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Andrianaivo, Lala
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Energy

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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.
Comparative Analysis of Water Injection Patterns and Rates for Oil Recovery Optimization in a Mature Reservoir Wibowo, Djunaedi Agus; Rahmawan, Sigit; Sabirey, Adrian Maulana; Andrianaivo, Lala
Journal of Earth Energy Science, Engineering, and Technology Vol. 9 No. 1 (2026): JEESET VOL. 9 NO. 1 2026
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/1t7py069

Abstract

Waterflooding is one of the most widely applied secondary recovery methods to maintain reservoir pressure and improve oil recovery in mature oil fields. However, ineffective injection patterns and non-optimal injection rates may reduce sweep efficiency and accelerate water breakthrough. Therefore, this study aims to evaluate and optimize waterflood injection patterns and injection rates in Layer Y of Field X using dynamic reservoir simulation with tNavigator. The study employed a full-field black-oil simulation model involving data preparation, model initialization, history matching, and production forecasting under several development scenarios. The evaluated scenarios included base case, infill drilling, and water injection using 3-spot, 5-spot, and 7-spot injection patterns with different injection rates. This study applied the integration of comparative injection-pattern analysis with injection-rate optimization using a validated full-field simulation model for a mature reservoir. The initialization and history matching results showed good agreement between the simulation model and historical field data, indicating that the model was reliable for forecasting purposes. The simulation results demonstrate that waterflood implementation significantly improved reservoir performance compared with the base case and infill drilling scenarios. Among all evaluated cases, the 5-spot injection pattern with an injection rate of 1000 STB/day produced the best performance, achieving a cumulative oil production of 97.36 MMSTB and a recovery factor of 46.76%. The study confirms that optimizing injection pattern geometry and injection rate plays an important role in improving sweep efficiency and maximizing oil recovery in mature reservoirs.
Co-Authors Abdillah, Ridho Andon Insani Djunaedi Agus Wibowo Husla, Ridha Iqlimah, Madhu A’la Zulaiqoh Kartini, Rachmi Muhammad Taufiq Fathaddin, Muhammad Taufiq Sabirey, Adrian Maulana Septianingrum, Wydhea Ayu Sigit Rahmawan