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Septianingrum, Wydhea Ayu
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Energy

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Journal : Journal of Earth Energy Science, Engineering, and Technology

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Modeling and Prediction of Kappaphycus alvarezii Viscosity Using Artificial Neural Network and Adaptive Neuro-Fuzzy Inference System Fathaddin, Muhammad Taufiq; Ridaliani, Onnie; Rakhmanto, Pri Agung; Mardiana, Dwi Atty; Septianingrum, Wydhea Ayu; Irawan, Sonny; Abdillah, Ridho
Journal of Earth Energy Science, Engineering, and Technology Vol. 8 No. 3 (2025): JEESET VOL. 8 NO. 3 2025
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/fh90e382

Abstract

This study examines the viscosity behavior of Kappaphycus alvarezii polymer solutions enhanced with TiO2 nanoparticles under varying concentrations, salinity, and temperature. Predictive models were developed using Artificial Neural Network (ANN) and Adaptive Neuro-Fuzzy Inference System (ANFIS) approaches. The experimental work involved preparing Kappaphycus alvarezii solutions with polymer concentrations ranging from 2,000 to 6,000 ppm and TiO2 nanoparticle concentrations from 2,000 to 4,000 ppm at salinities of 6,000–30,000 ppm and temperatures between 30 °C and 80 °C. Results showed that increasing Kappaphycus alvarezii concentration enhanced viscosity by 1.04–21.12%, while TiO2 nanoparticles improved viscosity stability, especially under high-salinity conditions. In contrast, higher salinity and temperature reduced viscosity due to ionic screening and increased molecular motion, although a slight rise was observed at 30,000 ppm salinity. The optimized ANN model (18 neurons, one hidden layer) achieved a superior correlation coefficient (r = 0.9980) compared to ANFIS (r = 0.8769), confirming higher predictive accuracy. These findings demonstrate the potential of Kappaphycus alvarezii–TiO2 nanofluids as sustainable viscosity modifiers for enhanced oil recovery (EOR) and verify the reliability of ANN and ANFIS models in predicting viscosity under complex multivariable interactions.
Characteristics and Performance of Xanthan Gum–Kappaphycus alvarezii Mixture for Increasing Oil Recovery in Reservoirs with High Salinity Septianingrum, Wydhea Ayu; Abdillah, Ridho; Iqlimah, Madhu A’la Zulaiqoh; Fathaddin, Muhammad Taufiq; Husla, Ridha; Insani, Andon; Kartini, Rachmi; Andrianaivo, Lala
Journal of Earth Energy Science, Engineering, and Technology Vol. 9 No. 2 (2026): JEESET VOL. 9 NO. 2 2026
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/n9b8cy58

Abstract

Polymer flooding is an effective Enhanced Oil Recovery (EOR) method; however, challenges arise in reservoir conditions with high salinity and temperature, which can degrade conventional polymers. This study aims to analyze the rheological characteristics and sweeping performance of a polymer mixture consisting of Xanthan Gum (XG) and a natural additive from red seaweed, Kappaphycus alvarezii (KA). The research methodology includes viscosity testing against variations in temperature and salinity (30,000–50,000 ppm), contact angle measurements for wettability evaluation, adsorption tests in porous media, and coreflooding experiments. The novelty of this research lies in the utilization of Kappaphycus alvarezii as a natural performance-enhancing agent for XG capable of significantly improving fluid-rock interactions. The results indicate that the addition of KA provides a synergistic effect in increasing solution viscosity and stability. Contact angle measurements prove that KA is much more effective in altering rock wettability to water-wet with a value of 29°, compared to XG at 87°, thus being more optimal in releasing oil from rock pores. Adsorption tests showed an increase in polymer retention as salinity rose, yet remained within operational tolerance. In the coreflooding stage, a 12,000ppm solution at 30,000 ppm salinity yielded the highest incremental recovery factor of 13.33%. Overall, the study concludes that the XG-KA mixture has high potential for application in high-salinity reservoirs due to its superiority in mobility control and wettability modification compared to the use of single polymers.
Co-Authors Abdillah, Ridho Andon Insani Andrianaivo, Lala Husla, Ridha Iqlimah, Madhu A’la Zulaiqoh Kartini, Rachmi Mardiana, Dwi Atty Muhammad Taufiq Fathaddin, Muhammad Taufiq Onnie Ridaliani, Onnie Rakhmanto, Pri Agung Sonny Irawan