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All Journal Journal of Petroleum and Geothermal Technology Journal of Earth Energy Science, Engineering, and Technology Prosiding Seminar Nasional Rekayasa Teknologi Industri dan Informasi ReTII Scientific Contributions Oil and Gas
Astuti, Dian Indri
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Aerospace Engineering Automotive Engineering Chemical Engineering, Chemistry & Bioengineering Civil Engineering, Building, Construction & Architecture Computer Science & IT Control & Systems Engineering Decision Sciences, Operations Research & Management Earth & Planetary Sciences Electrical & Electronics Engineering Energy Engineering Environmental Science Industrial & Manufacturing Engineering Materials Science & Nanotechnology Mechanical Engineering Physics Transportation

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Synthesis of Synthetic Brine to Estimate Carbonate Scale Index in Oil Industry Nugraha, Fanata Yudha; Asmorowati, Dewi; Saputra, Ega Dimas; Astuti, Dian Indri; Tony, Brian; Waisnawa, I Putu Gema Bujangga
Journal of Petroleum and Geothermal Technology Vol. 5 No. 2 (2024): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v5i2.13636

Abstract

The decreased oil production due to scaling in production equipment results in costs. In oil wells, ions such as calcium, barium, carbonate, sulfate, magnesium, sodium, and chloride are commonly present in formation water. Excessive solubility of ions can trigger precipitation or what is often called scale. This study focuses on creating synthetic brine with a composition resembling field formation water as an alternative solution for rapid laboratory-scale measurement of the scale index. In this study focus on carbonate and bicarbonate scale. The stages of the research involves synthetic brine preparation, physical and chemical testing of the brine, comparison with formation water, and calculation of the Stability Index (SI) using Stiff & Davis method. The results indicate that synthetic brine can be prepared based on laboratory analysis of field samples by estimating the materials and masses present in formation water, thus allowing replication using natural or chemical materials in the laboratory while considering parameters such as pressure, temperature, and pH during the manufacturing process. The pH significantly impacts the risk of scale formation, where a slightly basic pH, around pH 8, supports higher concentrations of carbonate ions (CO32-) and bicarbonate ions (HCO3-), thereby increasing the risk of scale formation.
The Analysis of Polyamine Mud Application in Drilling Claystone and Shale in ES Field Tony, Brian; Saputra, Ega Dimas; Astuti, Dian Indri
Journal of Earth Energy Science, Engineering, and Technology Vol. 8 No. 2 (2025): JEESET VOL. 8 NO. 2 2025
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/w83pta14

Abstract

Historically, the ES Field is a drilling area located in South Sumatera Basin that applies 10% KCl Polymer throughout the drilling section. Challenges such as pipe sticking and increased borehole diameter due to washout have been encountered in this field. Increased cement volume and tripping time are factors affecting drilling efficiency. Therefore, innovation and improvement in the type of drilling mud used are needed to address these challenges in the field. This paper discusses the effectiveness of polyamine through shale study analysis, including CEC, dispersion, accretion, XRD, and LSM, as well as performance analysis of mud application as an alternative to KCl-Polymer in the drilling of Well ED-24 in the ES Field. Results indicate that polyamine has advantages and benefits as an inhibitor. Shale study from the cuttings of Well ED-22 shows that shale in the Gumai Formation is characterized by kaolinite and is dispersive, hence the use of polyamine. In the 17.5-inch trajectory, tight hole issues were found due to swelling clay at a depth of 561 mMD, which had not occurred previously with 10% KCl-Polymer mud. In the 12.25-inch trajectory, the main cause of shale collapse was insufficient mud weight. Overall, polyamine mud effectively suppresses solid dispersion into the mud, prevents balling, and addresses hole cleaning issues during drilling. The use of 10% KCl-Polymer can be reconsidered for subsequent drilling in the Air Benakat claystone formation, while polyamine mud remains relevant and should be considered for drilling the dispersive Gumai shale formation to suppress solid dispersion.
Studi Perkiraan Pembentukan Indeks Scale Brine Sintetik Air Formasi (Variabel CO3 dalam Air Formasi) Astuti, Dian Indri; Sri Rahayu Gusmawarni; M Sri Prasetyo Budi
Retii 2024: Prosiding Seminar Nasional ReTII ke-19 (Edisi Penelitian)
Publisher : Institut Teknologi Nasional Yogyakarta

