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91	Mining Engineering and metallurgy	ABS-76
The Removal of Fe and Ca Elements from MnSO4 Precursor by CaCO3 Precipitation Method L Andriyah, FE Yunita, E Sulistiyono , LH Lalasari , F Firdiyono , A Suharyanto, T Arini, NC Natasha, AF Hakim, AP Kristanto, AH Yuwono Research Center for Metallurgy, National Research and Innovation Agency, South Tangerang, Indonesia 15314 Abstract Battery is one of the renewable energy sources that serves as a solution to reduce CO2 gas emissions. Lately, the utilization of manganese as a raw material for lithium battery electrodes has been developed. Manganese electrode battery raw materials can be synthesized from manganese leachate solution with sulfuric acid to produce manganese sulfate (MnSO4) products. However, the manganese leaching process with sulfuric acid produces impurities, two of which are iron and calcium. When used as battery electrodes, these impurities reduce battery capacity efficiency. This study aims to reduce impurities in the resulting MnSO4 leachate solution, especially iron and calcium impurities. The method used to precipitate iron is titration using 25% w/w CaCO3, while precipitating impurities is done by chemical precipitation using NH4F. The resulting solution is characterized using ICP OES, while the precipitate is characterized using XRD, XRF, and SEM EDS. The results show that iron can be precipitated up to 100% at pH 4, a temperature of 90 C, and a duration of 3 hours. For calcium ion precipitation, it can be achieved up to 99.6% with the addition of 3.5 grams of NH4F at a heating temperature of 50 C and a duration of 30 minutes. However, with these variables, a significant amount of manganese is also precipitated. The iron compound obtained in the iron impurity precipitate is goethite, while the calcium compound obtained in the calcium impurity precipitate is calcium fluoride. Keywords: Lithium battery, Manganese sulfate, sulfuric acid leaching, alkaline precipitation Share Link | Plain Format | Corresponding Author (LIA ANDRIYAH)

92	Mining Engineering and metallurgy	ABS-90
Critical Review of Bioreagent Performance for Desulfurization in Coal Flotation Edy Nursanto (a*), Shofa Rijalul Haq (a), Aldin Ardian (a), Imam Prasetyo (b), Rofa Dzulfikri Bulopa (a) a) Mining Engineering Department, Universitas Pembangunan Nasional Veteran Yogyakarta Jl. Padjajaran Jl. Ring Road Utara 104, Sleman 55283, Indonesia *edynursanto[at]upnyk.ac.id b) Metallurgical Engineering Department, Universitas Pembangunan Nasional Veteran Yogyakarta Jl. Padjajaran Jl. Ring Road Utara 104, Sleman 55283, Indonesia Abstract The efficiency of separation in flotation processes heavily relies on the reagents employed. Increasing environmental concerns have recently driven the research and development efforts towards the utilization of green reagents. Biotechnological and bioprocess approaches are being investigated as potential alternatives to conventional chemical and petroleum-based reagents. This article critically reviews the performance of green reagents, specifically biosurfactants, in the coal flotation process. It emphasizes the processing of high-sulfur coal found in Indonesia in an environmentally friendly manner to meet the rising global demand. This review aims to serve as a reference for further research, addressing current challenges, and optimizing the application of biosurfactants in coal flotation processes while adhering to principles of environmental sustainability. Keywords: Coal- Flotation- Bioreagent- Desulphurization Share Link | Plain Format | Corresponding Author (Imam Prasetyo)

93	Mining Engineering and metallurgy	ABS-99
Slope Failure Analysis Utilizing Radar Data on Wire Mesh Covered Slopes in an Open Pit Iron Ore Mine Joey Andreas Banuarea (a*), Balqis Pertiwi (b) a) Geotechnical Support Service, PT GroundProbe Indonesia, Balikpapan 76114, Indonesia *joey.banuarea[at]groundprobe.com b) School of Civil and Environmental Engineering, The University of New South Wales, NSW 2032, Australia Abstract Slope stability holds a pivotal role in open pit mining operations, as failures and rockfalls can lead to significant safety hazards, operational disruptions, and economic losses, highlighting the necessity for a sophisticated slope monitoring instrument, the Slope Stability Radar (SSR). The SSR earns broad recognition as an essential tool for managing high-risk slopes due to its ability to track deformation near real-time in sub-millimeter precision using the interferometry method. Wire mesh is often deployed on unstable slopes to mitigate the risk of rockfalls and slope failure by providing structural support and containment of loose debris. While enhancing the slope stability, its presence introduces complexities in radar data interpretation due to signal interference and the effect of steel expansion. Understanding how radar data behaves when collected from slopes covered by wire mesh is essential for optimizing monitoring strategies and ensuring accurate slope stability assessments. This study uses slope monitoring data collected by GroundProbe Slope Stability Radar-FX (SSR-FX) in case of failure occurred in an iron ore mine. The installation of wire mesh on the surface of mine walls impacts the slope stability radar data, resulting in specific repetitive patterns that follow daily cycles, referred to as diurnal deformation trends. At a lower rate of slope movement, these diurnal trends are prominent on deformation graphs. Consequently, determining slope behavior under these circumstances can be achieved through long-term analysis, focusing on the consistency of peak and trough. As the rate of slope movement increases, these patterns gradually diminish, and the trend will be increasingly determined by the real magnitude of deformation. In the case study, the failure exhibits the following behaviors: diurnal pattern (stable), linear, progressive, failure, ambiguity (rapid movement), and regressive deformation trend. Keywords: Slope Stability Radar- Wire Mesh- Slope Failure Characteristic- Slope Monitoring- Open Pit Mine Share Link | Plain Format | Corresponding Author (Joey Andreas Banuarea)

