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• W2076241793 abstract "Abstract Diversion techniques must be employed to remove all the damage from the entire producing interval. Diversion in carbonates is more difficult than in sandstones because of the ability of acid to significantly increase the permeability in carbonates as it reacts in the pore spaces and flow channels of matrix. The apparent viscosity of the in situ gelled acid based on polymer plays a key role in diversion because it creates a viscosity differential in treated and untreated zones. An extensive literature survey and field data, there is no agreement on the effectiveness of this acid system. Therefore , this study was conducted to better understand this acid system and determine factors that impact its viscosity build-up. Three commercially available in-situ acids were examined. The effect of salts, iron contamination on the apparent viscosity of these acids was examined. Several new findings were identified, including: Polymer and other additives were separated out of the acid when these acids were prepared in high salinity water. Preparing the in-situ gelled acid with saline water decreased the viscosity of the acid in live and neutralized conditions. Concentrated HCl solutions produced high concentrations of calcium chloride that reduced the viscosity of the acid system. Therefore, in-situ gelled acids that are based on the polymer should be used at low HCl concentrations (3-5 wt% HCl). Sodium, calcium or ferric chlorides reduced the apparent viscosity of live acids. A brown precipitate was noted during the neutralization of acid systems that contained Fe(III) even in the presence of the recommend concentration of iron control agents." @default.
• W2076241793 created "2016-06-24" @default.
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• W2076241793 date "2009-04-20" @default.
• W2076241793 modified "2023-10-17" @default.
• W2076241793 title "Viscosity Variations During Well Stimulation" @default.
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• W2076241793 doi "https://doi.org/10.2118/121728-ms" @default.
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