Disclosed are pumpable-fluid compositions and methods for establishing hydraulic isolation in cemented subterranean wells. The fluid compositions comprise solids-free solutions of water-soluble polymers. Upon entering voids and cracks in the cement sheath and contacting the set-cement surfaces, the fluid gels and forms a seal that prevents further leakage.

Abstract: Well-cementing compositions for use in high-pressure, high-temperature (HPHT) wells usually contain a complex array of cement additives, including retarders, dispersants and fluid-loss additives. Under these extreme conditions additive degradation, reactions between additives, reactions between additives and the cement, or combinations thereof may occur—causing slurry gelation, premature setting or both. Incorporation of polyvalent-metal salts in the cement compositions can help prevent or reduce the severity of slurry gelation, setting-time reduction or both.

Abstract: Well-cementing compositions for use in high-pressure, high-temperature (HPHT) wells usually contain a complex array of cement additives, including retarders, dispersants and fluid-loss additives. Under these extreme conditions additive degradation, reactions between additives, reactions between additives and the cement, or combinations thereof may occur—causing slurry gelation, premature setting or both. Incorporation of organoamine compounds in the cement compositions may help prevent or reduce the severity of slurry gelation, setting-time reduction or both.

Abstract: A grouting system for anchoring a reinforcement in a mine includes a package that is a tubular member formed of polymer film and has discrete first and second compartments. Hardenable cementitious material that is a hydratable substance and water is disposed in the first compartment. A method of forming a resin grouting capsule includes: injecting a hardenable material into a first compartment of the capsule having resin mastic; wherein the hardenable material does not substantially react with the resin mastic when injected into the first compartment. Another method of forming a resin grouting capsule includes: injecting a hardenable material into a first compartment of the capsule having catalyst mastic; wherein the hardenable material does not substantially react with the catalyst mastic when injected into the first compartment.

Abstract: A method is disclosed for reducing lost circulation in drilling wells, employing composite materials as lost circulation materials. The composites comprise a thermoplastic polymer and cellulosic fibers. Optionally the composites may include other components such as calcium carbonate, clay, oil and other blending agents.

Abstract: Methods and compositions are provided that relate to cementing operations. Methods and compositions that include a latex strength enhancer for enhancing the compressive strength of slag compositions.

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: Methods and compositions are provided that relate to cement compositions and methods comprising sub-micron calcium carbonate and latex. An embodiment includes a method of cementing in a subterranean formation. The method may comprise introducing a cement composition into the subterranean formation, wherein the cement composition comprises cement, water, sub-micron calcium carbonate, and latex. The method further may comprise allowing the cement composition to set in the subterranean formation. Another embodiment includes a cement composition that may comprise cement, water, a sub-micron calcium carbonate, and latex.

Abstract: A copolymer containing, as monomer components, a) at least one sulfonic acid-containing compound, b) at least one nitrogen-containing N-vinylamide, one acrylamide or methacrylamide and c) at least one bifunctional or higher-functional vinyl ether is proposed. These copolymers are suitable in particular as thixotropic agents, antisegregation agents and water retention agents and overall as an additive in cement-containing but also gypsum-based systems. Such copolymers having a molecular weight of >40 000 g/mol can be used in particular as admixtures in the exploration of mineral oil and natural gas deposits.

Abstract: Of the methods provided in this invention, one method includes: providing a treatment fluid comprising: an aqueous fluid, a microemulsion surfactant, and an amphiphilic polymer, wherein the amphiphilic polymer comprises a hydrophobic component, and a hydrophilic component; and introducing the treatment fluid into a subterranean formation, wherein the microemulsion surfactant forms a microemulsion that comprises the amphiphilic polymer within the subterranean formation.

