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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 716 Documents
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An Integrated Analysis Approach for Identifying Water Influx Mechanism in Gas Well: TMG Case Study Tjok Gede Satryangga; Amega Yasutra; Dedy Irawan; Amritzar Aimar; Seno Kushidayat
Scientific Contributions Oil and Gas Vol 49 No 3 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i3.2139

Abstract

Produced water is a primary operational challenge in gas fields, as it can restrict gas flow and severely reduce well productivity. Diagnosing and identifying water influx sources in directional gas wells is critical to mitigating this phenomenon and optimizing well performance. This study details a quantitative workflow evaluating water-gas production dynamics to identify key drivers of water influx, water coning and channeling. Furthermore, it determines whether the reservoir aquifer boundary has shifted. This study uses algorithms derived from classical model water-to-gas ratio diagnostic, reservoir and geological evaluations based on the transient analysis radius of investigation and predictive models to forecast cumulative gas production at breakthrough. By analyzing data from 4 wells, this study demonstrates that water-gas ratio trends and transient pressure behaviors can accurately classify fluid boundary geometries. Driven by localized reservoir heterogeneities and declining pressures, these dynamics accelerate water encroachment. This process culminates in water breakthrough, as confirmed by diagnostic log-log signatures of water channeling and water coning late channeling. The established method provides robust diagnostics for identifying produced water sources and improving predictive accuracy, directly guiding effective well management and field development strategies.
Bottom Hole Assembly Performance Evaluation for Horizontal Well Drilling: Case Study of Well “AM-63” in Penang Field, Indonesia Herianto; Harry Budiharjo S; Alip Meindar
Scientific Contributions Oil and Gas Vol 49 No 3 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i3.2142

Abstract

Horizontal well drilling is highly complex, particularly in the landing section, due to the increased inclination angle, which can increase torque and drag. These conditions reduce the effectiveness of Weight-on-Bit (WOB) transfer, lower the Rate of Penetration (ROP), extend drilling time, and increase the risk of hanging problems, which could lead to a stuck-pipe case. This study aims to evaluate the performance of the Bottom Hole Assembly (BHA) design in Well AM-63 and to formulate recommendations for a more effective BHA design for future wells. The study employs a quantitative, evaluative case study approach. The data analysed include the wellbore trajectory, BHA configuration, drilling parameters, torque and drag, ROP, and drilling time in the 12%" section (2,310-4,195 ftMD). The analysis results show that a relatively heavy BHA configuration increases the contact force between the drill string and the wellbore wall near the landing section (4.004-4.195 ft MD), resulting in increased torque and drag, decreased ROP, and increased drilling time. The actual drilling time for the 124" section was 160 hours, which was longer than the planned 65 hours, resulting in an additional 95 hours. This study provides a quantitative evaluation, based on field data, of the performance of the Bottom Hole Assembly (BHA) at the Penang Field by demonstrating the relationship between BHA configuration, wellbore trajectory, and increases in torque and drag due to friction. The findings of this study serve as a practical reference for optimizing BHA design while highlighting the trade-off between successful drilling direction control and efforts to minimize friction in horizontal well drilling operations. Based on the evaluation results, it is recommended to use a lighter BHA configuration to reduce torque and drag, improve WOB transfer efficiency, and minimize the risk of hanging while drilling subsequent horizontal wells. The results provide practical guidance for improving drilling efficiency and for optimizing BHAs in future horizontal well developments under similar field conditions.
Flow Assurance for Paraffinic Classified Crude Oil Using Water Heating Boiler Metode in Field Sepanjang East Java Tio Rizky Arga Sasmita; Muh Kurniawan
Scientific Contributions Oil and Gas Vol 49 No 3 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i3.2144

