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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 619 Documents
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An Lstm-Based Anomaly Detection on Subsea Oil-Producing Well Dara Ayuda Maharsi; Syaloom Zefanya Tampi; Ajeng Purna Putri Oktaviani
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.v48i4.1819

Abstract

The oil and gas industry faces substantial operational risks from anomalous events, necessitating effective Abnormal Event Management (AEM) to mitigate production losses and safety hazards. This study presents a supervised anomaly classification approach using Long Short-Term Memory (LSTM) networks on the 3W Dataset—comprising over 2,000 real, simulated, and expert-drawn events from offshore wells. Focusing on real instances with sufficient normal-state duration, the dataset was refined and segmented using observation windows of 60, 120, and 180 seconds. The models were trained on four selected pressure and temperature features and evaluated using precision, recall, and F1-score. Comparative analysis with Recurrent Neural Network (RNN) and Gated Recurrent Unit (GRU) models shows that the LSTM model consistently performs best, achieving a peak F1-score of 92% at a 120-second window. Furthermore, event-level performance analysis highlights the LSTM model’s strengths and limitations across different anomaly types. Compared to existing supervised and unsupervised methods on the 3W Dataset, the LSTM-based approach demonstrates competitive accuracy and robustness for real-time anomaly detection in offshore oil production systems.
Effects of Homogeneous and Heterogeneous Mineralogy in Carbonate Acidizing Wahyu Sutresno
Scientific Contributions Oil and Gas Vol 48 No 2 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i2.1820

Abstract

A series of carbonate acidizing coreflood experiments using HCl was conducted on core samples from the Kujung Formation, offshore Northwest Java. Using XRD, SEM, and thin-section petrography, these samples were characterized as exhibiting varying degrees of heterogeneity. X-ray diffraction analysis showed that core plug Sample 7 consists of about 93% calcite, 3% dolomite, and 1–2% gypsum and pyrite, whereas core plug Sample 2 contains nearly 99% calcite. Mineralogical heterogeneity can affect the success of acidizing stimulation by determining the geometry (shape and size) of the wormholes that form. In addition to mineralogical heterogeneity, the presence of impurities in the rock may also influence the acidizing process and its outcomes. Conversely, in more homogeneous carbonate samples, a more uniform acid attack is observed. In homogeneous samples, carbonate dissolution was found to extensively “clean” clays and fine particles from the pore space. This study is expected to demonstrate different processes for enhancing permeability and porosity when using core samples of heterogeneous versus homogeneous mineralogy in carbonate acidizing applications.
Performance of Lignoslfonate Derived from Coffee Husk as A Natural Emulsifier in Enhanced Oil Recovery: A Phase Behaviour Study Luthfi Rindra Salam Rindra Salam; Riska Laksmita Sari; Welayaturromadhona
Scientific Contributions Oil and Gas Vol 48 No 3 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i3.1822

Abstract

The oil industry faces challenges in enhancing oil recovery while reducing environmental impact. This study explores the utilization of lignin extracted from coffee husk, an agricultural waste, as a natural emulsifier in enhanced oil recovery (EOR). The research addresses key issues including identifying lignin's functional groups via fourier transform infrared (FTIR) spectroscopy before and after sulfonation, determining compatible lignosulfonate concentrations through aqueous stability tests, and optimizing salinity for effective emulsification. Lignin was extracted via soda pulping and modified through sulfonation with sodium bisulfite (NaHSO₃) to produce lignosulfonate. FTIR analysis confirmed successful sulfonation, evidenced by new peaks at 636 cm⁻¹ (S–O) and 1101 cm⁻¹ (SO₃⁻). Aqueous stability tests at 60°C showed that a 0.8% (w/v) lignosulfonate concentration remained stable in brine with 20,000 ppm salinity. Salinity scans identified optimal conditions at 25,000 ppm, where the system achieved a balanced solubilization ratio of 0.95, indicating low interfacial tension. These results demonstrate that sulfonated coffee husk lignin has significant potential as a sustainable emulsifier for EOR applications, with a concentration of 0.8% and a salinity of 25,000 ppm being optimal for emulsion stability. This study supports circular economy principles by valorizing agricultural waste and offers a promising alternative to synthetic chemicals in the oil industry.
Effects of Palm-Oil-Based Methyl Ester Sulfonate (MES) in Laboratory-Scale Enhanced Oil Recovery Process Onnie Ridaliani; Samsol; Rini Setiati; Muhammad Taufiq Fathaddin; Lilian Anggela; Andry Prima; Nandito Davy; 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.v48i4.1825

