Abstract: A slick water fracturing fluid including a brine, an inorganic nitrate, a nitrogen reducing bacteria, a scale inhibitor selected from the group consisting of a polyacrylate polymer, a polyacrylate copolymer, a polyacrylate terpolymer, and mixtures thereof, and a friction reducer, wherein the friction reducer is a polyacrylamide.

Abstract: A slick water fracturing fluid including a brine, an inorganic nitrate, a nitrogen reducing bacteria, a scale inhibitor selected from the group consisting of a polyacrylate polymer, a polyacrylate copolymer, a polyacrylate terpolymer, and mixtures thereof, and a friction reducer, wherein the friction reducer is a polyacrylamide.

Abstract: A method for scavenging hydrogen sulfide from geothermal steam in a condenser under vacuum. A fine curtain of atomized acrolein-water droplets may be sprayed into geothermal steam condensers in an amount of approximately 2:1 molar ratio of acrolein to H2S based on hydrogen sulfide in the incoming steam from the turbine. The range being approximately 0.1 ppm to 500 ppm of sulfide. The acrolein is allowed to react with the gas phase H2S to form non-volatile aldehyde byproducts which partition into the water phase, are returned to the cooling tower and ultimately removed by normal cooling-tower blow down.

Abstract: A method for heating/removing and/or preventing solids in onshore or subsea pipe or wellbore tubular includes pumping a solution or suspension containing carbon nanotubes (CNT) and/or CNT based derivatives into the pipe or wellbore to a position proximate the solids and applying electromagnetic energy or electric current at one or more selected frequencies to the pipe proximate the solution. The pipe or wellbore tubular itself may be pre-coated with carbon nanotube containing material and exposed to radio frequency energy, microwaves, and electric current upon formation of solids therein.

Abstract: A method for scavenging hydrogen sulfide from geothermal steam in a condenser under vacuum. A fine curtain of atomized acrolein-water droplets may be sprayed into geothermal steam condensers in an amount of approximately 2:1 molar ratio of acrolein to H2S based on hydrogen sulfide in the incoming steam from the turbine. The range being approximately 0.1 ppm to 500 ppm of sulfide. The acrolein is allowed to react with the gas phase H2S to form non-volatile aldehyde byproducts which partition into the water phase, are returned to the cooling tower and ultimately removed by normal cooling-tower blow down.

Abstract: A slick water fracturing fluid including a brine, an inorganic nitrate, a nitrogen reducing bacteria, a scale inhibitor selected from the group consisting of a polyacrylate polymer, a polyacrylate copolymer, a polyacrylate terpolymer, and mixtures thereof, and a friction reducer, wherein the friction reducer is a polyacrylamide.

Abstract: A method for scavenging hydrogen sulfide from geothermal steam in a condenser under vacuum. A fine curtain of atomized acrolein-water droplets may be sprayed into geothermal steam condensers in an amount of approximately 2:1 molar ratio of acrolein to H2S based on hydrogen sulfide in the incoming steam from the turbine. The range being approximately 0.1 ppm to 500 ppm of sulfide. The acrolein is allowed to react with the gas phase H2S to form non-volatile aldehyde byproducts which partition into the water phase, are returned to the cooling tower and ultimately removed by normal cooling-tower blow down.

Abstract: Defoamer compositions effective for the suppression of oil-based and water-based foams. The defoamer compositions comprise a fumed metal oxide, such as fumed silica, or another silica-based material dispersed in an organic solvent. The fumed metal oxide of silica-based material is preferably present at a low weight percentage and may be coated with polydimethylsiloxane (“PDMS”). The defoamer composition may also include one or more traditional defoamer compositions.

Abstract: Methods and systems for deliquification of fluid loaded, packed wells with sub-surface safety valves (“SSSVs”) utilizing timed and tailored chemical treatments. A flow meter measures the flow rate of the well and an intermitter initiates shut in of the well when a particular flow rate is reached. A chemical treatment is applied and allowed to penetrate the length of the well before production is restarted. Predetermined combinations of chemical treatments and production cycles are utilized based on past experience and well data, and the entire process can be automated through the use of a computer system.

Abstract: Materials such as amines, alcohols, aminoalcohols, ethers and mixtures thereof, including halogenated adducts thereof, have been found to be useful floc modifiers for water clarifiers to form an effective overall water clarifier composition. The water clarifier portion of the composition is a dithiocarbamate. The floc modifier of a particular water clarifier composition need not be the same compound that is reacted with carbon disulfide (CS.sub.2) to make the water clarifier portion of the novel compositions.

Abstract: Materials such as amines, alcohols, aminoalcohols, ethers and mixtures thereof, including halogenated adducts thereof, have been found to be useful floc modifiers for water clarifiers to form an effective overall water clarifier composition. The water clarifier portion of the composition is a dithiocarbamate. The floc modifier of a particular water clarifier composition need not be the same compound that is reacted with carbon disulfide (CS.sub.2) to make the water clarifier portion of the novel compositions.

Abstract: Method and additive are provided for clarifying an aqueous system which may contain an oil-in-water emulsion, a dispersion of a non-aqueous discontinuous phase, without production of a resultant uncontrollable floc in the system, by contacting the system with an effective water clarifying amount of a composition having present a dithiocarbamate of bishexamethylenetriamine, said dithiocarbamate having the formula: ##STR1## wherein: R is hydrogen, an alkali metal, an alkaline earth metal, ammonium, ion or an amine, the ratio of carbon disulfide to primary amine for said dithiocarbamate of bishexamethylenetriamine is approximately stoichiometric. The composition is maintained in the system for sufficient time to effectively clarify the system without production of an uncontrollable floc.

Abstract: Method and additive are provided for clarifying an aqueous system which may contain an oil-in-water emulsion, a dispersion of a non-aqueous discontinuous phase, without production of a resultant uncontrollable floc in the system, by contacting the system with an effective water clarifying amount of a composition having present a dithiocarbamate of bishexamethylenetriamine, said dithiocarbamate having the formula: ##STR1## wherein: R is hydrogen, an alkali metal, an alkaline earth metal, ammonium, ion or an amine, the ratio of carbon disulfide to primary amine for said dithiocarbamate of bishexamethylenetriamine is approximately stoichiometric. The composition is maintained in the system for sufficient time to effectively clarify the system without production of an uncontrollable floc.

Abstract: The precipitation of scale-forming salts is inhibited by adding to an aqueous solution partially neutralized phosphate esters of an ethoxylated or propoxylated urea. The compositions are particularly useful in oil wells, oil well brines, cooling or boiler water, and the like.