cover
Article Per Year (5 Year)
All
Home Page
OAI Link
Editorial Team
Contact
Reviewer
Google Scholar
Contact Name
Ristiyan Ragil Putradianto
Contact Email
ristiyan@upnyk.ac.id
Phone
+6285292102888
Journal Mail Official
jurusan_tm_ftm@upnyk.ac.id
Editorial Address
Jln. Padjajaran 104 (Lingkar Utara), Condong Catur, Depok, Sleman, DIY (55283)
Location
Kab. sleman,
Daerah istimewa yogyakarta
INDONESIA
Journal of Petroleum and Geothermal Technology
Published by Universitas Pembangunan Nasional Veteran Yogyakarta
ISSN : 27230988     EISSN : 27231496     DOI : https://doi.org/10.31315/jpgt.v1i1
Core Subject : Science, Engineering,
Earth & Planetary Sciences Energy Engineering
Journal of Petroleum and Geothermal Technology (JPGT) is a journal managed by Petroleum Engineering Department, Universitas Pembangunan Nasional "Veteran" Yogyakarta. This Journal focuses on the petroleum and geothermal engineering including; reservoir engineering, drilling engineering and production engineering.
Arjuna Subject : Teknik (semua kategori) - Teknik (Lain-Lain)
Articles 87 Documents
 4   5   6   7   8 
Integration Of 3G Data (Geomagnetic, Gravity And Geology) To Identify Geothermal System Controlled By Geological Structure Of Telomoyo Plateau (Study Case Of Candi Umbul Area) Boy Utama Bukit
Journal of Petroleum and Geothermal Technology Vol 5, No 1 (2024): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v5i1.11929

Abstract

As the technology development, there are more and more new innovations that utilize existing resources to support the energy needs and to fulfill the consumer needs. The energy source that is being discussed at this time is geothermal energy. Geothermal energy sources are considered effective because they are renewable and environmentally friendly when compared to other energies such as fossil energy. In Indonesia itself, geologically, it has a complex series of volcanoes that can be used as a heat source in this new energy innovation. One area that thought to have geothermal potential is the telomoyo mountain area, which is indicated by the manifestation of hot springs on the surface, precisely around Candi Umbul. However, it is necessary to conduct subsurface studies to identify the presence of subsurface structures such as faults or intrusions as heat sources, where this can be overcome using geophysical methods. This research was conducted using the integration of two geophysical methods, namely the geomagnetic method to determine the direction of the fault continuity and the gravity method to determine the regional heat source, and in the other side geological data as a reference for interpretation. From geomagnetic measurements, 163 rock magnetism data were obtained which indicated the existence of a fault continuity with northeast-southwest orientation in the direction of the river flow and cut the manifestation of hot springs. Meanwhile, from 176 gravity topex data, a high complete boguer anomaly value was obtained as an indication of an intrusion in the northeast that was cut by the fault recorded in the geomagnetic data. Based on geophysical data analysis and correlation with geological data from previous studies, it can be assumed that there is a geothermal system in the study area with andesitic intrusion as the heat source, fault structure with northeast-southwest orientation as a weak zone for meteoric water migration, andesite lava as caprock, unit tuff rock as a reservoir and the telomoyo plateau as a recharge area to supply meteoric water from the geothermal system.
EVALUATING CUTTING TRANSPORT ON 12 ¼” SECTION WELL TM-1 Ratna Widyaningsih; Kharisma Idea; Ayu Utami; Ristiyan Ragil Putradianto; Dhika Permana Jati; Pratama Dzulfiansyah; Puji Hartoyo
Journal of Petroleum and Geothermal Technology Vol 5, No 1 (2024): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v5i1.10742

Abstract

Mud hydraulics on a 12-1/4" section needs to be planned properly. Mud hydraulics design on a 12-1/4" section includes determining mud density, flow type, pressure loss, pump specifications, bit hydraulics and cutting lifting design. The purpose of bit hydraulics design is to determine the optimum flow rate. Mud hydraulics optimization is carried out using methods the Bit Hydraulic Horse Power (BHHP), Bit Hydraulic Impact (BHI) and Jet Velocity (JV) methods, where the analysis is in the form of graphs. The graph is analyzed by using a trial and error method to obtain the recommended flow rate so as to provide good cutting lifting. where the expected recommendation analysis are Cutting Transport Ratio (Ft) > 90%, Cutting Concentration (Ca) < 5%, and Carrying Capacity Index (CCI) > 1. The analysis results from the graph show that for the hole 12-1/4", it is recommended to use an optimum flow rate of 626.6 gpm with minimum value of Ft is 90.01%, Ca is 0.87% and CCI is 1.95. These values are stated to be good by using 15-15-16 nozzle bit combination. The Flowrate value can be increased up to 785 gpm by using 18-18-20 nozzle bit combination.. Keywords: Hydraulic Mud Planning, Optimum Flow Rate, Cuttings Removal.
New Perspective to Unlock the Potential of Lenses Gas Reservoir in Indonesia Using Integrated Reservoir-Production System Wijoyo Niti Daton; Steven Chandra; Nathania Jessica
Journal of Petroleum and Geothermal Technology Vol 4, No 2 (2023): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v4i2.9352