Abstract

Natural Declining oil production is often caused by reduced natural driving forces within reservoirs. To address this limitation, enhanced oil recovery (EOR) technology introduces external energy or chemical agents to mobilize residual oil. This study evaluated the performance of palm-oil-based methyl ester sulfonate (MES) an anionic and biodegradable surfactant synthesized from renewable feedstock for improving recovery efficiency under laboratory-scale conditions. Core-flood experiments were performed using Berea sandstone cores, intermediate 33°API crude oil, low salinity of 10,000 ppm, synthetic brine at 60 °C. The testing sequence included screening test of palm-oil-based MES, brine saturation, oil saturation, waterflooding, and subsequent surfactant flooding with 1.5% MES solution. During waterflooding, the recovery factor reached 62.8 %, leaving 31.29 % residual oil saturation. Injection of 1.5 wt % MES increased the recovery factor to 68.8 % and reduced residual oil saturation to 26.25 %, indicating enhanced displacement and improved microscopic sweep efficiency. The results confirmed that palm-oil-derived MES effectively mobilizes trapped oil and demonstrates strong potential as an environmentally friendly and locally available surfactant for chemical EOR applications in the reservoirs.
Determination of Scale Inhibitor Effective Dose for Well A28 Using A Differential Scale Loop Method Maulana Hardi; Rene Indrawan Pratamora; Oktaviani Kusuma Wardani; Dzulhijah Nur Meisinca
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.v48i4.1826

Abstract

Well A28 in the Rokan Field has been identified with scale deposition on the surface flowline. The Scaling Index (SI) calculated using the Stiff and Davis method was +3.89, showing a high potential for aggressive scale formation. These deposits originate from mineral precipitation in produced water. To address this issue, scale inhibitor injection was applied, and the optimum dosage was determined using the Differential Scale Loop (DSL) method. This method evaluates inhibitor performance based on differential pressure caused by scale formation under field conditions (temperature 127 °C, flow rate 5 mL/min, operating pressure 300 psi). Tests were conducted using inhibitor doses of 25 ppm, 35 ppm, and 50 ppm. The results showed that a dose of 35 ppm produced the highest inhibition efficiency, reaching 100.3%, while also exhibiting minimal pressure drop. This dosage proved more effective than the other concentrations evaluated. Identifying this optimum dose supports reductions in chemical consumption and maintenance frequency, offering practical and cost-efficient benefits for field operations.
Reservoir Characterization of Ngrayong Formation, Sandstone with Carbonate Intercalation, Using a Geostatistical Approach Based on Petrophysical Parameters, Northeast Java Basin, Indonesia Handoyo; Bernard Cavin Ronlei; Andy Setyo Wibowo; Asido Saputra Sigalingging; Edlyn Yoadan Nathania; Fatkhan Fatkhan; Aurio Erdi; Per Avseth; Ramon Carbonell; Pranowo Nugroho; Riky Hendrawan Bayu Pandito; Aladin Nasibov; Abdullah Ali Ali Husein
Scientific Contributions Oil and Gas Vol 48 No 3 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i3.1828

Abstract

Hydrocarbons have a vital role as a driver of the global economy, which causes demand to continue to increase. To achieve production targets, oil and gas companies try to conduct exploration using efficient and accurate methods to obtain optimal hydrocarbon reserves. One approach in hydrocarbon exploration is to use geostatistical analysis to understand the characteristics of petrophysical parameters of reservoir rocks (e.g. porosity, permeability, water saturation and facies). This study aims to characterize reservoirs in the NE Java Basin using a geostatistical approach that Sequential Gaussian Simulation (SGSIM) to produce random realizations that can be adjusted and validated through geostatistical analysis of data before and after the simulation. The dataset used in this study consist of well data, seismic line, and core data. The results shows the petrophysical properties distribution from the simulation reveals the dominance of carbonate sandstone reservoirs in the central part of the study area with a thinning slope towards the northwest and southeast, while sandstone reservoirs are only dominant in the southeast direction of the study area. This research provides important insights in understanding reservoir characteristics and can be a basis for efficient decision making in the exploration of hydrocarbon resources in this area.
CO2 Storage Screening Criteria Based on Seal Capacity in Indonesia Syifa Destiana; Dedy Irawan; Prasandi Abdul Aziz; Ika Merdekawati
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.v48i4.1829

Abstract

CO2 storage screening ensuring the long-term containment of injected CO2 and the integrity of carbon capture and storage. In Indonesia, robust seal evaluation is constrained by the limited availability of caprock core data. This study develops a dimensionless Caprock Quality Index (CQI) as a practical CO2 storage screening tool based on displacement pressure (Pd) and caprock thickness (h). Displacement pressure is estimated using an empirical Pd equation derived from existing caprock core data. The CQI provides a quantitative classification of seal quality within the 0-1 range, where values closer to 1 indicate better caprock quality. Based on the data availability of this study, the results show that the Banggai and Salawati basins currently exhibit the highest CQI, indicating strong suitability for CO₂ storage. This study provides a framework for conducting preliminary CO₂ storage screening, particularly valuable in settings where caprock core data are sparse and contributes to the development of a more efficient, data-driven framework for future CCS planning and implementation.
Investigation and Optimization of Enhanced Oil Recovery Mechanism by Sophorolipid Biosurfactant in Carbonate Reservoir Indah Widiyaningsih; Harry Budiharjo Sulistyarso; Ivan Kurnia; Taufan Marhaendrajana; Tutuka Ariadji
Scientific Contributions Oil and Gas Vol 48 No 3 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i3.1830

