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Petro : Jurnal Ilmiah Teknik Perminyakan
Published by Universitas Trisakti
ISSN : 19070438     EISSN : 26147297     DOI : https://doi.org/10.25105/petro.v11i2.14060
Core Subject : Economy, Science, Engineering,
Earth & Planetary Sciences Economics, Econometrics & Finance Energy Engineering
The PETRO Journal is all about the upstream oil and downstream oil and gas industry. Upstream studies focus on production technology, drilling technology, petrophysics, reservoir study, and eor study. Downstream technology focuses on the oil process, managing surface equipment, geothermal, and economic forecast.
Arjuna Subject : Ilmu Bumi dan Planet (semua kategori) - Geokimia danPetrologi
Articles 301 Documents
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ANALISIS PENYEBAB RESERVOIR RESISTIVITAS RENDAH PADA LAPISAN BATUPASIR FORMASI TALANG AKAR CEKUNGAN SUNDA ASRI DAN SUMATERA SELATAN Octavia, Dea; Rian Cahya Rohmana; Widi Atmoko
Petro : Jurnal Ilmiah Teknik Perminyakan Vol. 13 No. 2 (2024): Juni 2024
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/petro.v13i2.19686

Abstract

This research area is an oil and gas field characterized by low-resistivity zones in the Talang Akar Formation of the Sunda Asri and South Sumatra basins. The formation's lithology comprises sandstone, claystone, shale, and interspersed limestone, all deposited in a shallow marine environment. The objective of conducting petrophysical analysis is to identify the potential of the formation, particularly its low-resistivity reservoirs. The research utilizes well log, core, mud log, petrography, X-ray diffraction (XRD), and biostratigraphy data. Analysis of these data yields Gamma Ray logs, Resistivity logs, and Porosity logs, which include neutron log porosity (NPHI) and density porosity (RHOB). Several factors contribute to the low resistivity of reservoirs in this area, including the presence of clay minerals like kaolinite, chlorite, and illite in the Talang Akar formation, which interfere with low resistivity readings. The occurrence of conductive minerals such as pyrite, biotite, and tourmaline, the high salinity of formation water (>10,000 ppm), classified as High Saline Water, the fine to medium grain size of the sand (0.063 – 0.5 mm) which can retain formation water (irreducible water), leading to low resistivity readings, and the thickness of the rock layers, as evidenced by the depositional environment of the Talang Akar Formation, ranging from the upper delta plains to the lower delta plains, are also influential factors.
PENENTUAN SISA CADANGAN GAS MENGGUNAKAN METODE LOSS RATIO DAN TRIAL ERROR & X2-CHISQUARE TEST SUMUR “M” LAPANGAN “N” Prasetyaningrum, Herdiana; Ibrahim, Adytia Tri; Amanilutfie, Fajar
Petro : Jurnal Ilmiah Teknik Perminyakan Vol. 13 No. 2 (2024): Juni 2024
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/petro.v13i2.19696

Abstract

Sumur “M” merupakan sumur yang dimiliki oleh PT. Minarak Brantas Gas Inc. Sumur tersebut sudah memproduksikan gas selama belasan tahun. Oleh karena itu, perlu diketahui kembali jumlah cadangan yang ada sehingga perusahaan dapat mengetahui lamanya sumur tersebut untuk diproduksikan secara akurat. Penelitian ini bertujuan untuk menghitung sisa cadangan gas yang ada di dalam reservoir dan menentukan sisa waktu yang dibutuhkan untuk memproduksikan sumur secara ekonomis menggunakan Decline Curve Analysis. Metode yang digunakan adalah metode Loss Ratio dan Trial Error & X2 - Chisquare Test. Hasil analisis yang didapatkan, yaitu pada Sumur “M” terdapat sisa cadangan gas sebesar 4,45 Bscf. Metode yang paling tepat untuk penentuan tipe decline pada kasus Sumur “M“ adalah metode Trial Error & X2 -Chisquare Test. Metode tersebut dapat menentukan jenis decline nya dibandingkan metode Loss Ratio. Tipe decline pada kasus sumur penelitian, yaitu Harmonic decline. Dari hasil perhitungan didapatkan bahwa Sumur “M” masih dapat diproduksikan sampai batas ekonomisnya dalam kurun waktu 17,5 tahun. Selain itu, didapatkan nilai Recovery Factor-nya sebesar 71,910%, nilai Estimated Ultimate Recovery sebesar 3197,532 Mmscf, dan nilai Estimate Recoverable Recovery 1154,49183 Mmscf.
ANALYSIS OF BLOWOUT PREVENTER MAINTENANCE PERFORMANCE ON RIG #55 AND RIG #99 BASED ON DEGRADATION TEST DATA IN "DERE" FIELD: ANALISIS PERFORMANCE MAINTENANCE BLOWOUT PREVENTER PADA RIG #55 DAN RIG #99 BERDASARKAN DATA DEGRADATION TEST DI LAPANGAN “DERE” Tampoy, Divtara; Setiyaningrum, Priskila Rully; Kadarisman, Muhammad
Petro : Jurnal Ilmiah Teknik Perminyakan Vol. 13 No. 2 (2024): Juni 2024
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/petro.v13i2.19826

