Optimasi Sifat Reologi Lumpur KCl-Polymer Polyamine pada Suhu 300°F dengan Menggunakan XCD Polymer
DOI:
https://doi.org/10.31004/jutin.v9i1.53038Keywords:
Drilling Fluid, KCL-Polymer Polyamine, XCD Polymer, Rheology, TemperatureAbstract
The drilling fluid system is a crucial component in drilling operations. Problems commonly occur when penetrating formations containing reactive clay or shale, which may affect wellbore stability. Drilling fluid functions to maintain wellbore conditions; therefore, chemical additives are required to improve mud properties. This study aims to evaluate the mud properties of Water-Based Mud of the KCl Polymer Polyamine type through testing at original temperature, 200°F, 250°F, and 300°F. The measured parameters include mud weight, pH, rheology, API filtrate, solid content, MBT, K+, and Cl-. At 300°F, the rheological values did not meet the specification, requiring additional XCD Polymer of 0.1–0.4 ppb. The results indicate that adding 0.3 ppb XCD Polymer produces suitable rheological properties at high temperature. Mud preparation was performed by mixing and testing using mud balance, rheometer, API filtrate press, retort kit, and digital pH meter with Bentonite, NaOH, Starch, PAC-LV, Soltex, CaCO3, XCD, Barite, KCl-Polymer, and Polyamine.References
Akpan, E. U., Enyi, G. C., & Nasr, G. G. (2020). Enhancing the performance of xanthan gum in water-based mud systems using an environmentally friendly biopolymer. Journal of Petroleum Exploration and Production Technology, 10(5), 1933–1948. https://doi.org/10.1007/s13202-020-00837-0
Bardhan, A., Vats, S., Prajapati, D. K., Halari, D., Sharma, S., & Saxena, A. (2024). Utilization of mesoporous nano-silica as high-temperature water-based drilling fluids additive: Insights into the fluid loss reduction and shale stabilization potential. Geoenergy Science and Engineering, 232, 212436. https://doi.org/10.1016/j.geoen.2023.212436
Beg, M., Kumar, P., Choudhary, P., & Sharma, S. (2020). Effect of high temperature ageing on TiO2 nanoparticles enhanced drilling fluids: A rheological and filtration study. Upstream Oil and Gas Technology, 5, 100019. https://doi.org/10.1016/j.upstre.2020.100019
Ghebremedhin, M., Schreiber, C., Zielbauer, B., Dietz, N., & Vilgis, T. A. (2021). Interaction of xanthan gums with galacto- and glucomannans. Part II: Heat induced synergistic gelation mechanism and their interaction with salt. Journal of Physics: Materials, 3(3), 034014. https://doi.org/10.1088/2515-7639/ab9ac9
Hadadi, M., Kamali, F., Mirhosseininia, J., Shahbazi, M., & Vaferi, B. (2024). Experimental investigation of biopolymers influences on rheology and filtration properties of water-based drilling fluids. Heliyon, 10(23), e40780. https://doi.org/10.1016/j.heliyon.2024.e40780
Ismail, A. R., Mohd Norddin, M. N. A., Latefi, N. A. S., Oseh, J. O., Ismail, I., Gbadamosi, A. O., & Agi, A. J. (2020). Evaluation of a naturally derived tannin extracts biopolymer additive in drilling muds for high-temperature well applications. Journal of Petroleum Exploration and Production Technology, 10(2), 623–639. https://doi.org/10.1007/s13202-019-0717-7
Reinoso, D., Martín-Alfonso, M. J., Luckham, P. F., & Martínez-Boza, F. J. (2019). Rheological characterisation of xanthan gum in brine solutions at high temperature. Carbohydrate Polymers, 203, 103–109. https://doi.org/10.1016/j.carbpol.2018.09.034
Downloads
Published
How to Cite
Issue
Section
License
Copyright (c) 2026 Rusandy Ramadhan, Fachri Insani Rafsanzani, Muhammad Rizqie Fathan Rahman, Maria Sinka Elizabeth Sitompul
This work is licensed under a Creative Commons Attribution-ShareAlike 4.0 International License.