Abstract

Field Development and Drilling of New Wells in Indonesia continues to be carried out with the aim of maintaining and increasing oil and gas production. When transporting crude oil from the well to the storage tank, special handling is required. The transportation of crude oil through pipelines has the potential for several issues, one of which is wax deposition. This study aims to analyze the causes of wax deposition in pipelines, analyze the effect of pipe diameter on wax deposition, analyze the impact of using insulation on wax deposition, and analyze the influence of insulation thickness on wax buildup. Flow assurance is essential to determine the optimum pipeline size based on the results of reservoir well tests, considering operating pressure and flow rate. If the pipeline size is increased, pressure and temperature will drop. This could cause the fluid not to reach its destination and may result in the formation of hydrates, wax, and asphaltenes inside the pipeline. On the other hand, if the pipeline size is too small, the pressure and temperature will be very high. This will require a thicker pipeline design and is likely to cause significant thermal expansion. Flow assurance is a term that refers to the process of maintaining the flow of fluids (water, gas, oil) from the well to the pipeline transfer point using chemical treatments and engineering approaches. The basis of flow assurance lies in fluid chemistry (composition, pressure, and temperature) and fluid hydraulics (ratios, production rates, and topography)
SEM-XRD Aging Study of Pre-Stressed 2024-T3 Alloys for Oil and Gas Supporting Components Wikan Jatimurti; Azzahwa Fariha Padmavati; Sulistijono; Alvian Toto Wibisono; Agung Purniawan
Scientific Contributions Oil and Gas Vol 49 No 3 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i3.2146

Abstract

AA2024-T3 aluminum alloy has a high strength-to-weight ratio and the potential for use in oil and gas support components that are not wetted and do not experience pressure, such as lightweight brackets, instrument guards, inspection equipment housings, and auxiliary structures of operational vehicles. This study evaluated the effects of 0%, 2%, 4%, and 6% pre-strain and artificial aging at 175 and 190 °C on material integrity using scanning electron microscopy (SEM), X-ray diffraction (XRD), Vickers hardness testing, tensile testing, and fractography. The aging duration is 8 hours. The P4-A175 condition yielded a hardness of 158 HV, a yield strength of 366 MPa, a maximum tensile strength of 505 MPa, and an elongation of 12.4%, so it was chosen as the best strengthening condition among aging conditions that still retain an elongation of at least 12% and a ductile fracture morphology. In contrast, P6-A190 produces a tensile strength of 437 MPa and an elongation of 7.8%, accompanied by shallow dimples and secondary cracking. These findings suggest that increased violence is not always synonymous with increased integrity. The implications of the study are limited to non-wet, non-pressure-retaining supporting components because exposure to CO₂, H₂S, brine, cyclic loads, and oil-and-gas service conditions has not been simulated.
Enhancing Economic Resilience in Marginal Oilfields Through Discrete Event Simulation Optimization of Coiled Tubing Reutilization Warno; Suharjito
Scientific Contributions Oil and Gas Vol 49 No 3 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i3.2149

Abstract

Coiled Tubing Gas Lift (CTGL) is an artificial lift method contributing the majority of oil production in marginal fields. These fields face a double challenge: reserves continue decreasing while operational costs tend to increase. This research aims to develop optimization models for reutilizing coiled tubing, shifting from current practices where CTGL installations always use new coiled tubing materials. A Discrete Event Simulation (DES) mirrors current operational practices based on empirical historical data (2019-2024) from the mature marginal oilfield Kutai Basin, with a target reservoir interval of 700 to 8000 ft in East Kalimantan, Indonesia. A baseline model (Scenario 0) and four optimization models (Scenarios 1- 4) of DES were developed to evaluate the most optimal strategies incorporating recycling and distinctive cutting policies. Scenario 1 (Dynamic Recycle) emerged as the best-performing model, delivering the highest Net Present Value (NPV) of $58.53 million with 100% demand fulfillment; Scenario 4 (Hybrid Cut) performed equivalently but generated slightly more scrap, while the fixed-cut policies (Scenarios 2–3) were operationally unviable. Compared to the current practice (Scenario 0), which incurs an average Coiled Tubing (CT) cost of $69,000 per well, Scenario 1 improves NPV by 7.62% (~$4.1 million), creating significant value for marginal fields to maintain profitability and continuity. It also drastically reduces CT consumption by 53% and metal scrap by 60% while fulfilling 100% of job demand. The DES approach successfully validated that recycling CT is highly viable without compromising operational continuity. Earlier studies on coiled tubing are related to technical and operational failure factors and quality of service, while this research addresses problems such as the permanent application of CTGL in long-term project economies. Using DES, decision-makers can quantify the economic trade-offs of strategies without risk before implementation in the oil and gas industry.
Development of Machine Learning for Lost Production Opportunity Prediction and Production Optimization Through Workover Scheduling in Pertamina Hulu Sanga Sanga Field, Sanga-Sanga Block of East Kalimantan, Indonesia Adinsya Yudha; Suranto; Frans Richard Kodong; Muhammad Rahmanaji Soeparmono
Scientific Contributions Oil and Gas Vol 49 No 3 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i3.2150

