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Muhammad Taufiq Fathaddin
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Program Studi Magister Teknik Perminyakan (Master of Petroleum Engineering) Fakultas Teknologi Kebumian dan Energi Universitas Trisakti Gedung D Lantai 5 Universitas Trisakti, Jalan Kyai Tapa No.1 Grogol, Jakarta Barat, 11440, Indonesia.
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INDONESIA
Journal of Earth Energy Science, Engineering, and Technology
Published by Universitas Trisakti
ISSN : 26153653     EISSN : 26140268     DOI : https://doi.org/10.25105/jeeset.v1i1
Core Subject : Science,
Energy
This journal intends to be of interest and utility to researchers and practitioners in the academic, industrial, and governmental institutions.
Arjuna Subject : Energi (semua kategori) - Energi Terbarukan, Keberlanjutan dan Lingkungan
Articles 121 Documents
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Laboratory Study: Comparison of Physical Properties of XCD Polymer Drilling Mud and PHPA Fattahanisa, Aqlyna; Yanti, Widia; Rizkina Rangga Wastu, Apriandi; Ristawati, Arinda; Setiati, Rini; Fadliah; Poluan, Chris Elvano; Juanda, Firdaus
Journal of Earth Energy Science, Engineering, and Technology Vol. 6 No. 3 (2023): JEESET VOL. 6 NO. 3 2023
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/jeeset.v6i3.13998

Abstract

The physical properties of the drilling mud greatly affect the success of the mud in lifting cuttings. The value of the physical properties of the drilling mud that is not in accordance with the required specifications can make cutting removal not optimal. In this study, an analysis of the physical properties of XCD Polymer and PHPA drilling mud will be carried out at temperatures of 100 oF, 200 oF, and 300 oF. This research is experimental which will test the characteristics or physical properties of the mud used. At the beginning of testing the physical properties of the XCD Polymer and PHPA mud using the initial composition of each of these muds, the results obtained did not fit into the mud specifications that had been determined due to the influence of the temperature increase. If you continue to use the same mud composition, the higher the temperature, some of the physical properties of the drilling mud will decrease. To overcome this problem, additives are added to the mud composition at each temperature to be tested. This is done so that the results of testing the value of the physical properties of the mud tested at each temperature are in accordance with predetermined specifications. After re-testing using the composition of the mud that has been added with additives, the results obtained from the two tested muds are the density value of 8.9-11.2 ppg, viscosity of 24-33 sec/qt, plastic viscosity of 20-33 cps, yield point of 21-28 lb/100 sqft, gel strength 10 seconds and 10 minutes respectively of 4-6 lb/100 sq. ft and 6-8 lb/100 sqft, filtration loss of 1.9- 4.6 ml, the thickness of the mud cake is 0.6-1 ml, and the pH is 9-10.
Evaluation of the Viscosity of Terrafloc Polymer and Xanthan Gum Polymer Amri, Sulthoni; Setiati, Rini; Fathaddin, Muhammad Taufiq; Rakhmanto, Priagung; Swadesi, Boni; Ratnaningsih, Dyah Rini
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 1 (2024): JEESET VOL. 7 NO. 1 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/jeeset.v7i1.17309

Abstract

Polymer injection is one of the EOR methods using chemical which is injected into the reservoir to increase oil recovery. The polymer functions to maintain the flow of fluids, especially water, so that it does not boil ahead of oil towards production wells. This is due to the ability of the polymer to increase the viscosity of the fluid in the reservoir. The polymers commonly used in the petroleum world are synthetic polymers and natural polymers which are often referred to as biopolymers. The type of biopolymer in this article is Xanthan Gum while the synthetic polymer used is Terrafloc. The characteristics of these two polymers are compared so that the performance that will be obtained in an effort to increase the recovery of petroleum can be estimated. From the results of the viscosity measurement, it turned out that the Xanthan Gum polymer had a much greater viscosity value than the Terrafloc polymer. Thus, the use of Xanthan Gum and Terrafloc polymers can be adjusted to the needs related to the type of crude oil in the reservoir to be injected so that the results of obtaining petroleum can be optimal.
Characterization of Addition Porang on Polyacrylamide Polymer for Enhanced Oil Recovery Siahaya, Jacob; Mardiana, Dwi Atty; Fathaddin, Muhammad Taufiq
Journal of Earth Energy Science, Engineering, and Technology Vol. 6 No. 3 (2023): JEESET VOL. 6 NO. 3 2023
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/jeeset.v6i3.17423