Abstract: The invention relates to providing controlled delivery of subterranean fluid additives to a well bore treatment fluid and/or a surrounding subterranean environment using intelligent materials that respond to a magnetic stimulus to release subterranean fluid additives downhole in a subterranean environment. Methods disclosed include a method of releasing a subterranean fluid additive in a subterranean formation comprising: providing a magnetically-sensitive component that comprises a subterranean fluid additive; providing a magnetic source; and releasing the subterranean fluid additive in the subterranean formation from the magnetically-sensitive component using a magnetic force generated from the magnetic source.

Abstract: Copolymers based on a polyamide containing at least one graft lateral chain consisting of ethylenic unsaturated compounds, in construction chemistry, as well as with the prospecting, exploiting and completion of oil-and gas deposits and with deep bore holes.

Abstract: A method of servicing a wellbore comprising placing a sealant composition comprising solid latex into the wellbore.

Abstract: Fluid compositions comprising an aqueous epoxy resin, a hardener and particles comprising silica, aluminosilicate or both are useful for establishing hydraulic isolation in cemented subterranean wells. Upon entering voids and cracks in or adjacent to the cement sheath, and contacting the set-cement surfaces, the composition reacts and forms a seal that prevents further leakage.

Abstract: The present invention relates to methods and compositions useful for isolating a portion of a wellbore. In one embodiment, a method includes preparing a sealant composition containing two phases. The sealant composition is placed into the wellbore where one phase sets upon subjecting the sealant composition to a thermal source followed by the setting of the other phase.

Abstract: High solids content slurry, systems and methods. The slurry comprises a carrier fluid and a solids mixture of first, second, third and fourth particle size distribution (PSD) modes wherein the first PSD mode is at least three times larger than the second PSD mode, which is larger than the third PSD mode, which is larger than the fourth PSD mode, and wherein at least one of the second and third PSD modes is less than 3 times larger than the respective third or fourth PSD mode. The method comprises forming the slurry, positioning a screen in a wellbore and circulating the slurry through the wellbore such that the solids mixture is deposited between the screen and the wellbore. The system comprises a pump to circulate the slurry, a workstring to position the screen and means for converting the slurry to a gravel pack.

Abstract: A composition for use in plugging a well includes a mud having a plurality of plugging members therein, wherein the plugging member has a density more than about eight times that of water. A method of providing the composition into the well is also provided.

Abstract: A composition for treating a subterranean formation is formed from water, a water-soluble polymer and a crosslinking system. The crosslinking system utilizes 1) primary crosslinking agent of at least one of a dialdehyde benzene source, a dioxane, and a trioxane, 2) a secondary low temperature organic crosslinking agent that generates aldehyde, and 3) a phenol source. The crosslinking system provides the composition a delayed gel time of about 2 to about 20 hours at temperatures of about 250° F. (121° C.) or higher. A method of treating a subterranean formation penetrated by a wellbore is also accomplished by forming a treatment fluid from the composition and introducing the treatment fluid into the formation through the wellbore.

Abstract: The invention provides a method made of steps of injecting into a wellbore, a composition comprising a solvent, a surfactant, a foaming gas, a foam enhancer, a crosslinkable polymer, and a crosslinking agent capable of crosslinking the polymer, wherein the foam enhancer increases the foam half-life of the gel composition compared to the gel composition without the foam enhancer; and allowing viscosity of the composition to increase and form a gel.

Abstract: According to an embodiment, a well treatment composition comprises: an aqueous liquid; a fluid loss additive, wherein the fluid loss additive comprises a high molecular weight, water-swellable polymer; and an amphiphilic dispersant, wherein the well treatment composition has an activity of at least 10%. According to another embodiment, a method of cementing in a subterranean formation comprises: introducing a cement composition into the subterranean formation, the cement composition comprising: (i) cement; (ii) water; and (iii) the well treatment composition; and allowing the cement composition to set.