Abstract

Lost Production Opportunity (LPO) measures production that cannot be realized because a well or facility is constrained. In many field-planning workflows, LPO and workover schedules are still estimated from historical averages and a fixed production uplift for each job. Although practical, these assumptions do not represent the nonlinear interaction among production behavior, equipment failures, downtime, and intervention timing. This work examines whether those interactions can be learned from field data and used to improve the monthly scheduling of rigless workover jobs.Historical production, Planned Downtime (PDT), Unplanned Downtime (UPDT), and operational event records from Field ‘X’ were compiled at monthly resolution. XGBoost regression models were trained using a chronological data split and evaluated with MAE, RMSE, sMAPE, and actual-versus-predicted plots. The resulting LPO forecasts and feature-importance rankings were then incorporated into a Decision Support System (DSS). Together with workover capacity, expected uplift, job cost, commodity price, and operational constraints, the DSS assigns a monthly risk level and recommends whether workover activity should be increased, selected cautiously, or reduced.The gas and oil models produced sMAPE values of 16.79% and 19.06%, respectively. In the 2026 simulation, DSS-based scheduling increased gas production from 83.43 to 84.56 MMscfd and oil production from 9,650 to 9,805 BOPD relative to the conventional schedule. These results suggest that field data can be used not only to estimate LPO, but also to place rigless workover jobs in months where their production benefit is less exposed to operational disruption.
Design of a Swab Cup Running Tool to Reduce Fluid Bypass during Liquid Swabbing Operations in Dual Size Tubing Completion Oil and Gas Wells Karnando; Dedy Irawan; Amega Yasutra
Scientific Contributions Oil and Gas Vol 49 No 3 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i3.2155

Abstract

Swabbing is a liquid unloading method used in the oil and gas industry to reduce hydrostatic pressure caused by fluid accumulation in the wellbore. In wells with dual-size tubing completions (4.5-inch and 3.5-inch), tubing diameter transitions can reduce Swab Cup sealing performance, causing fluid bypass and lowering lifting efficiency. This study develops a modified Swab Cup Carrier and swab mandrel to support continuous fluid lifting in dual-size tubing completions. An engineering design research approach was applied, including field problem identification, conceptual design, Computer-Aided Design (CAD), Finite Element Analysis (FEA), prototype development, tubing simulation, and functional evaluation. The proposed design incorporates a cam-guided release-and-carry mechanism that enables the Swab Cup Carrier to release at the tubing X-over during Run In Hole and reconnect during Pull Out of Hole. FEA of AISI 4130 alloy steel showed a maximum von Mises stress of 278.6 MPa, below the material yield strength of 460 MPa, indicating adequate structural safety. Prototype testing using a PVC tubing simulation verified the proposed mechanism. The design has the potential to minimise fluid bypass, maintain lifting continuity, and improve swabbing effectiveness in dual-size tubing completions. Further laboratory and field validation is required to confirm its operational performance.
Investigation of the Effects of Multi-Walled Carbon Nanotubes Concentration and Sonication Time on the Performance of EOR Nanofluids Heydar Ruffa Taufiq; Ngurah Ayu Ketut umiati; Diah Ayu Purbowati; Eva Fariha Sal Shabillah; Khasan Rowi; Nesti Dwi Maharani; Agus Subagio
Scientific Contributions Oil and Gas Vol 49 No 3 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i3.2162

