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Hadziqul Abror
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Program Studi Teknik Perminyakan, Fakultas Teknik, Universitas Jember Jl. Kalimantan Tegalboto No.37, Krajan Timur, Sumbersari, Kec. Sumbersari, Kabupaten Jember, Jawa Timur 68121.
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Journal of Sustainable Energy Development
Published by Universitas Jember
ISSN : -     EISSN : 30482585     DOI : -
Core Subject : Science, Engineering,
Energy Engineering
The Journal of Sustainable Energy Development is the official scientific journal of Petroleum Engineering, Faculty of Engineering, University of Jember for the dissemination of information on research activities, technology engineering development and laboratory testing in sustainable energy development. The focus and scope of JSED as follows: Oil and Gas Technology: Production, Reservoir, and Drilling Technology, Enhance Oil Recovery Geothermal Technology: Reservoir Characterization and Modeling, Development of Productivity-Enhancing Methods, Plan of Vevelopment Earth Science: Geology, Geophysics, Geochemical Renewable Energy: Wind energy, Hydro energy, Solar cell energy, Biomass
Arjuna Subject : Energi (semua kategori) - Energi Terbarukan, Keberlanjutan dan Lingkungan
Articles 23 Documents
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Penentuan Nilai Porositas pada Sample Berea di Routine Core Analysis Laboratorium BBPMGB “LEMIGAS” Febriyana, Marine Chyntya; Welayaturromadhona
Journal of Sustainable Energy Development Vol. 2 No. 1 (2024): Journal of Sustainable Energy Development (JSED)
Publisher : Petroleum Engineering, Faculty of Engineering, University of Jember

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.19184/jsed.v2i1.756

Abstract

This study aims to analyze routine cores, especially for determining the porosity of a rock.  The samples tested by the coreval tool were 3 samples of 1.5 inch diameter with a length of 4.5 cm each. The sample used is a sample of Berea sandstone.  When the core sample comes, it is continued with ct-scan and spectral gamma ray. The next process is washing the fluid in the core sample. After cleaning from other fluids, the core sample will be dried in the oven. After it is completely dry, the sample must be stored in a desiccator containing silica gel. After ambient temperature, then the core sample is tested using Coreval 700.  The data inputted into the coreval computer are the name of the core sample, the dry weight of the core, the length of the core, and the diameter of the core. The coreval tool takes readings of bulk volume, pore volume, and porosity. This reading resulted in bulk volume values of 50.091 cc; 53.446 cc; and 52.410 cc, respectively. The pore volume value of each sample is 12.091 cc; 13.787 cc; and 13.385 cc. As for porosity, the value of each sample is 25.767%; 25.795%; and 25.540%. Keywords: coreval 700; permeability; porosity, RCAL
Analisis Penanggulangan Kadar Gas H2S Pada Aliran Minyak Di Stripper Melalui Penerapan Injeksi Sweetening Gas dan Oil Rate Lilo Al Fiqriansyah; Abror, Hadziqul; Triono, Agus
Journal of Sustainable Energy Development Vol. 2 No. 2 (2024): Journal of Sustainable Energy Development (JSED)
Publisher : Petroleum Engineering, Faculty of Engineering, University of Jember

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.19184/jsed.v2i2.812

Abstract

This research evaluates the performance of an existing stripper in handling H2S content in the oil stream in Sukowati Field, Bojonegoro Regency. With H2S content ranging from 2-3%, there's a risk of danger and damage to the piping system. The study aims to assess the stripper's performance, propose an optimization scenario for managing H2S content, and compare the existing stripper's performance with the optimization scenario. The research involved evaluating the stripper from October to December 2023, formulating an optimization scenario, and implementing it in January 2024. Results indicate that the % absorption ratio in the sweetening process averaged 98.99% in the existing stripper and 99.75% in the optimization scenario. The oil rate to sweetening gas ratio averaged 89.31% in the existing stripper and 88.01% in the optimization scenario. The sweetening gas injection to oil rate ratio averaged 10.7% in the existing stripper and 12.0% in the optimization scenario. The optimization scenario reduced H2S content from 24000 ppm to 60 ppm, meeting standards. Overall, optimizing the oil rate to sweetening gas injection ratio improved H2S content reduction efficiency in the stripper, with H2S content at the outlet less than 100 ppm.
Analisis Retention Time Terhadap Pemisahan Fasa Pada Three Phase Separator di Unit Lube Oil Complex (LOC) III Devfara, Muhammad Farel; Abror, Hadziqul; Triono, Agus
Journal of Sustainable Energy Development Vol. 2 No. 2 (2024): Journal of Sustainable Energy Development (JSED)
Publisher : Petroleum Engineering, Faculty of Engineering, University of Jember