94	Mining Engineering and metallurgy	ABS-114
Thermal Upgrading of A Limonite Ore from Tinanggea Area, South Konawe Regency of Southeast Sulawesi Using Coal as Reductant Sufriadin (1*), Purwanto (1), Dandy Adrianus (1), Muhammad Zahran Mubarok (1), Akmal Saputno (2), Akane Ito (3) 1) Department of Mining Engineering, Faculty of Engineering, Hasanuddin University, Jl. Poros Malino KM. 6, Bontomarannu, Gowa 92171 Sulawesi Selatan, Indonesia. *sufri.as[at]unhas.ac.id 2) Institute of Geological Science, Jagiellonian University, Golebia Street 24, 31-007 Krakow, Poland 3) Department of Earth Resources Engineering, Kyushu University, 744 Motooka, Nishi-ku Fukuoka, Japan 819-0395 Abstract A limonite ore sample from Tinanggea Area of Southeast Sulawesi has been investigated via reduction roasting method using coal as reducing agent. The aims of this study were to find out the mineralogical and chemical characteristics of the ore, to analyse the effect of heating temperatures and dosages of reductant for the mineral transformation and the upgrading of nickel. Mineralogical and chemical characterization of the sample was performed by optical microscopy, XRD, and XRF methods respectively. Reduction roasting of limonite was done at the different temperatures (750, 850, 950, and 1050) degree C and reducing agent (5, 10, and 15) % with heating duration of 60 minutes. The results of microscopic and XRD analysis showed that limonite ore contains goethite, talc, quartz, lizardite and magnetite. Chemical composition of limonite ore determined using XRF was dominated by Fe2O3 (56.74%) followed by SiO2 (19.70%), Al2O3 (6.43%), MgO (4.05%), Cr2O3 (1.59%), MnO (0.67%), and Ni (1.43%). Roasting of limonite at 750 to 850 degree C has led to the transformation of goethite into hematite, and maghemite. Further increase of temperature at 950 degree C cause the formation of magnetite, whereas talc and lizardite were altered to forsterite. At the temperature of 1050 degree celcius, the minerals such as fayalite, spinel, and tridymite were formed. The result of reduction roasting experiment indicated that Ni could be upgraded up to 1.90% from the initial value in the ore of 1.43%, which was achieved at the roasting temperature of 1050 degree C with an addition of 15% coal reductant. Keywords: limonite- reduction roasting- reductant- goethite- magnetite Share Link | Plain Format | Corresponding Author (Sufriadin Sufriadin)

95	Mining Engineering and metallurgy	ABS-117
Characterizing the Leaching Behavior of Red Mud at Different pH Levels Riskaviana Kurniawati, Wiwik Dahani, Subandrio Subandrio, Christin Palit, and Kisal Albrian Gheraldy S Department of Mining Engineering, Faculty of Earth Technology and Energy, Universitas Trisakti Abstract Red mud is classified as hazardous waste due to its high alkalinity and presence of radioactive materials. The purpose of this study is to investigate the leaching properties of major metals and rare earth elements in red mud at pH levels of 2, 7, and 13. We performed XRD, XRF, and SEM analyses to determine the effect of pH on metal leaching in red mud. The findings revealed that the pH of the solution had a substantial effect on the concentration of dissolved metals. Metal dissolution increases dramatically at an acidic pH (pH 2), but metal concentration drops quickly at a neutral pH (pH 7). At alkaline pH (pH 13), Al dissolves significantly, whereas Fe remains reasonably stable. These findings indicate that the red mud processing industry can utilize pH modulation to enhance the leaching effectiveness of specific metals, a crucial step towards developing more efficient and environmentally friendly purification procedures. Keywords: leaching, pH, red mud Share Link | Plain Format | Corresponding Author (Riskaviana Kurniawati)

