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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 12 Documents
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Search results for , issue "Vol 47 No 3 (2024)" : 12 Documents clear
Optimization of Crude Oil Transmission Process by Installing Electric Heat Tracing in Off-Plot Piping Oksil Venriza; Cut Reza Wahyuni
Scientific Contributions Oil and Gas Vol 47 No 3 (2024)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.47.3.1631

Abstract

Crude oil transmission is distributing crude oil from one plane to another. Problems that often occur in the crude oil transmission process are freezing or crystallization of paraffin when the temperature in the environment reaches the Pour Point Temperature. Usually, this can be overcome by injecting Pour Point Depressant into crude oil. However, using Pour Point Depressant is still ineffective if used continuously. This is because Pour Point Depressant can affect the quality of crude oil and increase environmental risks and if the transmission process is carried out on a large scale, it will also require large costs to meet these needs. Therefore, this research examined the application of constant wattage type Electric Heat Tracing as an alternative to Pour Point Depressant in the off-plot piping section, precisely in the PT ABC transmission pipe network. By carrying out transient simulations using OLGA version 2022.1.1 software, several scenarios for the most optimal Electric Teat Tracing installation in the crude oil transmission process were developed while minimizing the costs incurred. From the simulations carried out, it is known that the constant wattage type Electric Teat Tracing with a capacity of 3 x 100 kW can maintain the pipe temperature above the Pour Point Temperature value, namely 111ºF with 2 installation spots KP 1+700 to KP 3+200 and KP 5+800 to KP 7 +300. Apart from that, the use of Electric Heat Tracing is also more economical compared to Pour Point Depressant injection.
Refined Fluid Property Characterization in Data-Limited Reservoirs: Evaluating EOS and Black Oil Models for Optimized Simulation of The PSE Field in The Central Sumatra Basin Dike Fitriansyah Putra; Muhammad Zaidi Jaafar; Ayyi Husbani; Hasan Ali Ma’sum; Muhammad Fadhil
Scientific Contributions Oil and Gas Vol 47 No 3 (2024)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.47.3.1632

Abstract

The PSE Field, located in the Central Sumatra Basin, faces significant challenges due to outdated and incomplete fluid property data from Well X, where the last measurements were taken in 1992. This lack of comprehensive fluid data hampers accurate reservoir characterization, which is critical for optimizing production strategies. This study aims to bridge this gap by utilizing thermodynamic fluid characterization software (PVTp) to generate reliable fluid data, comparing two approaches: the Equation of State (EOS) model and the Black Oil model. Both models are evaluated based on key parameters such as saturation pressure (Psat), gas-oil ratio (GOR), (FVF), density, and viscosity. EOS model, grounded in thermodynamic principles, is compared to the empirically based Black Oil model to assess their predictive accuracy. The average absolute error percentage (AAE%) is used as a benchmark for performance. Results indicate that EOS model achieved an average AAE% of 1.2%, significantly lower than the 10.94% observed for the Black Oil model. Specifically, EOS model showed 0% error for Psat, 0.81% for relative volume, 3.7% for GOR, 1.4% for FVF, and 0.1% for density, while the Black Oil model demonstrated substantially higher errors, particularly for GOR (40.6%) and FVF (7.7%). This research highlights the limitations of the Black Oil model, especially in complex reservoirs where adjustments to laboratory data are necessary. In contrast, EOS model proves to be a more reliable alternative for accurate fluid characterization. The novelty of this study lies in its focus on the Central Sumatra Basin, where previous fluid property data was limited, making the validation of EOS model a valuable contribution to the field. The practical significance of this study extends beyond addressing the challenges of Well X, offering a framework that can be applied to other fields with similar data constraints. This research advocates for a transition from traditional Black Oil methods to more accurate EOS-based simulations, providing better decision-making tools for reservoir management and enabling greater efficiency and cost savings in future field operations
Petroleum Fiscal Regimes Attractiveness in Indonesia, Malaysia and Thailand: Application on Offshore Project Development Dwi Atty Mardiana; Pri Agung Rakhmanto; Shabrina Sri Riswati; Eleonora Sofilda; Saptianta Aribawa; Gabriela Martines
Scientific Contributions Oil and Gas Vol 47 No 3 (2024)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.47.3.1633