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.19184/jsed.v2i2.1362

Abstract

This research analyzes the retention time of the three phase separator in separating oil, water, and gas phases at PT Pertamina refinery unit IV Cilacap. With an initial retention time ranging from 31 - 34 minutes, there are phases that are still not separated in the separator. This study aims to provide recommendations for retention time based on unseparated phases and how to apply them to the separator at the refinery. This study involves three types of lube oil analyzed, namely DAO, MMO, and LMO. The results show that there is still a difference between the phases at the inlet and outlet which indicates that the phase separation at the initial retention time is still not optimal so that new retention time recommendations need to be made. In the type of DAO lube oil with a retention time of 33 minutes with the largest difference at the inlet and outlet of 0.040. In the type of MMO lube oil with a retention time of 31.2 minutes with the largest difference of 0.037. In the type of LMO lube oil with a retention time of 34.2 minutes with the largest difference of 0.036. After making retention time recommendations based on the results of the difference between inlet and outlet, the retention time recommendations for DAO are 54.6 minutes, MMO is 51.6 minutes, and LMO is 55.8 minutes. The application of retention time recommendations for the separator can be done by optimizing the flow rate at 432,439 m3/day or adding new separator facilities that can accommodate operational volumes of up to 60.4 m3.
EVALUASI KINERJA HEAT EXCHANGER 260E-103 PADA KILANG LUBE OIL COMPLEX III UNIT 260 PT KILANG PERTAMINA INTERNASIONAL RU IV CILACAP Villia Rian Ashari; welayaturromadhona, welayaturromadhona
Journal of Sustainable Energy Development Vol. 2 No. 2 (2024): Journal of Sustainable Energy Development (JSED)
Publisher : Petroleum Engineering, Faculty of Engineering, University of Jember

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.19184/jsed.v2i2.1364

Abstract

In the process of processing petroleum, PT Pertamina International RU IV Cilacap is equipped with a heat exchanger asa supporting tool for the production and processing. Heat exchanger functions as a heat exchange that works with theprinciple of heat exchange without mass transfer. The use of heat exchangers that are in extreme environments and areused for a long period of time to pass fluids, there is a high probability of deposit formation or impurities that can affectthe pressure drop and decrease the performance efficiency of the heat exchanger in terms of heat exchange. Planning forcleaning must be considered to maintain the performance of the heat exchanger performance so that it remains in optimalcondition. The heat exchanger that will be evaluated in this study is Heat Exchanger 260E-103 at PT PertaminaInternational RU IV Cilacap. The research was conducted using quantitative methods through the calculation of foulingfactor, pressure drop, and heat transfer efficiency. The results showed that the Rd value of Heat Exchanger 260E-103 ofLMO was 0.0317 hr ft2 oF/Btu; 0.0058 hr ft2 oF/Btu; 0.0048 hr ft2 oF/Btu, MMO was 0.0193 hr ft2 oF/Btu; 0.0157 hr ft2oF/Btu; 0.0070 hr ft2 oF/Btu, and DAO of 0.0153 hr ft2 oF/Btu; 0.0193 hr ft2 oF/Btu; 0.0029 hr ft2 oF/Btu. The pressuredrop value of Heat Exchanger 260E-103 of LMO is 12.021 Psi; 10.632 Psi; 10.416 Psi, MMO is 11.077 Psi; 11.108 Psi;10.435 Psi, and DAO is 14.149 Psi; 13.764 Psi; 13.625 Psi. The efficiency for Heat Exchanger 260E-103 of LMO is22.81%; 79.47%; 82.16%, MMO is 29.07%; 46.03%; 72.16%, and DAO is 17.43%; 60.06%; 45.04%. The results showthat Heat Exchanger 260E-103 is not suitable for use because it has Rd and pressure drop values exceeding normallimits, and efficiency is below standard.
ANALISIS KEBERHASILAN KERJA ULANG PINDAH LAPISAN PADA SUMUR SKW-33 LAPANGAN SUKOWATI Desyana Nindya Prastiwi; Abror, Hadziqul; Hafwandi, Babas samudera
Journal of Sustainable Energy Development Vol. 2 No. 2 (2024): Journal of Sustainable Energy Development (JSED)
Publisher : Petroleum Engineering, Faculty of Engineering, University of Jember

