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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 22 Documents
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Search results for , issue "Vol 49 No 1 (2026)" : 22 Documents clear
The Significance of Nanofluids as Working Fluids in Energy Extraction Process on Geothermal Heat Exchanger System Utilizing Abandoned Oil Wells: A Review Prihtiantoro, Dedhy; Maula, Mohamad Izzur; Imaduddin, Fitrian
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.v49i1.1815

Abstract

Geothermal energy offers significant potential as an environmentally friendly renewable resource; however, large-scale deployment remains constrained by high drilling and infrastructure costs. Repurposing abandoned oil and gas wells as geothermal heat exchanger systems has emerged as a promising alternative, yet research on the application of nanofluids in such systems remains limited and fragmented. This review employs a narrative synthesis approach to analyze more than 80 peer-reviewed studies related to wellbore geothermal heat exchangers, working fluids, and nanofluid thermal enhancement mechanisms. The review identifies a clear knowledge gap regarding the integration of nanofluids into geothermal heat extraction processes in deep coaxial and U-tube systems, particularly with respect to long-term stability, pressure drop, and techno-economic feasibility. Findings indicate that nanofluids, especially metal-oxide and hybrid formulations, can substantially enhance thermal conductivity and heat transfer performance, with TiO₂- and CuO-based nanofluids showing the most promising results. However, challenges remain in optimizing concentration, ensuring stability, and mitigating increased pumping power. Overall, this review provides a consolidated understanding of existing research and highlights key directions for future development to improve heat extraction efficiency in geothermal systems utilizing abandoned wells.
Polymer-Oxygen Scavenger for Oil Recovery in Sandstone Jati, Dhika Permana; Hetharia, Putri Diantha; Damayandri, Dadan; Widyaningsih, Ratna; Kaesti, Edgie Yuda; Taufantri, Yudha; Putra, Ilham Ardatul
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.v49i1.1854

Abstract

Polymer degradation caused by dissolved oxygen remains a major challenge in Enhanced Oil Recovery (EOR) for sandstone reservoirs, especially under moderate salinity (18,000 ppm) and temperature (60°C) conditions, which accelerate viscosity loss. While HPAM polymers are highly effective, ensuring their long-term stability requires strategies that preserve molecular integrity throughout the injection process. This study employs laboratory experiments to assess two HPAM variants (FP 3630 and FP 3230), both in conventional formulations and with an oxygen scavenger (NaHSO₃), using Bentheimer synthetic cores. Evaluations cover fluid-to-fluid (compatibility, rheology, filtration, thermal stability) and fluid-to-rock (injectivity, core flooding) performance under reservoir conditions. Results identify FP 3630 at 1400 ppm with 0.1% NaHSO₃ as the optimal formulation. The oxygen scavenger significantly improves thermal stability and reduces viscosity degradation from 32.83% to 4.24%. This formulation achieves an ideal Resistance Factor (11.44) and causes minimal formation damage (RRF 1.01), while enhancing the Recovery Factor from 67.38% to 87.29%. These findings confirm that the incorporation of oxygen scavengers effectively minimizes polymer degradation and establishes them as a crucial component for the successful implementation of EOR in moderate-salinity sandstone reservoirs.
Identification and Mitigation of Stuck Pipe Problem During Cement Drill-Out Cement in XSF Well Suranta, Bambang Yudho; Sofyan, Akhmad; Siahan, Paradongan; Sidiq, Asep
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.v49i1.1905

Abstract

This study aimed to develop an integrated diagnostic framework to identify pack-off–type stuck pipe during cement drill-out operations and strengthen quantitative risk assessment for workover interventions. A stuck pipe event in the XSF well (9-5/8-in. section) at 724.42 m was investigated using drilling data, drill-string mechanics, drilling fluid evaluation, and hydraulic/cutting-transport analysis. The results of the mechanical assessment showed that excessive loading and overpull were unlikely primary causes of stuck pipe problem. However, the hydraulic and transport evaluation showed inadequate cutting removal, consistent with particle settling and progressive pack-off formation. To evaluate this event, a diagnostic classification matrix combining four operational indicators was applied, showing complete agreement with an established pack-off classification method. The pipe was ultimately freed after 99 hours using controlled tension-cycling with spotting-fluid support. Based on the transport analysis, this study recommended operational controls, which included maintaining a minimum circulation rate of 340 GPM and the use of shale shakers during cement removal to reduce pack-off risk. Furthermore, the prolonged liberation time showed the substantial cost impact of stuck pipe problem, supporting the economic case for preventive implementation.
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.
Bridging The Gap in Non-Process Energy Management: A Comprehensive Audit of A Power Plant Site Office in Power Generation Facilities Linked to Oil and Gas Operations Mohd Nor, Norfakhira; Razali, Mohd Azahari; Adha Narrudin, Nur Syafiqah; Suzuki, Masataro; Tarmizi Nasir, Ahmad; Akhyan, Amnur
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.v49i1.1937