Abstract

Several factors are required to be considered in offshore and deepwater field development, including uncertainty in geological conditions, advanced technology, investment needed, fluctuating oil and gas prices, as well as fiscal regimes. Therefore, this study aimed to compare and evaluate the economic and fiscal regimes attractiveness ranks in Indonesia, Malaysia, and Thailand, applied to three cases of offshore oil and gas field development. The three offshore field cases included a new frontier gas field (Block A), a developed deep-water gas field (Block B), as well as a mature oil and gas field (Block C) with reserves of more than 100 mmboe and an investment range of 3 to 9 billion dollars. The discounted cash flow model was used to evaluate the contractor profitability, while government take, front loading index (FLI), and composite score (CS) were applied to rank the fiscal regime attractiveness. The result showed that profit split and ceiling of cost recovery affected fiscal attractiveness in government take. Front loading for contractor was observed at the early production phase from royalty and profit split. The fiscal attractiveness ranking generated a different order for each case, with Indonesia PSC CR being the most attractive to use in Block A due to the lowest FLI value. This PSC GS was the most attractive to use in Block B, providing the best economic results. Furthermore, concession scheme in Thailand was the most attractive to use in Block C, showing the best economic and the lowest FLI value. This showed that regardless of fiscal regime used in a country, parameter flexibility should accommodate uncertain conditions
Mapping Iron Oxide Distribution on the Ground Surface of the Tugu Barat Oil and Gas Field Using Landsat 8 OLI and Field Data Tri Muji Susantoro; Suliantara Suliantara; Ketut Wikantika; Asep Saepuloh; Agung Budi Harto; Herru Lastiadi Setiawan; Fitriani Agustin; Adis Jayati; Kurdianto Kurdianto; Sayidah Sulma; Sukristiyanti Sukristiyanti
Scientific Contributions Oil and Gas Vol 47 No 3 (2024)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.47.3.1634

Abstract

Previous studies have demonstrated that Landsat series data can be utilized to map rock change in arid and semi-arid environments. In this study, Landsat 8 Operational Land Imager (OLI) was used to map the presence of iron oxide (ferrous, ferric, and hematite) in the topsoil of the Tugu Barat Oil and Gas Field, Northwest Java Basin, Indonesia. The aim is to map the distribution of iron oxide and analyze it for detection of the presence of microseepage. The results show that the concentration of the mineral hematite indicates an anomaly, where the edge of the field is very low and tends to rise in the middle, but this condition is unclear, because of the presence of red soil containing high hematite in the north. Based on analysis indicates an anomaly, where the edge of the field is very low and tends to rise in the middle, but this condition is unclear, because of the presence of red soil containing high hematite in the north. Based on analysis of Landsat 8 OLI data, ferrous oxide concentrations show an increase at the edge of the field, especially in the southeast. However, this condition is less visible in the west because of the high vegetation density. The ferric oxide concentration shows the opposite pattern to the ferrous oxide concentration. These results are supported by the ferrous oxide index results from soil reflectance spectra recorded using Analytical Spectral Devices (ASD). Where the ferrous oxide concentration is low at the edge then tends to rise in the middle of the field. Meanwhile, the analysis of ferric oxide from the spectral reflectance of soil from ASD results does not show clear differences. The Normalized Iron Oxide Difference Index (NIODI) analysis shows the presence of small amounts of hematite and no geotite. The research results show evidence of microseepage indications at the edge of the field, especially at the southeastern edge. Iron oxide mapping has the potential to support oil and gas exploration through analysis of alteration processes which are thought to be the impact of micro-seepage.
Laboratory Study on The Use of Local Additive of Clam Shell in Water Based Mud Nur Suhascaryo; Farrel M Dhaffa
Scientific Contributions Oil and Gas Vol 47 No 3 (2024)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.47.3.1635

Abstract

The use of clam shells as additives in water-based mud has gained attention as a natural material in drilling fluids. This study tested the physical properties and rheology of water-based mud with varying amounts of clam shells. The density of the mud after adding clam shell additives was determined using a mud balance, and the rheology was tested using a viscometer. Filtration volume and mud cake thickness were also tested using an LPLT (Low-Pressure, Low-Temperature) filter press for 30 minutes. The pH measurement was performed from the filtrate volume. The results showed that adding varying amounts of clam shell additives increased the density by 8.7 ppg, 8.9 ppg, and 9 ppg, respectively. The filtration loss and mud cake produced were considered good, with filtration loss and mud cake being 13 mL and 1.6 mm, 12.2 mL and 1.4 mm, and 10.4 mL and 1.3 mm, respectively. Clam shell can be used as a fluid loss reducer because it can affect the viscosity value of the mud, resulting in a low filtration loss value. Proportional to filtration loss: if the filtrate comes out a little, the resulting mud cake is thinner.
Organic Thermal Maturity Based on Color Index of Halang Formation, Banyumas Basin, Central Java, Indonesia Eko Yulianto; Woro Sri Sukapti; Emma Yan Patriani; Ruly Setiawan
Scientific Contributions Oil and Gas Vol 47 No 3 (2024)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.47.3.1636