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.19184/jsed.v2i2.1603

Abstract

This study explores the effectiveness of re-perforation operations at Well SKW-33 in the Sukowati Field to enhance oil production. The background highlights the decline in production rates despite the well's initial success with natural flow since June 2015. The primary objective is to evaluate the impact of re-perforation on oil production and water cut. The research employs methods such as squeeze cementing, Cement Bond Log (CBL) analysis, well logging and subsequent re-perforation. The results demonstrate a significant increase in oil production from 100-150 barrels per day (bopd) to a peak of 305 bopd post-re-perforation. Additionally, the water cut reduced from 95-96% to 80%, indicating a successful reduction in water production. The conclusion asserts that re-perforation significantly boosts short-term oil production and reduces water production, though ongoing management is essential for maintaining long-term efficiency.
Analisis Pengaruh Number of Stages dan Banyak Pompa ESP di Sumur X Saputri, Eriska Eklezia Dwi; Vani Nur Azizah
Journal of Sustainable Energy Development Vol. 2 No. 2 (2024): Journal of Sustainable Energy Development (JSED)
Publisher : Petroleum Engineering, Faculty of Engineering, University of Jember

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.19184/jsed.v2i2.1679

Abstract

In well X, there has been a decline in oil production, leading to a decrease in the company’s revenue. This is due to an increase in the watercut percentage, as the reservoir itself operates on a water drive mechanism. Therefore, a follow-up action is needed to address this situation by using an artificial lift ESP with a tandem design. This approach aims to enhance the effectiveness and economic efficiency of the production process. The artificial lift Electrical Submersible Pump (ESP) used is a CENTRILIFT with model FC2700, series 400, installed at depths of 6371 ft and 6382 ft, respectively. A comparison of the two artificial lifts shows that the number of stages in the upper section is greater than in the lower section, resulting in a higher oil flow rate at the top, reaching 68.52 STB/d. Meanwhile, in the ESP well, oil flow rate has increased by 77.46 STB/d.
Production Performance Analysis to Mature Field Development Plan: Production Performance Analysis to Mature Field Development Plan Raharjo, Cahyo Tri; Laksmita Sari, Riska
Journal of Sustainable Energy Development Vol. 2 No. 2 (2024): Journal of Sustainable Energy Development (JSED)
Publisher : Petroleum Engineering, Faculty of Engineering, University of Jember

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.19184/jsed.v2i2.2193

Abstract

The research focuses on evaluating the production performance of three oil wells-Well F55A MB, Well Hovea 13 ST1, and Well Pedirka-1-using Inflow Performance Relationship (IPR) and Vertical Lift Performance (VLP) analysis to determine optimal artificial lift methods for each case. The study explores critical production parameters such as reservoir pressure, temperature, and gas-to-oil ratio (GOR) while employing decision tree methodologies to select suitable artificial lift systems. For Well Hovea 13 ST1 and Well Pedirka-1, gas lift installations significantly enhanced oil recovery rates by optimizing injection pressures and valve placements, achieving production gains of 694 and 300 barrels per day, respectively. In contrast, Well F55A MB, characterized by high water cut and lower reservoir temperatures, was deemed unsuitable for artificial lift based on the decision tree analysis, with a stable production of 2832 stb/d. This work highlights the importance of tailored artificial lift strategies for maximizing oil recovery and improving well performance in diverse reservoir conditions.
Estimasi Cadangan Lapangan RTD Menggunakan Metode Decline Curve Analysis Dan Log WC Vs Np Maulana, Nadhif; Abror, Hadziqul; welayaturromadhona
Journal of Sustainable Energy Development Vol. 3 No. 1 (2025): Journal of Sustainable Energy Development (JSED)
Publisher : Petroleum Engineering, Faculty of Engineering, University of Jember

Show Abstract | Download Original | Original Source | Check in Google Scholar

Abstract

Lapangan RTD dibor pada tahun 1984 dengan sumur RTD-1 dan terus berproduksi sejak saat itu. Hingga tahun 2020, total sumur yang dibor di lapangan sebanyak 20 sumur, 13 diantaranya masih berproduksi dan 6 sumur digunakan untuk injeksi air. Lapangan RTD terdiri dari 3 reservoir yaitu Holland Greensand, De Lier Sandstone, dan Ijsselmonde Sandstone. Ketiga reservoir Rotterdam menghasilkan minyak, air dan sejumlah kecil gas. Reservoir Batupasir IJsselmonde telah berproduksi sejak tahun 1984, Reservoir Batupasir De Lier telah berproduksi sejak tahun 1986 dan Reservoir Holland Greensand telah berproduksi sejak tahun 1988. Penelitian ini membahas tentang evaluasi cadangan pada lapangan RTD dengan melakukan perhitungan cadangan. Metode yang digunakan adalah metode Decline Curve Analysis dan metode Log WC vs Np. Perhitungan akan dikelompokkan menjadi 2 yaitu seluruh lapangan RTD dengan menggunakan kedua metode dan yang kedua yaitu menggunakan metode Log WC vs Np pada masing-masing lapisan. Metode penelitian yang digunakan adalah study literatur yang berhubungan dengan perhitungan cadangan pada lapangan RTD yaitu dengan mengumpulkan informasi data sekunder mengenai data – data untuk forecasting dalam bentuk buku – buku literatur, jurnal, dan tugas akhir yang berkaitan dengan judul peneliti. Lapangan RTD memiliki total STOOIP 319 MMSTB dari 3 reservoir dan masing-masing reservoir memiliki watercut 56% - 82%. Perhitungan cadangan Lapangan RTD mendapatkan hasil RR 8,71 MMSTB dengan EUR 67,52 MMSTB, dan memperoleh hasil RR 8,25 MMSTB dengan EUR 67,05 MMSTB. Hasil masing-masing lapisan di lapangan RTD bila ditotal mendapatkan hasil RR 6,62 MMSTB dengan EUR 65,43 MMSTB.
Desain Hydraulic Fracturing Sebagai upaya Peningkatan Produktivitas Sumur X Lapangan Y Berliana Dewi, Salsabila; Abror, Hadziqul; welayaturromadhona, welayaturromadhona
Journal of Sustainable Energy Development Vol. 3 No. 1 (2025): Journal of Sustainable Energy Development (JSED)
Publisher : Petroleum Engineering, Faculty of Engineering, University of Jember

