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Scientific Contributions Oil and Gas
Published by LEMIGAS
ISSN : 20893361     EISSN : 25410520     DOI : -
Core Subject : Science, Engineering,
Chemical Engineering, Chemistry & Bioengineering Energy
The Scientific Contributions for Oil and Gas is the official journal of the Testing Center for Oil and Gas LEMIGAS for the dissemination of information on research activities, technology engineering development and laboratory testing in the oil and gas field. Manuscripts in English are accepted from all in any institutions, college and industry oil and gas throughout the country and overseas.
Arjuna Subject : Energi (semua kategori) - Teknologi Bahan Bakar
Articles 30 Documents
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Search results for , issue "Vol 48 No 4 (2025)" : 30 Documents clear
Porosity Estimation in A Natural CO2-Water Reservoir Using Integrated Density-Resistivity Log Approach Pahala Dominicus Sinurat; Hari Sasongko; Nabil Samawi
Scientific Contributions Oil and Gas Vol 48 No 4 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i4.1887

Abstract

Natural CO₂ reservoirs represent important analogues for Carbon Capture and Storage (CCS) and Carbon Capture, Utilization, and Storage (CCUS), as they provide direct evidence of long-term CO₂ retention and trapping mechanisms. This study assesses porosity in a natural carbonate CO₂ reservoir using an integrated density–resistivity log approach. Conventional porosity logs, such as density, neutron, and sonic, often overestimate porosity in carbonate systems due to their limited sensitivity to pore connectivity. To overcome this limitation, density log-derived total porosity was integrated with resistivity-derived effective porosity, allowing for the differentiation between connected and isolated pore systems. Fluid density estimations, including supercritical CO₂ and brine, were computed and validated against standard references to ensure accuracy. The results show that density-only porosity overestimates values by up to 10% in dolomitic intervals, whereas the integrated method provides estimates that are more consistent with core measurements. Isolated porosity, averaging 2% in the upper dolomite and 1.5% in the lower dolomite, was identified as a non-contributing pore volume for injectivity, although it remains relevant for storage capacity. These findings underscore the importance of integrated log interpretation for precise reservoir characterization and offer new insights into evaluating natural CO₂ reservoirs for long-term geological storage.
Application of Anthracite and Activated Carbon Filter Media to Enhance Injection Water Quality for Water Flooding Operations in “DE” Field Dahrul Effendi; Rian Cahya Rohmana; Priskila Rully Setiyaningrum; Aliyah Muhamad Bisyir
Scientific Contributions Oil and Gas Vol 48 No 4 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i4.1895

Abstract

Produced water is used as injection water for water flooding. When untreated injection water of poor quality is introduced into the formation, it can lead to severe plugging issues. This is primarily due to the poor quality of the water, which is characterized by high levels of solid particles, elevated turbidity, a high scaling index, significant oil content, high TSS concentration, and a high RPI. The application of anthracite and activated carbon filter media has been shown to effectively reduced the scaling index, oil content, turbidity, particle size, TSS, and RPI in the injection water. These filter media enable the filtering out of insoluble materials from the injection water. By evaluating the effectiveness of different filter media on injection water quality, it is possible to select a filtrate with improved water quality, characterized by a clear appearance and minimal amounts of solid particles. The resulting filtrate demonstrated very low TSS concentrations and a significantly reduced RPI value. Overall, the filtrate can be classified as high-quality injection water suitable for water-flooding applications. The morphology of TSS before and after filtration through anthracite and activated carbon filter media was detected using SEM.
Drilling Fluid Optimization Using Response Surface Methodology Bayu Satiyawira; Mustamina Maulani; Lisa Samura; Havidh Pramadika; Asri Nugrahanti; Cahaya Rosyidan; Andry Prima; Muhammad Dzaki Arkaan; Widia Yanti
Scientific Contributions Oil and Gas Vol 48 No 4 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i4.1900

