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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 6 Documents
 1 
Search results for , issue "Vol. 1 No. 2 (2018): JEESET-VOL.1-NO.2-2018" : 6 Documents clear
Production of Bagasse-Based Natrium Ligno Sulfonat (Nals) Surfactant for Chemical Flooding Emmy Fatmi Budhya; Muhammad Taufiq Fathaddin; Sugiatmo Kasmungin
Journal of Earth Energy Science, Engineering, and Technology Vol. 1 No. 2 (2018): JEESET-VOL.1-NO.2-2018
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (272.759 KB) | DOI: 10.25105/jeeset.v1i2.3940

Abstract

Oil recovery may be increased by lowering interfacial tension between oil and water due to surfactant injection. Bagasse is one of the organic materials which has a fairly high lignin content, where lignin is the basic substance of making Natrium Lignosulfonate (NaLS) Surfactants. The research was divided into three sections. The first was experiment to produce lignin from bagasse. In this experiment 100 gram of bagasse with size of 60 mesh or 80 mesh extracted by benzene + ethanol (2:1) and then 20%, 50%, or 75% NaOH was added to activate lignin. The maximum amount of lignin produced was 24.88%. The second experiment was to produce NaLS surfactant from obtained lignin. FTIR equipment was used to verify the NaLS surfactant yielded using the method. The maximum amount of NaLS surfactant produced was 20.264% of bagasse mass. After that NaLS surfactant obtained from the previous process was used in chemical flooding experiment. In the experiments, the surfactant concentration in the solution was varied at 0.05%, 0.10%, 0.15%, and 1.00%. While temperature was set at 30°C, 40°C, 60°C, 70°C, or 80°C. The optimum condition happened when a solution with surfactant concentration of 1% was injected at 60°C. The recovery factor of oil using the condition was 0.47.
Field Case: Application of Polyamine Based Mud System to Drill Kintom Formation in Sulawesi and Comparison to Conventional KCl-Polymer Mud System Dominico Alphan Setyanto; Rachmat Sudibjo; Abdul Hamid
Journal of Earth Energy Science, Engineering, and Technology Vol. 1 No. 2 (2018): JEESET-VOL.1-NO.2-2018
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (367.647 KB) | DOI: 10.25105/jeeset.v1i2.3941

Abstract

Drilling mud has a vital role in onshore or offshore oil and gas drilling operations with its primary function as the hydrostatic pressure to balance the formation pressure. There are some formations in Indonesia where the drilling hazards are extensive, but the problem that most likely to overcome is the shale/clay swelling. Today there is a water based mud called Polyamine Mud, a Polyamine mud has the advantages over conventional water base mud and also in some functions are as good as the Oil Base Mud. Some companies are still trying to adopt this technology into their drilling projects with various aspects to be considered and are wondering whether it will help them to drill a formation with shale/clay problem characteristics. A field location on the island of Sulawesi has drilled some  wells on  the Kintom formation using the Polyamine mud for a total depth of about 7,000 ft – 9,000 ft. The drill hole problem was not only the shale/clay swelling, but was also followed by some problems such as differential sticking and partial to total mud losses. The wells have now been drilled successfully and the gas production was above expectation. This paper will discuss a comparison of the Polyamine mud with the conventional mud system such as KCL-Polymer mud by doing some unconventional tests in the laboratory, including inhibition test, dispersion test, accression test, and bulk hardness test. After being tested in the laboratory, the Polyamine 3% mud system has drilled succesfully in some wells.
Determination of Rock Type Using Hydraulic Flow Unit Concept to Predict Permeability with Artificial Neural Network Ghanima Yasmaniar; Ratnayu Sitaresmi; Suryo Prakoso
Journal of Earth Energy Science, Engineering, and Technology Vol. 1 No. 2 (2018): JEESET-VOL.1-NO.2-2018
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (501.628 KB) | DOI: 10.25105/jeeset.v1i2.3942

