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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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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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Modeling of Shrimp Chitosan Polymer Adsorption Using Artificial Neural Network Fathaddin, Muhammad Taufiq; Mardiana, Dwi Atty; Sutiadi, Andrian; Maulida, Fajri; Ulfah, Baiq Maulinda
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 2 (2024): JEESET VOL. 7 NO. 2 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/jeeset.v7i2.21134

Abstract

One phenomenon that can occur when a polymer solution is injected into an oil reservoir is adsorption. Adsorption occurs due to interactions between polymer molecules and the reservoir pore surface. Adsorption causes some polymer molecules to be removed from solution. So, this process results in a reduction in the polymer concentration in the solution. In this study, an artificial neural network (ANN) model is used to estimate the adsorption of shrimp chitosan polymer on the surface of 40 mesh and 60 mesh sand grains. The ANN model can estimate adsorption more accurately than previous models. This is because previous models only predicted certain adsorption patterns, while the ANN model is able to predict adsorption with complex relationships. The comparison of the mean absolute relative errors (MAREs) of the ANN, Langmuir, Freundlich, Henry, and Harkins-Jura models is 5.7%, 15.9%, 14.6%, 15.2%, and 14.5%, respectively.
Promising Accurate Equation of State Models for High-Pressure, High-Temperature Wells Babalola, Faith; Olasesan, Ibukunoluwa
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 2 (2024): JEESET VOL. 7 NO. 2 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/hatayg77

Abstract

This study analyzed and compared promising Equation of State models for High-Pressure High-Temperature (HPHT) well applications. The study examined four fluid phase behavior Equation of State (EOS) models namely, (Peng-Robinson (PR), Cubic-Plus-Association (CPA), Perturbed-Chain Statistical Associating Fluid Theory (PC-SAFT) and Peng-Robinson-Babalola-Susu (PRBS). Their strengths, weaknesses, and computational efficiencies in calculating molar volumes with pressure change were rigorously analyzed using the Python program for five reservoir fluid systems: WELL 1, WELL 2, WELL 3, WELL 4 and WELL 5. PRBS, PC-SAFT, and CPA showed accurate predictions at specific high-pressure ranges between 90 and 160 MPa on the average, PRBS exhibited the lowest percentage Absolute Average Deviation (%AAD) of 21.0, followed by PC-SAFT with 28.0, followed closely by CPA with 31.8 while PR was shown to be totally unapplicable to high pressure reservoir systems as it had a %AAD of 125.4.
Analysis of the Effect of Inorganic Compound Nano Ferric Oxide (Fe2O3) on Increasing Cement Strength Novrianti, Novrianti; Deswanto, Jefri; Khalid, Idham; Pandjaitan, M. M Lanny W.; Lukas
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 2 (2024): JEESET VOL. 7 NO. 2 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/jeeset.v7i2.20152

Abstract

The objectives of this research are to analyze the inorganic compound nano-Fe2O3 ironstone for enhancing the compressive and shear bond strength of drilling cement. According to the American Petroleum Association (API), the minimum recommended compressive strength value to continue drilling operations is 500 psi, while the minimum shear bond strength is 100 psi. Nano-Fe2O3 in this study was obtained by synthesizing ironstone from Jorong, West Sumatra, using the coprecipitation method. Based on XRF and XRD tests, 62.8% Fe was obtained in the ironstone compound, and nano-Fe2O3 with the alpha phase was detected using Match 3. Five samples with different concentrations were prepared before starting the cement strength test. The test was conducted following the bio-axial loading test procedure, where each sample will be loaded with a certain amount of load force until the sample breaks. The pressure at the point where the sample broke was recorded as the maximum loading value to determine the compressive strength (CS) and shear bond strength (SBS). The highest CS value obtained was 2536.2953 psi with the addition of 1% nano-Fe2O3, and the highest SBS value obtained was 351.8479 psi with the addition of 1% nano-Fe2O3.
Comparison of Determining Oil Reserves in Reservoir Z Based on Volumetric Methods, Material Balance, and Decline Curve Analysis Azzahra, Baiq Maulida; Rahalintar , Pradini
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 3 (2024): JEESET VOL. 7 NO. 3 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/4djrch37