Abstract

Blowout Preventer (BOP) digunakan untuk mengatasi risiko semburan liar dengan menutup sumur sebelum terjadinya semburan. Penelitian ini akan menganalisis masalah yang terjadi pada BOP di Rig #55 dan Rig #99 di Lapangan “DERE” menggunakan metode performance maintenance. Data yang digunakan untuk menganalisis kinerja BOP di kedua Rig tersebut adalah data degradation test. Metode performance maintenance akan menghitung MTBF (Mean Time Between Failures), MTTR (Mean Time To Repair), serta availability. Selain itu, akan dilihat penyebab penurunan kinerja dan memberikan rekomendasi optimalisasi perawatan BOP dengan menggunakan diagram fishbone. Hasil analisis menunjukkan bahwa selama beroperasi pada periode tahun 2023 Rig #55, nilai MTBF adalah 11520 menit, MTTR adalah 2160 menit, availability 89%. Rig #99, nilai MTBF adalah 18.720 menit, MTTR adalah 1440 menit dan availability 92%. Sedangkan Rig #99 di tahun 2021 nilai MTBF adalah 40320 menit, MTTR adalah 1440 menit, availability 96%. Faktor kemunduran yang terjadi pada Rig #55 dan Rig #99 dipengaruhi oleh packing element, sehingga perlu dilakukan pengecekan dan penggantian sesuai dengan jam operasionalnya. Aspek lingkungan tempat kerja, kurangnya kebersihan area BOP, usia part yang sudah usia, prosedur pengantian part belum berjalan efektif dan faktor manusia kurang konsentrasi dan kurangnya kepedulian terhadap SOP menyebabkan penurunan kualitas pada BOP.
ANALISIS PENGARUH KULIT BIJI BUNGA MATAHARI SEBAGAI VISCOSIFIER PADA LUMPUR BERBAHAN AIR TAWAR PADA SUHU 80oF dan 200oF Waropen, Rika Maharani; Wastu, Apriandi Rizkina Rangga; Yulia, Prayang Sunny
Petro : Jurnal Ilmiah Teknik Perminyakan Vol. 13 No. 4 (2024): Desember 2024
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/petro.v13i4.20533