Abstract: According to an embodiment, a well treatment composition comprises: a water-soluble, organic liquid, wherein the organic liquid comprises the continuous phase of the well treatment composition, and wherein the organic liquid comprises a polyglycol or a derivative of polyglycol; a fluid loss additive, wherein the fluid loss additive is insoluble in the organic liquid, and wherein the fluid loss additive comprises a high molecular weight, water-swellable polymer; and a suspending agent, wherein the suspending agent comprises an organophilic clay, wherein the well treatment composition has an activity of at least 15%. According to another embodiment, a method of cementing in a subterranean formation comprises: introducing a cement composition into the subterranean formation, the cement composition comprising: (i) cement; (ii) water; and (iii) the well treatment composition; and allowing the cement composition to set after introduction into the subterranean formation.

Abstract: The invention is a composition, for use in treating oil wells, comprising fibres, hot melt adhesives and particulate solids. This composition has a wide range of applications including preventing or lessening lost circulation, wellbore strengthening or consolidation, controlling fluid loss, producing a “stress cage” effect, gravel packing, acting as an aid to cementing, and for proppant backflow control.

Abstract: Disclosed are compositions and methods for providing fluid-loss control in subterranean wells. Well-completion fluids contain fine particulate additives whose glass-transition temperatures are below the anticipated bottomhole temperature. The particles soften upon injection into the well, whereupon they soften and become deformable. The particles then migrate to the borehole wall and form a seal that reduces further fluid flow from the borehole into the formation. The additive may be supplied as a powder or in the form of a liquid suspension.

Abstract: A method of servicing a wellbore comprising contacting a wellbore servicing composition with a rheology modifying additive wherein the rheology modifying additive comprises a gum and a polymeric material. A method of cementing in a subterranean formation comprising providing a sealant composition comprising cement, water, and a rheology modifying additive wherein the rheology modifying additive comprises a gum and an anionic polymer, placing the composition in the subterranean formation, and allowing the cement composition to set therein.

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: Of the many embodiments presented herein, one is a subterranean treatment fluid comprising: an aqueous fluid; and a water-soluble degradable synthetic vinyl polymer having a labile link in its backbone. Also provided in one instance is a water-soluble degradable synthetic vinyl polymer with labile group in its backbone made by a redox polymerization, the redox polymerization reaction comprising these reactants: a macroinitiator that comprises a labile link, an oxidizing metal ion, and a vinyl monomer.

Abstract: The invention relates to the use of vinyl phosphonic acid or a salt thereof for improving the biodegradability of mixed polymers, comprising 25 to 99.5% by weight of structural units of one or more monomers selected from the group made of compounds of formula (1) and formula (3), where R1 and R2 independently are hydrogen or C1-C4-alkyl, formula (4), where n is 3, 4, or 5, and formula (5), where X is OH or for NR3R4, and R3 and R4 independently are H or C1 to C4-alkyl, in that 0.5 to 25% by weight of vinyl phosphonic acid is polymerized into the mixed polymer.

Abstract: The use of a setting accelerator composition for inorganic binders which comprises at least one water-soluble comb polymer suitable as a superplasticizer for hydraulic binders and calcium silicate hydrate particles in the development, exploitation and completion of underground mineral oil and natural gas deposits and in deep wells is proposed. The use according to the invention not only accelerates the setting and hardening of the cement slurries but also shortens the time in which the static gel strength of the hardening cement slurries increases from 100 lb/100 ft2 (4.88 kg/m2) to 500 lb/100 ft2 (24.4 kg/m2).

Abstract: A plurality of solid particles including a thermoplastic composition having a softening temperature in a range from 50° C. to 180° C. and a blocked isocyanate resin; optionally at least some of the particles in the plurality of solid particles comprise both the thermoplastic composition and the blocked isocyanate resin. A composition comprising the plurality of particles dispersed in a fluid is also disclosed. A method of modifying a wellbore within a geological formation is also disclosed. The method includes introducing the fluid composition into the wellbore. A method of making a plurality of particles, for example, to use in the fluid composition, is also disclosed.