Abstract

This study was conducted at Reservoir Z, an oil well in East Kalimantan, known as one of the largest producers in the area with a production rate of 500 BOPD. Determining the oil reserves in this new production well is crucial, as well as using volumetric and material balance methods to estimate the initial oil in place. The volumetric method calculated an Original Oil in Place (OOIP) of 0.197596.080 MMSTB, while the Material Balance method estimated 0.2075 MMSTB. The 5% difference between the two methods indicates their accuracy in determining OOIP. The study also examines the dominant drive mechanism. Using the Material Balance-Havlena Odeh method with the drive index, it was found that the dominant drive mechanism in Reservoir Z is the Solution Drive, with gas expansion in the oil playing a significant role in pushing oil to the production well. To predict future well performance, the Decline Curve Analysis method was used. The results showed an economically recoverable cumulative production of 130,938.94 STB, and the well can be produced for 3 years and 2 months. The recovery factor at Reservoir Z, indicating the amount of producible oil compared to the initial amount, is 81%. This study provides essential information for managing the oil well in Reservoir Z and understanding its reserve potential better.
Optimizing of Electrical Submersible Pump with Stage Variation Using Nodal Analysis at “Rha” Well, Cepu Field for Enhancing Oil Production Aditya, Rhera; Rohmana, Rian Cahya; Budiono
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 2 (2024): JEESET VOL. 7 NO. 2 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/jeeset.v7i2.20896

Abstract

Well “Rha”, located in Cepu Field, is an old well that no longer produces oil naturally (natural flow), so an artificial lift is needed to produce oil. The artificial lift method used in this well is an electrical submersible pump. The well has a maximum flow rate of 1016.04 BFPD with a water cut of 98.2%, indicating a significantly high proportion of water in the flow. The installed pump in this well is REDA DN450/42 Hz, with an operating range of 246–383 BFPD. The evaluation showed that the head pressure exceeded the maximum operating range, causing an upthrust. This research aims to optimize the installed pump by replacing it and performing nodal analysis to obtain the stage that matches the optimum flow rate. This study applied the Wiggins IPR method to calculate the well's maximum flow rate. The study identified and troubleshot performance issues with the existing pump and applied nodal analysis to optimize production. The optimal production rate in this well is 609.62 BFPD, which operates outside the DN450 pump's recommended operating range. Therefore, optimization was carried out using a new pump in the field DN750/42 Hz with 171 stages. Subsequent nodal analysis showed that 124 stages, with a horsepower of 10.01 HP and a pump efficiency of 56.42%, aligned with the optimal production rate. With a water cut of 98.2%, the initial oil rate was 5.2 barrels of oil per day (BOPD), which increased to 10.94 BOPD after optimization. This research demonstrates that optimization by adjusting the stages of ESP can achieve optimal production rates.
Investigation of the Impact of Wellbore Trajectory on the Onset of Liquid Loading Kinate, Bright; Epelle, Somiari
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 2 (2024): JEESET VOL. 7 NO. 2 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/jeeset.v7i2.21112

Abstract

Liquid loading phenomenon and the influencing factors requires adequate investigation to avoid it and continue production without dropout. It is important to accurately predict liquid loading at an early stage and also when and where it starts to occur in the well in order to put together a suitable solution to combat it. In this work, the impact of wellbore trajectory on the onset of liquid loading in gas wells was investigated. Numerical simulation approach was adopted with two case scenarios of a wellbore model, “trajectory_1” inclined at 45.33° and a second wellbore model “trajectory_2” inclined at 46.39° were created and simulated for the different trajectories. At the start of production, the gas production rate was 0.703794MMscf/day for well with trajectory_1 and 0.703819 MMscf/day for well with trajectory_2. Result shows that for a period of 24hrs, the liquid production rate from well with trajectory_1 was lower than that from well with trajectory_2. Also, the liquid holdup of the well with trajectory_1 was higher than the well with trajectory_2 over a duration of 9.6hrs. A high wellbore inclined angle increased the liquid production rate and results in a reduction in liquid loading.
Adsorption Modeling of Amorphophallus oncophyllus Prain Using Artificial Neural Network Sutiadi, Andrian; Mardiana, Dwi Atty; Fathaddin, Muhammad Taufiq
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 3 (2024): JEESET VOL. 7 NO. 3 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/qagty424

Abstract

Adsorption is the process of interaction between a liquid and a solid surface. It happens because of physical forces or chemical bonds, which moves substance molecules dissolved in a liquid to the solid surface. As a result, the concentration of the substance in the solution drops. In this study, an artificial neural network (ANN) was applied to model the adsorption of Amorphophallus oncophyllus Prain and xanthan gum on sand grains with sizes of 40 mesh and 60 mesh. Two ANN models were developed. The first ANN model was used to predict the final concentration of the polymer solution after the adsorption process. This model had a correlation coefficient for the training, validation, and testing phases of 0.9968, 0.9982, and 0.9990, respectively. Meanwhile the second ANN model was used to predict the adsorbed polymer. This model had a correlation coefficient for the training, validation, and testing phases of 0.9984, 0.9996, and 0.9985, respectively. These models were capable of accurately predicting the final concentration and adsorbed polymer when compared to laboratory data.
Optimization of Well Placement Based on Reservoir Fluid Contact Irawan, Sonny
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 3 (2024): JEESET VOL. 7 NO. 3 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/6bwf7771