96	Palaeontology, stratigraphy, quarter geology quarter	ABS-77
CRITICAL ELEMENT SILICA SAND POTENTIAL AND DEPOSITIONAL ENVIRONMENT FOR OPTIMIZING NATURAL RESOURCES SAMBOJA AREA, KUTAI KARTANEGARA, WEST BORNEO Faiz Akbar Prihutama [1], Hedi Pangestiadi [2], Nico Andreas Nainggolan [2], Ari Soeldjana [2] [1]Magister Geology of Hasanuddin Unversity [2]PT Riset Sumberdaya Alam Utama Abstract Quartz sand is an industrial mineral that is useful in various industries such as the ceramic industry, paint industry, cement industry, glass industry, refractory brick industry, foundry industry, and as a raw material for making solar panels. The administrative research area is in Samboja District, Kutai Kartanegara Regency, East Kalimantan. Regionally stratigraphically, the research area is part of the Kutai Basin and is included in the Kampungbaru Formation and Alluvial Deposits. According to the regional geological map of the Samarinda sheet, the Kampungbaru formation consists of quartz sandstone with intercalations of clay, shale- silt and lignite, which are generally soft and easily crushed (S. Supriatna et al., 1995). The Kampungbaru Formation is an interesting research object because it contains quartz sand deposits which are quite widely distributed. The aim of this research is to determine the depositional environment, seek optimization of recovery and seek optimization of silica content in quartz sand in the Kampungbaru Formation. The depositional environment of the research area is included in the transitional lower delta plain (Horne, 1978) with sub-environments in the form of channels, levees and interdistributary bays. Sampling uses the test pit method, which is a sampling method by making a hole dug to a certain depth. Then samples are taken in two ways, namely separate samples and composite samples. The samples that have been taken are then carried out sample preparation. The sample preparation stages include washing the sample with water, drying it in an oven, washing the sample with water and a magnet, drying it in an oven, then splitting the sample into four parts. Quartz sand recovery was obtained from sizing results, where the most samples collected were in mesh 120 (0.125 mm), meaning that the dominant quartz sand recovery was medium sand grain size. Based on the results of chemical analysis, samples without washing had SiO2 levels of 93.5% - 99.4% and Fe2O3 levels of 390 - 2360 ppm. The washed samples had a SiO2 content range of 99.32% - 99.7% and Fe2O3 content of 170 - 510 ppm. Then the samples that were washed with a magnet had a SiO2 content range of 99.59% - 99.7% and Fe2O3 content of 210 - 320 ppm. Keywords: quartz sand, depositional environment, recovery, grade Share Link | Plain Format | Corresponding Author (Faiz Akbar Prihutama)

97	Palaeontology, stratigraphy, quarter geology quarter	ABS-84
Analysis of Depositional Environment and Geochemical Characteristics of Source Rocks in Mallawa Formation, South Sulawesi Province Aufariq Asaria Cifa, Yarra Sutadiwiria, Rendy, Ariq Haykal Yusuf, Amalia Yunita Puteri, Rahmat Ramadana, Miftahul Gamara Geological Engineering Department, Faculty of Earth Technology and Energy, Universitas Trisakti, Jln. Kyai Tapa No. 1, Jakarta 11440, Indonesia Abstract The research conducted on the outcrops of Shale and Coal in the Mallawa Formation in South Sulawesi aims to understand the geochemical characteristics of the source rocks and the geological features to determine their depositional environment. Source rocks are sedimentary rocks where hydrocarbons accumulate, typically fine-grained sedimentary rocks. The objective of this study is to analyze the maturity and potential of the parent rocks in the Mallawa Formation, South Sulawesi. The methodology involves field sampling of rock specimens for laboratory analysis, including Total Organic Carbon (TOC), Rock Eval Pyrolysis, %Ro (% Reflectance), GC-GCMS (Gas Chromatography - Gas Chromatography Mass Spectrometry), and fossil analysis. By employing these methods, the research aims to provide insights into the hydrocarbon potential and depositional environment of the source rocks within the Mallawa Formation in South Sulawesi. The findings of this study could serve as a basis for further exploration of natural resources in the region. Keywords: Source Rock, Depositional Environtment Share Link | Plain Format | Corresponding Author (Aufariq Asaria Cifa)

98	Reservoir engineering	ABS-8
Variation of Palm Oil MES Surfactant Concentrations Using CMG Software Firdha Meidya Buana (a), Muhammad Taufiq Fathaddin (a), Prayang Sunny Yulia (a)* a) Petroleum Engineering Department, Faculty of Earth and Energy Technology, Universitas Trisakti, Jakarta, Indonesia *prayang[at]trisakti.ac.id Abstract This study utilizes computer simulation to explore the potential utilization of Methyl Ester Sulfonate (MES) surfactants derived from palm oil in enhancing oil stability in well XY. The focus lies in identifying the most optimal structural variations of MES. The findings provide an in-depth understanding of the potential of MES surfactants in improving the recovery factor and the steps involved in using CMG STAR simulation. Through the computer simulation approach, this research enables a more detailed exploration and accurate modeling compared to experimental methods. It is hoped that these findings can serve as a foundation for the development of more efficient and sustainable oil industry practices, as well as stimulate innovation within the sector. Keywords: Methyl Ester Sulfonate, Recovery Factor, CMG STAR Share Link | Plain Format | Corresponding Author (Prayang Sunny Yulia)

