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 619 Documents
 55   56   57   58   59 
New Perspective of Unconventional Hydrocarbon Production With Emission Calculations Estherlita Elizabeth Syaranamual; Silvya Dewi Rahmawati; Ardhi Hakim Lumban Gaol
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.v48i3.1790

Abstract

The Paris Agreement aims to limit global temperature rise to below 2°C, with Indonesia committing to achieving net zero emissions by 2060. The oil and gas industry contributes around 15% of global emissions. On the other hand, as a developing country, we still depend on fossil fuels to meet our energy needs. Based on data from the IEA in 2015, Indonesia has 303 TCF of shale gas reserves that we use to meet future energy needs. This study conducts a case study on a shale gas field (field X) by calculating greenhouse gas emissions using engineering estimation methods. These calculations estimate methane and carbon dioxide emissions using activity data from each process and emission factors published in the 2021 API Compendium. Furthermore, this study analyzes emission control strategy scenarios so that field X produces fluids optimally with lower emissions. Based on the results of the field emission source study, emissions originate from two stages, namely pre-production, including normal operating processes such as mud degassing in drilling operations, flowback in hydraulic fracturing, and well test operations, followed by the production stage, including venting or gas release operations such as pneumatic controllers, casing gas vents, workover processes, and several gas processing tools such as glycol dehydration and glycol pumps. Thus, the total emissions generated during 12 years of production are estimated at 90.24 million tons of CO2e. A development scenario for field X is a combination scenario of 20% regulating the production flow rate and number of wells, resulting in an emission reduction ratio of 23% and a recovery factor of 28%.
Machine Learning-Based Prediction of Shear Wave Velocity: Performance Evaluation of Bi-GRU, ANN, and The Greenberg-Castagna Empirical Method Muhammad Raihan Ulil; Sonny Winardhi; Ekkal Dinanto
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.v48i3.1797

Abstract

Shear wave velocity (Vs) is recognized as an important elastic parameter for lithology and fluid identification in oil and gas exploration. However, Vs data is not always recorded in well logs. Various empirical approaches are often used to estimate Vs, but these methods show limitations in terms of accuracy and time efficiency. With technological advances, machine learning has become an effective and efficient alternative for predicting Vs from well log data. This study is utilizing the Bi-GRU model, a sophisticated artificial neural network specifically designed to process sequential data. This capability makes Bi-GRU particularly suitable for predicting log Vs data. Four Bi-GRU modeling scenarios are being developed with different hyperparameter configurations and are being compared with ANN models using two input variations: with and without Vp data. The results show that scenario 2 (Bi-GRU with five hidden layers, batch size 64, learning rate 0.005) is achieve the best performance, with R² values of 0.9787 (without Vp) and 0.9868 (with Vp). The MAE values obtained are being recorded as 9.36 (without Vp) and 11.22 (with Vp). Compared to shows ANN, MLR, and empirical Castagna methods, the Bi-GRU model show a more significant improvement in prediction accuracy. These findings are indicating that Bi-GRU have strong potential for accurately and efficiently predicting Vs from well log data.
Techno-Economic Analysis of Dme Implementation in Indonesia’s Household Energy Sector Faqih Supriyadi; Irawan Adhi Putra; Riva Yudha Abriyant; Danang Sismartono; Cahyo Setyo Wibowo; Bambang Priyono
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.v48i2.1804

Abstract

Indonesia's increasing demand for Liquefied Petroleum Gas (LPG) – projected to reach 13.2 million tonnes by 2050 – and its heavy dependence on imports, require alternative and sustainable fuel solutions. Among the options under development, researchers and industry stakeholders consider Dimethyl Ether (DME)—particularly from abundant domestic low-rank coal—a viable and strategic substitute. DME has physicochemical properties similar to LPG, as well as its compatibility with existing storage and distribution infrastructure. This comprehensive study evaluates the techno-economic aspects of replacing LPG with coal-based DME in the household sector. The factors analyzed include energy equity, production and distribution costs, and projected fiscal impacts on the national economy. Assuming a production capacity of 1.4 million tons per year and an Internal Rate of Return (IRR) of 12%, analysts estimate DME’s Free-On-Board (FOB) price at IDR 8.03 million per ton, with a benchmark price equivalent to LPG at IDR 16,666/kg. At this rate, replacing imported LPG with domestic DME can save the country's foreign exchange around IDR10.71 trillion per year, but has the potential to increase subsidies by IDR3.97 trillion. The government can use the foreign exchange savings to cover the potential increase in DME subsidies.
Structure Evolution and Palinspastic Analysis of The Gurami-Tamiang Area, North Sumatra Basin, Indonesia Dumex Pasaribu; Benyamin Sapiie; Indra Gunawan
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.v48i3.1806