Abstract

The development of oil fields was often troubled with the predicament of figuring the optimum well location, been it vertical or horizontal wells. The process of hydrocarbon resources extraction from a reservoir which was economically effective is required for producers and injectors to drilled and positioned at an optimal location. One of the contributing factors of decided an optimized location of well is reservoir fluid contact, gas-oil contact (GOC) and oil-watered contact (OWC). Reservoir overlying a strong aquifer typically had high watered cut thus impairing oil production rate also, leads to water coning. The optimized location of well could have affected by water coning mechanism in oil-water and gas-water system differently due to the density difference of the hydrocarbon. Water coning due to increased water cut in the OWC region is the most common phenomena therefore, the purpose of this studied is to observed water cut increment along production period. Besides, monitoring downhole well constraint in water cut and production rate estimation could also be done in ordered to estimate optimal location or placement of horizontal well with respect to GOC and OWC. Vertical and horizontal well placement is simulated with varying downhole constraints to ensured efficient production rate of hydrocarbon. Therefore, estimation of water cut and breakthrough timed is conducted after increased in water cut thus, oil production rate and oil recovery factor against water cut increment could be generated to illustrate which well showed highest productivity and efficiency.
Analysis of Polyamine Polymer and KCl Polymer Mud Properties in Brine at Various Temperatures Meier, Carolyn Rose; Prapansya, Onnie Ridaliani; Husla, Ridha
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 3 (2024): JEESET VOL. 7 NO. 3 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/zra98494

Abstract

Drilling mud is an essential element in oil and gas well drilling operations. With primary functions such as lifting cuttings to the surface and maintaining borehole stability, it plays a vital role in ensuring a smooth and successful drilling process. The major challenge in drilling operations is dealing with reactive clay or shale formations that are susceptible to clay swelling and formation damage. To overcome this problem, high-performance water-based muds, such as KCl and Polyamine polymer muds, have been developed. Laboratory studies were conducted to test the physical properties of the muds at temperatures of 80 ˚F, 200 ˚F, and 250 ˚F for 16 hours using a hot roller. Tests included density, viscosity, rheology, and plastic viscosity. The mud composition was equalized at all temperatures to assess comparative performance. The results showed a decrease in the physical properties of polyamine polymer and KCl polymer muds with increasing temperature. To maintain the performance of the mud at high temperatures, additional treatment with additives were required. Barite, PAC LV, XCD, and PHPA were the additives introduced to the polymer KCl and polyamine mud in this experiment. It took 45 grams of barite in total to reach the necessary density requirements. For polyamine mud, 1.5 grams of PAC LV and for polymer KCl mud, 3.5 grams of PAC LV were needed to reach the necessary viscosity requirements. In the meantime, 1.5 grams of XCD and 2.5 grams of PHPA were needed to achieve the plastic viscosity requirements for polyamine mud, and 1 gram of XCD and 2 grams of PHPA were needed for polymer KCl mud.
Integration of Empirical Methods for Accurate Water Saturation Calculation in Low Resistivity Reservoir Citrowati, Sekar Ayu; Dedy Irawan; Pahala Dominicus Sinurat
Journal of Earth Energy Science, Engineering, and Technology Vol. 7 No. 3 (2024): JEESET VOL. 7 NO. 3 2024
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/6qfar389

Abstract

The Indonesian oil and gas industry faces significant challenges in exploring low-resistivity reservoirs, such as the Talang Akar Formation in South Sumatra, the Tanjung Formation in East Kalimantan, and the Gumai Formation in South Sumatra and West Java. These reservoirs often contain clay, clayey sand, and conductive minerals, which complicate geophysical log interpretation, leading to missed hydrocarbon potential. Common methods such as Archie’s Law are often used to calculate water saturation but tend to be inaccurate in formations with high conductivity due to clay content. The Simandoux method attempts to address this limitation by considering the conductivity of clay, but the assumption of homogeneous clay distribution often does not match actual conditions. This study proposes a modification to the Simandoux method by accounting for the non-linear behavior of clay conductivity and formation-specific parameters derived from core analysis. This approach integrates multi-parameter log data and advanced petrophysical models to address mineralogical heterogeneity and clay distribution. The results show that the modified Simandoux method provides more accurate water saturation estimates in low-resistivity zones. Validation with core and production data demonstrates the improved reliability of this model, supporting optimal field development and hydrocarbon exploration in Indonesia.

Page 11 of 13 | Total Record : 121

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