25 research outputs found
Corrosion Inhibitors for Sour Oilfield Environment (H2S Corrosion)
Lower-grade steel materials are the most commonly used construction materials for oil and gas wells
due to their low cost and high performance. However, they are susceptible to corrosion when they
come in contact with corrosive environments that are highly acidic. In oil wells, particularly deep oil
wells, hydrogen sulfide (H2S) is commonly found. The dissolution of H2S gas in produced water
makes the fluid corrosive. The use of corrosion inhibitors is perhaps the most practical and costeffective
means of controlling corrosion of low carbon steels in the sour environment. In this chapter,
typical corrosion inhibitors used in oil and gas fields to control the internal corrosion of oilfield
equipment caused by H2S are being examined. The inhibitors found to be effective are polar
functional compounds, with many being based on nitrogen-containing compounds, such as amines,
imidazolines, and quaternary ammonium salts. Drawbacks of these compounds in practical
applications and potentials of future developments are discussed
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Methods for collection and analysis of geopressured geothermal and oil field waters
Present methods are described for the collection, preservation, and chemical analysis of waters produced from geopressured geothermal and petroleum wells. Detailed procedures for collection include precautions and equipment necessary to ensure that the sample is representative of the water produced. Procedures for sample preservation include filtration, acidification, dilution for silica, methyl isobutyl ketone (MIBK) extraction of aluminum, addition of potassium permanganate to preserve mercury, and precipitation of carbonate species as strontium carbonate for stable carbon isotopes and total dissolved carbonate analysis. Characteristics determined at the well site are sulfide, pH, ammonia, and conductivity. Laboratory procedures are given for the analysis of lithium, sodium, potassium, rubidium, cesium, magnesium, calcium, strontium, barium, iron, manganese, zinc, lead, aluminum, and mercury by atomic absorption and flame emission spectroscopy. Chloride is determined by silver nitrate titration and fluoride by ion-specific electrode. Bromide and iodide concentrations are determined by the hypochlorite oxidation method. Sulfate is analyzed by titration using barium chloride with thorin indicator after pretreatment with alumina. Boron and silica are determined colorimetrically by the carmine and molybdate-blue methods, respectively. Aliphatic acid anions (C/sub 2/ through C/sub 5/) are determined by gas chromatography after separation and concentration in a chloroform-butanol mixture
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Gas-water-rock interactions in Frio Formation following CO2 injection: Implications for the storage of greenhouse gases in sedimentary basins
Bureau of Economic Geolog
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The U-tube: A novel system for acquiring borehole fluid samples from a deep geologic CO2 sequestration experiment
Bureau of Economic Geolog
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Measuring permanence of CO2 storage in saline formations: the Frio experiment
Bureau of Economic Geolog