cover
Article Per Year (5 Year)
All
Home Page
OAI Link
Editorial Team
Contact
Reviewer
Google Scholar
Contact Name
Wulandari
Contact Email
jurnal.lemigas@esdm.go.id
Phone
+6221-7394422
Journal Mail Official
jurnal.lemigas@esdm.go.id
Editorial Address
Jl. Ciledug Raya Kav. 109, Cipulir, Kebayoran Lama, Jakarta Selatan 12230
Location
Kota adm. jakarta selatan,
Dki jakarta
INDONESIA
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 33 Documents
 1   2   3   4 
Search results for , issue "vol 49 no 2 (2026)" : 33 Documents clear
Petrophysical Evaluation of Lam Member Reservoir, Madbi Formation (Late Jurassic), using Well Log and Core Data in Habban Field, Sab'atayn Basin, Yemen Ali S. Ghurab; Ahmed AL-Dujaili; Adel. M Al-Matary; Basim. S Al-Khirbash; Mohammed. M. H. Hakimi; Azmi, S.Al-Audi
Scientific Contributions Oil and Gas Vol 49 No 2 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i2.2005

Abstract

The present work aims to quantify the Lam lithological and reservoir petrophysical characteristics of the Late Jurassic in the Habban oil field, Marib Shabwah Basin, Yemen, from the wireline logs and core data.  The results revealed that the Lam Member rocks consist of an interbedded sequence of claystone, intercalated limestone, dolomite claystone, and sandstone. Lam Member lithology consists of clayey and strongly carbonate-cemented, very fine to coarse-grained Sandstone, divided into three main layers with possible reservoir units in the upper and lower sections. The Lam Member rocks are encountered with a relatively thick thickness reaching up to 5008 m and have reasonable porosity (11-25%), shale content (15-25 %), and high hydrocarbon saturation in the Habban oil field up to (70%) with maximum pay thicknesses reaching 40 m. A scatter plot of petrophysical gamma ray values versus core gamma ray values gave an approximate linear relationship. Also, Cross-plots of porosity-density values versus core values revealed a linear relationship between the two datasets. Poor-sorting, pore-filling with clay, and carbonate cementation are the main causes of poor reservoir quality. The Lam reservoir is a tight or unconventional that will rely on Perforating, natural fracturing, and/or fracture stimulation to produce oil.
Optimizing CO2 Storage Strategies for Enhanced Mineral Trapping and Plume Containment in The Aquifer Zone of an Indonesian Gas Reservoir Utomo Pratama Iskandar; Arik; Panuju; Garindia Grandis; Nanda Ilham
Scientific Contributions Oil and Gas Vol 49 No 2 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i2.2067

Abstract

This study evaluates optimized CO₂ storage strategies in the aquifer zone of the SK gas field in Indonesia to improve plume containment and explore the potential for enhanced mineral trapping. A coupled compositional-flow and reactive-transport simulation workflow was applied using an upscaled reservoir model under a common safe operating pressure envelope and a containment constraint requiring the plume to remain within the aquifer zone over a 120-year simulation period. Three groups of scenarios were examined: well-placement sensitivity (A1–A3), production-assisted injection (B1–B3), and completion-design sensitivity (C1–C3). Among the baseline cases, A3 provided the best plume containment, with the most compact lateral footprint and smallest vertical plume spread, while A1 gave the highest total stored CO₂. Among the production-assisted cases, B2 was the most effective pressure-management option, producing the largest pressure reduction and a modest increase in total stored CO₂. Completion redesign generated the largest storage gains, increasing total stored CO₂ by about 28–33.3% relative to the corresponding baseline cases. Most scenarios maintained the plume confinement within the aquifer zone, although C1 showed localized upward CO₂ occurrence near the free-water level. Overall, the tested strategies improved storage performance, with A3 providing the best plume containment among the baseline cases, B2 delivering the strongest pressure-management benefit and increasing total stored CO₂ by approximately 3.93% relative to A2, and completion redesign producing the largest storage gains, increasing total stored CO₂ by about 28–33.3% relative to the corresponding baseline cases. Mineral trapping increased slightly in the completion-design cases, although it remained a minor component of total storage within the 120-year simulation period.
Potential Use of Kepok Banana Peel Waste as Raw Material for Carboxymethyl Cellulose for Oil and Gas Drilling Fluid Applications Apriandi Rizkina Rangga Wastu; Asep Kurnia Permadi; Deana Wahyuningrum; Asri Nugrahanti
Scientific Contributions Oil and Gas Vol 49 No 2 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i2.2070