Abstract

Pemboran termasuk ke dalam proses penting dalam industri minyak dan gas bumi. Operasi pemboran dapat dilakukan dengan menggunakan fluida pemboran. Fluida pemboran ini dikenal juga dengan lumpur pemboran, lumpur terdiri dari berbagai komponen penyusun salah satu contohnya yaitu polimer. Tujuan: Penelitian ini bertujuan untuk melakukan percobaan pembuatan lumpur berbahan dasar air dengan tambahan aditif kulit biji bunga matahari, kemudian dianalisis pengaruh penambahan terhadap sifat fisik yang berhubungan dengan kekentalan suatu fluida pemboran seperti viskositas, plastik viskositas, yield point, dan gel strength. Metode yang digunakan adalah eksperimen di laboratorium dengan hasil akhir berupa data kuantitatif. Komposisi aditif kulit biji bunga matahari yang digunakan 2, 4, 6, dan 8 gram dengan pengaruh temperatur 80oF dan 200oF. Hasil kegiatan penelitian ini didapatkan nilai viskositas sebesar 26 – 55 sec/quartz pada temperatur 80oF dan 23 – 50 sec/quartz pada temperatur 200oF. Selanjutnya nilai plastik viskositas sebesar 15 – 20 cps pada temperatur 80oF dan 13-17 cps pada temperatur 200oF. Pada sifat fisik yield point nilai 10 – 20 lb/100sqft pada temperatur 80oF, dan 9-19 lb/100sqft pada temperatur 200oF. Pada sifat fisik gel strength didapatkan nilai gel strength 10 detik memiliki nilai 5 – 12 lb/100sqft pada temperatur 80oF dan 3 – 10 lb/100sqft pada temperatur 200oF, berikutnya nilai gel strength 10 menit sebesar 7 – 19 lb/100sqft pada temperatur 80oF dan 5 – 17 lb/100sqft pada temperatur 200oF. Kesimpulan: Kenaikan nilai viskositas, plastik viskositas, yield point dan gel strength diakibatkan oleh adanya kandungan kimia yaitu 42.7% selulosa, Hemiselulosa 24%, dan lignin 23,2% pada kulit biji bunga matahari sebagai partikel penyusun secara signifikan sehingga lumpur menjadi lebih viscous.
STUDI LABORATORIUM INJEKSI MES KONSENTRASI RENDAH PADA BATUAN SANDSTONE DI SUHU 60ᵒC Pratama, Putra; Pauhesti; Pramadika, Havidh; Wijayanti, Puri; Widyayanti
Petro : Jurnal Ilmiah Teknik Perminyakan Vol. 13 No. 4 (2024): Desember 2024
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/petro.v13i4.20572

Abstract

Penurunan produksi minyak seiring perkembangan waktu akan semakin menurun. Salah satu metode yang dapat dilakukan untuk mengatasi hal tersebut adalah Enhanced Oil Recovery (EOR). Penelitian ini akan berfokus pada metode injeksi surfaktan dengan menggunakan surfaktan anionik, yaitu MES (Methyl Ester Sulfonate) dengan variasi konsentrasi 0,5; 0,7; 0,9; 1,1; dan 1,3% di suhu 60ᵒC. Tujuan: Penelitian ini bertujuan untuk mengetahui keefektifan surfaktan MES dalam meningkatkan perolehan minyak. Metodologi dan hasil: Dalam penelitian ini terdapat beberapa parameter yang diuji sebelum masuk ke tahap injeksi surfaktan untuk melihat kecocokan surfaktan MES terhadap kondisi reservoir, pengujian tersebut antara lain: uji densitas dan SG (specific gravity),viskositas, kelakuan fasa. Selain itu ada pengujian tegangan antarmuka (IFT) dan uji core batuan. Dari uji kelakuan fasa yang dilakukan diperoleh hasil bahwa adanya emulsi fasa atas yang terbentuk pada konsentrasi 1,1 dan 1,3%. Berdasarkan hasil tersebut sampel dengan konsetrasi 1,3% dipilih untuk pengujian tegangan antarmuka dan diperoleh nilai IFT sebesar 6,51-E01 dyne/cm. Untuk uji core batuan, beberapa data telah diketahui permeabilitas, porositas, volume bulk, Volume pore, diameter dan tinggi. Penelitian dilanjutkan ke tahap saturasi brine 9000 ppm dan saturasi minyak untuk mengetahui nilai Originial Oil In Place (OOIP), kemudian proses injeksi dapat dilakukan untuk memperoleh nilai Recovery Factor (RF). Kesimpulan: dari pengujian coreflood yang dilakukan diperoleh nilai RF untuk waterflooding sebesar 55% dan untuk surfactantflooding menggunakan MES 1,3% sebesar 5%.
STRATEGI PENINGKATAN PRODUKSI MINYAK: OPTIMASI SUMUR ESP, PEMILIHAN TEKANAN SEPARATOR DAN PENAMBAHAN POMPA SENTRIFUGAL DI JARINGAN PIPA LAPANGAN J SUMATERA SELATAN Pedraza, Putri Rizkika Ramadhanti
Petro : Jurnal Ilmiah Teknik Perminyakan Vol. 13 No. 4 (2024): Desember 2024
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/petro.v13i4.21428