Abstract

The main purpose of polymer injection is to reduce the water-oil mobility ratio. By increasing the viscosity of the injection fluid, polymer injection can increase sweep efficiency, thereby increasing oil recovery. This study aims to determine the viscosity and adsorption effects of adding porang to polyacrylamide polymers. The method used in this research is a laboratory experiment. The salinity of the formation water used in this study was 6000 ppm, 12000 ppm, and 18000 ppm, with variations in polymer concentrations of 2000 ppm, 4000 ppm, and 6000 ppm on the polymer without a mixture of porang and with a mixture of porang. The result of measuring the viscosity of polyacrylamide by adding porang at the salinity of 6000 ppm and polymer concentration of 6000 ppm was 21.82 cp. With the addition of porang to the polyacrylamide polymer at 2000 ppm concentration and 18000 ppm salinity, the adsorption value of the polymer decreased from 2.708 mg/gr to 1.748 mg/gr for 40 mesh sand and from 3.333 mg/g to 2.358 mg/g for 60 mesh sand.  
Analysis of Light Hydrocarbon (Ethane) Content in Propane Using the Boil off Gas System at the ABC LPG Terminal Rahmadani, Rizki; Ardhiyanto, Nano Koes
Journal of Earth Energy Science, Engineering, and Technology Vol. 6 No. 3 (2023): JEESET VOL. 6 NO. 3 2023
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/jeeset.v6i3.18182

Abstract

LPG is a fuel that comes from refining petroleum or natural gas. Composed of various light hydrocarbons, LPG is one of the fuels with more environmentally friendly emissions than BBM. The ease with which light hydrocarbons in LPG evaporate causes problems such as increasing pressure in storage tanks during the landfill process. The use of the Boil-off Gas System is one of the systems used by ABC LPG Terminal to reduce evaporation loss in tanks due to high pressure. In this research, research was conducted on the effect of the inclusion of light hydrocarbons (ethane) in propane using the Boil-off Gas System. Based on the research results, the ethane content included in the propane at the ABC LPG Terminal exceeds the tolerance limit which affects the pressure in the propane drum condensate tank as a storage tank for the results of the BOG system, valve openings leading to flaring combustion and total losses in flaring. Using the Correlational Method supported by the Simple Linear Regression Test on data with a confidence level of 95% shows the effect of the relationship between ethane content and pressure in the propane drum condensate tank of 91.8%, valve opening to flaring combustion of 99.2% and total losses in flaring of 98.5%. It is classified as a powerful correlation relationship.
Evaluating Hydrocarbon Prospects and Petrophysical Properties in Sepinggan Formation, East Kalimantan's Lower Kutai Basin Purnomo, Rezandy Purnomo Setyo; Rohmana, Rian Cahya; Atmoko, Widi
Journal of Earth Energy Science, Engineering, and Technology Vol. 6 No. 3 (2023): JEESET VOL. 6 NO. 3 2023
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/jeeset.v6i3.18253

Abstract

This study aims to determine hydrocarbon zones and analyze petrophysics in the Sepinggan Formation, located in the lower Kutai Basin, which is one of the oil and gas producing formations in Indonesia. The data used includes 5 well log data and mudlog data. The results of the study show that the Sepinggan Formation has 14 potential zones dominated by carbonate sandstone lithology with a slight mixture of coal. Some key findings in the petrophysical analysis include the largest average shale volume of about 41% in zone 1 of well SPG-V8, the largest average porosity of about 24% in zones 1 and 2 of well SPG-V1, the largest average permeability of about 2591.08 mD in zone 1 of well SPG-V2, and the largest average water saturation of about 56% in zone 2 of well SPG-V7. Based on these results, further evaluation of hydrocarbon potential in the identified potential zones and optimization of exploration and exploitation techniques are needed to improve the efficiency of oil and gas production in the Sepinggan Formation.
Investigating Potential Neglected Oil Reservoirs Using a New Approach Putri Caesar, Athifa; Lestari; Wijayanti, Puri; Wihardjo, Lukas; Kadarusman, Sunarto
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 1 (2024): JEESET VOL. 7 NO. 1 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/jeeset.v7i1.18323