Abstract

Water-based drilling fluids commonly exhibit rheological degradation under high-temperature, high-pressure (HTHP) conditions, resulting in significant reductions in viscosity, yield point (YP), and gel strength (GS). Previous studies relying on conventional additives such as PAC, CMC, KOH, and NaOH have not fully resolved this issue, particularly in maintaining rheological stability at elevated temperatures. This study addresses this gap by introducing an alkaline polymer as a multifunctional additive intended to replace several conventional components while enhancing thermal resistance. Response Surface Methodology (RSM) with a Box–Behnken design was used to evaluate the combined effects of Carboxymethyl Cellulose (CMC) and alkaline polymer at three temperature levels: 80°F, 150°F, and 250°F. Experimental results show that at 150°F, the optimized formulation consists of 3.5 g CMC and 3.6 g alkaline polymer, yielding a viscosity of 17.64 cP, plastic viscosity of 12.46 cP, and a YP of 7.72 lb/100 ft², representing a substantial improvement compared to the baseline formulations, where YP values decreased significantly with temperature. The optimized mud also demonstrated improved gel strength and consistent filtrate control relative to non-optimized systems. The novelty of this study lies in the use of an alkaline polymer as a single multifunctional substitute for multiple drilling-fluid additives, combined with a multi-temperature RSM optimization framework. The findings provide a simplified, thermally stable drilling-fluid formulation suitable for HTHP environments.
Rheological Interactions Between Divalent Barium and Sulfate Ions in Hydroxypropyl Guar Polymer Fracturing Fluids Dewi Asmorowati; Miftah Hidayat; Dedi Kristanto; Ardhi Hakim Lumban Gaol; Tutuka Ariadji; Taufan Marhaendrajana
Scientific Contributions Oil and Gas Vol 48 No 4 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i4.1904

Abstract

The use of produced water as a primary component in formulating polymer-based fracturing fluids is becoming a viable option due to the limited availability of fresh water in the field. Nevertheless, the practical use of production water faces several challenges due to its complex composition, which includes monovalent and divalent ions that considerably affect the fluid’s viscosity. Recent studies have shown that calcium ions substantially influence the viscosity of linear fracturing fluids, whereas magnesium ions, do not have a notable effect. However, the effects of other divalent ions commonly found in production water, such as barium and sulfate, remain underreported. In this study, the influence of barium and sulfate ions on linear fracturing fluids will be examined. The viscosity of linear gel fracturing fluids, prepared using hydroxypropyl guar (HPG) polymer with varying concentrations of barium and sulfate ions, will be investigated under different shear rates and temperatures. The results indicate that produced water contains barium and sulfate ions, which affect the rheology of the linear fracturing fluid. A concentration of 150 ppm of BaCl2 can increase the viscosity by 30%, whereas 150 ppm of Na2SO4  increases the HPG viscosity by 7% at ambient temperature (25 °C). At 70 °C, the effect of barium and sulfate ions on the increase in viscosity of the HPG linear fracturing fluid are observed to be less significant.
Coiled Tubing Circular Efficiency: A Systematic Literature Review on Failure Mechanisms, Inspection Methods, and Reuse Potential Warno; Suharjito
Scientific Contributions Oil and Gas Vol 48 No 4 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i4.1906

Abstract

Coiled tubing (CT) has become a critical technology in oil and gas operations, yet its service life is constrained by fatigue, corrosion, and erosion. In marginal fields, the high capital cost of new CT strings for permanent installations such as gas lift creates significant economic challenges. Reusing existing CT assets presents a cost-efficient and sustainable alternative. This study conducts a systematic literature review of 33 Scopus-indexed journal and conference publications to examine CT failure mechanisms, integrity inspection methods, and the economic potential of reuse in marginal fields. The reviewed data were classified by failure mode, inspection technique, application, and economic perspective. The findings reveal that low-cycle fatigue is the most extensively studied failure mode, with wall thickness reduction identified as a key indicator of structural degradation. Current integrity assessments rely heavily on predictive modelling and non-destructive evaluation (NDE) methods, particularly magnetic flux leakage (MFL) and eddy current testing (ECT). Nevertheless, the absence of reliable, field-practical wall thickness measurement remains a critical gap, for which ultrasonic testing (UT) emerges as a promising solution. Case studies further demonstrate the technical feasibility and cost-effectiveness of CT reuse. This review underscores the importance of transitioning from a linear “use-and-scrap” paradigm toward a circular “use-inspect-reuse” framework, with UT serving as a pivotal enabler. This approach enhances economic viability and advances alignment with the United Nations Sustainable Development Goals.
Improvement of Operating Performance of Medium-Speed Marine Diesel Engines Using Marine Diesel Oil with Air Microbubbles Hideo Kawahara; Tomohiro Sunada; Yasuhito Nakatake; Koichi Terasaka; Hiroshi Kawahara; Hidechika Goto
Scientific Contributions Oil and Gas Vol 48 No 4 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i4.1908