Abstract

The Remaining Oil in Place (ROIP) in carbonate rock reservoirs is often substantial. This is due to the tendency of carbonate rocks to be oil-wet in terms of wettability. The oil's inherent property of wetting the rock causes the residual oil to adhere to the rock's pores, making it challenging to extract to the surface. One method to enhanced oil recovery (EOR) is through biosurfactant injection, i.e., sophorolipid, a fungal biosurfactant that possesses the properties of surfactants in general. This study aims to evaluate the effectiveness of sophorolipid biosurfactant injection in enhancing oil recovery in carbonates, as well as to identify the dominant mechanism at work during the injection process and optimize it through coreflooding simulation. This research was conducted through laboratory testing and validation using a simulator, comprising two phases: coreflooding tests and coreflooding simulations. Coreflooding simulation was conducted to reduce the need for coreflooding experiments, which are time-consuming and costly. The simulator used in this research is CMG-GEM with sensitivity parameter and optimization using CMOST. The Sobol Analysis was conducted to assess the sensitivity parameters and identify the primary mechanism of sophorolipid. Then, optimization is achieved by adjusting the parameters, such as sophorolipid concentration, pore volume (PV) injection, and injection rate. Coreflooding sensitivity results show that the dominant parameter is the nonwetting trapping number (DTRAPN), which is closely related to the mechanism of wettability alteration and mix viscosity. The effectiveness of the Sophorolipid mechanism in modifying wettability, enhancing displacement efficiency, and facilitating emulsion formation, hence improving sweeping efficiency. The recovery factor (RF) increased from the coreflooding simulation optimization results, reaching 19%-33%.
Determination of Hydrotreated Vegetable Oil (HVO) in Blended Diesel Fuel Using Calibration of Isooctane by GC-FID Measurement Novilia Novilia; Sylvia Ayu Bethari; Handajaya Rusli; Muhammad Bachri Amran
Scientific Contributions Oil and Gas Vol 48 No 3 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i3.1835

Abstract

Hydrotreated vegetable oil (HVO) is emerging as a promising renewable fuel that is sharing similar chemical characteristics with fossil diesel, making it suitable as a blending component. However, this similarity is presenting challenges in distinguishing and quantifying HVO in diesel blends. The present study is focusing on developing a simple, cost-effective, and reliable method using gas chromatography with flame ionization detection (GC-FID) for determining HVO content in diesel mixtures. Two candidate markers, hexadecane (C₁₆H₃₄) and heptadecane (C₁₇H₃₆), are being evaluated based on linearity, detection limits, and accuracy. Calibration curves are being constructed using HVO–isooctane mixtures from 0 to 50% v/v HVO. The heptadecane peak is demonstrating superior performance with excellent linearity (R² = 0.9994), a low detection limit (1.77% v/v), and quantification limit (5.36% v/v). In contrast, the hexadecane peak is showing similar linearity but lower sensitivity. Accuracy tests are being conducted on diesel samples spiked with 10% HVO, showing recovery rates above 95% for both markers. Overall, heptadecane is proving to be a consistent and reliable marker for quantifying HVO in diesel blends using GC-FID.
Innovation in Inspection Planning Using The Corrosion Assessment Information System (CAIS) Analytical Tool to Prevent Stationary Equipment Failure in Crude Distillation Unit (CDU) Muki Satya Permana; Mirwan Prasetiyo Soeweify; Brammantyo Nugroho; Fauzi Yusupandi; Hary Devianto; Ardian Dwi Prakoso
Scientific Contributions Oil and Gas Vol 48 No 3 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i3.1848

Abstract

Equipment failure caused by corrosion remains a critical challenge in ensuring the reliability and refinery asset integrity in the oil and gas industry. This study aims to develop a Corrosion Assessment Information System (CAIS), designed to assess and visualize corrosion severity through a color-coded Process Flow Diagram (PFD). The CAIS methodology consists of four key stages: analysis of design and operational data, process simulation and validation, compilation of contaminant data for each Crude Distillation Unit (CDU), and identification of corrosion mechanisms according to API 581 and API 571 standards. The system produces a corrosion risk map with four color indicators i.e. green (low), blue (moderate), yellow (high), and red (very high) which assists in prioritizing inspection and maintenance activities based on corrosion severity. Implementation results demonstrate that CAIS improves analytical efficiency, data accessibility, and collaboration between engineering and maintenance teams. Furthermore, it supports predictive monitoring and enables faster decision-making to reduce corrosion-related failures. External validation and integration into refinery workflows confirm CAIS as a strategic digital solution that strengthens risk-based inspection and predictive maintenance practices. Overall, CAIS provides a reliable platform for enhancing digital corrosion monitoring and asset integrity management at PT Kilang Pertamina Internasional, Refinery Unit VI Balongan, Indonesia.

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