Abstract

Energy efficiency research in oil and gas and power generation facilities has predominantly focused on core process systems, while non-process energy consumption in ancillary and administrative buildings remains under- represented in both regional and international literature. Existing building energy audit studies largely emphasise standalone commercial and institutional buildings, offering limited insight into site offices embedded within industrial facilities operating under extended schedules and tropical climatic conditions. This study addresses this gap by presenting a comprehensive non-process energy audit of a site office supporting a coal-fired power generation facility linked to oil and gas operations in Malaysia. The audit follows Malaysian Standard MS1525:2019 and integrates two years of electricity consumption data (April 2023–March 2025), Building Energy Intensity (BEI) benchmarking, end-use load apportioning, and indoor environmental quality (IEQ) assessment. The seasonal analysis confirmed that electricity consumption is strongly influenced by climate-driven cooling demand, with higher peaks occurring during hotter months. However, reductions in base-load consumption during milder periods reveal opportunities for improved operational efficiency and highlight the importance of distinguishing climate effects from controllable energy use when interpreting performance in industrial office environments. The site office recorded a BEI of 172.7 kWh/m²/year, exceeding the MS1525;2019 benchmark of 135 kWh/m²/year and lying at the upper range of values reported for conventional office buildings in tropical climates. HVAC systems dominate electricity consumption (55%), followed by lighting (24%) and general equipment (14%), indicating higher cooling dependency than typically observed in non-industrial office studies. Visual inspection revealed widespread over-illumination, while IEQ assessment identified temperature fluctuations and intermittent CO₂ exceedances, reflecting inconsistencies in environmental control. Collectively, these findings indicate that inefficiencies arise from the combined effects of HVAC operation, lighting design, and control strategies. Addressing these areas holistically offers potential to reduce BEI, flatten peak demand, and improve occupant comfort, while supporting integrated industrial energy management under Malaysia’s NEEAP and EECA 2024.
Adsorption Performance of Regenerated Molecular Sieves for Moisture Removal in Compressed Oxygen Gas Febriyanti, Zaeturohmah; M. Baqir; Maulana, Fahrul; Nugraha, Asep; Hidayat, Rachmat; Jakariya
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.v49i1.1952

Abstract

This study focuses on evaluating the adsorption performance of regenerated molecular sieves repurposed as moisture adsorbents for compressed oxygen gas. The spent adsorbents are collected from a Phase Technology Freezing Point analyzer after saturation is achieved through repeated operational cycles. Two thermal regeneration methods are  investigated, namely (1) staged heating in a furnace at 350 °C for 2 hours followed by a 30-minute vacuum treatment, and (2) staged heating in a gas chromatography (GC) oven at 350 °C with a dry-nitrogen purge for an hour, followed by another 1 hour without purging and a 30-minute vacuum duration. Furthermore, the physical characteristics after regeneration are assessed using the UOP Method 422 for particle size distribution (PSD) through micromesh sieving. Moisture adsorption performance is evaluated according to ASTM D1142 using a dew-point measurement with compressed oxygen at operating pressures and flow rates of 30–50 psi and 0.5–1.0 L/min, respectively. The results indicate that regenerated molecular sieves retain approximately 80–90% of the adsorption capacity of new material, which demonstrates that the GC-oven regeneration method exhibits slightly superior performance compared to furnace regeneration. These finding prove that appropriate thermal regeneration enables effective reuse of spent molecular sieves, providing a technically viable and economically favorable strategy for moisture removal in oxygen-drying applications while reducing laboratory waste.
Reservoir Engineering Evaluation of Water Rock Compatibility and Permeability Damage in PX Field: Compatibility Injection Water and Reservoir Rahayu, Cece; Hardi, Maulana; Rizqullah , Muhammad Daffa; Wardani, Oktaviani Kusuma
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.v49i1.1955

Abstract

Compatibility between injection fluids and reservoir rocks is a crucial factor in the success of waterflooding operations, particularly in reservoirs with complex characteristics. Therefore, this study aimed to evaluate injection water–reservoir rock compatibility from a reservoir engineering perspective, focusing on permeability impairment mechanisms associated with fine migration and suspended solids during water injection in the PX Field. Rock samples were obtained from a selected formation, while injection water was collected from the Water Injection Plant (WIP). Laboratory experiments were conducted by injecting both Total Suspended Solids (TSS)-free water and water containing TSS into 1.5-inch core plugs positioned vertically in a Hassler-type core holder under an overburden pressure of 1,725 psi, backpressure of 250 psi, and room temperature conditions. Moreover, the injection water viscosity during the process of the experiment was 0.95 cP. The results showed a pronounced permeability reduction of up to 98% in the PX Field sample. The permeability decline occurred rapidly and intermittently in distinct stages, which initially proposed clay swelling as a possible mechanism. However, X-ray diffraction (XRD) analysis presented negligible smectite content, excluding clay swelling as the dominant cause of damage. Permeability impairment was primarily attributed to pore blockage from fine migration and suspended particles, as supported by particle size distribution (PSD) and TSS analyses. These results showed the importance of comprehensive rock–fluid compatibility evaluation before water injection implementation to minimize formation damage and optimize waterflooding performance.
1D Basin Modeling and Geochemical Analysis of Source Rock The Arafura Basin Mamengko, David Victor; Mamengko, Michael Davidjoy Hamonangan; Setyowati , Tri Peni
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.v49i1.1967