Abstract

Permeability is one of the important of reservoir characteristics, but is difficult to predict it. The accurate permeability values can be obtained from core data analysis, but it is not possible to do at all of the well intervals in the field. This study used 191 sandstone core samples from the Upper Cibulakan Formation in the North West Java Basin. The concept of HFU (Hydraulic Flow Unit) developed by Kozeny-Carman is used to generate the relationship between porosity and permeability for each rock type. Afterward, to estimate the permeability value at uncored intervals, the statistical methods of artificial neural network based on log data are used on G-19 Well, G Field which is located in the North West Java Basin. Based on core data analysis from this research, the reservoir consists of eight HFU with different equations to estimate permeability for each HFU. From this reserarch, the results of permeability calculations at uncored intervals are not much different from the core data at the same depth. Therefore the approach of permeability prediction can be used to determine the value of permeability without performing core data analysis so that it can save the company expenses.
The Effect of Interfacial Tension and Thermal Stability on Surfactant Injection Aqlyna Fattahanisa; Rini Setiati; Sugiatmo Kasmungin
Journal of Earth Energy Science, Engineering, and Technology Vol. 1 No. 2 (2018): JEESET-VOL.1-NO.2-2018
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (286.186 KB) | DOI: 10.25105/jeeset.v1i2.3944

Abstract

In this research, bagasse NaLS surfactant was used as an injecting reservoir fluid at low salinity. The purpose of this study was to observe the effect of IFT and thermal stability on oil recovery factors in various compositions. The material used in this study isbagasse based NaLS surfactant, light oil and sandstone, while spinning drop is used to measure the interface tension. The oven was used for thermal stability testing and core flooding equipment for the surfactant injection. The success in this study was based on the value of the recovery factor, the small IFT value, and stability of IFT in the thermal stability test. The IFT results obtained for CF1, CF5,and CF7 were 10.4 mN / m, 4.09 mN / m, and 4.34 mN / m, respectively. Based on The results of the thermal stability test only the CF7 was stable with an IFT value of 2.11 mN / m, while the other two variations were unstable. The recover factor of CF1, CF5, and CF7 was 3.24%, 3.52%, and 5.34%, respectively. It can be concluded that IFT as well as thermal stability affect the frecovery factor.
Aerated Drilling Optimization in Geothermal Well Drilling in Field “X” Cluster “Y” Raka Aditya Pratama; Astra Agus Pramana; Bambang Kustono
Journal of Earth Energy Science, Engineering, and Technology Vol. 1 No. 2 (2018): JEESET-VOL.1-NO.2-2018
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (516.452 KB) | DOI: 10.25105/jeeset.v1i2.3945

Abstract

Aiming for productive fault in Suban Agung Rim, Field X Cluster Y Bengkulu Province, Indonesia, PT Pertamina Geothermal Energy (PGE) drilled some wells to discover the potential awaited. However there are challenge awaits each meter ahead especially in reservoir sections where loss circulation is expected. Knowing the risk, PGE decided to drill the well utilizing aerated drilling. The method has known for decades to be the most effective approach in dealing loss circulation. The method applies certain value of compressed air to be injected in fluid stream, so bubbling process can be achieved in order to reduce the mud weight. The method has benefit to maintain ROP and minimize the risk for pipe get stuck due to poor hole cleaning in fractured formation. There are three wells drilled in Field X Cluster Y which has the same problem in 9-7/8” section; all experienced stuck pipe while drilling. During the process aerated drilling was utilized, however it was not sufficient. This paper will discuss and explain on how the occurrence happened and what to do next in similar condition to avoid the problems.
Flare Gas Recovery System Using Integrated Reciprocating Compressor in Gathering Station C Tamado Sitorus; Ratnayu Sitaresmi; Hari Hari Oetomo
Journal of Earth Energy Science, Engineering, and Technology Vol. 1 No. 2 (2018): JEESET-VOL.1-NO.2-2018
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (377.416 KB) | DOI: 10.25105/jeeset.v1i2.3946

Abstract

Flare gas recovery is needed to handling gas flares in oil and gas fields. Field C production wells experience a decline as a result the gas flow pressure in the wellhead becomes low. Low pressure gas enters the LP separator then is burned as a gas flare containing CO2 of 33.38 mol and GHV of 1048.9 BTU / ft3. The flare gas recovery system is applied to reduce gas flares with the integrated reciprocating compressor unit for compression at suction pressure ± 10 psig, discharge pressure ± 100 psig and total flowrate ± 1 MMSCFD. Then the CO2 removal plant produces gas with a CO2 content of 7.09% mol and GHV of 1314.9 BTU / ft3. During operation, requires gas fuel ranging 11 MSCFD and the actual power ranges from 36.46 HP and 39.64 BHP. Economic aspects analysis, gas flare monetization for the period of 2015 until 2022, gross reserves 2,062,917 MMBTU and gross income of US$ 6,026,744. The operating cost of the the lease purchase scheme, the government US $ 2,079,696 and the contractor US $ 1,386,464 with POT 1.7 years and IRR 151.5%.

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