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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 6 Documents
 1 
Search results for , issue "Vol. 8 No. 1 (2019): MARET" : 6 Documents clear
UNLOCKING HIDDEN POTENTIAL OF SHALLOW RESERVOIR AT 1955-2342 mSS, IN RUHOUL FIELD Abda Anwaratutthifal; Lestari Lestari; Reno Pratiwi
PETRO:Jurnal Ilmiah Teknik Perminyakan Vol. 8 No. 1 (2019): MARET
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (913.583 KB) | DOI: 10.25105/petro.v8i1.4288

Abstract

As a human, live in the ever-changing environment, with the abundant amount of human movement, increasing population, and advancing technology, consumpting high energy is inevitable. Indonesia has been working to obtain better energy to fuel the world. As the multinational energy company, Pertamina Hulu Mahakam, located in East Kalimantan, operate world wide to extract oil and gas from the reservoir in Mahakam Delta, which already used high technology and qualified human resource to support the safe, efficient, and effective production process.The petroleum system models, the contribution of marine shales to the generation of liquid and gaseous hydrocarbons in the Mahakam was considered negligible. The production of the oil fields has started quite early, however the major development phase of gas accumulation started within the last decade, with increasing activity since.Ruhoul is an offshore gas field belongs to Pertamina Hulu Mahakam that located in Mahakam Delta, East Kalimantan, Indonesia. It covers an area of 350 km2 and has a gross thickness of the payzone over 2000 m. Structural architecture of Ruhoul field is multilayered un-faulted anticline. Stratighraphycally, Ruhoul reservoirs are divided into two intervals which are Ruhoul Main Zone and Ruhoul Shallow. This study is only focused in Shallow zone area, they are Sh-8a, Sh-8c, and Sh-8d, as it is considered as remaining prospective area for Ruhoul field. For more specific, Sh-8a was produced by wells RJ-16A-M and RJ-2G-M.T3, Sh-8c was produced by well RJ-2G-M.T3, and Sh-8d was produced by well RJ-2G-M-T3.Over time, the gas production in Ruhoul Field keep decreasing, therefore hidden gas production potential needs to be re-evaluated. The evaluation can be done by doing the dynamic synthesis analysis based on completion type used, production history, and well correlation.The main objective of this study is to evaluate hydrocarbon potential in Ruhoul Shallow specific area. Several approaches will be used to assess Ruhoul Shallow zone prospect such an updated database, zone change inventory, and well correlation based on netpay map by layer with software Geolog 7.2.Perform Dynamic Synthesis Analysis and P/Z Straight Line Material Balance Calculation are chosen as the methodology to assess the prospect zone of this field. The results of this process are candidates to be the re-opening zone, the value of GIIP, EUR, RR, RF, also the drive mechanism applied to each layer. Not only that, the results also obtained the Plateau rate stage curve in each layer.The results showed two categories of re-opening candidates, P/Z methodology to calculate the value of GIIP and RF, and Plateau stage in each layer. Along with this study, the only well that suit to be the candidate for re-opening zone was only RJ-2G-M.T3 in Sh-8a, while the other layers and wells were not suit to be the candidate for re-opening zone. From the P/Z Straight Line calculation, the GIIP for the candidate (Sh-8a produced by RJ-2G-M.T3) is 1.15 BSCF, with 1.02 BSCF Gp max, and 89% RF, and has depletion drive as its drive mechanism. Based on Plateau stage with 4 MMSCFD as the plateau rate, the decline in RJ-2G-M.T3 (Sh-8a) started on July 2015. 
OPTIMASI PRODUKSI SUMUR EC-6 DENGAN MEMBANDINGKAN PENGANGKATAN BUATAN GAS LIFT DAN ELECTRIC SUBMERSIBLE PUMP Jonathan Jonathan; Sisworini Sisworini; Samsol Samsol; Hari Oetomo
PETRO:Jurnal Ilmiah Teknik Perminyakan Vol. 8 No. 1 (2019): MARET
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (1395.161 KB) | DOI: 10.25105/petro.v8i1.4289

