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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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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.
The Application of Machine Learning (DT-Chan-Performance) in Determining Idle Well Reactivation Candidates at PT. Pertamina EP Regional 4 Zone 11 Cepu Field Sayoga Heru Prayitno; Boni Swadesi; Hariyadi Hariyadi; Damar Nandi Wardhana; Herlina Jayadianti; Geovanny Branchiny Imasuly; Indah Widiyaningsih; Ndaru Cahyaningtyas
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.v48i2.1657

Abstract

Indonesia faces a significant challenge in achieving its goal of oil production 1 million barrels of oil per day by 2030, particularly as it relies on old fields or mature fields (brownfields) to extract remaining hydrocarbons. One of the strategies involves reactivating of idle wells in Cepu field, managed by PT. Pertamina EP Regional 4 zone 11. This study focuses on identifying suitable candidates for reactivation through combination of research, innovation and production-focus analysis. The process begins with problem definition, aiming to understand the factors influencing idle wells and review recent advancements in reactivation prediction. Data were collected from both primary and secondary sources covering period 2018-2023. The next stage is implementing Machine Learning (ML), specifically Decision Tree (DT) model, to overcome problems related to data accuracy and complexity. A web application was developed to support decision-makers in selecting wells with high reactivation potential which can provide the best solution of increasing oil recovery. The research results show a high success rate on Accuracy Under Curve and Receiver Operating Curve score of 0.99, indication strong predictive capability. Using entropy-based analysis, two potential wells were identified for reactivation for improvement. These wells were further evaluated using Chan Diagnostic and Production Performance analysis.
Case Study of Heterogeneity Index’s Effect on The Successful Workover Based on The Apriori Algorithm Fahrizal Maulana; Amega Yasutra; Zuher Syihab
Scientific Contributions Oil and Gas Vol 48 No 1 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i1.1658

Abstract

The Indonesian government has set a target to reduce the consumption-production gap by increasing national oil production to 1 million barrels of oil per day (BOPD) and 12 billion standard cubic feet per day (BSCFD) of gas by 2030. Amongst several approaches, the optimization of mature fields offers a significant opportunity for quick production gains. However, analyzing these fields presents challenges due to the complexity, incompleteness, and poor quality of historical data. Heterogeneity Index (HI) is one of the methods that quickly measure well performance. This method is as simple as measuring a certain well as compared to the average performance at certain time. The parameter being used might vary, but production data is the most frequent one given its availability. Despite simple and practical, skepticism on the reliability of this method is still questionable. This work revisited "XYZ" field consisting of XX wells producing more than 32 years with hundreds of workovers. We brought evidences and insights on how HI leads to the workover success from. Apriori algorithm, an Association Rule Mining (ARM) technique, is employed to uncover rules from the noisy data. The results show that workover on wells with low HI mostly leads to success. Another insight is that of scale treatment is the most influential one in determining the success. Given these findings, the flow efficiency is the issue that should be well treated and HI is representative enough to measure this one.
Optimization of CO2 Injection Through Cyclic Huff and Puff to Improve Oil Recovery Dedi Kristanto; Hariyadi Hariyadi; Eko Widi Pramudyohadi; Aditya Kurniawan; Unggul Setiadi Nursidik; Dewi Asmorowati; Indah Widiyaningsih; Ndaru Cahyaningtyas
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.v48i2.1659

Abstract

One of the Enhanced Oil Recovery (EOR) strategies in the petroleum industry is CO2 injection using the huff and puff method. The method is performed on one well that acts as an injection and a production well. The method works by injecting a certain volume of carbon dioxide (CO2) gas into the reservoir and then closing the well for a period of time. This injection cycle can take place over several cycles. Production can be carried out after one or more cycles according to the design. In this study, CO2 injection optimization with the huff and puff method is carried out with reservoir simulation (GEM-CMG) by taking data from one of the oil and gas wells in Indonesia, with carbonate rock characteristics that are water wet. The simulation work steps include inputting data (fluid, rock properties, and production), initialization, history matching, and CO2 injection optimization with the huff and puff method. The optimization scenarios include optimization of injection pressure and number of cycles. The injection pressure scenario uses a range of 500 - 3000 psi, based on the simulation results obtained that the injection pressure of 500 psi produces the highest recovery factor (RF) of 22.2%. Then, the cyclic scenario was carried out at the optimum injection pressure (500 psi) with the number of cycles 2 - 6 cycles. From the simulation results, it is found that the number of cycles for this carbonate reservoir condition does not have a significant effect, as evidenced by the RF values ranging from 22.1 - 22.3%.
A Simulation Study on Polymer Mobility Design Strategies and Their Impact on Oil Recovery Efficiency and Displacement Mechanisms Ndaru Cahyaningtyas; Boni Swadesi; Mahruri Sanmurjana; Muhammad Rizky Rahmadsyah Lubis; Dedi Kristanto; Indah Widiyaningsih
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.v48i2.1661

Abstract

Polymer flooding is an effective enhanced oil recovery (EOR) technique, particularly when waterflooding alone proves insufficient in improving oil recovery. It is prominent to acquaint the principle of mobility control to understand the ability of polymer to overcome the oil displacement inefficiency of waterflooding, a requirement for a better sweep efficiency. This paper presents a comparative study of mobility control methods as critical parameters for polymer design. This paper investigates a simulation study of different simulation model to optimize polymer mobility design by comparing various mobility control methods. In this study, a compositional simulation model was built based on previous laboratory experiments validated by matching simulation results. Furthermore, to visualize the polymer displacement process, this study performs 1D, 2D, and 3D simulation models. The results indicates that polymer mobility design could affect the upstream viscosity, leading to high sweep efficiency and higher oil recovery. The study also suggests that the unit mobility ratio from the existing concept of conventional mobility control has invalid criteria to distinguish favourable and unfavourable conditions. The comparison with various mobility design methods reveals differences in recovery factors, influenced by some factors such as underlying assumptions and the specific conditions favoured by each method.
METHYL ESTER SULFONATE: AN ANIONIC BIOSURFACTANT FOR ENHANCED OIL RECOVERY IN HARSH CONDITION Muhamad Raihan Al Fikri; Veni Dwi Amelia Putri; Indra Gunawan; Novia Rita; Muslim Abdurrahman
Scientific Contributions Oil and Gas Vol 48 No 1 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i1.1673

Abstract

Chemical enhanced oil recovery (EOR) is a tertiary phase method used to extract significant amounts of residual crude oil that primary and secondary recovery phases cannot recover. Surfactants are crucial in chemical EOR for their impact on rock surfaces and water-oil interfaces. Optimizing these formulations under reservoir conditions is essential before their use in oil recovery. However, screening is challenging due to the variety of surfactants and their sensitivity to reservoir conditions and rock types. This study introduces methyl ester sulfonate (MES), an anionic bio-surfactant, to improve the oil recovery factor (RF). Spontaneous imbibition (SI) experiments measured MES's ability to enhance oil RF in sandstone reservoir rocks under high salinity and temperature. The results showed MES's excellent performance even under high salinity conditions. On day 14, MES samples under 30 kppm salinity and 80°C with concentrations of 0.5 mM, 2 mM, and 3 mM had RF values of 12%, 18%, and 26%, respectively. Under 40 kppm salinity and 80°C, the RF values were 17%, 19%, and 27%, respectively. MES enhances oil recovery efficiency and preserves environmental health due to its biodegradability, making it a safer alternative to traditional surfactants. Its use can significantly improve chemical EOR processes under challenging conditions. As a novelty, this study also explains the mechanism of MES in changing the wettability of sandstone to the intermolecular scale.

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