99	Reservoir engineering	ABS-15
WEB APPLICATION BASED ON COMPUTER VISION IN DETECTING CHAN WATER CONTROL DIAGNOSTIC PLOT Geovanny Branchiny Imasuly, Wilma Latuny, Robert Hutagalung, and Sri Hikmat Yesicawati Mayaut Department of Petroleum Engineering, Faculty of Engineering, Pattimura University, Jl. Ir. M. Putuhena, Poka, Kec. Tlk. Ambon, Kota Ambon, Maluku, 97233 Abstract Chan water control diagnostic plots introduced by K. S. Chan were used to determine the mechanism of excessive water production, as well as observe the log plots of WOR and WOR^ vs. time to find out problems with water behaviour in the well which can occur with a normal displacement of oil by water, multilayer channelling, and rapid channelling. In identifying water behaviour problems in wells, the root of the problem is the inconsistency of human judgment and the absence of criteria in appropriate classification patterns, which are the key to identifying water behaviour problems in wells. While relying on professional human judgment is common, there is significant value in seeking consistency, and it may be difficult to differentiate clearly. This shows that there is an opportunity to find out the problem of water behaviour in the well if it is carried out correctly with the application of Artificial Intelligence (AI) to learn patterns from data sets and excel at predicting outcomes, in contrast to conventional software engineering, where rules are defined more explicitly. This paper developed a Web application with models of computer vision that can overcome problems of data accuracy and complexity, as well as create efficient and accurate visualizations and classification patterns, which can help take proactive monitoring decisions that require identifying signature patterns in Chan plots, so it can usefully automatically classify whether a well shows a particular Chan plot signature, to flag it for review in a broader petroleum engineering decision framework. Keywords: : Chan water control diagnostic, Artificial Intelligence, Web Application Share Link | Plain Format | Corresponding Author (Geovanny Branchiny Imasuly)

100	Reservoir engineering	ABS-23
C02 ADSORPTION ISOTHERM OF LAKAT COAL RELATED TO THEIR CHEMICAL AND ORGANIC COMPOSITION Muh. Rizki Ramdhani (a,b), Yan Rizal (a), Sigit Arso Wibisono (b), Muh. Arief Pinandita (b), Rizki Satria Rachman (b) (a) Geological Engineering Department, Faculty of Earth Science and Technology, Institut Teknologi Bandung (b) Center for Mineral, Coal, and Geothermal Resources, Geological Agency, Ministry of Energy and Mineral Resources Abstract Deep seated coal seams are one of the attractive options for geological CO2 sequestration. These seams are particularly interesting due to their ability in adsorb gas especially CO2. Indonesia has great potential in deep seated coal as in Lakat Formation which located in Central Sumatera Basin. The objective of this study is to determine the CO2 adsorption capacity in Lakat Coal related to their chemical and organic composition. In this context, several analyses were conducted in three Lakat coal samples such as proximate, ultimate, petrography, and adsorption isotherm analyses. Moisture and Ash content are varied from 13,48% to 19,66% and 5,27% to 25,74% in as received basis respectively. Calorific value of these samples ranging from 5.246 to 6.885 cal/gr. Vitrinite reflectance vary from 0,54 to 0,57. The maceral composition is dominated by vitrinite (76,8% to 86,2%). The inertinite and liptinite content is 5,6 to 6,2% and 1,6 to 11,4% respectively. According to the ASTM, the rank of these coals is classified from Subbituminous A to High Volatile C Bituminous. The adsorption isotherm analyses were performed at 33 degrees celcius and absolute pressure from 0,24 MPa to 6,78 MPa. The CO2 sorption capacity vary from 2,1 to 25,98 cc/gr in as received basis and 3,16 to 31,56 cc/gr in dry ash free basis. The CO2 sorption capacity in this study is affected by moisture content, ash content, and maceral composition. Ash and inertinite content show negative relationship with CO2 sorption capacity, while fixed carbon and vitrinite content present positive relationship. Moisture content exhibit weak positive relationship with CO2 sorption capacity. These analyses will support CCS/CCUS study in deep seated coal seams by providing the information of CO2 maximum holding capacity in Lakat coal and their relationship to its chemical and organic composition. Keywords: CO2 adsorption capacity, Lakat Coal, Organic Composition, Chemical Composition Share Link | Plain Format | Corresponding Author (Muhammad Rizki Ramdhani)

101	Reservoir engineering	ABS-28
Surfactant Concentration Optimization in Alkaline Surfactant Polymer Flooding to Maximize Recovery Factor Using Reservoir Simulation Method Rayhan Irvan1,a), M. Taufiq Fathaddin1,b), R. Hari Karyadi Oetomo1,c) and Shabrina Sri Riswati1,d) Department of Earth and Energy Technology, Universitas Trisakti, Jakarta, Indonesia Abstract Enhanced Oil Recovery (EOR) is the method to increase the recovery factor of oil, one of them is by injecting chemicals into the reservoir, in this case surfactant. In this research, the data was taken from laboratory experiment, and then reservoir simulation was performed to match the oil recovery factor from the experiment. The purpose of simulating laboratory experiment is to find out the surfactant concentration which yields to optimum oil recovery factor. The research method involves varying the surfactant concentration- 0%, 0.5%, 0.15%, 0.25%, 0.35%, 0.45%. Concentration of 0% surfactant, yields to recovery factor of 18.96%. Concentration of 0.5% surfactant, yields to recovery factor of 73.794%. Concentration of 0.15% surfactant, yields to recovery factor of 73.786%. Concentration of 0.25% surfactant, yields to recovery factor of 73.77%. Concentration of 0.35% surfactant, yields to recovery factor of 73.77%. Concentration of 0.45% surfactant, yields to recovery factor of 73.77%. The amount of surfactant concentration to obtain the optimal recovery factor value is 0.5% with a recovery factor value of 73.794%. Keywords: EOR, Chemical Injection, Surfactant Injection, Recovery Factor Share Link | Plain Format | Corresponding Author (Rayhan Irvan)

