Methods and systems for treating tailings at an elevated pH using lime are disclosed herein. In some embodiments, the method comprises (i) providing a tailings stream comprising bicarbonates and a pH less than 9.0, (ii) adding a coagulant comprising calcium hydroxide to the tailings stream to form a mixture having a pH of at least 11.5 and a soluble calcium level no more than 800 mg/L, and (iii) dewatering the mixture to produce a product having a solids content of at least 40% by weight. In some embodiments, the pH and soluble calcium level of the mixture cause chemical modification of clay materials of the mixture via pozzolanic reactions. In some embodiments, the undrained shear strength of the product increases over a period of time of at least two days.

Methods and systems for treating tailings at an elevated pH using lime are disclosed herein. In some embodiments, the method comprises (i) providing a tailings stream comprising bicarbonates and a pH less than 9.0, (ii) adding a coagulant comprising calcium hydroxide to the tailings stream to form a mixture having a pH of at least 11.5 and a soluble calcium level no more than 800 mg/L, and (iii) dewatering the mixture to produce a product having a solids content of at least 40% by weight. In some embodiments, the pH and soluble calcium level of the mixture cause chemical modification of clay materials of the mixture via pozzolanic reactions. In some embodiments, the undrained shear strength of the product increases over a period of time of at least two days.

A method of servicing a wellbore extending from a surface of the earth and penetrating a subterranean formation, including: removing water from an aqueous based wellbore servicing fluid by contacting the aqueous based wellbore servicing fluid with a porous substrate coated with a hydrophilic and oleophobic coating, whereby water is removed from the aqueous based wellbore servicing fluid via passage through the porous substrate, and whereby a water concentration and a volume of the aqueous based wellbore servicing fluid are reduced and a density of the aqueous based wellbore servicing fluid is increased to provide a modified aqueous based wellbore servicing fluid.

Described herein are various methods, systems, and apparatus for reducing and eliminating biofilms from hydrocarbons. A combination of oxidizing agents and radiation of certain wavelengths forms a synergistic reaction. The synergistic reaction generates EMODs, which are effective in reducing microbial count and eliminating or blocking biofilm formation, particularly in anaerobic environments. This synergistic reaction has a relationship to EMOD creation and has a detrimental effect on Microbial Contamination (MC), Microbial Influenced Corrosion (MIC) and biofilm creation. MC, MIC and biofilm can be eliminated or greatly reduced with the treatment methods in or on equipment including pipelines, storage tanks, and refinery processing equipment.

A process mechanically breaks colloidal suspension bonds with the surrounding fluids through high energy impact with a stationary plate or a colliding fluid stream. The fluid with a colloidal suspension is pumped through one or more to 3 nozzles to collide with either a stationary plate in an impact chamber at high velocity, another similar or different fluid stream, or both another fluid stream and an impact plate. The process breaks the bonds maintaining the colloidal suspension, disassociates these materials, and allows for gravity or chemical separation of the previously colloidal particles from the fluid. The process can separate colloidal particles from a liquid medium through pressurization followed by high energy impact and rapid release.

A process is presented where a feed stream containing a hydrogen sulfide and another feed component is introduced into an absorber that the feed stream flows upward from the bottom of the absorber and contacts a liquid treatment solution, where the liquid treatment solution contains a sulfur dye catalyst. The hydrogen sulfide is absorbed into the liquid treatment solution and converted into sulfide ions. The other feed component is removed from the absorber vessel substantially free of the hydrogen sulfide and a spent treatment solution is also removed from the absorber vessel and fed to an oxidation vessel where it is contacted with an oxygen containing gas causing the sulfide ions to oxidize to thiosulfate and converting the spent sulfur dye catalyst to regenerated sulfur dye catalyst. The thiosulfate is recovered, and the regenerated sulfur dye catalyst can be recycled as part of the liquid treatment solution.

A method for managing carbon containing gases, including conveying the carbon containing gas to a reactor vessel, conveying propylene oxide to the vessel, reacting the carbon containing gas with the propylene oxide to create propylene carbonate (PC), applying the propylene carbonate to a cuttings stream from a borehole in a subsurface drilling operation and dissolving residual oil from cuttings of the stream into the propylene carbonate. A system for managing carbon containing gas emissions from a borehole drilling operation, including a carbon containing gas emitter, a reactor vessel fluidly connected to the emitter, a propylene oxide supply fluidly connected to the reactor vessel and an applier connected to the reactor vessel, the applier configured to apply propylene carbonate (PC) created in the reactor vessel to a cuttings stream.

The present disclosure discloses a waterless foam generator for fracturing shale oil and gas reservoirs and use thereof. The structure of the waterless foam generator includes: a top of the proppant storage tank is provided with a proppant inlet, a second feed port of liquid CO.sub.2 and a safety valve, and a bottom of the proppant storage tank is connected to the high-pressure gas-liquid-solid mixer, a side wall of the high-pressure gas-liquid-solid mixer is provided with a first feed port of liquid CO.sub.2, an feed port of N.sub.2 and an feed port of waterless foam foaming agent, and the high-pressure gas-liquid-solid mixer is connected to the first shaker of waterless foam fracturing fluid, the first shaker of waterless foam fracturing fluid, the second shaker of waterless foam fracturing fluid and the third shaker of waterless foam fracturing fluid are connected in sequence.

A drilling fluid and method for drilling in a coal containing formation. The method includes: providing a mixed metal-viscosified drilling fluid including at least 1% potassium salt; circulating the drilling fluid through the well; and drilling into a coal seam.

A method for removing sulfides from an aqueous liquid, wherein the aqueous liquid is contacted with an oxidizer in the presence of fibrous material dyed with at least one sulfur dye or sulfurized vat dye, to convert the sulfides in the aqueous liquid to a non-toxic product.