Abstract: A composition, treatment fluid and method using hydrolyzable fines. A treatment fluid, which may optionally include a high solids content fluid (HSCF) and/or an Apollonianistic solids mixture, includes a fluid loss control agent comprising a dispersion of hydrolyzable fines, optionally with one or more of a surfactant, plasticizer, dispersant, degradable particles, reactive particles and/or submicron particles selected from silicates, ?-alumina, MgO, ?-Fe2O3, TiO2, and combinations thereof.

Abstract: A composition, treatment fluid and method using hydrolyzable fines. A treatment fluid, which may optionally include a high solids content fluid (HSCF) and/or an Apollonianistic solids mixture, includes a fluid loss control agent comprising a dispersion of hydrolyzable fines, optionally with one or more of a surfactant, plasticizer, dispersant, degradable particles, reactive particles and/or submicron particles selected from silicates, ?-alumina, MgO, ?-Fe2O3, TiO2, and combinations thereof.

Abstract: A composition, treatment fluid and method using hydrolyzable fines. A treatment fluid, which may optionally include a high solids content fluid (HSCF) and/or an Apollonianistic solids mixture, includes a fluid loss control agent comprising a dispersion of hydrolyzable fines, optionally with one or more of a surfactant, plasticizer, dispersant, degradable particles, reactive particles and/or submicron particles selected from silicates, ?-alumina, MgO, ?-Fe2O3, TiO2, and combinations thereof.

Abstract: Incorporation of carbonaceous materials in a cement slurry increases the linear thermal-expansion coefficient of the set cement. When placed in a subterranean well having at least one casing string, cement sheaths with linear thermal-expansion coefficients similar to that of the casing will be subjected to lower compressive and tensile stresses during downhole-temperature changes. Such cement slurries are particularly advantageous in the context of thermal-recovery wells.

Abstract: Downhole tool positioning systems and methods are disclosed which employ buoyancy-mediated tool displacement wherein the density of the tool or string connected to it, and the treatment fluid are matched to facilitate hydraulic translation of the tool in a deviated borehole or lateral with or without a mechanical translation device.

Abstract: A well treatment fluid comprising a Pickering particle emulsion comprising particles of a first liquid phase dispersed in a continuous second liquid phase, and comprising a plurality of colloidal particles adsorbed to a liquid-liquid interface between the first liquid phase and the second liquid phase. Methods, equipment and/or systems for treating a subterranean formation utilizing such treatment fluids are also disclosed.

Abstract: A well treatment fluid comprising a Pickering particle emulsion comprising particles of a first liquid phase dispersed in a continuous second liquid phase, and comprising a plurality of colloidal particles adsorbed to a liquid-liquid interface between the first liquid phase and the second liquid phase. Methods, equipment and/or systems for treating a subterranean formation utilizing such treatment fluids are also disclosed.

Abstract: A thickened composition comprising a polymer, a divalent ions source, water and cement is disclosed. Such composition enables fluid loss reduction and higher gel strength. This may be useful for treating a well for example as a fluid spacer or a scavenger; this may also be used a hydraulic fracturing fluid.

Abstract: Well cementing compositions comprise water, an inorganic cement and flexible particles having an average density higher than 1.5 g/cm3. The flexible particles may be elastomers. The flexible particles and cement particles may be present in a trimodal particle size distribution. The compositions may be placed in subterranean wells in the context of primary or remedial cementing.

Abstract: A method and system for increasing fracture conductivity. A slurry, of a solid particulate freely dispersed in fluid spaces around macrostructures suspended in a carrier fluid, is injected into a fracture, the solid particulate is aggregated in the fracture to form clusters, and the pressure reduced to prop the fracture open on the clusters and form interconnected, hydraulically conductive channels between the clusters. The system comprises a subterranean formation, a treatment slurry stage disposed in a wellbore penetrating the formation, and a pump system to inject the treatment fluid stage into a fracture.

Abstract: A method of treating a subterranean formation of a well bore comprises providing a treatment fluid comprising a carrier fluid, a particulate material, a viscosifying agent and fumed silica, wherein fumed silica is in such concentration to reduce the settling rate of the particulate material in the treatment fluid; and introducing the treatment fluid into the wellbore.

Abstract: Well cementing compositions comprise water, an inorganic cement and flexible particles having an average density higher than 1.5 g/cm3. The flexible particles may be elastomers. The flexible particles and cement particles may be present in a trimodal particle size distribution. The compositions may be placed in subterranean wells in the context of primary or remedial cementing.

Abstract: A composition, treatment fluid and method using hydrolyzable fines. A treatment fluid, which may optionally include a high solids content fluid (HSCF) and/or an Apollonianistic solids mixture, includes a fluid loss control agent comprising a dispersion of hydrolyzable fines, optionally with one or more of a surfactant, plasticizer, dispersant, degradable particles, reactive particles and/or submicron particles selected from silicates, ?-alumina, MgO, ?-Fe2O3, TiO2, and combinations thereof.

Abstract: A water-in-oil type emulsion having a dispersed particle volume fraction of greater than about 60 volume percent, based on the based on the total volume of the emulsion. Methods to produce the emulsion, treatment fluids comprising the emulsion, and uses thereof are also disclosed.

Abstract: A well treatment fluid comprising a 2-oxo-aldehyde having 3 or more carbon atoms is disclosed herein. Methods to prepare and to utilize the fluid, and to inhibit biological degradation of a well treatment fluid, are also disclosed.

Abstract: A well treatment fluid comprising a Pickering particle emulsion comprising particles of a first liquid phase dispersed in a continuous second liquid phase, and comprising a plurality of colloidal particles adsorbed to a liquid-liquid interface between the first liquid phase and the second liquid phase. Methods, equipment and/or systems for treating a subterranean formation utilizing such treatment fluids are also disclosed.

Abstract: Energized slurries (including foams) comprising an Apollonian particle mixture and at least one additive selected from the group consisting of viscosifiers, gelling agents and rheological agents. Also, methods, fluids, equipment and/or systems for treating a subterranean formation penetrated by a wellbore, relating to treatment fluids based on the energized slurries.

Abstract: Fluids comprising elongated nanoparticles and methods of using the fluids in treating a subterranean formation penetrated by a wellbore are disclosed.

Abstract: Electromagnetically active slurries comprising stabilized fluids and methods of using the stabilized, electromagnetically active slurries in fluid flow control and detection. Also, methods, fluids, equipment and/or systems for treating a subterranean formation penetrated by a wellbore, relating to treatment fluids based on the stabilized, electromagnetically active slurries.

Abstract: A composition, treatment fluid and method using hydrolyzable fines. A treatment fluid, which may optionally include a high solids content fluid (HSCF) and/or an Apollonianistic solids mixture, includes a fluid loss control agent comprising a dispersion of hydrolyzable fines, optionally with one or more of a surfactant, plasticizer, dispersant, degradable particles, reactive particles and/or submicron particles selected from silicates, ?-alumina, MgO, ?-Fe2O3, TiO2, and combinations thereof.