102	Reservoir engineering	ABS-43
Analysis of Permeability and Porosity Relationship with Power Law and Exponential Equation Approach Havidh Pramadika1, a), Mulia Ginting,1,b) R. Hari Karyadi Oetomo,1,c) Andry Prima1,d), Rizka Chairil Arfantia1,e) 1Petroleum Engineering, Universitas Trisakti, Jl. Kyai Tapa No.1 Jakarta, Indonesia Abstract Porosity- a measure of the ability of hydrocarbon reservoir rock to hold reservoir fluid- and permeability- a measure of the ability of hydrocarbon reservoir rock to transmit hydrocarbon fluid- are very important parameters in the producing hydrocarbon fluid at optimal production, and in the recovery of hydrocarbon throughout the life of the hydrocarbon field. It is important to have a relationship between permeability and porosity determined from core sample. This relationship will be utilized to estimate the permeability from well logging measurement. There are 23 core samples measurements that being analyzed for permeability and porosity correlation. The approaches to calculate permeability value from porosity are using Power Law Equation approach and Exponential Equation approach. The Power Law Equation needs to obtained 7 constants. The calculated permeability as compared to permeability data from 23 measurement by using Power Law Equation, gives 2.48% of error. While the calculated permeability from the Exponent needs to obtained 6 constants. The calculated permeability as compared to measure permeability give 6.93% of error. Keywords: Please Just Try to Submit This Sample Abstract Share Link | Plain Format | Corresponding Author (Havidh Pramadika)

103	Reservoir engineering	ABS-44
Analytical Solution of Buckley-Leverett Equation For Oil-Water Flow Using Artificial Neural Network Based Relative Permeability Model A. Wahyudi (a), T. Marhaendrajana (a), Z. Syihab (a), K.A. Sidarto (b) a) Petroleum Engineering, Bandung Institute of Technology Jalan Ganesha 10, Bandung 40132, Indonesia a) Mathematics, Bandung Institute of Technology Jalan Ganesha 10, Bandung 40132, Indonesia Abstract This paper presents an approximation of the oil-water relative permeability equation using Deep Learning to solve the Buckley-Leverett equation analytically. An artificial neural network-based approximation was developed to obtain two network models, namely for relative water permeability and oil relative permeability. Initially, an approximation of the oil-water relative permeability equation is prepared based on empirical data on relative permeability. Next, this approximation is used in the fractional flow equation to solve the equation analytically. To verify the model, the resulting solution is compared with an analytical adjustment based on the Corey relative permeability model. The comparison shows that the analytical solution based on the artificial neural network model has reasonable agreement with the solution based on the Corey model. The artificial neural network model was developed using the Tensorflow Python library. The advantage of using this library is the automatic gradient capability so that derivatives of fractional flow equations can be obtained and used in analytical solutions. Mathematically, approximation using artificial neural network has the advantage of a relative permeability value that is continuous along the saturation value. Keywords: neural network, relative permeability, buckley leverett Share Link | Plain Format | Corresponding Author (Agus Wahyudi)

104	Reservoir engineering	ABS-50
Estimating the Effect of Flow Efficiency on Oil Flow Rates Using Artificial Neural Network Andrian Sutiadi (a*), Muhammad Taufiq Fathaddin (b*), Suryo Prakoso (b), Dwi Atty Mardiana (b) a) PT. Prima Energi, Sahid Sudirman Centre, 53rd Floor, Jl. Jend. Sudirman Kav. 86, Jakarta Pusat 10220, Indonesia *andrian.sutiadi[at]primaenergy.id b) Department of Petroleum Engineering, Universitas Trisakti, Jakarta Barat, Indonesia *muh.taufiq[at]trisakti.ac.id Abstract Frequently drilling activity causes formation damage. The damage can be estimated from the drill stem test analysis. Formation damage is indicated by a skin factor (S) with higher than 0 or Flow Efficiency (FE) parameter lower than 100%. Improvement of formation damage can cause an increase in flow rate. Artificial Neural Network (ANN) model is used to estimate the increase flowrate of productive zones on ^X^ Field with FE 20% to 100%. The ANN model used reservoir pressure, temperature, permeability, formation thickness, specific gravity of oil, gas to oil ratio, oil viscosity, and flow efficiency as input parameters. While the flow rate is as the output parameter. Based on predictions with the ANN model, obtained the increase in flow rate varies between 1.1% to 78.0%. Besides, it is found that flowrate of the layers on the field is influenced by the product of kh, where kh is equivalent with the flowrate. Keywords: artificial neural network- flow efficiency- flowrate- skin factor- oil reservoir Share Link | Plain Format | Corresponding Author (Andrian Sutiadi)