Abstract

This research aims to explore the potential of neglected oil reservoirs through thin layer analysis. In this condition, drilling data based on oil base mud are used for analysis so that the effect of drilling mud invasion can be minimized. With the complete Oil Base Mud Imager (OBMI) Log Imager, the results of petrophysical calculations are compared based on standard logs, standard logs with resistivity from oil base mud imager, and using square log modeling for gamma ray, density, neutron and resistivity curves. From modeling and analysis of a 15 ft thick oil layer, the results show that PhiSo*H increases significantly. Based on the calculation results for the high-resolution resistivity log input, the PhiSo*H value has increased by 25% compared to the standard log input. Meanwhile, square log input increases the PhiSo*H value by 235% compared to standard log input. These indicate that there are thin oil layers that are not detected when using standard log input.
Assessing Fracture Intensity and Petrophysical Properties in the Jatibarang Formation's Volcanic Reservoirs, North West Java Basin Baihaqie, Qosha; Rohmana, Rian Cahya; Atmoko, Widi
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 1 (2024): JEESET VOL. 7 NO. 1 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/jeeset.v7i1.18359

Abstract

Volcanic rock reservoirs, characterized by fractures in their formations, have gained attention in Indonesia due to their oil content, particularly in the Jatibarang Formation in West Java. This study focuses on four wells in the West Java Basin containing the Jatibarang Formation, aiming to determine fracture intensity using conventional log data and to perform petrophysical analysis. The research employs well log, mud log, and core data, utilizing qualitative analysis to identify potential reservoir zones and quantitative analysis to calculate fracture intensity and petrophysical properties. The results show that fractures in the Jatibarang Formation can be identified through fracture intensity analysis using conventional log data (MSFL, RHOB, Caliper, PEF, and DT). Fracture intensity calculations were only carried out on the QB-3 well because the other wells did not have complete log data. The results of the fracture intensity analysis showed that the fractures that occurred in the QB-3 well had 1-23%. Petrophysical analysis of the four wells reveals that the cutoff values for clay volume (50%), porosity (10%), and water saturation (70%) indicate potential candidates for further reservoir research. The QB-3 well has seven potential zones with a fracture index value of more than 10%. Permeability in wells QB-3 and QB-4 is more than 60 mD, making these four wells potential candidates for further research on volcanic rock reservoirs.
Prediction of Optimum Hydrate Inhibitors Mass Percent for Hydrate Formation Prevention Kinate, Bright Bariakpoa; Igwe, Ikechi; Elikee, Uchenna Daniel
Journal of Earth Energy Science, Engineering, and Technology Vol. 6 No. 3 (2023): JEESET VOL. 6 NO. 3 2023
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/jeeset.v6i3.18386

Abstract

The production tubing and pipeline have the critical task of transporting economically significant fluids.  As a result, they must be meticulously designed to manage potential issues like gas hydrate formation that can lead to blockage of the pipeline. In this study, the OLGA dynamic multiphase simulator and Multiflash were employed to determine the optimum mass percentages of thermodynamic inhibitors- namely, methanol, monoethylene glycol (MEG), diethylene glycol (DEG) and triethylene glycol (TEG) that are necessary to prevent hydrate formation within the pipeline. The pipeline model was developed using OLGA and Multiflash to characterised the fluid properties and generate the requisite input files (hydrate and PVT table files) for dynamic multiphase simulation with OLGA. Sensitivity analyses were performed to determine the optimum mass percent of methanol, MEG, DEG, and TEG required to suppress hydrate formation in the pipeline. Different mass percent of 10%, 20% 30%, 40%, 50%, 60%, 70%, 80% and 90% of the four inhibitors were introduced into the pipeline to evaluate their impact on hydrate volume fractions and locations along the pipeline at where hydrate attains thermodynamic stability. Addition of the inhibitors was stopped when the system exhibited conditions of no hydrate volume fraction. Result shows that the optimum mass percent for complete hydrate inhibition was 60% for methanol, 45% for MEG, and 70% for TEG inhibitors in the pipeline. DEG showed reduced hydrate fraction but did not inhibit formation effectively even at 90%. It was observed that as the inhibitor mass percent increases, the hydrate dissociation temperature (the temperature below which the hydrate will form) is reduced for a given pressure. Consequently, Monoethylene glycol (MEG) with an optimal mass percentage of 45% was the most efficient inhibitor for curbing hydrate formation within the given pipeline, surpassing the performance of other inhibitors and offering potential cost saving.
Challenges towards Sustainable Energy as a Substitute for Fossil Fuels for the Case of Municipal Waste Management Owusu, Prince Appiah; Borkloe, Julius Kwame; Mahamud, Yussif
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 1 (2024): JEESET VOL. 7 NO. 1 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/jeeset.v7i1.18798