Abstract

The Sumatran back-arc basins developed beginning in the Middle Eocene, characterized by a variety of graben alignment patterns, which serve as critical indicators in understanding their formation history. One such basin is the North Sumatra Basin, dominated by north-south-trending grabens. These grabens are best observed in the Gurami-Tamiang Area. This research focuses on the subsurface analysis of this area, specifically: (i) detailed seismic interpretation of four east-west cross-sections that span several grabens, and (ii) palinspastic reconstructions to investigate structural and strain evolution over time, and its tectonochronostratigraphic chart. Generally, the structural configuration of the Gurami-Tamiang Area is defined by half-grabens bounded by east-dipping faults originating from negative flower structures at depth. The results show three phases of evolution: (i) Extensional Phase (45 - 32 Ma) is characterized by growth strata and strain magnitudes of (+) 4.2% to (+) 11.64%, (ii) Transitional Phase (32 - 22 Ma) is displaying both positive and negative strains of (+) 2.3% to (-) 1.7%,  with growth strata that are extending across grabens; and (iii) Contractional Phase (22 Ma – present) is characterized by negative strains of (-) 0.92% toward zero and mostly covered by post-extensional and syn-inversion deposits. The evolutionary phases indicate a novelty in the area, with the graben formation being part of a wrench fault system that includes the Khlong-Marui Fault, the Lokop-Kutacane Fault, and the Sumatra Fault.
A Techno-Economic Approach to Optimizing CCS Fiscal Parameters in Indonesia: A Case Study of Integrated Oil and Gas Development in CO2-Rich Areas Najeela Faza Ramadhani; Dedy Irawan; Sudono; Prasandi Abdul Aziz
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.v48i3.1809

Abstract

This study introduces a techno-economic approach to optimizing storage fees for CCS integrated with oil and gas development. The analysis adopts the production sharing contract cost recovery model in accordance with the implementation of Ministerial Regulation of Energy and Mineral Resources No. 16 of 2024, which addresses CCS-related parameters. Technical assessment confirms the studied reservoir’s suitability for long-term CO₂ injection through 5 injection wells, while oil and gas development are supported by 10 oil wells and 8 gas wells. The project’s economic viability under baseline conditions shows an IRR of 10.14% and POT of 15.73 years. Sensitivity analysis across fiscal parameters, such as investment credit, FTP, contractor split, CCS service fee and storage fee, CAPEX, royalty, and tax, identifies the storage fee as the most influential factor for viability. To achieve a commercially viable IRR of 15%, the project requires a minimum CCS service fee of 55 US$/MT and a storage fee of at least 35 US$/MT. The study underscores the need for clear regulations on fiscal incentives, CO₂ pricing, storage fees, and PSC integration to enhance CCS economic viability, while also offering a replicable framework for CO₂ assessments under dynamic fiscal regimes.
Performance Evaluation of Tween 60 Surfactant for EOR: Interfacial Tension Reduction and Microemulsion Formation Pauhesti Pauhesti; Ridha Husla; Sri Feni Maulindani; Apriandi Rizkina Rangga Wastu; Nadira Cahya Sutikna; Lailatul Wastiyah; Ade Kurniawan Saputra
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.v48i3.1812