105	Reservoir engineering	ABS-51
Estimating the Porosity and Initial Water Saturation in South Structure of X Field Using Artificial Neural Network Andrian Sutiadi (a*), Muhammad Taufiq Fathaddin (b*), Suryo Prakoso (b), Dwi Atty Mardiana (b) a) PT. Prima Energi, Sahid Sudirman Centre, 53rd Floor, Jl. Jend. Sudirman Kav. 86, Jakarta Pusat 10220, Indonesia *andrian.sutiadi[at]primaenergy.id b) Department of Petroleum Engineering, Universitas Trisakti, Jakarta Barat, Indonesia *muh.taufiq[at]trisakti.ac.id Abstract Determining the location of development wells requires rock and fluid data by carrying out petrophysical correlation between existing wells. That is done to estimate the potential of future wells or newly drilled wells. In this study, the porosity and saturation distribution of formations nearby CS-01 well with coordinates X = 722861.58 and Y = 9300235.29 at depths between 5377.5 ft to 6399.5 ft was estimated by applying an artificial neural network model (ANN). The ANN model was developed using data from three wells in X field. The data used includes measured depth, gamma ray, resistivity log, neutron log, density log as input parameters. Based on the results obtained correlation coefficients for training, validation, and testing processes for sequential porosity prediction are 0.9278, 0.9147, and 0.9303. Meanwhile, correlations for training processes, validations, and tests for initial water saturation prediction in sequence are 0.8787, 0.9162, and 0.8220. The implementation of ANN model shows prediction of porosity and initial water saturation in average of 0.24 and 0.49 respectively. Keywords: artificial neural network, flow efficiency, flowrate, skin factor, oil reservoir Share Link | Plain Format | Corresponding Author (Andrian Sutiadi)

106	Reservoir engineering	ABS-71
Well Patterns and Nutrient Injection Rates Optimization for Microbial Enhanced Oil Recovery (MEOR) in the DHP Field Boni Swadesi, Difa Hascarya Paramita, Suwardi, Indah Widiyaningsih Petroleum Engineering, UPN Veteran Yogyakarta Abstract Microbial Enhanced Oil Recovery (MEOR) involves injecting nutrients into oil reservoirs to enhance the oil recovery. This technology has the capacity to increase the amount of oil that can be extracted. Microbes in the reservoir oil can be activated by nutrients that they come into contact with, leading to a response. The interaction between nutrients and microbes in the reservoir oil can optimize oil recovery efficiency by catalyzing the decomposition of hydrocarbon chains. This research is written based on the information provided. The objective of this study is to evaluate the efficacy of nutrition injection by analyzing data obtained from scientific journals. The aim of this study is to investigate the impact of different injection-production well designs and the most effective nutrient injection rate on enhancing oil recovery and the recovery factor value in the DHP Field using MEOR injection. The methodology employed in this study comprises a comprehensive review of existing literature and the utilization of reservoir simulation techniques. This data is subsequently utilized to conduct reservoir simulation for nutrient injection using a simulator. The problem lies in the fact that the scenarios generated only incorporate sensitivity analysis of the injection-production well layouts and injection rates, without taking into account the economic factors. The study^s findings indicate that employing suitable nutrient injection well layouts and optimizing the nutrient injection rate can enhance oil recovery in the MEOR process through nutrient injection. The simulation findings for the base case, Scenario 1, 2, 3, and 4 yielded oil recovery factors of 12.17%, 13.20%, 17.13%, 14.23%, and 16.36% respectively. Hence, the most optimal approach for enhancing oil recovery in the DHP Field by MEOR nutrition injection is Scenario 2, which involves a five-spot injection design and an injection rate of 700 bbl/day. Keywords: MEOR, nutrients injection, reservoir simulation well patterns. Share Link | Plain Format | Corresponding Author (Boni Swadesi)

107	Reservoir engineering	ABS-93
Improving History Matching with Hydraulic Flow Unit Approach: Case Study of Carbonate Gas ^B^ Field Jhon Johanes Wood (a), Suryo Prakoso (b), Muhammad Taufiq Fathaddin (b) a) Master Program of Petroleum Engineering Department, Faculty of Earth and Energy Technology, Universitas Trisakti, Jakarta, Indonesia b) Petroleum Engineering Department, Faculty of Earth and Energy Technology, Universitas Trisakti, Jakarta, Indonesia Abstract History matching between reservoir simulation results and actual production data is essential for determining a reservoir^s production potential. However, this process is particularly difficult for carbonate reservoirs due to their heterogeneous rock formations. In earlier research on the ^B^ gas field, which contains carbonate reservoir rocks, modeling was performed using a reservoir facies division method based on lithology types such as grainstone, wackestone/packstone, and mudstone. This lithology-based approach posed difficulties during the history matching stage of the simulation. In this study, the author aims to introduce a rock classification analysis method for the carbonate reservoirs in the ^B^ gas field using the hydraulic flow unit (HFU) technique. This method will be applied as the basis for history matching, with the goal of improving the accuracy of the results. Keywords: history matching, hydraulic flow unit, reservoir simulation Share Link | Plain Format | Corresponding Author (Jhon Johanes Wood)