Abstract: This invention is generally related to using treatments fluids having additives that modify rheological characteristics. Some embodiments of the present invention provide methods of using treatment fluids comprising an aqueous fluid and an associative polymer additive, wherein the associative polymer additive increases the PV of the treatment fluid by more at least 50% and wherein the associative polymer additive increases the yield point by no more than about 30% of the corresponding increase in the PV relative to a treatment fluid without the associative polymer additive in a portion of a subterranean formation.

Abstract: A compressible and highly flexible plugging agent comprises the following components in parts by weight: 70-80 parts of natural rubber, 0.5-1 part of polyacrylamide (PAM), 1.5-3 parts of polyanionic cellulose (PAC), 0.5-1 part of biopolymer XC and 10-15 parts of ultrafine calcium carbonate; and the preparation method thereof comprises the following steps: adding the components in the weight parts into the natural rubber in order according to the common preparing method at normal temperature and pressure, mixing and stirring evenly, drying and then grinding into particles of 0.05-50 mm. The plugging agent is characterized by wide raw material sources, simple process, safe application, high plugging ratio and high compressibility, which is suitable for oil recovering and geological drilling applications.

Abstract: According to one embodiment, a treatment fluid for a well includes: (a) a water-soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non-acidic ethylenically unsaturated polar monomer; (b) an organic crosslinker comprising amine groups, wherein the organic crosslinker is capable of crosslinking the water-soluble polymer; (c) a Lewis acid; and (d) water; wherein the treatment fluid is a crosslinkable polymer composition.

Abstract: According to one embodiment, a treatment fluid for a well includes: (a) a water-soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non-acidic ethylenically unsaturated polar monomer; (b) an organic crosslinker comprising amine groups, wherein the organic crosslinker is capable of crosslinking the water-soluble polymer; (c) a salt of a weak Bronsted base and a Bronsted acid; and (d) water; wherein the treatment fluid is a crosslinkable polymer composition.

Abstract: According to one embodiment, a treatment fluid for a well includes: (a) a water-soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non-acidic ethylenically unsaturated polar monomer; (b) an organic crosslinker comprising amine groups, wherein the organic crosslinker is capable of crosslinking the water-soluble polymer; (c) a weak organic acid; and (d) water; wherein the treatment fluid is a crosslinkable polymer composition.

Abstract: A gravel packing system, method and slurry. The system comprises a blending device to prepare a slurry comprising a carrier fluid suspending first, second and third particulates, wherein the carrier fluid comprises a brine and less than about 2.4 g/L (20 lb per 1000 gallons) of a viscosifier, and wherein the sum of the mass of the particulates is greater than about 2.4 kg/L (20 pounds per gallon), wherein the first average particle volume is between 27 and 3375 times larger than the second average particle volume, which in turn is between 27 and 3375 times larger than the third average particle volume. The system can also include tubing to position a screen in the wellbore and a slurry pump to circulate the slurry from the blending device in the wellbore in any order such that the particulates are deposited in the screen annulus to form a gravel pack.

Abstract: The water retention agents according to the invention are outstandingly suitable as additives in construction chemistry systems and in the development, exploitation and completion of underground mineral oil and natural gas deposits and in deep wells, their effect being particularly advantageous at increased temperatures and because of their lack of influence on the rheological properties of the well slurries.

Abstract: Compositions and methods according to the invention are directed to a cement composition for use in a subterranean formation. The cement composition comprises: (A) cement; (B) water; and (C) a polymer, wherein the polymer: (i) comprises a monomer or monomers selected from the group consisting of epoxysuccinic acid, a substituted epoxysuccinic acid, and an alkali metal salt, alkaline earth metal salt, or ammonium salt of any of the foregoing, and any combination of any of the foregoing; (ii) has the following characteristics: (a) is water soluble; and (b) is biodegradable; and (iii) is capable of providing: (a) a thickening time of at least 2 hours for a test composition at a temperature of 190° F. and a pressure of 5,160 psi; and (b) an initial setting time of less than 24 hours for the test composition at a temperature of 217° F. and a pressure of 3,000 psi, wherein the test composition consists of 860 grams of Class-H Portland cement, 325 grams of deionized water, and 0.

