In life of the oil field, reservoir pressure tends to decrease with the development of the production.The use of primary and secondary recovery techniques enables recovery of only 35-50% of the oilin the reservoir. That means a significant amount oil is left in the reservoir untapped. The remainingoil can either be residual oil to the water flooding or oil by passed by water flooding. Residual oilmainly contains capillary trapped oil. The injection of chemicals such as Surfactant, Alkaline andPolymers or their combinations is one of the potential techniques that can influence the recovery ofthe oil remaining in the reservoir after water flooding.For the Norne field, the situation is not far from this reality. The use of water flooding alone hasrecovered about 60% of the oil reservoir. Although this recovery rate is high compared to the rest ofthe sub sea fields, the use of water flooding alone will not be able to recover the remaining amountof oil as now the production is declining sharply and the rate of increase in water cut is high. Theuse of appropriate EOR process will help to produce the remaining amount of the oil. Basing onthe screening done on different EOR methods using EORgui software in the first part of the study,Norne E-segment was found to be a good candidate of chemical EOR technique.The aim of this study was to confirm the suitability of different chemical methods on Norne Esegmentby doing comparative simulation study compared to water flooding basing on incrementaloil production that was used to find the most promising method with high incremental Net PresentValue. A number of different simulation plans were run, where Alkaline, surfactant, polymer aswell as their mixtures were tested in various ways including different concentrations, injection timeas well as injection duration.From simulation results and economic analysis, Polymer flooding was confirmed to be the bestchemical method for Norne E-segment having an incremental NPV of +68.7 million USD in 2020.This was obtained when polymer flooding at concentration of 1.5 kg/m3 was run for five yearsfrom 2006. Polymer flooding reduces the effect of viscous fingering for heavy oil and also performbetter for heterogeneous reservoir with light oil. Alkaline and surfactant flooding were found to bepoor candidates for this field as their incremental oil production could not cover the operationalcost including chemical cost. The combination of Polymer with alkaline and surfactant (ASP andSP flooding) had higher incremental oil production compared to polymer alone. However, theincremental NPV for ASP and SP flooding was low compared for Polymer flooding along.Nevertheless, the NPV calculation did not include all the costs including pumping cost as wellas extra operational expenditures for all chemical flooding. On the other hand these costs can becompensated by using the most compatible chemicals after doing a laboratory evaluation and findthe accurate chemicals properties that will comply with fluid and rock properties of the NorneE-segment.