108	Reservoir engineering	ABS-106
LABORATORY RESEARCH ON THE FORMATION OF EMULSIONS WITH MES PALM OIL SURFACTANT AND ALCOHOL ADDITIVES ON 33 DEGREE API OIL Muhammad Furqon Haryono B., Rini Setiati, Arinda Ristawati, Muhammad Taufiq Fathaddin, Widia Yanti Trisakti University Abstract Enhanced Oil Recovery (EOR) is an effective method for increasing crude oil production. In this study, researchers examined palm oil-based MES surfactant with 96% ethanol for Enhanced Oil Recovery (EOR). Ethanol enhances emulsion stability, vital for stable phase formation, improving crude oil production efficiency effectively The purpose of this research is to determine the effect of concentration changes on the emulsion phase transition and the impact of alcohol added to the system. This research involves testing the compatibility of palm oil-based MES surfactant with alcohol additives on 33 degree API oil. The study was conducted in the laboratory to evaluate the results of Aqueous Stability testing using an oven at 60 degree C for 3 days. Furthermore, Phase Behavior testing was conducted using an oven at 60 degree C for 3 weeks or 21 days. The surfactant concentrations tested included 0.5%, 0.75%, 1%, 1.25%, 1.5%, 1.75%, and 2% under a salinity condition of 12,500 ppm. The laboratory test results on Aqueous Stability showed that all surfactant concentrations with the addition of alcohol produced clear solutions. In the Phase Behavior test, a middle phase emulsion formed at surfactant concentrations of 1% and 1.25% with a relatively small emulsion volume, approximately 1.25%. At other concentrations, a lower phase emulsion formed, ranging from 0.75% to 2.5%. From this research, it was concluded that the combination of palm oil-based MES with alcohol additives on 33 degree API oil produced a middle phase emulsion of 1.25%. Keywords: Surfactant, Methyl Ester Sulfonate (MES), Ethanol 96%, Aqueous Stability, phase behavior. Share Link | Plain Format | Corresponding Author (Muhammad Furqon Haryono Bimantoro)

109	Reservoir engineering	ABS-107
Effect of Alcohol Addition on Phase Behavior and Interfacial Tension of MES Surfactants Rambun Pamenan Khaifi (a*), Rini Setiati (b), Listiana Satiawati (a), Asri Nugrahanti (a), Muhammad Taufiq Fathaddin (b), Dwi Atty Mardiana (c) a) Departement of Petroleum Engineering, Universitas Trisakti, Jakarta, Indonesia b) Master Program of Petroleum Engineering, Universitas Trisakti, Jakarta, Indonesia c) Environment, Development, and Sustainability - Faculty of Graduate School, Chulalongkorn University, Thailand Abstract Oil wells in Indonesia are facing a steady decline in production due to their advanced age. To restore optimal oil production rates, Enhanced Oil Recovery (EOR) methods using surfactant injection have been chosen. This study investigates the effectiveness of using Methyl Ester Sulfonate (MES) derived from palm oil as a surfactant, with the addition of 96% ethanol as an additive. The goal of surfactant injection is to reduce the Interfacial Tension (IFT) between water and oil, thereby lowering capillary pressure in the reservoir rock^s narrow pores. Laboratory experiments were conducted using different concentrations of MES surfactant (0.5%, 0.75%, 1%, 1.25%, 1.5%, 1.75%, and 2%) with 96% ethanol as an additive in brine with a salinity of 7,500 ppm at 60C. Initial tests revealed the surfactant solution was unstable, prompting the addition of a co-surfactant. Each concentration of surfactant and co-surfactant was then mixed with light oil (33API) in pipette tubes. Stability tests showed that the surfactant and co-surfactant solution was stable. The best middle phase emulsion was achieved at a concentration of 1.25% with a salinity of 7,500 ppm, forming 0.06 ml or 1.5% of emulsion. At this concentration, the surfactant also exhibited the lowest IFT value of 0.457 dyne/cm. Keywords: EOR- Surfactant- MES- Cosurfactant- IFT Share Link | Plain Format | Corresponding Author (Rambun Pamenan Khaifi)