Abstract

Field J, managed by PT Medco E&P Indonesia, is an old oil field in the Baturaja Carbonate Formation with a water cut of up to 99%. The objective is to maximize the reservoir capacity in Field J through various production optimization scenarios, both at the single-well level and within the pipeline network. First, a single-well model is created using software and matched until the error is less than 5%. Wells are identified based on the capacity of the existing pump relative to the reservoir capacity. If the existing pump capacity is sufficient, the Size Up method is applied. If not, a new pump design with a larger capacity is created. The optimized single-well model is then incorporated into a network simulation. Pipeline network optimization is carried out with two scenarios: reducing separator pressure and adding pumps, as well as analyzing differential pressure sensitivity to determine the optimal value. The total fluid flow rate from the initial 12 wells was 21,360.30 STB/d. After single-well optimization, the flow rate increased to 48,801.36 STB/d, an increase of 128.47%. Pipeline network optimization, by reducing separator pressure from 44 psig to 15 psig, resulted in an increase of 0.98%, from 48,111.49 STB/d to 48,518.98 STB/d. Adding pumps to the surface facilities increased the flow rate by 1.86%, from 48,518.98 STB/d to 49,422 STB/d at an optimal differential pressure of 150 psi. The simulation results indicate that the proposed production optimization scenarios can increase the fluid flow rate in Field J from 21,360.30 STB/d to 49,422 STB/d, with a percentage increase of 131.38%.
PENENTUAN KAPASITAS SIMPAN SHALE GAS PADA SUMUR “R26”, LAPANGAN “RKO Ohorella, Ramdhan; Effendi, Dahrul; Triaji, Nandang
Petro : Jurnal Ilmiah Teknik Perminyakan Vol. 13 No. 4 (2024): Desember 2024
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/petro.v13i4.21429

Abstract

Global demand for oil and gas is projected to increase by 6% from 2022 to 2028, reaching 105.7 million barrels per day (bopd), driven by strong demand from the petrochemical and aviation sectors. Consequently, exploration is needed to discover new oil and gas reserves, with attention shifting to unconventional resources, considering the depletion and challenges in finding conventional reserves. This study aims to analyze the adsorption behavior of five shale rock samples from the "RKO" field, well "R26," determine the maximum adsorption values using Langmuir isotherm modeling, and evaluate the effect of depth on adsorption capacity. The data used in this research includes proximate analysis and adsorption isotherm data to illustrate the adsorption curves that occur in the samples. Based on the test results, it was found that the five shale samples from well "R26," namely samples RM-001, RM-002, RM-003, RM-004, and RM-005, follow a Type 1 adsorption isotherm pattern, where the amount of adsorbate increases linearly with increasing pressure. Furthermore, the Langmuir isotherm modeling results for the samples indicate a maximum adsorption pressure of 2851 psi, with maximum adsorption volumes of 2.35 m³/t for RM-001, 2.44 m³/t for RM-002, 2.42 m³/t for RM-003, 2.48 m³/t for RM-004, and 2.42 m³/t for RM-005. The test results also show that depth variation does not affect the volume and adsorption capacity.
ANALISIS ESTIMASI  VOLUME COMBINED CRUDE OIL DALAM PROSES TRANSFER FEED DENGAN METODE QUANTITY ACCOUNTING SYSTEM Dian Pertiwi, Permata
Petro : Jurnal Ilmiah Teknik Perminyakan Vol. 13 No. 4 (2024): Desember 2024
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/petro.v13i4.21464