Abstract

Marine diesel engines are widely adopted as the main auxiliary engines in ships because of their ability to utilize inexpensive heavy fuel oil and their high thermal efficiency per unit engine. This study focuses on practical marine medium-speed diesel engines to investigate the impact of introducing air as fine bubbles into low-sulfur A heavy fuel oil on the operating performance. The results indicated that when fine bubbles were introduced into the fuel, the engine exhibited poor combustion and became unstable at any load when Qa was 0.4 L/min or higher. However, when Qa was below 0.4 L/min, the fuel efficiency improvement increased significantly with increasing load, reaching a maximum reduction of 4.5% at 75% load and Qa = 0.3 L/min. Regarding the exhaust gas characteristics, at low loads, no significant changes were observed in the CO2 and NOx emissions with varying microbubble injection levels. However, at loads of 75% or higher, both the CO2 and NOx emissions decreased as the microbubble injection level increased. Furthermore, introducing fine bubbles into the fuel promoted atomization after fuel injection, similar to the results for heated C heavy oil, leading to improved heat generation rates across the entire engine load range.
Application of Ultra Fine Bubble Addition to Diesel Fuel on The Performance of Agricultural Transport Vehicle Engines Ahmad Ardiansyah; Sam Herodian; Faqih Supriyadi; Riva Yudha Abriyant; Cahyo Setyo Wibowo
Scientific Contributions Oil and Gas Vol 48 No 4 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i4.1921

Abstract

Diesel engines have long been the primary choice across various industrial sectors, including agricultural transport vehicles. However, energy efficiency and fuel consumption remain significant challenges. One approach to address these issues is the application of Ultra Fine Bubble (UFB) technology to diesel fuel, which aims to enhance physical fuel properties and improve combustion efficiency. This study was conducted to evaluate the effect of UFB treatment on B0 CN-51 and B40 fuels in relation to fuel quality and diesel engine performance. The fuel characterization tests showed that the calorific value of B0 CN-51 increased from 43.73 MJ/kg to 45.68 MJ/kg, and B40 from 42.46 MJ/kg to 42.94 MJ/kg. The cetane number also increased, accompanied by a reduction in sulfur content and lubricity. Performance testing using a chassis dynamometer indicated improvements in maximum power and torque. B0 CN-51 UFB produced 95.68 kW of power and 344.18 Nm of torque, while reducing specific fuel consumption (SFC) from 42.25 to 39.82 g/kWh. In addition, fuel consumption in ℓ/100 km decreased significantly, with an average reduction in efficiency of up to 4.85%. For B40, SFC decreased from 44.99 to 43.75 g/kWh, with an average consumption reduction of 1.73%. These results demonstrated that UFB can significantly improve diesel engine performance and fuel efficiency.
Utilizing Used Lubricants to Enhance Intermediate Crude Oil Recovery Through Water-in-Oil Emulsions Mukhlis Noor Alfatih; Dwi Atty Mardiana; Shabrina Sri Riswati; Changhyup Park
Scientific Contributions Oil and Gas Vol 48 No 4 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i4.1924