Abstract

This research aims to evaluate the potential of kepok banana peel as a raw material for carboxymethyl cellulose synthesis and to assess its effects on the rheological properties and filtration of bentonite-based drilling mud. CMC is synthesized through a process of delignification, bleaching, alkalization, and carboxymethylation. CMC characterization includes alpha cellulose content, degree of substitution, purity, pH, FTIR, SEM, and EDS. The obtained CMC was added in drilling mud at concentrations of 3 g, 6 g, and 9 g, and the resulting mud was tested for mud rheology and filtrate volume. The results showed that the alpha-cellulose content was 91.60%, the degree of substitution was 1.0, and the purity was 88.17%, meeting the SNI CMC grade II standard. The application of CMC increased plastic viscosity (12–14 cP), yield point (19–21 lb/100 ft²), and gel strength (8–13 lb/100 ft² for 10 seconds; 12–17 lb/100 ft² for 10 minutes) as the concentration increased. The filtrate volume decreased from 15 ml to 13 ml/30 minutes, and the mud cake thickness decreased from 0.5 mm to 0.3 mm. The pH value was stable in the range of 9. It was concluded that CMC derived from kepok banana peel has the potential to serve as an environmentally friendly drilling mud additive.
The Next Generation of Safety: Artificial Intelligence and Machine Learning Strategies for a Safer Oil and Gas Industry Shahabodin Taheri; Yousef Azimi
Scientific Contributions Oil and Gas Vol 49 No 2 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i2.1786

Abstract

This study explores the transformative potential of Artificial Intelligence (AI) and Machine Learning (ML) in revolutionizing safety practices within the oil and gas industry. Through a systematic literature review and conceptual analysis of peer-reviewed publications, industry reports, and regulatory frameworks, this research synthesizes current knowledge on AI applications in safety management. The study critically examines the ethical implications and potential drawbacks of AI-driven safety systems, such as data privacy concerns, algorithmic bias, and the evolving dynamics of human-machine interaction in high-risk environments. The regulatory landscape is scrutinized, highlighting the need for adaptive policies that can accommodate rapidly evolving technologies while maintaining robust safety standards. Furthermore, the paper explores emerging trends, including the convergence of AI with the Internet of Things (IoT) and 5G technologies, the development of explainable AI for safety-critical applications, and the increasing role of autonomous systems in hazardous operations. Based on the synthesis of empirical evidence and theoretical frameworks, the findings reveal that while AI and ML offer unprecedented opportunities in the oil and gas sector, their efficacy is contingent upon overcoming significant technical, organizational, and ethical challenges. The study proposes a holistic framework for AI implementation that emphasizes phased adoption, stakeholder engagement, and continuous evaluation of safety metrics. This work contributes to the growing body of knowledge on digital transformation in high-risk industries and provides actionable insights for policymakers and safety professionals seeking to leverage AI for improved safety performance in the oil and gas sector.
Development of A Risk-Based Pre-Tender Assessment Tool for Oil and Gas Construction Projects Using Analytical Hierarchy Process Sudirman; Rosmariani Arifuddin; M Asad Abdurrahman
Scientific Contributions Oil and Gas Vol 49 No 2 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i2.1962

Abstract

The pre-tender stage is a critical decision point in oil and gas construction projects, particularly in capital-intensive, technically complex environments, where inappropriate project selection may increase financial, technical, operational, and regulatory risks. In practice, contractors often rely on subjective judgment in early project evaluation due to the limited availability of structured, quantitative decision-support tools. This study aims to develop a risk-based pre-tender assessment tool to support project selection decisions in oil and gas construction projects in Indonesia. The study integrates a literature review with a questionnaire-based survey involving 90 experienced construction practitioners occupying supervisory and managerial positions. Data were analyzed using descriptive statistics and the Analytical Hierarchy Process (AHP) to determine the relative priority weights of evaluation criteria and sub-criteria.The results indicate that all major criteria contribute significantly to pre-tender decision-making, with financial aspects obtaining the highest priority weight (22.9%), followed by commercial (20.1%), technical (19.4%), legal and social (19.3%), and marketing aspects (18.3%). At the sub-criteria level, expected profit margin, implementation risk, and project owner legality emerged as dominant evaluation factors. A case study application further demonstrates the practical applicability of the proposed framework, with the pipeline installation project achieving a higher feasibility score (7.48) than the oil storage terminal project (6.32). Sensitivity analysis also confirms that the ranking results remain stable under alternative weighting scenarios.The findings demonstrate that the proposed framework provides a structured, transparent, and risk-informed approach for evaluating project feasibility during the pre-tender stage. The study contributes by developing an integrated weighting-based decision-support framework specifically tailored to the characteristics and risk exposure of oil and gas construction projects, thereby supporting more objective and consistent contractor decision-making.
Optimization of Chemicaly Activated Candlenut and Walnut Shell Biosorbents for Produced Water Purification Within an Iot-Based Monitoring System Muhammad Khairul Afdhol; Rika Lala Saputri; Mursyidah; Fiki Hidayat; Tomi Erfando; Ari Prasetyo; Adiella Zakky Juneid
Scientific Contributions Oil and Gas Vol 49 No 2 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i2.1972

