Abstract: A method for remediating fractures in a cement structure including heating the cement structure to a temperature at or above the melting temperature of the eutectic metal alloy particles to allow the particles to flow in liquid state into the fractures in the cement structure until the heat source is discontinued, allowing the particles to cool and solidify.

Abstract: A fluid composition including a mixed metal oxide viscosifier, a clay viscosifier, and solid eutectic metal alloy particles. A method including pumping a drilling fluid downhole in a wellbore. The drilling fluid including water, a mixed metal oxide viscosifier, a clay viscosifier, and solid eutectic metal alloy particles. The method further including allowing the drilling fluid to reach a target zone with elevated permeability and forming a filter cake containing solid eutectic metal alloy particles in the target zone. The method including heating the filter cake to a temperature greater than the melting temperature of the eutectic metal alloy particles, allowing the particles to melt and become liquid eutectic metal alloy particles. The method including discontinuing heating and allowing the filter cake to cool to a temperature lower than the melting temperature of the solid eutectic metal alloy particles to produce a strengthened filter cake.

Abstract: A method includes conveying a wellbore fluid into a container of a wellsite system, the container having a float angle hydrometer housed therein and the float angle hydrometer including a buoyant structure, and a measuring component housed within or attached to the buoyant structure. The method further includes determining one or more fluid properties of the wellbore fluid with the float angle hydrometer based on an inclination of the buoyant structure within the wellbore fluid, the one or more fluid properties including at least one of density, specific gravity, or fluid level.

Abstract: A eutectic metal alloy is placed through a coiled tubing into a wellbore formed in a subterranean formation. The eutectic metal alloy includes a mixture of multiple metals. The eutectic metal alloy has a melting temperature that is less than a melting temperature of each individual metal of the multiple metals making up the eutectic metal alloy. The eutectic metal alloy is heated to a temperature equal to or greater than the melting temperature of the eutectic metal alloy to liquefy the eutectic metal alloy. The liquefied eutectic metal alloy is flowed from the wellbore and into the subterranean formation, thereby exposing the liquefied eutectic metal alloy to a specified downhole temperature within the subterranean formation and causing the liquefied eutectic metal alloy to solidify to form a seal. The seal prevents fluid from flowing from the wellbore and into the subterranean formation.

Abstract: Compositions for treating a wellbore include an exothermic additive capable of initiating an exothermic event following contact with a carrier fluid. The exothermic additive can have a coating that delays the exothermic event after contact with the carrier fluid. Methods disclosed herein include emplacing a fluid loss treatment composition in an interval of a wellbore, the fluid loss treatment including: a metallic fluid loss additive; an exothermic additive; and a carrier fluid; and reacting the exothermic additive to initiate an increase in temperature in the interval of the wellbore above a melting point of the metallic fluid loss additive; and converting the metallic fluid loss additive to a molten fluid loss additive; and treating the interval of the wellbore with the molten fluid loss additive.

Abstract: A method includes conveying a wellbore fluid into a container of a wellsite system, the container having a float angle hydrometer housed therein and the float angle hydrometer including a buoyant structure, and a measuring component housed within or attached to the buoyant structure. The method further includes determining one or more fluid properties of the wellbore fluid with the float angle hydrometer based on an inclination of the buoyant structure within the wellbore fluid, the one or more fluid properties including at least one of density, specific gravity, or fluid level.

Abstract: Methods include the use of a probe array that includes a flotation device configured to maintain the probe array adjacent a surface of a wellbore fluid; an acquisition module secured to the flotation device such that the acquisition module is positioned below the surface of the wellbore fluid, and that include one or more of a dissolved oxygen probe, a pH probe, a turbidity probe, or a conductivity probe; transmitter configured to receive data acquired from the acquisition module and transmit the data to a computer system configured to receive the data from the transmitter and configured to perform the steps of: processing the data to determine one or more wellbore fluid properties, displaying the one or more wellbore fluid properties and/or one or more remedial actions.

Abstract: A system for simulating in situ drilling and treatment conditions on a core sample from a subterranean formation. The system re-creates various subterranean loads and temperatures on a test sample representative of actual in situ conditions from the particular formation while a test structure within the system performs drilling activities on the core sample using drilling and treating under evaluation for use in the particular subterranean formation. Thus, the impact on selected drilling and treating fluids can be evaluated as well as the impact those fluids had on a sample from the subterranean formation under in situ conditions.