Abstract: The invention provides a system made of fibers and a material able to exhibit reverse solubility. The invention preferably is used in a well and as a method to cure lost circulation.

Abstract: Methods and compositions are provided that relate to well bore treatments that comprise swellable particles. An embodiment includes a method that comprises introducing a fluid comprising a dual oil/water-swellable particle into a subterranean formation. Another embodiment includes a method of cementing that comprises: introducing a cement composition comprising cement, water, and a dual oil/water-swellable particle into a space between a pipe string and a subterranean formation; and allowing the cement composition to set in the space. Another embodiment includes a well treatment composition comprising a dual oil/water-swellable particle.

Abstract: A composition based on polyvinyl alcohol and a sulfonated ketone/formaldehyde condensate in the preferred mixing ratio of 1:1 as a further component, is provided as a fluid loss additive in mixtures containing hydraulic binders.

Abstract: Compositions and methods are directed to a cement composition for use in a subterranean formation. In an embodiment the cement composition comprises: (A) cement; (B) water; and (C) a polymer, wherein the polymer: (i) consists essentially of a monomer or monomers selected from the group consisting of acrylic acid, esters of acrylic acid, maleic acid, methacrylic acid, esters of methacrylic acid, itaconic acid, fumeric acid, citraconic acid, mesoconic acid, and any alkali metal, alkaline earth metal, or ammonium salt of any of the foregoing, and any combination of any of the foregoing; (ii) has the following characteristics: (a) is water soluble; and (b) is biodegradable; and (iii) is capable of providing: (a) a thickening time of at least 2 hours for a test composition maintained under a temperature condition of 190° F. and a pressure of 5,160 psi; and (b) an initial setting time of less than 24 hours for the test composition maintained under a temperature condition of 217° F.

Abstract: Compositions and methods of reducing a flow of aqueous liquids through a subterranean formation are provided. The compositions and methods are used for water control. The compositions include a water control additive that is prepared by reacting a soluble sodium silicate and a hydrolysable organosilane compound to produce silanol that reacts and forms a bond with the formation thereby producing a binding polysiloxane.

Abstract: A graft copolymer based on a component a) consisting of silica which has been reacted with an unsaturated silane, and a polymer component b) containing sulphonic acid is proposed. The silica used is preferably a nanosilica and the unsaturated silane is an ethylenically unsaturated alkoxysilane. The component b) is represented by a copolymer based on AMPS and a further ethylenically unsaturated monomer. The polymer according to the invention, which as a rule is a nanocomposite, is outstandingly suitable as an additive in construction chemistry applications and in the development, exploitation and completion of underground mineral oil and natural gas deposits, its effect as a water retention agent being particularly advantageous at high salinities and increased temperatures.

Abstract: A sealant composition comprising an inverse emulsion polymer and methods of servicing a wellbore using the same are disclosed. In one embodiment, a method of servicing a wellbore that penetrates a subterranean formation is disclosed. The method comprises placing a sealant composition comprising an inverse emulsion polymer into the wellbore to reduce a loss of fluid to the subterranean formation during placement of the fluid in the wellbore.

Abstract: Providing a solution of at least one salt capable of reacting with a set cement to form a solid phase comprising a precipitate or an expanded phase of the cement; contacting a region of the set cement to be repaired with the solution so as to form the solid phase in voids in the region of the set cement to be repaired.

Abstract: The invention relates to a cementing material, to a production method and to a cement slurry comprising polymer particles coated with at least one powdered mineral additive.

Abstract: Water production from a subterranean formation is inhibited or controlled by pumping a fluid containing coated particles through a wellbore into the formation. The particles have been previously coated with a relative permeability modifier (RPM). Upon contact with water, the RPM coating expands or swells and inhibits and controls the production of water. The RPM may be a water hydrolyzable polymer having a weight average molecular weight greater than 100,000. The particles may be conventional proppants or gravel.