Abstract

Produced water from petroleum operations contains high levels of hydrocarbons, suspended solids, and dissolved contaminants that must be treated before discharge or reuse. This study aims to optimize biosorbents derived from candlenut and walnut shells through chemical activation using potassium hydroxide (KOH) for the purification of produced water. In addition, an Internet of Things (IoT)-based monitoring system was integrated to enable real-time assessment of water quality parameters. The biosorbents were characterized using Fourier Transform Infrared Spectroscopy (FTIR) and Scanning Electron Microscopy (SEM) to identify surface functional groups and morphological modifications. Experimental evaluations of turbidity, bulk density, and total dissolved solids (TDS) were conducted under various operating conditions. The activated biosorbents exhibited enhanced hydroxyl and carboxyl functional groups, as confirmed by FTIR, with an optimal bulk density of 0.76 g/cm³. Under optimum conditions (pH 7, contact time 90 min, adsorbent dosage 15 g/L), turbidity and TDS removals reached 80% and 75%, respectively. The IoT system successfully enabled real-time data acquisition and process monitoring, ensuring operational reliability. The maximum adsorption capacity based on the Langmuir model reached 33.8 mg/g for KOH-activated walnut and 31.2 mg/g for candlenut biosorbent. Overall, the chemically activated candlenut and walnut biosorbents demonstrated excellent adsorption capacity and potential for sustainable produced water treatment. This approach offers an environmentally friendly and cost-effective solution by utilizing local biomass waste integrated with modern IoT-based control technologies. Adsorption behavior was further evaluated using Langmuir/Freundlich isotherm and kinetic models.
Failure Mechanisms and Risk-Based Mitigation of Hydrocarbon Pipeline Blockages: A Comprehensive Review Hamdani Wahab; Asral; Awaludin Martin
Scientific Contributions Oil and Gas Vol 49 No 2 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i2.2011

Abstract

Hydrocarbon pipelines play a vital role in ensuring the continuous transportation of oil and gas. However, pipeline blockages remain a major operational challenge because of their significant impacts on safety, environmental protection, and production reliability. This study presents a literature review aimed at identifying and classifying the hazards and risks associated with hydrocarbon pipeline blockages using a 5×5 risk matrix based on the MIL-STD-882B military safety standard. Historical incident data from 1970–2024 were collected from the Pipeline and Hazardous Materials Safety Administration of the US Department of Transportation to support the risk assessment process. The analysis indicates that environmental damage is the most significant consequence of pipeline blockage incidents (28%), followed by fire and explosion (22%), toxic gas exposure (17%), overpressure (13%), economic losses (11%), and production losses (9%). Furthermore, environmental recovery costs account for approximately 88.6% of the total financial impact, while the probability of severe incidents reaches 80%, with estimated economic losses up to USD 20 million or production disruptions of 25%. The findings highlight the urgent need for effective mitigation and prevention strategies to improve pipeline integrity, operational safety, and sustainability within the oil and gas industry.
A System Dynamics Approach to Analyze Biodiesel Production and Oil Import Dependency in Indonesia Andry Prima; Bayu Satiyawira; Havidh Pramadika; Daud Asrun Nauw; Lisa Samura; Mustamina Maulani; Cahaya Rosyidan; Maman Djumantara; Djunaedi Agus Wibowo; Wiwik Dahani; Osama Jawaid Butt
Scientific Contributions Oil and Gas Vol 49 No 2 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i2.2019