Abstract

We analyzed palinomorfs and foraminifera fossils on two samples taken from the claystone layer of the Halang Formation. We conducted this analysis to evaluate the thermal maturity of the sample as well as to determine its age and depositional environment. Both samples contained poor amounts of pollen, spores, dinoflagellate, and diatom, but they contained abundant foraminifera. In these two samples, pollens, spores, dinoflagellates, and diatom were primarily black or blackish, gray to dark brown—the color of the foraminifera tests was also dark, principally gray. No index fossils were found in the pollen assemblages. However, the presence of Spinizonocolpites echinatus, Monoporites annulatus, and Pinuspollenites type indicates the samples are not older than the Paleocene. The foraminifera assemblage in both samples suggests that the age of the samples is Early Pliocene. The lack of pollen grains and spores and the abundance of foraminifera indicate that the depositional environment of the two samples was offshore. Melonis pompiliodes, Cibicidoides wuellerstorfi, and Bulimina affinis suggest these samples were deposited in a lower slope/lower bathyal environment. The color of the pollen, spore, dinoflagellate, diatom, and foraminifera fossils indicates the degree of thermal maturity of the samples have reached a mature or dry gas (barren) level. The high level of thermal maturity of the relatively young Halang Formation is supposed to be related to the presence of post-depositional volcanic activities
The Characteristics of Sapindus Rarak Green Surfactant Injection to Enhance Oil Recovery Fajri Maulida; Andrian Sutiadi; Muhammad Taufiq Fathaddin; Dwi Atty Mardiana; Rini Setiati; Pri Agung Rakhmanto; Arinda Ristawati; Sonny Irawan; Muhammad Dzaki Arkaan
Scientific Contributions Oil and Gas Vol 47 No 3 (2024)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.47.3.1637

Abstract

Green surfactants are surfactants derived from natural materials such as plants, animals, and microorganisms. Sapindus Rarak contains saponins, one type of natural surfactant that is widely known. This study evaluated the effectiveness of surfactant injection using Sapindus Rarak. This study involved laboratory experiments and analytical design with variations in salinity of 6,000 and 10,000 ppm and six variations of Sapindus Rarak surfactant concentrations from 0.5% to 3.0% using Berea sandstone cores at a temperature of 60℃. Compatibility testing based on water stability and phase behavior tests showed that only three samples of surfactant solutions, namely Sapindus Rarak surfactant concentration of 2.0% at a salinity of 6,000 ppm and surfactant concentrations of 2.5% and 3.0% at a salinity of 10,000 ppm, were homogeneous. The two best samples were selected based on the largest middle phase emulsion volume for each salinity, namely Sapindus Rarak surfactant concentration of 2.0% at a salinity of 6,000 ppm and surfactant concentration of 2.5% at 10,000 ppm. The wettability test of the two selected samples showed strongly water wet properties with contact angles of 26.86° and 23.28°, respectively. The results of the interfacial tension (IFT) test for the two selected samples were 2.15 x 10-1 and 1.71 x 10-1 mN/m, respectively. Based on the thermal stability test, the IFT values after 12 weeks for the two selected samples were smaller, namely 5.81 x 10-2 and 1.51 x 10-1 mN/m, respectively. Oil recovery factor (RF) for water injection showed that the use of 6,000 ppm salinity was better than 10,000 ppm salinity, which were 35.35% and 25.00%, respectively, while for surfactant flooding, the RF for the two selected Sapindus Rarak solution samples were 14.14% and 23.49%, respectively. This study offers a great opportunity to include green alternatives to improve conventional chemical-enhanced oil recovery techniques.
Stability Analysis of Jet Fuel-Bioethanol Blends: an Experimental Approach Chantika Putri Rahmawati; Shafa Putri Kamasinta; Kemal Putri Ginanjar; Lies Putri Aisyah; Riesta Putri Anggarani; Cahyo Setyo Wibowo; Nur Allif Fathurrahman
Scientific Contributions Oil and Gas Vol 47 No 3 (2024)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.47.3.1638