Abstract

In the world of oil is very common in the production system. This production system produces oil from wells after drilling and well compressions. Over time, the production of a well may decrease due to several parameters of pressure drop and the presence of clay which makes the pipe diameter narrower. There are several methods used to increase the decrease in production including adding artificial lifts such as sucker rod pump, electric submersible pump and gas lift, reservoir stimulation and pipe cleaning if the pipe diameter is reduced due to clay. The well has been installed an artificial lift is a gas lift and this well need an optimization to increase its production. The EC-6 well optimization is planned by comparing the lift-up scenario of the gas lift by adjusting the rate of gas injection and deepening the orifice injection and also an installation of electrical submersible pump. Best percentage of optimization production from EC-6 Well, last scenario is chosen which is new installation artificial lift ESP from gas lift (existing) and gaining 18.52% form existing production
PENGARUH SCALE TERHADAP PRODUKTIVITAS PADA SUMUR BN-52, BN-104, DAN BN-110 DI LAPANGAN “X” Abhikama Pradipta; Lestari Lestari; Samsol Samsol
PETRO:Jurnal Ilmiah Teknik Perminyakan Vol. 8 No. 1 (2019): MARET
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (648.979 KB) | DOI: 10.25105/petro.v8i1.4290

Abstract

BN-52, BN-104, and BN-110 wells are located on the X field, PT. PERTAMINA FIELD RAMBA ASSET 1, South Sumatra. The three wells are oil-producing wells in field X. Using the Vogel equation, the IPR curve and maximum flow rate of each well are obtained, which are 152.14 BOPD, 57.2 BOPD, and 53.76 BOPD respectively. By using the exponential Decline Curve Analysis calculation method, it can be seen the rate of decline in production, as well as the time of well production to economic limit. The results of the Decline Curve Analysis show that the BN-52 well will still be in production until March 2022, and the BN-110 well can produce until March 2020. In the analysis with the Stiff & Davis Method, carbonate deposits are proven, with each Stability Index value  +1.19, +1.60, and +1.35, whereas with the Skillman, Mcdonald & Stiff method there was no scale sulfate, with S values of each well at 57,272 meq / l, 54,416 meq / l, and 55,147 meq / l. The scale causes oil production to decrease, consequently the IPR curve shifts to the left. The decreasing production of the three wells is due to a scale that inhibits the flow rate. Maximum flow rate was obtained by using the Standing correlation in each well of 100.06 BOPD, 54.53 BOPD, and 28.72 BOPD. The decline in oil production caused by scales must be handled appropriately.
PERHITUNGAN POTENSI CADANGAN PANASBUMI LAPANGAN “X” MENGGUNAKAN DATA EKSPLORASI Syahda Ahyar Habibirahman; Lestari Lestari; Bambang Kustono
PETRO:Jurnal Ilmiah Teknik Perminyakan Vol. 8 No. 1 (2019): MARET
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (965.863 KB) | DOI: 10.25105/petro.v8i1.4291

Abstract

The method used in this reserve estimation is volumetric, regulated by Badan Standar Nasional Indonesia (BSNI) (SNI 13-6482-2000). This method considers that the reservoir is a form of dimensional space so that its volume can be measured. This type of method can also be used in reserve classes ranging from hypothetical resources up to proven reserves, with parameters used in this calculation obtained through assumptions and those that are the result of preliminary survey activities, which consist of geological (MT maps), geophysics (MT maps), and geochemistry (geothermometer) surveys. Data obtained from preliminary survey activities contains data on thickness, area, and temperature of the reservoir. Other parameters that have not been obtained from preliminary survey activities, such as rock porosity and heat capacity, final temperature, water and steam saturation, internal energy of water and steam, water and steam density, recovery factor, load factor and span and are based on assumptions compiled by BSNI (SNI 13-6482-2000). In addition of using volumetric methods, calculations are also performed using the Monte Carlo simulation method. This method uses random numbers as uncertainty factors in some parameters that have been obtained from the preliminary survey as mentioned above, with the type of distribution determined based on calculation parameters.. With the reservoir temperature of 220oC, area of 7.4 km2, & thickness reaches 1550 m, the potential for geothermal reserve at "X" Field based on the volumetric method is 36.90 MWe. Meanwhile, using the Monte Carlo simulation method, the potential reserves at a 90% confidence level are around 47.93 MWe: which has the the most likely reservoir temperature of 220oC with the range of values varies around 200-225oC, reservoir area with the most likely value is 7.5 km2 ranging from 4-11 km2, and the most likely thickness value is 1550 m with 1200-1700 m for the minimum and maximum values.The calculation results of the geothermal energy reserve potential in the "X" Field are 36.90 MWe using volumetric method and 47.93 for Monte Carlo simulation method.
ANALISIS PENGARUH INJEKSI CO2 TERHADAP RECOVERY FACTOR MENGGUNAKAN SIMULASI CMG DI LAPANGAN X Vera Fernanda; Mulia Ginting; Prayang Sunny Yulia
PETRO:Jurnal Ilmiah Teknik Perminyakan Vol. 8 No. 1 (2019): MARET
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (790.574 KB) | DOI: 10.25105/petro.v8i1.4292