Abstract

The QAS method combines tank level measurements, oil density, temperature, BS&W content to provide accurate volume estimates. The QAS method ensures that the calculation of the volume of crude oil to be transferred is in accordance with the required standards, thus supporting efficient operations and quality control of the final product. The calculation results of the QAS method are then compared with the results of flowmeter measurements to identify the suitability and potential differences in volume estimates. This study aims to assess the reliability of the QAS method in calculating the volume of crude oil and comparing it with data obtained from the flowmeter during the transfer process. From the analysis results, it was found that the difference in the results between the combined crude oil estimates obtained from the QAS method and the results of direct measurements in the field of PT. KPI RU IV OM 70 Cilacap showed discrepancies of 1.36% for the QAS calculation and 1.38% for the actual measurement in barrels. This shows that the calculation method used in the QAS is able to calculate correction factors accurately, such as temperature and density, so that it approaches the actual volume measured in the field. This study shows that the QAS method is able to provide more comprehensive and reliable volume estimates, especially in the context of density variations and environmental conditions that affect oil volume.
OPTIMASI PRODUKTIVITAS SUMUR X MELALUI ANALISIS PENGGUNAAN SISTEM GAS LIFT DENGAN PENDEKATAN SOFTWARE KOMERSIAL Erlely, Roberth; Chandra, Steven; Silahooy, Stevi
Petro : Jurnal Ilmiah Teknik Perminyakan Vol. 13 No. 4 (2024): Desember 2024
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/petro.v13i4.21594

Abstract

Decreased well productivity is a common problem in the petroleum industry caused by decreased flow rates and reservoir pressure. One solution to overcome this problem is the use of artificial lift, namely the gas lift method. Gas lift is a method that injects high-pressure gas into the well to reduce hydrostatic pressure, allowing the fluid to rise to the surface. This study aims to analyze the effectiveness of the gas lift system in increasing the productivity of well X using commercial software. The method used in the research is a quantitative method with the help of commercial software used as a data processing tool. The results showed that the optimum production rate that can be achieved at well X is 378.32 STB/day with an optimum gas injection rate of 0.3 MMscf/day. In addition, several parameters affecting well productivity were analyzed, namely water cut, reservoir pressure, and gas injection rate where it was found that every 10% increase in water cut caused a decrease in production of 40-43 STB/day, while a decrease in reservoir pressure to 500 psig decreased production from 435.5 STB/day to 162.3 STB/day. Increasing the gas injection rate is proven to increase oil production, but there is an optimal limit to avoid increasing operational costs that are not balanced with increased production.
EVALUASI FLUID ABOVE PUMP UNTUK OPTIMASI ELECTRICAL SUBMERSIBLE PUMP PADA LAPANGAN SLN Kurniadi, Ahmad Dzikri; Rahmawan, Sigit; Widiyatni, Harin
Petro : Jurnal Ilmiah Teknik Perminyakan Vol. 14 No. 1 (2025): Maret 2025
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/petro.v14i1.17392

Abstract

The SLN field is a field that has several fields and produces fluids using artificial lift, specifically electrical submersible pumps (ESP). The objective of this research is to obtain the latest recommended value for fluid above the pump (FAP) by evaluating the FAP in each field within the SLN field. This will help determine the minimum fluid above the pump as a reference for future operations in the SLN field. In this study, the method used to calculate the fluid above the pump involves interpolating the FAP data with casing pressure, gas production, and gas-oil ratio (GOR) data. This is done to obtain the best regression graph and determine the minimum FAP value. Based on the research conducted on the evaluation of fluid above the pump in the Dik 01 and Dik 02 fields, the results for the Dik 01 field indicate that when the FAP is low, the gas production rate (Qg) and GOR are also low, indicating the absence of free gas. Conversely, when the FAP is high, there is an indication of free gas. The minimum FAP values obtained for the Dik 01 field are 1918 ft for Qg (Mscf/d) and 1967.44 ft for GOR (scf/stb). The results for the Dik 02 field show that a high FAP value corresponds to a low Qg and GOR, indicating the absence of gas. Conversely, a low FAP value corresponds to a high Qg and GOR, indicating the presence of free gas. The minimum FAP values obtained for the Dik 02 field are 3895 ft for Qg (Mscf/d) and 3776.32 ft for GOR (scf/stb).

Page 27 of 31 | Total Record : 301

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