Abstract

The Arafura Basin is a frontier basin with significant hydrocarbon potential that remains poorly understood, particularly regarding source rock effectiveness across different structural settings. This study evaluates source rock potential, geochemical characteristics, and thermal maturity history using geochemical data and 1D basin modeling from five exploration wells (ABDX-1, BRX-1, KBX-1, KLX-1, and BBX-1). The analysis identifies several potential source rock intervals ranging from Permian, Jurassic, Cretaceous, to Tertiary ages. Geochemical evaluation reveals a stark contrast between depocenters and structural highs. Wells in the northern and southern depocenters (ABDX-1 and KLX-1) contain source rocks of fair to excellent quality that have reached optimal thermal maturity phases, ranging from peak to late mature. Conversely, wells in the structural high areas (BRX-1, KBX-1, and BBX-1) are to be non-generative as all source rock intervals remain immature due to insufficient burial history. Thermal history reconstruction indicates that the main phase of hydrocarbon generation occurred in the Neogene, triggered by a surge in sedimentation rates in response to the Melanesian Orogeny. This study concludes that exploration in the structural highs of the Arafura Basin carries high source rock risk, and successful hydrocarbon accumulation in these areas relies heavily on lateral migration from active hydrocarbon kitchens developing in the northern and southern depocenters.  
ML Modeling for Carbonate Reservoir Characterization Mahfudhoh, Sayyidah Adilia; Welayaturromadhona
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.v49i1.1969

Abstract

Reservoir characterization is essential for understanding rock and fluid behavior in hydrocarbon field development. In the Baturaja Formation, South Sumatra Basin, this process is challenging due to heterogeneity resulting from depositional and diagenetic variations. Limited core data and the high cost of conventional analysis encourage the use of machine learning (ML). This study aims to predict formation, facies, porosity, and permeability using ML algorithms and to assess the impact of feature augmentation. The dataset includes well log and core data from 13 wells. The workflow consists of preprocessing, feature selection, feature engineering, and supervised learning using Decision Tree, Random Forest, XGBoost, and KNN. Performance was evaluated using the F1-score for classification and MAE/RMSE for regression, followed by blind testing on wells HARLEY and XSR. Random Forest achieved the best formation prediction (F1-score 0.9890; blind test 0.9975) because the well data fall within the range of the training data distribution, although accuracy decreased in XSR due to differences in data distribution. XGBoost was the most accurate for facies prediction, improving from an F1-score of 0.9648 to 0.9741 after feature augmentation. For porosity and permeability, Random Forest produced the lowest errors, although permeability remained challenging in heterogeneous carbonates. Overall, ML provides an efficient and accurate approach, with Random Forest and XGBoost performing best, and feature augmentation consistently enhancing model generalization.
Enhancing Subsurface Geological Model Resolution in Challenging Seismic Conditions by Using Model-Based Deterministic Inversion Mawalid, Abi; Haris, Abdul; Wijanarko, Edy
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.v49i1.1976

Abstract

The limited resolution of 2D seismic data often limits the accuracy of subsurface interpretation. This study explores how deterministic inversion can enhance the elastic representation of low resolution intervals in Field X and contribute to more precise reservoir interpretation. By applying deterministic inversion, we aimed to improve the mapping of lithological variations throughout the interval. Petrophysical data show that the target zone contains porosity values of 11–22%, Gamma Ray readings of 10–120 API, and P-impedance values of 11022–15343, which were used for well–seismic tying and model calibration. The inversion generated an acoustic impedance model that closely aligns with the log trends, showing a coherence error of just 6.23% within the target interval. Domains with increased permeability and diminished GR readings are distinguished as faint impedance irregularities, whereas more consolidated phases are marked by heightened impedance. The ensuing impedance reaction encapsulates geologically significant mid range lithological fluctuations, although constraints imposed by seismic resolution persist in diminishing the precision of stratigraphic demarcations. In general, the findings demonstrate that when deterministic inversion is meticulously fine-tuned with petrophysical datasets, it can yield a consistent and measurable impedance framework, even in areas with constrained seismic fidelity, thereby facilitating more dependable reservoir analysis.

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