Abstract

Enhanced Oil Recovery (EOR) techniques are essential for maximizing crude oil extraction from mature reservoirs. Surfactant injection, particularly using surfactants such as Tween 60, has shown great potential in reducing interfacial tension (IFT) and enhancing oil recovery. This study evaluates the performance of Tween 60 for EOR applications, focusing on its aqueous stability, phase behavior, IFT reduction, and core flooding efficiency at temperatures of 60°C and 80°C. The research addresses a gap in the literature by examining the long-term stability and phase behavior of Tween 60 at these temperatures. Aqueous stability tests over seven days indicate that Tween 60 remains clear and stable at 60°C but becomes cloudy and unstable at 80°C. Phase behavior tests reveal that a 0.5% concentration of Tween 60 produces the largest middle-phase microemulsion (5.75% volume), forming a bicontinuous Winsor III microemulsion that enhances oil-water interaction. IF T tests using a spinning drop tensiometer show a reduction in IFT to 0.00525 dyne/cm. Core flooding tests confirm that surfactant injection contributes an incremental oil recovery of 8.33% beyond what was achieved by waterflooding without surfactant, increasing the total recovery factor from 62.5% to 70.83%. However, limitations such as the short testing period (14 days) and the use of a single type of oil (39 ° API) underscore the need for further research.
Comparative Performance Analysis of Natural Fruit Peel Extract and Na2EDTA As Environmentally Friendly Scale Inhibitors in Tubular Systems Novrianti; Taufiq Hidayat; Neneng Purnamawati; M. Ridha Fikri
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.v48i2.1813

Abstract

Scale found in production tubing is still a severe operational problem in the oil and gas industry. This shows the need for scale control using synthetic chemicals such as disodium ethylenediaminetetraacetate (Na2EDTA), hydrogen chloride (HCL), or hydrogen fluoride (HF). However, concerns about the environmental impact and sustainability of long-term use of synthetic materials promote the search for alternatives based on natural materials such as tannin. Therefore, this study aims to determine and compare the effectiveness of tannins from rambutan binjai (Nephelium lappaceum), rambutan nona (Nephelium mutabile), and mangosteen (Garcinia mangostana) peel extract as natural scale inhibitors against Na2EDTA performance. To achieve the objective, UV-Vis spectrophotometric analysis  carried is out and shows tannin containing 20.91% (rambutan binjai peel), 21.14% (rambutan nona peel, and 21.58% (mangosteen peel). Laboratory tests are conducted with variations in tannin volume (5 mL, 10 mL, and 15 mL) as well as soaking times of 20 and 60 minutes in 20ml distilled water. The results showed that the increase in tannin volume addition and soaking duration is positively correlated with the decrease in scale mass. The highest performance is shown by mangosteen peel extract, which reduce scale by 0.132 grams (6.6%) at 15 mL in 60 minutes. For comparison, Na2EDTA under the same conditions reduces 0.176 grams (8.8%). These results show the potential of tannin-rich fruit peel extract as an environmentally friendly and sustainable scale inhibitor alternative for oil and gas production systems.
Development of Analytical Method for Determination of Palm-Based Hydrotreated Vegetable Oil (Hvo) in Diesel Blends Using Gas Chromatography: Preliminary Study Sylvia Ayu Bethari; Handajaya Rusli; Muhammad Bachri Amran
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.v48i2.1816

Abstract

Hydrotreated vegetable oil (HVO) is a renewable paraffinic biofuel derived from the catalytic hydrotreatment of triglycerides, particularly from palm oil. Because HVO's hydrocarbon structure is so similar to petroleum diesel, it can be mixed directly with regular diesel fuel. But because of this structural similarity, it is very difficult to accurately quantify HVO in diesel blends, which is essential for maintaining fuel quality and complying with regulations. In this study, gas chromatography–mass spectrometry (GC-MS) was used to identify the compounds and gas chromatography–flame ionization detection (GC-FID) was developed to quantify biofuel HVO. The chromatographic profiles of diesel, HVO, and biodiesel displayed distinct hydrocarbon distributions. Two diagnostic peaks at retention times of 17.5 – 17.7 minutes, identified as heptadecane and 2,6,10,14-tetramethylpentadecane (pristane), were used for preliminary identification. The heptadecane peak, present in both diesel and HVO, was selected as a quantifier, while the heptadecane-to-pristane ratio of 1.25 in diesel was applied as a correction factor. The accuracy of the method was confirmed by the observation of a strong linear correlation (R2 = 0.9991) for HVO concentrations ranging from 0 to 40% v/v. Recovery rates ranging from 97.0% to 102.2% further illustrated how reliable the method is for routinely analyzing the amount of HVO in diesel blends.
Kinetics of Dissolution and Wormhole Formation in Carbonate Rocks Using Lactic Acid: A Laboratory Study Berkah Hani; Asep Kurnia Permadi; Utjok W.R. Siagian; Harry Budiharjo
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.v48i2.1817