Abstract: A system for simulating in situ drilling and treatment conditions on a core sample from a subterranean formation is disclosed. The system re-creates various subterranean loads and temperatures on a test sample representative of actual in situ conditions from the particular formation while a test structure within the system performs drilling activities on the core sample using drilling and treating under evaluation for use in the particular subterranean formation. Thus, the impact on selected drilling and treating fluids can be evaluated as well as the impact those fluids had on a sample from the subterranean formation under in situ conditions.

Abstract: A water-based drilling fluid containing high molecular weight crosslinked polyacrylic acid as viscosifying agent exhibits stability at well temperatures in excess of 150° C. The drilling fluid may further contain a lubricant, weighting agent and/or a wetting agent as well as laponite clay. The aqueous based drilling fluid exhibits a coefficient of friction which is substantially close to the coefficient of friction of oil based drilling muds.

Abstract: A water-based drilling fluid containing high molecular weight crosslinked polyacrylic acid as viscosifying agent exhibits stability at well temperatures in excess of 150° C. The drilling fluid may further contain a lubricant, weighting agent and/or a wetting agent as well as laponite clay. The aqueous based drilling fluid exhibits a coefficient of friction which is substantially close to the coefficient of friction of oil based drilling muds.

Abstract: A method of drilling a gas or oil well consists of use of a water-based drilling fluids containing high molecular weight crosslinked polyacrylic acid as viscosifying agent. The drilling fluid may further contain a lubricant, weighting agent and/or a wetting agent as well as a synthetic silicate or smectite clay. The aqueous based drilling fluid exhibits a coefficient of friction which is substantially close to the coefficient of friction of oil based drilling muds. The drilling fluid exhibits stability at well temperatures in excess of 150° C.

Abstract: The invention provides a method of enhancing the recovery of shale-containing cuttings during the drilling of a borehole in a shale-containing subterranean formation which comprises adding to the drilling fluid circulating in the borehole a finely ground, very sparingly soluble, anhydrous, alkali metal silicate glassy material to provide the drilling fluid with a concentration of soluble silica in the range from about 0.1% to about 1.0% by weight of the aqueous phase of the drilling fluid. Preferably the drilling fluid has a pH in the range from about 8.0 to about 11.0, most preferably about 8.5 to less than 11.0. The preferred alkali metal is potassium.

Abstract: The invention discloses methods of formulating an alkali metal silicate-containing drilling fluid and drilling a well therewith. Thus an alkali metal silicate is added to an aqueous base drilling fluid, when the drilling fluid is being circulated while drilling, at a rate sufficient to react with the drilled cuttings and freshly exposed surface of the borehole while leaving very little excess soluble silicate in the drilling fluid circulated to the surface. The rate of addition of the silicate is based on the circulation rate of the drilling fluid in the wellbore and the volume of the hole being drilled.

Abstract: A lubricating composition containing one or more esters obtained as a reaction product from a reaction mixture of a glycerol component, a fatty acid component, and a carboxylic acid component wherein said glycerol component comprises glycerol, glycerol oligomers, or combinations thereof and further wherein said glycerol oligomers comprise linear chains, branched chains, cyclic chains, or combinations thereof and further wherein said glycerol oligomers have at least 2 repeat glycerol units and further no more than about 32 repeat glycerol units; wherein said fatty acid component comprises alkyl groups having at least about 8 carbon atoms and further wherein said alkyl groups have no more than about 32 carbon atoms; wherein said carboxylic component has at least one carbon atom per molecule and no more than about 8 carbon atoms per molecule; and wherein the fatty acid component comprises at least 50 percent by weight of the fatty acid component of oleic acid; wherein the fatty acid component comprises at least

Abstract: The present invention comprises the use of hexamethylene diamine (HMDA) and its salts formed with organic or inorganic acids as an inhibitor for shales and clay found in drilling and producing petroleum oil and gas wells. When HMDA is added to the aqueous base of a drilling fluid, the resultant mixture inhibits shale and clays to impart and/or increase permanent permeability stability in reservoirs. Thus, with the use of the present invention, a more environmentally acceptable, chloride free, water base drilling fluid may be used in place of an oil base drilling fluid, or fluid with the heretofor more commonly used potassium additives. The present invention may be used as a completion fluid, and as a drill-in fluid.

Abstract: A method and apparatus for determining the lubricity of an oil well drilling fluid, whereby a sample in a cell holder may be subjected to a desired pressure, temperature, kinetic friction, and lubricating fluid to simulate drilling conditions in a well bore, and particularly to simulate the drilling conditions of a non-vertical well bore such as encountered in horizontal drilling which generates sliding non-rotational frictional forces.

Abstract: An additive for drilling in water-sensitive shales comprising a partially hydrolyzed acrylamide-acrylate copolymer, potassium chloride and a polyanionic cellulose.