Exemplary methods of producing methane in a reservoir may include accessing a consortium of microorganisms in a geologic formation. The methods may include delivering an aqueous solution including waste product to the consortium of microorganisms. The methods may include increasing production of gaseous materials by the consortium of microorganisms The methods may include recovering gaseous products from the reservoir. The gaseous products may by characterized by an enriched methane concentration.

Macroparticulates may be formed through at least partial self-assembly by reacting an epoxide-containing (meth)acrylic polymer or copolymer with a compound bearing a nitrogen nucleophile. An internal cavity may be formed when functionalizing the (meth)acrylic polymer or copolymer in the presence of a hindered amine base. When appropriately functionalized, the macroparticulates may be used to sequester a contaminant from a substance in need of contaminant remediation, such as produced water or flowback water from a wellbore job site. Reclaimed water obtained from the macroparticulates may be utilized to form a treatment fluid. The macroparticulates may be located within a continuous flow line, particularly within a removable cartridge, to promote removal of at least one contaminant from a substance in need of contaminant remediation. The substance in need of contaminant remediation and/or the macroparticulates may be visually or spectroscopically interrogated to determine whether the macroparticulates have become saturated with contaminant.

Systems and methods for forming aqueous based, water-soluble polymer slurry systems may include (1) a liquid phase which may be a suspension comprised of salt, water, and a water-soluble organic solvent and (2) a solid phase which may comprise a water-soluble polymer powder. The aqueous based, water-soluble polymer slurry systems may optimize processing of the suspension package so that it may slurry in low and high salt tolerance polymers, and the finished product can survive over 30 days at an approximately 120-degree Fahrenheit aging temperature, thereby overcoming economic performance and stability challenges through its high flash point, long shelf-life, high-temperature tolerance, and low cost.

A wellbore treatment fluid comprising: a base fluid; and a water-soluble salt, the salt comprising: a cation; and an anion, wherein the anion is selected from phosphotungstate, silicotungstate, phosphomolybdate, and silicomolybdate. The treatment fluid can have a density greater than or equal to 13 pounds per gallon. A method of treating a portion of a subterranean formation penetrated by a well comprising: introducing the treatment fluid into the well.

A drilling fluid composition that contains micronized barite particles with a particle size in the range of 1 to 5 m, and also a method of fracturing a subterranean formation using the drilling fluid composition. Various embodiments of the micronized barite particles and the method of making thereof, the drilling fluid composition, and the method of fracturing a subterranean formation are also provided.

Methods and compositions for treating subterranean formations, and more specifically, to smart fracturing fluids. In one or more embodiments, the methods comprise providing a fracturing fluid that comprises a base fluid and an additive having a high dielectric constant; and introducing the fracturing fluid into least a portion of a subterranean formation. In one or more embodiments, the compositions comprise a base fluid and an additive having a high dielectric constant.

A drilling mud composition including Aloe vera particles with a largest dimension of 75-600 m, an aqueous base fluid, and a viscosifier, where the Aloe vera particles are present in the drilling mud composition at a concentration of less than 150 ppm, relative to the total weight of the drilling mud composition. A process for fracking a geological formation, whereby the drilling mud composition is injected into the geological formation through a well bore at a pressure of at least 5,000 psi to fracture the geological formation.

Methods of treating a carbonate formation are provided. The methods include introducing a nanoparticle gel system into the carbonate formation at a rate and pressure sufficient to create or enhance at least one fracture in the carbonate formation. The nanoparticle gel system includes a gelling agent, a nanoparticle-size clay, and a proppant. The methods further include allowing a portion of the proppant to deposit in the at least one fracture, pumping an acidic fluid into the carbonate formation, and allowing a portion of the acidic fluid to at least partially reduce a viscosity of the nanoparticle gel system and to react with the carbonate formation.

The invention relates to a method for the autonomous generation of safe self-limiting concentrations of chlorine dioxide for the treatment of process water. The method comprises a system that is self-limiting such that variations in water flow-rate and/or feed-rate of chlorite donor does not allow for increased concentrations of chlorine dioxide. The effluent concentration from the system does not exceed 3000 ppm thereby providing a means of generating chlorine dioxide for use where remote applications and/or where unskilled personnel are involved.

The invention relates to a method for the autonomous generation of safe self-limiting concentrations of chlorine dioxide for the treatment of process water. The method comprises a system that is self-limiting such that variations in water flow-rate and/or feed-rate of chlorite donor does not allow for increased concentrations of chlorine dioxide. The effluent concentration from the system does not exceed 3000 ppm thereby providing a means of generating chlorine dioxide for use where remote applications and/or where unskilled personnel are involved.