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Abstract

Decrease in oil production that occurs due to the presence of solids in production equipment caused by ion imbalances in formation water.due to ion imbalance in formation water. Scale formation can be influenced by several factors including the property characteristics property characteristics of the produced fluid, especially in heavy oil types, due to changes in temperature, pressure, pH, and mineral composition of formation water that exceeds the solubility limit. solubility triggers the formation of scale solids. In oil wells will usually formation water containing ions of calcium, barium, carbonate, sulphate, magnesium, sodium and chloride. In this study, the manufacture of synthetic brine with a composition that resembles field formation water as an alternative in laboratory scale scale index measurement testing solutions and and save time so as to speed up testing. Manufacture of synthetic brine this synthetic brine can utilise materials from the laboratory such as calcium, barium, carbonate, sulphate, magnesium, sodium and chloride dissolved in distilled water. Then experiments were carried out to change the mass of one or in the formation water formula on several mineral ions as a key in making synthetic brine.key in making synthetic brine that resembles the conditions in the field. Brine testing using the compleximetric method of formation water analysis chemically and physically like testing formation water from the field.
Fluid-To-Fluid Interaction of Rhamnolipid Biosurfactants with Divalent Ions: Investigation of Interfacial Tension and Emulsion Viscosity Hariyadi; Cahyaningtyas, Ndaru; Nugraha, Fanata Yudha; Larasati, Karina; Fatahillah, Azhar Faari; Astuti, Dian Indri
Scientific Contributions Oil and Gas Vol 49 No 1 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i1.1927

Abstract

Rhamnolipid biosurfactants derived from microbial sources have gain substantial interest as environmentally sustainable alternatives to synthetic surfactants, particularly in the realm of Microbial Enhanced Oil Recovery (MEOR). Their biodegradability, low toxicity, and effectiveness under extreme conditions make them ideal candidates for improving oil displacement in reservoir. However, the presence of divalent ions, specifically calcium (Ca²⁺) and magnesium (Mg²⁺), which are abundant in reservoir brine, can significantly affect the performance of these biosurfactants. This research investigates the influence of Ca²⁺ and Mg²⁺ ions on the phase behavior, stability, and interfacial properties of rhamnolipid-based microemulsion systems, which play a critical role in MEOR processes. A series of experiments was conducted to analyze the impact of varying concentrations of Ca²⁺ and Mg²⁺ ions on rhamnolipid microemulsions. The study evaluated phase transitions, stability, and microstructural characteristics of emulsions using a spinning drop tensiometer to measure interfacial tension (IFT) and rheological analysis to determine viscosity. The results demonstrate that both Ca²⁺ and Mg²⁺ ions influence the optimal salinity conditions required for microemulsion stability, with their presence causing shifts in the phase boundaries. Notably, Ca²⁺ ions exert a more pronounced effect on phase stability compared to Mg²⁺, leading to increased IFT and viscosity at higher concentrations. These findings further elucidates the crucial role of divalent ions in governing the stability and functionality of biosurfactant systems under reservoir conditions and highlight the importance of controlling ion concentrations to achieve efficient MEOR applications. Overall, this research provide valuable insight for optimizing the formulation of rhamnolipid-based systems to enhance oil recovery performance while mitigating the adverse effects of high divalent ion content in brine. The research contributes to ongoing efforts to improve biosurfactant efficacy, offering a pathway toward refining MEOR strategies and advancing sustainable oil recovery technologies.
Co-Authors Cahyaningtyas, Ndaru Dewi Asmorowati Fatahillah, Azhar Faari Hariyadi Karina Larasati M Sri Prasetyo Budi Nugraha, Fanata Yudha Saputra, Ega Dimas Sri Rahayu Gusmawarni Tony, Brian Waisnawa, I Putu Gema Bujangga