110	Reservoir engineering	ABS-109
Study of Sapindus rarak Properties as A Natural Surfactant for Enhanced Oil Recovery Injection Fluids Fajri Maulida (b), Muhammad Taufiq Fathaddin (a*), Dwi Atty Mardiana (b), Rini Setiati (b), Asri Nugrahanti (b), Marmora Titi Malinda (b), Samsol (b) Department of Petroleum Engineering, Universitas Trisakti, West Jakarta 11440, Indonesia Abstract Sapindus rarak or lerak belongs to the Sapindus genus. Sapindus rarak or commonly called soapberries (soapnuts) are fruits that look similar to walnuts and grow on trees that reach 10 meters in height. Lerak fruit contains saponin which produces foam and functions as a cleaning agent for clothes, floors and various kitchen utensils. The aim of this research is to measure the density, viscosity and static adsorption of Sapindus rarak surfactant on Berea core rock. The surfactant solution concentrations in this study were 5000, 10000, 15000, 20000, 25000 and 30000 ppm and the formation water salinity levels were 6,000 and 10,000 ppm. The measurement results show that increasing salinity from 6000 ppm to 10000 ppm causes an average density increase of 0.004 gr/cc or an increase of 0.41%. Measurements also show that increasing salinity from 6000 ppm to 10000 ppm causes an average increase in viscosity of 0.20755 cp or an increase of 14.5%. In addition, adsorption measurements showed that increasing salinity from 6000 ppm to 10000 ppm caused an average decrease in adsorption of 2.17 mg/gr or an increase of 8.8%. Keywords: Sapindus rarak- density- viscosity- adsorption- salinity Share Link | Plain Format | Corresponding Author (Fajri Maulida)

111	Reservoir engineering	ABS-119
CARBONATE ROCKS GROUPING USING CRITICAL POROSITY APPROACH IN MIOCENE ROCKS, BANGGAI BASIN Sigit Rahmawan1*, Syamsul Irham1, Asri Nugrahanti1 , Firman Herdiansyah2, Samsol1, Suryo Prakoso3, Muhammad Burhannudinnur2, Djunaedi Agus Wibowo1, Hari Karyadi Oetomo1, Teddy Irano4, Thalia Ribka Marinada1 1Teknik Perminyakan,Universitas Trisakti, Jakarta, Indonesia 2Teknik Geologi, Universitas Trisakti, Jakarta, Indonesia 3Magister Teknik Perminyakan, Universitas Trisakti, Indonesia 4Exploration, JOB-Pertamina-Medco E&P Tomori Sulawesi, Jakarta, Indonesia Abstract Reservoir is the trapped underground tank of hydrocarbon fluid with heterogeneity of physical rock properties. The characteristics of rock heterogeneity significantly influence the rock^s ability to flow hydrocarbon fluid. Several methods have been developed to classify the heterogeneity of reservoir rocks, such as the Amaful, Permadi and Wibowo methods- among others. These methods are developed based on laboratory experiments using sandstone rocks- although in some studies, they are also frequently employed in categorizing carbonate reservoir rocks. However, these commonly used methods still face challenges in rock classification when actual rock samples are unavailable. In this study, the classification of carbonate reservoir rock is conducted using a Critical Porosity approach, and comparing with the Permadi and Wibowo method of the hydraulic flow unit classification method. The data utilized in this study consists of rock samples from the Miocene era of the Banggai Basin. This study reveals that using the Wibowo and Permadi method, ten rock classification is obtained, whereas employing the critical porosity approach resulting in six rock classification. Both methods demonstrate a correlation between rock pore structure and rock geometry- where rocks categorized under rock type #10 in the Wibowo and Permadi method, and rock type #6 in this study critical porosity method exhibit the smallest pore geometry values as compared to other rock types. Each rock classification signifies the rock^s fluid flow capability, with rocks categorized under rock type #1 indicating better fluid flow capability as they possess finer geometries. Keywords: Critical Porosity, Permeability Prediction, Pore Geometry, Pore Structure, Rock Typing Share Link | Plain Format | Corresponding Author (Sigit Rahmawan)

112	Reservoir engineering	ABS-121
ANALYSIS OF RESULT PRESSURE BUILD UP TEST BEFORE AND AFTER ACIDIZING IN GAS WELL YA- 01 Arinda Ristawati (a)*, Mulia Ginting (a), Jasmine Ghina Kaynes (a), Onnie Ridaliani Prapansya (a), R. Hari Karyadi Oetomo (a) , Puri Wijayanti(a) Fakultas Teknologi Kebumian dan Energi, Prodi Teknik Perminyakan, Universitas Trisakti, Jakarta Abstract The YA- 01 production well is a well that has decreased production. The decrease in the amount of production can be caused by continuous production activities or it can also be caused by formation damage. One way to overcome formation damage is by acidizing. The success of acidizing can be shown based on the analysis of the Pressure Build Up Test. Based on the analysis of the Pressure Build Up test, it can be obtained reservoir characteristics such as skin factor (s), permeability (k), permeability thickness (kh), initial reservoir pressure, reservoir model, well model, boundary model, and wellbore storage model. From the results of these parameters can be used to determine the success of acidizing. Pressure Build Up testing is done by using the Horner method with Pseudo-Pressure Approach and assisted by software. This test was carried out based on activities before and after acidizing. Based on the analysis before acidizing, it is known that the YA- 01 gas well has a skin value of 10.4, which means that there is formation damage around the wellbore. Therefore, the YA- 01 gas well is acidized with the aim of reducing the skin value. After acidizing, the skin factor value decreased to -1.38, which means the well has been repaired. Based on the results of this analysis, it can be said that the acidizing in well YA- 01 was successfully carried out. Keywords: acidizing, horner, pressure build up, skin Share Link | Plain Format | Corresponding Author (ARINDA RISTAWATI)

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