Abstract

The potential in energy generation from municipal waste management (MSW) has great gains in low-income communities in terms of promoting healthy living conditions, attenuating global warming potential (GWP), and enhancing environmental sustainability. The use of waste-to-energy system (WtES) for MSW conversion into renewable energy resources in Ghana has great prospects at Asokore Mampong Municipality. The study put together WtES options in anaerobic digestion and thermochemical for energy potential and compared their GWP and greenhouse gases (GHGs) with those originating from fossil fuel. Thermochemical energy recovery of MSW was estimated to provide 4.24×104 kWh/day and 1.6×104 MWh/year of electricity, equivalent to 1.3295 kilotonnes of oil equivalent (ktoe) and 8.2% of the power requirement for the Municipality in 2021. The anaerobic potential of energy recovery of 55% of the organic fraction of MSW was estimated to provide a biogas production potential (BGrp) estimate of 2.54×106 m3/year and 5.65×107 MJ of thermal heat energy per annum which translates to 5.5 ×103 MWh/year and equivalent of 0.472 Ktoe. In terms of GWP, thermochemical and anaerobic energy recovery generated 24 kg and 3.3 kg of CO2 equivalent (CO2e) for every ton of MSW. There are 302 g and 115 g of CO2e for each kWh of electricity produced through thermochemical and anaerobic recovery respectively. Fossil fuels; natural gas, oil, and coal produce CO2e range of 290 – 930 g CO2e /kWh, 510 – 1170 g CO2e /kWh, and 740 – 1689 g CO2e /kWh respectively. This makes WtES better in terms of GWP. The energy recovery from thermochemical and anaerobic processes is key in managing MSW in low-income communities for a sustainable environment. The strategy has the potential to unravel the complications in overwhelming MSW management which has implications for environmental health hazards, soil and water pollution. The global fight towards GHG reduction from fossil fuels could have a positive impact through the furtherance of the concept used. For successful WtES facilities and benefits to low-income dwellers like Asokore Mampong Municipality in Ghana, strong engineering judgment and technical competence are necessary and this requires collaboration with all stakeholders. Proper management of MSW energy value chain and intervention therefore has the potential for the provision of employment opportunities and economic sustainability in developing economies.
Well Deliverability Analysis Using Modified Isochronal Test: Study Case on AG Gas Well: Analisis Well Deliverability Menggunakan Modified Isochronal Test: Studi Kasus Pada Sumur Gas AG Gushari, Akba; Nirmala, Gerry Sasanti; Yulianto, Yudha
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 1 (2024): JEESET VOL. 7 NO. 1 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/jeeset.v7i1.18952

Abstract

The AG Well is a gas well that undergoes well testing utilizing the Modified Isochronal Test method to assess the reservoir characteristics of the NVR Field. In this paper, Type Curve and Horner Plot are analyzed for Pressure Build Up test and well deliverability determination using C and n method to obtain Absolute Open Flow Potential value of NVR reservoir to construct inflow performance relationship curve and Vertical Lift Performance of the well. The reservoir model of Two Porosity Slab and Boundary Intersecting Fault - 31° with an AOFP of 10574.8 MSCF/d was made with Ecrin software.

Page 10 of 13 | Total Record : 121

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