A particulate plugging agent, such as a diverting agent and/or loss circulation material, using a particular polyvinyl alcohol with a certain amount of monovalent metallic salt, which is water-soluble and has a buffer effect even if the environment is acidic, and thus stable, which in particular finds use in various subsurface oil production operations.

Disclosed are a high-temperature-resistant tertiary amine-grafted silica nano-plugging agent and water-based drilling fluids, relating to oil-gas field drilling. The nano-plugging agent is prepared from a hydrazine compound, a diallyl compound, an enamine compound, silica particle, and an amino-containing silane coupling agent by stepwise reaction. The nano-plugging agent has a grain size of 58-280 nm.

A method may include: analyzing each of a group of inorganic particles to generate data about physicochemical properties of each of the inorganic particles; and generating a correlation between a reactivity index of each of the inorganic particles and the data.

A system and method for generating base water and precipitate, including combining produced water with seawater to precipitate barium sulfate from barium in the produced water and from sulfate in the seawater, and separating the precipitate to give the base water and the precipitate. The base water may have less than a specified amount of sulfate and be utilized for hydraulic fracturing fluid. The precipitate may give a weighting agent for drilling.

A modified high density brine for use in subterranean drilling and completion operations. The modified high density brine includes the addition of high density particle addition that can optionally be surface-modified. The resultant modified high density brine eliminates the need for toxic, corrosive, and costly ZrBr.sub.2 additions or other ionic additives to boost the density of the modified high density brine to 15-17 lbs./gallon or greater.

A modified high density brine for use in subterranean drilling and completion operations. The modified high density brine includes the addition of high density particle addition that can optionally be surface-modified. The resultant modified high density brine eliminates the need for toxic, corrosive, and costly ZrBr.sub.2 additions or other ionic additives to boost the density of the modified high density brine to 15-17 lbs./gallon or greater.

The present invention relates to a viscosity modifying, demulsifier and flow improver composition for use in (crude) petroleum, its method of manufacture, and its uses, among them, to improve the flowability of heavy and extra-heavy crude oils, to increase the production of oil in the well and to improve the quality of the oil permanently produced from the addition of a formulated product containing conditioned organic surfactants for each type of crude oil.

A method for the fracking or stimulation of a hydrocarbon-bearing formation, said method comprising the steps of: providing a wellbore in need of stimulation; inserting a plug in the wellbore at a predetermined location; inserting a perforating tool and a spearhead or breakdown acid into the wellbore; positioning the tool at said predetermined location; perforating the wellbore with the tool thereby creating a perforated area; allowing the spearhead acid to come into contact with the perforated area for a predetermined period of time sufficient to prepare the formation for fracking or stimulation; removing the tool from the wellbore; and initiating the fracking of the perforated area using a fracking fluid. Also disclosed is a corrosion inhibiting composition for use with the acid composition.

A treatment method for remediating various contaminants including H.sub.2S, CO.sub.2, NH.sub.3 and other contaminants contained in fluids being extracted from the earth comprises steps of: preparing an aqueous based treatment composition containing water and collectively 35-55 weight percent of one or more hydroxide compounds; injecting a dosage amount of the treatment composition into contaminated fluids located in a subterranean deposit under the earth's surface such that the treatment composition mixes with the fluids deep under the earth's surface; and extracting a mixture of the contaminated fluids and the treatment composition through a well such that the treatment compositions remediates contaminants in the fluids as the mixture passes through the well to the earth's surface, wherein a dosage amount of the treatment composition may be 0.010 to 10.0 ml of the aqueous based treatment composition/liter of the contaminated fluids being extracted from the subterranean deposit.

A treatment method for remediating various contaminants including H.sub.2S, CO.sub.2, NH.sub.3 and other contaminants contained in fluids being extracted from the earth comprises steps of: preparing an aqueous based treatment composition containing water and collectively 35-55 weight percent of one or more hydroxide compounds; injecting a dosage amount of the treatment composition into contaminated fluids located in a subterranean deposit under the earth's surface such that the treatment composition mixes with the fluids deep under the earth's surface; and extracting a mixture of the contaminated fluids and the treatment composition through a well such that the treatment compositions remediates contaminants in the fluids as the mixture passes through the well to the earth's surface, wherein a dosage amount of the treatment composition may be 0.010 to 10.0 ml of the aqueous based treatment composition/liter of the contaminated fluids being extracted from the subterranean deposit.