Abstract

This study experimentally analyzes the impacts of water-in-oil (W/O) emulsion derived from used lubricants on enhanced intermediate-crude-oil recovery. The objective is to identify a viable and economically efficient method to enhance the extraction of intermediate crude oil. Typically, W/O emulsions have been employed as displacing fluids in heavy oil reservoirs. According to the results, there have been challenges experienced in the selection of an affordable petroleum-based product and ensuring its availability for emulsion preparation. Used lubricants can be incorporated as a component in the formulation of an emulsion solution by mixing them with brine. The physical and chemical properties of these used lubricants are evaluated to determine their suitability as a displacing agent. Subsequently, several concentrations of the emulsion were prepared, ranging from 5% to 60% (vol/vol), to effectively evaluate their suitability as a displacing fluid. The experimental workflow covered viscosity testing, mobility ratio measurement, IFT evaluation, emulsion stability checks, adsorption analysis, and thermal stability assessment. Core-flooding is performed to determine the recovery factor. A 5% W/O emulsion is found to be an effective displacing fluid for intermediate crude oil. The core-flooding results showes about a 27% increase in recovery when using the conventional flooding emulsion. Overall, the findings indicate that adding used lubricants to W/O emulsions improves intermediate oil recovery due to their favorable viscosity and stability.
The Integration of Hybrid Capacitance Resistance Model and Machine Learning: A Data-Based Workflow for Optimizing Waterflood Performance and Reservoir Management Syifa Alviola Muhendra; Novia Rita; Fajril Ambia; Agus Dahlia
Scientific Contributions Oil and Gas Vol 48 No 4 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i4.1928

Abstract

This study aims to minimize uncertainty in waterflood performance by employing a data-driven workflow that combines the Capacitance Resistance Model (CRM) with Machine Learning. Two CRM variants, CRM-P (Producer-based) and CRM-IP (Injector-Producer-based), are utilized to evaluate interwell connectivity and time constants on three reservoir models: homogeneous, heterogeneous, and a real field scenario (Volve Field). The model is evaluated using R² and Mean Absolute Percentage Error (MAPE) and is compared against the Random Forest and eXtreme Gradient Boosting (XGBoost) techniques. The results indicate that CRM-IP provides more realistic estimates than CRM-P, particularly for response time. XGBoost consistently demonstrates superior prediction accuracy, achieving R² values of 0.76–0.98 and MAPE values of 0.5–10%. Three-dimensional (3D) visualizations of interwell connectivity and streamline analysis strengthen the understanding of fluid flow and sweep efficiency. This further demonstrates that integrating CRM and Machine Learning serves as a decision-support tool for Enhanced Oil Recovery optimization, as evidenced by R² and MAPE analyses that characterize sweep efficiency and the reservoir's capacity to accommodate additional injection.
Comparative Study of Capacitance Resistance Model and Machine Learning for Sensitivity Analysis of Polymer Injection Performance Azri Agus Rizal; Fajril Ambia; Novia Rita; Ira Herawati
Scientific Contributions Oil and Gas Vol 48 No 4 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i4.1929

Abstract

The objective of this study was to evaluate the performance of polymer injection in the Volve Field by validating full-physics tNavigator simulation results. This process was performed using two independent data-driven approaches: the Capacitance Resistance Model (CRM) and machine-learning algorithms Random Forest and XGBoost. This validation framework addresses uncertainty in flow-parameter and ensures that simulated production responses align with data-driven injection–production behavior. The simulation model was constructed using 20 years of historical field data, consisted of five years of polymer injection at 1000–3000 ppm, followed by 15 years of chase water flooding. The simulation results showed that polymer injection increased the oil recovery factor from 21.12% to 21.30% in the best-case scenario, indicating a modest improvement in sweep efficiency. CRM, applied through CRM-P and CRM-IP configurations, successfully reconstructed production profiles and quantified interwell connectivity (R² = 0.94; MAPE < 10%). Machine-learning validation further confirmed these results, with Random Forest achieving R² = 0.92 (MAPE < 1%) and XGBoost achieving R² = 0.99 (MAPE < 1%). Overall, CRM and machine learning provide effective and independent validation pathways, enhancing confidence in simulation outcomes and allowing for reliable assessment of polymer-injection performance in field applications.

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