Abstract

Indonesia’s persistent dependence on imported diesel fuel poses significant challenges to national energy security, fiscal stability, and exposure to global market volatility. In response, the government plans to implement a mandatory B50 biodiesel blending policy starting in 2026 to reduce diesel imports by leveraging domestic bioenergy resources. While higher blending mandates are often assumed to directly lower imports, existing studies largely rely on static or deterministic approaches that inadequately capture feedback dynamics and long-term uncertainty. This study addresses this gap by integrating system dynamics modelling with Monte Carlo simulation to analyze the impact of biodiesel blending policies on diesel import dependency under structural and parametric uncertainty. The model incorporates biodiesel production growth, domestic allocation after exports, diesel demand growth, and blending effectiveness within a feedback-based framework calibrated using historical data from 2013 to 2024. Simulation results indicate that the B50 policy consistently reduces diesel import requirements relative to the baseline; however, absolute imports may continue to rise without sufficient domestic supply expansion. Cumulative results show that by 2035, the B50 policy achieves import reductions of approximately 55–58 million kiloliters, increasing to around 60 million kiloliters when combined with accelerated biodiesel production growth. Monte Carlo analysis reveals robust medium-term outcomes by 2030 but increasing uncertainty by 2035. The findings highlight that blending mandates must be accompanied by sustained supply-side development to ensure long-term effectiveness and resilience.
Edge Computing–Enabled Real-Time CO₂ Emissions Monitoring: A Low-Latency and Bandwidth-Efficient Architecture for Oil and Gas Sector Suka Handaja; Bambang Yudho Suranta
Scientific Contributions Oil and Gas Vol 49 No 2 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i2.2020

Abstract

The oil and gas industry is facing increasing pressure to reduce carbon dioxide (CO₂) emissions while maintaining operational efficiency and regulatory compliance. However, conventional cloud-based emissions monitoring systems often suffer from latency, bandwidth limitations, and reduced reliability in remote operational environments. This study aims to explore the role and implementation of edge computing as an enabling technology for real-time CO₂ emissions monitoring in oil and gas facilities. The architecture of the proposed system integrates the Internet of Things (IoT) gas sensors, local data processing units, and cloud platforms for long-term analytics and reporting. The system is designed to process the emissions data closer to the source with the aim of significantly reducing latency, improving measurement reliability, and enhancing responsiveness to abnormal emissions events. The performance was subsequently evaluated through a distributed monitoring test scenario that simulated multiple emissions monitoring points under intermittent network connectivity conditions often experienced in remote oil and gas operations. The focus was on key performance indicators including data latency, bandwidth utilization, and system availability. The results showed that the edge-enabled architecture reduced average data latency from approximately 3.8 s to 0.9 s and data transmission volume by an estimated 79% through local preprocessing while maintaining monitoring availability above 96% during network disruptions. The trend reflected the ability of edge computing to provide a scalable and robust solution for continuous CO₂ emissions monitoring, particularly in geographically distributed and harsh operational environments often associated with oil and gas operations.
Structural Integrity Assessment of A Low Temperature Separation Unit (LTSU) Strainer Handle-Plate in Oil and Gas Operations: Coupled CFD and FEA Analysis of Fluid-Induced Loads Mohd Azni Md Kasim; Mohd Azahari Razali; Norfakhira Mohd Nor; Iman Fitri Ismail; Masataro Suzuki; Amnur Akhyan
Scientific Contributions Oil and Gas Vol 49 No 2 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i2.2033

Abstract

Structural strainers play a vital role in oil and gas processing facilities by removing solid contaminants from process fluids and protecting downstream equipment. In a Low Temperature Separation Unit (LTSU), a premature failure occurred at the handle punching plate connection of a strainer after approximately five years of continuous operation. This study aims to identify the root cause of the failure and to evaluate improved design configurations capable of withstanding operational loads. A coupled Computational Fluid Dynamics (CFD) and Finite Element Analysis (FEA) methodology was employed. CFD simulations were conducted to determine internal flow characteristics, pressure distribution, and pressure drop under both normal and contingency operating conditions. The resulting fluid-induced pressure loads were transferred to structural models for FEA to evaluate von Mises stress, displacement, strain, and unity check (UC) values for three designs with different punching plate thicknesses. The original design (Geometry A) exhibited high stress concentration at the handle–plate interface and UC values exceeding allowable limits, explaining the observed field failure. Geometry B showed improved performance under normal conditions but approached critical limits during contingency operation. Geometry C demonstrated the best structural integrity, maintaining UC values within acceptable limits in all cases while reducing peak stresses and deformation. The results confirm that insufficient plate thickness was the primary cause of failure and that increasing thickness significantly enhances structural reliability. The study demonstrates that the coupled CFD–FEA approach is an effective tool for failure diagnosis and design optimisation of process equipment subjected to fluid-induced loading in oil and gas operations.

