Hydrolyzed polyacrylamide HPAM may be the most extensively applied polymer for the Title Loaded From File following reasonsCopyright 2022 by the authors. In most polymer flooding projects, the viscosity on the polymer answer is higher than 20 cp 2 thus, higher HPAM concentrations can be expected to enable for acceptable EOR. One example is, in lowsalinity circumstances, 50 significantly less polymer is needed to attain the target mobility ratio 5. A highly concentrated polymer solution makes polymer flooding projects economically unattractive.Figure 1. Viscosity of 1.1 107 molkg of Pusher 1000, a commercial HPAM option, at 28.five C, adapted from Samanta et al. four.On the list of basic properties discovered within the last century with respect to linear and crosslinked polyam.To improve its viscosity in exceptionally high salinity brines is explained by the antipolyelectrolyte impact, resulting within the unfolding of macromolecular chains of chargebalanced polyampholytes at a quasineutral state, which happens as a result of screening of the electrostatic attraction involving oppositely charged moieties. The novelty of this study is that, in highsalinity reservoirs, the amphoteric terpolymer AamAMPSAPTAC could surpass HPAM in oil displacement capability.Citation Gussenov, I.S. Mukhametgazy, N. Shakhvorostov, A.V. Kudaibergenov, S.E. Comparative Study of Oil Recovery Making use of Amphoteric Terpolymer and Hydrolyzed Polyacrylamide. Polymers 2022, 14, 3095. https doi.org10.3390polym14153095 Academic Editor Antonio Zuorro Received 16 June 2022 Accepted 28 July 2022 Published 29 July 2022 Publishers Note MDPI stays neutral with regard to jurisdictional claims in published maps and institutional affiliations.Keywords and phrases ternary polyampholyte TPA hydrolyzed poly acrylamide HPAM antipolyelectrolyte effect sandpack model water flooding polymer flooding oil recovery factor ORF1. Introduction Water flooding will be the most broadly utilized oil recovery process. Nevertheless, in several reservoirs, water can‘t offer a steady oil displacement front due to the unfavorable mobility ratio involving these fluids, which final results in viscous fingering, specifically in highviscosity oil reservoirs. Furthermore, permeability heterogeneities also can result in premature water breakthrough, and, as a result, much less oil is developed than would happen to be achievable with much better conformance handle 1. Such difficulties is usually solved by increasing the water viscosity, ergo watersoluble polymers are employed for this purpose, typically at low concentrations of 0.5.5 g 1 , as they present viscosity values which can be high enough to properly push the oil out through polymer flooding 2. Hydrolyzed polyacrylamide HPAM may be the most broadly applied polymer for the following reasonsCopyright 2022 by the authors. Licensee MDPI, Basel, Switzerland. This article is definitely an open access article distributed under the terms and circumstances of your Inventive Commons Attribution CC BY license https creativecommons.orglicensesby 4.0.Its low price Its commercial availability Its exceptional capability to increase viscosity Its acceptable and adjustable injectivity Its resistance to microbial degradation.Nonetheless, the viscosity of HPAM decreases as brine salinity increases three. Figure 1 shows the dependence from the viscosity of Pusher 1000, a commercial HPAM, versus brine salinity four. As might be observed, the viscosity of HPAM decreases from one hundred cp to four.five cp uponPolymers 2022, 14, 3095. httpsdoi.org10.3390polymhttpsmdpijournalpolymersPolymers 2022, 14,2 ofa rise in NaCl content from 0.05 to 8 wt. . Here, 8 wt. NaCl corresponds to 84 g 1 salinity, which is much less than the salinity of quite a few oilfield brines, for instance these that are discovered in Kazakhstan.