Abstract

The rising global energy demand drives the development of more efficient and environmentally friendly enhanced oil recovery (EOR) technologies. Nanofluids based on multi-walled carbon nanotubes (MWCNTs) stabilized by the surfactant sodium dodecyl sulfate (SDS) can improve oil recovery by altering rock wettability and increasing the viscosity of the injected fluid. This study investigates the effects of two synthesis parameters of the MWCNT/SDS nanofluid in two stages: MWCNT mass concentration and sonication time. In the first stage, nanofluids were synthesized at varied MWCNT concentrations (0.0002–0.001 g/100 mL) under 20 minutes of sonication. In the second stage, the best-performing concentration was used while the sonication time was varied (10–60 minutes). Nanofluid performance was evaluated through contact angle, viscosity, and colloidal stability tests. The results show that increasing the MWCNT concentration decreased the contact angle from 47.73° to 31.22° and increased the viscosity from 0.9414 to 1.0384 cP. At the best-performing concentration (0.001 g/100 mL), prolonging the sonication time reduced the contact angle to 19.22° at 60 minutes, increased the viscosity to 1.0770 cP, and improved the colloidal stability (stable up to 36 hours). The combination of an MWCNT concentration of 0.001 g/100 mL and a sonication time of 60 minutes produced the MWCNT/SDS nanofluid with the best characteristics within the tested range for EOR applications.
Multi-Stakeholder Agent-Based Decision Framework for Sustainable Horizontal Well Placement: Field Validation of Ultra-Deep Azimuthal Resistivity Integration Across Three Well Examples Ida Bagus Gede Hermawan Manuaba; Dermawan Wibisono; Manahan Parlindungan Saragih Siallagan; Taufan Marhaendrajana; Haifeng Wang
Scientific Contributions Oil and Gas Vol 49 No 3 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i3.2164

Abstract

The oil industry is under mounting pressure to reconcile economic viability with environmental sustainability while managing complex stakeholder dynamics. Traditional modelling approaches struggle to capture emergent behaviours from multi-agent decision-making in sustainable oil recovery (Bonabeau, 2002; Macal & North, 2010). Three field wells are examined through an economic review within an agent-based framework that integrates Ultra-Deep Azimuthal Resistivity (UDAR) technology with 3D far-field petrophysics to optimize sustainable oil recovery by improving stakeholder collaboration (Manuaba et al., 2025a). We developed a multi-agent system comprising nine stakeholder types of petrophysicists, drilling engineers, geologists, reservoir engineers, oil operators, service companies, government regulators, oil market analysts, and geopolitical forces that incorporate UDAR’s 3D far-field characterization capabilities. The model examines four critical points: economic feasibility, environmental impact, technical risk, and political stability. An agent-based framework illustrates how UDAR technology serves as a central information hub, facilitating informed decision-making across technical, business, and regulatory domains (Manuaba et al., 2024; Pewekar et al., 2025). The model captures complex feedback mechanisms, including market signals, regulatory alignment, technology integration loops and human interactions. Sustainability metrics, such as well lifespan, energy efficiency, social impact, economic viability, and resource conservation, are embedded in agents' decision-making processes (Erhueh et al., 2023). Results show that integrating UDAR technology with agent-based provides a robust framework for optimizing sustainable oil recovery operations. This approach enables coordinated stakeholder action while balancing competing objectives and adapting to dynamic market and regulatory conditions, offering significant potential for improving both economic and environmental outcomes.
Geospatial Analysis of Surface and Subsurface Factors for Mapping Geothermal Potential Zones in Central-Western Taiz, Yemen Anwar Abdullah; Ghareb Hamada; Abbas Al-Khudafi; Ibrahim Farea; Fahd Alakbari
Scientific Contributions Oil and Gas Vol 49 No 3 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i3.2167

Abstract

This study evaluates the application of remote sensing and GIS techniques for mapping geothermal potential areas in the central-western Taiz, Yemen. The objective is to identify prospective areas for hydrothermal water exploration. Geothermal potential mapping was based on nine factors derived from remote sensing, geological, and geophysical datasets. Several steps were used to prepare these factors such as rasterization, re-projection, re-sampling, classification and weighting. The weighted values of the classes for each factor map were assigned based on their spatial correlation with eight known hydrothermal water locations. A GIS-based Weighted Overlay Technique (WOT) was applied. The resulting geothermal potential map categorizes the area into five classes: very high, high, moderate, low, and very low, covering 5.08%, 9.65%, 14.65%, 50.46%, and 20.16% of the study area, respectively. However, 7 of the 8 hydrothermal occurrences identified (87.5%) are located in the very high potential zone. The observed concentration is approximately seventeen times greater than random expectation, providing further evidence that the model is able to identify areas favorable for geothermal occurrence. This supports logical consistency but is not proof of independent validation. Independent field data are needed to validate the predictive power of the map. Given the limited number of validation points, the results should be considered as a regional screening tool.

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