Page 1 of 4 | Total Record : 33

 1   2   3   4 

Filter by Year

2026 2026


Reset
Filter By Issues
All Issue Vol 49 No 3 (2026) Vol 49 No 2 (2026) Vol 49 No 1 (2026) Vol 48 No 4 (2025) Vol 48 No 3 (2025) Vol 48 No 2 (2025) Vol 48 No 1 (2025) Vol 47 No 3 (2024) Vol 47 No 2 (2024) Vol 47 No 1 (2024) Vol 46 No 3 (2023) Vol 46 No 2 (2023) Vol 46 No 1 (2023) Vol 45 No 3 (2022) Vol 45 No 2 (2022) Vol 45 No 1 (2022) Vol 44 No 3 (2021) Vol 44 No 2 (2021) Vol 44 No 1 (2021) Vol 43 No 3 (2020) Vol 43 No 2 (2020) Vol 43 No 1 (2020) Vol 42 No 3 (2019) Vol 42 No 2 (2019) Vol 42 No 1 (2019) Vol 41 No 3 (2018) Vol 41 No 2 (2018) Vol 41 No 1 (2018) Vol 40 No 3 (2017) Vol 40 No 2 (2017) Vol 40 No 1 (2017) Vol 39 No 3 (2016) Vol 39 No 2 (2016) Vol 39 No 1 (2016) Vol 38 No 3 (2015) Vol 38 No 2 (2015) Vol 38 No 1 (2015) Vol 37 No 3 (2014) Vol 37 No 2 (2014) Vol 37 No 1 (2014) Vol 36 No 3 (2013) Vol 36 No 2 (2013) Vol 36 No 1 (2013) Vol 35 No 3 (2012) Vol 35 No 2 (2012) Vol 35 No 1 (2012) Vol 34 No 3 (2011) Vol 34 No 2 (2011) Vol 34 No 1 (2011) Vol 33 No 3 (2010) Vol 33 No 2 (2010) Vol 33 No 1 (2010) Vol 32 No 3 (2009) Vol 32 No 2 (2009) Vol 32 No 1 (2009) Vol 31 No 3 (2008) Vol 31 No 2 (2008) Vol 31 No 1 (2008) Vol 30 No 3 (2007) Vol 30 No 2 (2007) Vol 30 No 1 (2007) Vol 29 No 3 (2006) Vol 29 No 2 (2006) Vol 29 No 1 (2006) Vol 28 No 3 (2005) Vol 28 No 2 (2005) Vol 28 No 1 (2005) Vol 27 No 3 (2004) Vol 27 No 2 (2004) Vol 27 No 1 (2004) Vol 26 No 2 (2003) Vol 26 No 1 (2003) Vol 25 No 3 (2002) Vol 25 No 2 (2002) Vol 25 No 1 (2002) Vol 24 No 2 (2001) Vol 24 No 1 (2001) Vol 23 No 3 (2000) Vol 23 No 2 (2000) Vol 23 No 1 (2000) Vol 22 No 2 (1999) Vol 22 No 1 (1999) Vol 21 No 2 (1998) Vol 21 No 1 (1998) Vol 18 No 2 (1995) Vol 18 No 1 (1995) Vol 17 No 1 (1994) Vol 16 No 1 (1993) Vol 15 No 1 (1992) Vol 14 No 2 (1991) Vol 14 No 1 (1991) Vol 13 No 1 (1990) Vol 12 No 1 (1989) Vol 11 No 1 (1988) Vol 10 No 3 (1987) Vol 10 No 2 (1987) Vol 10 No 1 (1987) Vol 9 No 1 (1986) Vol 8 No 2 (1985) Vol 8 No 1 (1985) Vol 7 No 2 (1984) Vol 7 No 1 (1984) Vol 6 No 1 (1983) Vol 5 No 2 (1982) Vol 5 No 1 (1982) More Issue