Abstract

Matrix acidizing in carbonate reservoirs typically relies on hydrochloric acid (HCl), which reacts rapidly, causes equipment corrosion, and limits penetration depth. Laboratory experiments confirmed that lactic acid exhibits measurable reactivity with carbonate rocks under reservoir-representative conditions, with apparent first-order rate constants of 0.0841 min⁻¹ (0.05 M), 0.0814 min⁻¹ (0.10 M), and 0.0788 min⁻¹ (0.15 M) at 60 °C and 500 RPM. Moderate R² values (48–49%) suggest partial mass-transfer control and limited acid concentration sensitivity in this range. Arrhenius analysis between 60–90 °C yielded an activation energy of 63.8 kJ/mol, consistent with organic acid–carbonate reaction behavior. Core flooding experiments at 80 °C and 100 psi confirmed that injection rate significantly influences wormhole formation efficiency. Permeability increased from 2.54 mD to 6.25 mD. PVbt analysis revealed an optimal condition at 0.3 mL/min (PVbt ≈ 0.73), supporting dominant wormhole formation, while lower rates (0.1 mL/min, PVbt ≈ 2.7) led to uniform dissolution and higher acid consumption. Intermediate and high rates (0.5 and 0.9 mL/min) generated ramified/branching channels. Overall, the study demonstrates that bio-derived lactic acid is a safer, less corrosive, and environmentally responsible alternative to conventional HCl acidizing, offering well-defined kinetic parameters and validated injection strategies that support efficient wormhole development.
Co-optimization of Carbon Capture, Utilization, and Storage (CCUS) Project Using Iterative Latin Hypercube Sampling (ILHS) Dr. Eng. Utomo Pratama Iskandar; Masanori Kurihara
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.v48i2.1818

Abstract

Economic optimization of Carbon Capture, Utilization, and Storage (CCUS) projects, which simultaneously enhance oil recovery through CO₂-EOR while permanently storing CO₂, is critical to ensuring project viability amidst energy market volatility and operational uncertainties. This study develops and applies an Iterative Latin Hypercube Sampling (ILHS) algorithm, an adaptive, stratified sampling technique that accelerates convergence by iteratively re-weighting high-probability sub-regions, to determine the optimal CO₂ injection rate, using Net Present Value (NPV) as the unified economic criterion. The algorithm is coupled, via a FORTRAN driver, to the CMG-GEM compositional simulator and applied to the PUNQ-S3 field case; the economic model explicitly includes the CO₂ purchase price (US$60 t⁻¹), carbon credits (US$40 t⁻¹) and capital expenditure (CAPEX = US$40 million + US$12 000 × Qᵢ) to capture key financial drivers. Three economic scenarios combining oil prices of US$70 bbl⁻¹ and US$30 bbl⁻¹ with discount rates of 0 % and 10 % are evaluated to quantify NPV sensitivity. ILHS converged in ≤130 simulation runs (≈3 h CPU time), identifying scenario-specific optimum injection rates of 8.1–8.6 × 10³ m³ day⁻¹ that deliver NPVs ranging from US$1.9 billion to US$4.6 billion. By bridging the gap between technically oriented and financially oriented optimization, the proposed framework offers a scalable, computationally efficient approach for co-designing oil recovery and CO₂ storage under dynamic market conditions, thereby advancing field-scale CCUS decision making.

Page 57 of 62 | Total Record : 619

 55   56   57   58   59 

Filter by Year

1982 2026


Reset
Filter By Issues
All Issue 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