Show Abstract | Download Original | Original Source | Check in Google Scholar

Abstract

The decline in oil production due to aging wells and formation damage has become a critical challenge in the petroleum industry. This study focuses on the design of hydraulic fracturing to improve Well X's productivity in the Telisa Formation, Central Sumatra Basin. The research utilized FracCADE 7.0 software to simulate hydraulic fracturing scenarios and optimize fracture geometry and conductivity. The parameters investigated included variations in fracturing fluid volume, proppant types, and injection methods, culminating in 12 simulation scenarios. The geomechanical analysis revealed that the Telisa Formation, dominated by low Young’s modulus (<3×10⁶ psi) and low Poisson’s ratio, is favorable for fracturing, as it tends to generate wider fractures at lower pumping pressures. However, higher Young's modulus layers at greater depths showed the potential for longer but narrower fractures, albeit requiring higher pumping pressures. These characteristics guided the selection of fracturing intervals and operational parameters to optimize stimulation results. The results showed that the optimal scenario utilized 32,239 gallons of fracturing fluid, Brady Sand as the proppant, and the Proppant Concentration Step-Wise Increasing (PCSI) injection method. This configuration produced fractures with a half-length of 171 ft, width of 0.149 inches, height of 253.3 ft, and fracture conductivity of 13,592 mD.ft, resulting in a Fold of Increase (FOI) of 6.82. Economically, this scenario required a total cost of $574,576.47 and achieved a pay-out time (POT) of 48 days, with a net present value (NPV) of $3,534,073.21 after one year. This research highlights the technical and economic advantages of hydraulic fracturing in maximizing well productivity. It provides a detailed recommendation for future stimulation activities in Well X, emphasizing the balance between production enhancement and cost efficiency.
Analisis Kinerja Produksi Sumur LX Menggunakan Artificial Lift PCP dan SRP Serta Pendekatan Keekonomian Gunawan, Benny; Eklezia Dwi Saputri, Eriska; Triono, Agus
Journal of Sustainable Energy Development Vol. 3 No. 1 (2025): Journal of Sustainable Energy Development (JSED)
Publisher : Petroleum Engineering, Faculty of Engineering, University of Jember

Show Abstract | Download Original | Original Source | Check in Google Scholar

Abstract

In the oil industry, the main challenge is to maintain a stable oil production rate, especially when reservoir pressure decreases. Therefore, artificial lift methods are used to increase production rates. The LX well is one of the wells located in the Tarakan field, North Kalimantan, where at the beginning of production the Artificial Lift method had not been used. This study aims to analyze the production performance and economic aspects of the use of 2 artificial lift methods, namely Progressive Cavity Pump (PCP) and Sucker Rod Pump (SRP). The simulation results show that the flow rate increases with increasing operating speed and number of strokes per minute. The optimal speed for PCP is 400 rpm with a flow rate of 1668.14 STB/d, while for SRP, the optimal SPM is 22 with a flow rate of 1686.89 STB/d. The analysis of the economic calculation of the use of the PCP artificial lift method obtained a POT of 0.69 years. Calculation with DCA method, obtained IRR ranging from 132% - 133% and NPV ranging from $3,499,432 - $3,842,340. Based on the results of economic calculations from the use of the SRP artificial lifting method, the POT is 1 year. Calculation with the DCA method obtained IRR values ranging from 82% - 84% and NPV ranging from $1,661,827 - $2,008,573. These results indicate that this project is financially feasible.

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