Abstract

X-Field is located in South Sumatra, where there are several gas fields with considerable CO2 gas potential. In this field, no research has been conducted on CO2 injection neither in the laboratory nor simulation. Therefore, the purpose of this study is to analyze the effect of CO2 injection on the value of recovery factor with one-dimensional simulation using CMG. To be able to make an accurate simulation model, it is necessary to do validation by comparing the results obtained with the CO2 injection test from experiments in the laboratory. Laboratory experimental data used in this study is from Vulin’s literature. The result of recovery factor for X-field is 98.80%. From the results of this study, it is known that the injection rate of CO2 has no effect on changes in recovery factor. However, the difference of CO2 injection pressure in these two samples influences the change in recovery factor. The higher injection pressure of CO2 in an immiscible condition is, the higher the value of the recovery factor is achieved. In addition, the difference in oil composition in these two samples affects the value of MMP, where the higher the intermediate component of a reservoir fluid is, the lower the MMP will be. X-field has a high intermediate component fraction, therefore the value of MMP obtained is lower than the MMP from Vulin’s literature. The value of MMP in X-field is 2610.68 psia
EVALUASI ISI AWAL GAS DI TEMPAT DAN ANALISIS DECLINE CURVE PADA RESERVOIR YS Yogie Seto S. W; Onnie Ridaliani; Lestari lestari
PETRO:Jurnal Ilmiah Teknik Perminyakan Vol. 8 No. 1 (2019): MARET
Publisher : Jurusan Teknik Perminyakan Fakultas Teknologi Kebumian dan Energi Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (1368.114 KB) | DOI: 10.25105/petro.v8i1.4293

Abstract

YS reservoir has data of gas initial in place (GIIP) with a volumetric method of 3,476 Bscf. Because of improvement of data, GIIP can be evaluated using material balance method. Then the production of wet gas will be forcasted until below economic limit. The PVT data that needs to be calculated in this study is the gas and water compressibility factor and the formation volume factor each year. In determining the type of drive mechanism, a plot of P / Z versus cumulative gas production is carried out, from the analysis, the type of drive mechanism is water drive, it is necessary to calculate the water influx, the method used is the Van Everdengen-Hurst method. After all the required parameters are available, the calculation of the initial gas in place will be calculated, the method used is the material balance method and the straight line material balance method. The results of the initial gas in place calculation using the material balance and straight line material balance methods are 3,430 Bscf and 3,428 Bscf. If the results of the material balance method and the straight line material balance method are compared with available GIIP volumetric method data, the percent difference is 1,32% and 1,37%. It can be said that GIIP result using the material balance method and the straight line material balance method is accurate because after being evaluated using volumetric method, it only has a small percentage difference. Then from the decline curve and Trial Error and X2 – Chisquare Test analysis, the decline curve is exponential with Di at 1,103 / month. After forecasting until production of wet gas is below the economic flow rate of 0,045 Mscf / d, it is known that the productive age is until 1st September 2021 with the values of EUR and RR respectively 2,309 and 0,014 Bscf. Using the results of GIIP using the material balance and straight line method, the current recovery factor are 67,34% and 67,37 %.

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