Abstract

Incorporating bioethanol into jet fuel blends has garnered increasing attention as a viable strategy to reduce dependence on fossil fuels and address environmental issues. This study investigates the influence of different amounts of bioethanol on the stability properties of jet fuel blends. Bioethanol addition to jet fuel causes a steady increase in its freezing point. The alteration has been attributed to the destabilizing effect caused by polar hydrogen bonds in bioethanol on the intermolecular forces. Oxidation stability analysis demonstrates a clear correlation between ethanol content and a swift decrease in pressure resistance. Although pure jet fuel is highly stable, mixes that include bioethanol show much lower stability. This decline highlights the reduced impact of bioethanol on fuel stability and oxidation processes. The simultaneous occurrence of gum formation emphasizes the need for careful formulation strategies to prevent stability problems and system complexities. Moreover, the complex influence of bioethanol on the temperature, stability, and oxidation properties of jet fuel blends highlights the importance of using accurate formulation methodologies to improve aviation fuels.
Optimization of Process Design and Operating Parameters of H2S Removal Unit to Reduce Lean Amine Inlet Temperature of Amine Contactor at Upstream Oil and Gas Subsidiary SI Budi Sulistyo Nugroho; Restu Ramadhani Pratama Putra; Aprilia Indah Mandaka; Genoveva Lestari Kulaleen; Adhi Kurniawan
Scientific Contributions Oil and Gas Vol 47 No 3 (2024)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.47.3.1644

Abstract

Upstream Oil and Gas Subsidiary SI is a natural gas processing company that operates an H2S removal unit to convert natural gas rich in CO2 and H2S into sweet gas. The main problem of this unit is the high temperature of lean amine entering the Amine Contactor. The purpose of this study is to determine the factors of high lean amine temperatures, evaluate the lean amine cooler, amine regenerator overhead cooler, and plate exchanger performance, and determine the optimal process design configuration and operating parameters. The method used is the simulation of the H2S removal unit with Aspen HYSYS, followed by a comparative analysis between simulation data and equipment design data. The independent variables of this study include Reboiler duty, reflux ratio, and heat transfer area in the Plate Exchanger, with the main dependent variable being lean amine temperature. The results showed that the high lean amine temperature was caused by a decrease in the performance of the Lean Amine cooler and amine regenerator overhead cooler, as seen from the UA and LMTD values of the simulation results which were smaller than the design. In contrast, the Plate Exchanger still functions well with a UA value greater than the design. Optimization was carried out by adjusting the process design and operating parameters of the H2S removal unit. The optimized design involves bypass reflux from the regenerator to the rich amine stream entering the rich/lean amine exchanger and increasing the heat transfer surface area of the plate exchanger to 62.17 m². The influential operating parameters are reboiler duty, liquid flow rate to the mixer, and plate exchanger heat transfer surface area. Optimal operating conditions were achieved at a Reboiler duty of 1,642 kW, a liquid flow rate of 1.4 m³/h, the reflux to Mixer ratio is 100%, and a heat transfer surface area of 62.17 m². In addition, it can be concluded that the optimization of process design and operating parameters successfully reduced the lean amine inlet temperature of the Amine Contactor.
Risk-Based Inspection Analysis of Api 581 Pressure Safety Valve & Stripper Acid Gas Removal Unit at PT XY Andre Teurupun; Budi Sulistyo Nugroho; Arif Nurrahmana; Kevin Alfarizi
Scientific Contributions Oil and Gas Vol 47 No 3 (2024)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.47.3.1645

Abstract

The process involving the stripper equipment in the Amine Gas Recovery Unit (AGRU), which separates rich amine, is a crucial part of the natural gas purification system. The use of a pressure safety valve is essential to maintaining operational safety. Long-term mechanical damage can lead to equipment failures such as leaks, fires, and poisoning, negatively impacting production efficiency and personnel safety. Risk-Based Inspection (RBI) is a method for inspecting, preventing, and controlling incident risks through mathematical inspections related to Probability of Failure (POF) Analysis, Consequence of Failure (COF) Analysis, and Risk Evaluation, with the output being an inspection schedule. The study results include the probability of overpressure under fire scenarios (2,82504 x 10-08), overfilling (7,06261 x 10-07), failure to open (1,49 x 10-05), and leak (3,64 x 10-02), with the consequence category averaging E, indicating that the Matrik Risiko from these scenarios is high risk. The inspection schedule is set every four years because the remaining life is half the project duration, warranting inspections at a maximum interval of 10 years. This four-year interval is based on the regulations from the Ministry of Energy and Mineral Resources No. 38 of 2017. Operational conditions, such as frequent foaming in the AGRU influence it.

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