Abstract

The potential of lenses gas reservoirs has become an interesting target in meeting energy needs in Indonesia. As the next energy backbone in Indonesia, the most suitable strategy needs to be developed for maintaining productivity and maximizing gas recovery. Developing gas reservoir can be challenging due to several reservoir and fluid characteristics. The development strategy must use a special production scenario and an optimized completion design.This paper discusses the process of development strategy determination for lenses gas reservoir by using commercial software. The lenses gas reservoir consists of four interest zones which penetrated by one offshore well. Each interest zone has different reserve and deliverability.The available data used are PVT, petrophysics, tubing diameter, and production parameters. By inputting these data into the software, the well recovery can be estimated. Various production scenarios are tested until a scenario is selected as the suitable production method. The production method selected is commingled using scenario 1, which to produce all lenses together with considering plateau rate 15 MMSCFD for 10 years production. Referring to the suitable production method, optimized completion designs are also selected (wellhead pressure and tubing diameter). The wellhead pressure selected is 150 psig, while the tubing diameter selected is 4.5-inch.
OVERCOMING THE SAND PROBLEM USING THE GRAVEL PACK METHOD IN WELL X IN THE FIELD OF KALREZ PETROLEUM (SERAM) LTD Wa Riska Lanongko
Journal of Petroleum and Geothermal Technology Vol 5, No 1 (2024): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v5i1.11052

Abstract

In the oil and gas industry, there are often various problems that can interfere with the production process. One of the problems that often occurs is sand problems. The impact of sand problems is to cause damage to downhole and surface equipment. To solve the problem of sand in boreholes, gravel fill can be used. This study was conducted Kalrez Petroleum (Seram) Ltd Field Well X. The purpose of this study was to determine the size of gravel Bagging overcomes sandy issues and determines front and rear production performance Installing a gravel pack and determining the cost comparison of the gravel pack method and sand screening method in terms of cost benefit analysis. Based on the smallest average size of sand grains is 0.024 inch, this size is in accordance with the size of gravel pack in general, namely 16/30 M. Calculation of PI after the use of gravel pack has increased production from 4.4 bbl/psi to 7.8 bbl/psi. Based on the IPR curve before the use of gravel pack, the maximum flow rate (Q max) was 527.4372 bpd, experiencing an increase in the maximum flow rate (Q max) of 907.108 bpd. Based on calculations using cost benefit analysis (Coast Benefit Analysis) between the gravel pack and screen liner methods. The screen liner method can be an alternative to overcome the sand problems, this is because it is seen from the value of the B/C ratio> 1 or 2,3. This means that for every one dollar invested in the method, a savings ratio of 2.3 will be obtained. So the screen liner method is more useful and also efficient. Keywords: Sand problem, downhole and surface equipment, gravel pack, sieve analysis, cost benefit analysis
Evaluation of The Use of Diptube and Cyclone on The HPU Pump Downhole to Address The Sand Problem and Gas Interference in The ARD-22 Pangkalan Susu Field Widodo, Aris; Suranto, Suranto; Swadesi, Boni; Ratnaningsih, Dyah Rini; Kristanto, Dedy; Ridha, Syahrir
Journal of Petroleum and Geothermal Technology Vol. 5 No. 2 (2024): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v5i2.12349

Abstract

The problem of sand and gas interference in artificial lift pumps is a serious problem. The ARD-22 well in Pangkalan Susu often goes offline due to sand and gas interference. Solutions to overcome sand problems by reducing drag force and mechanical methods. Reducing drag force by setting the well production rate below or equal to the critical sand flow rate. The mechanical method is carried out by adjusting the flow pattern on the artificial lift and also by adding a downhole tool in the form of a Cyclone, which functions to make the fluid flow from the reservoir turbulent so as to separate solid particles from liquid. Another dominant problem with this well is the rising GOR or gas interference which causes gas lock problems, so it is necessary to redesign the diptube as a separation area between gas particles and liquid fluid. The monitoring results from this research showed that the fluid flow from the sampling point showed that there was no intermittent gas and the dynagraph readings also showed normal results. Optimum production can be recovered according to the initial potential of G/N 50/45, production lifetime increased after installation diptube cyclone to reach 7 more months and increased company revenues totaled Rp. 8.306.660,000.
Evaluation of Electric Submersible Pump (ESP) by Calculating the Economic Factor on Well KGH 32 Haiva, Kumala Galuh; Fattahanisa, Aqlyna; Wijayanti, Puri
Journal of Petroleum and Geothermal Technology Vol. 5 No. 2 (2024): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v5i2.12864

Abstract

This This research was conducted by performing quantitative analysis on data from PT. Pertamina EP Cepu Regional 4 Zone 11 the data included reservoir data, well data, and production data. The objectives of this research are to determine the maximum flow rate and optimum flow rate using the Composite IPR Method in Well KGH 32, evaluate the Volumetric Efficiency of the ESP pump based on the conducted assessment in Well KGH 32, and ascertain the profitability results from the Economic Evaluation in Well KGH 32.The first step in this research was to calculate the Inflow Performance Relationship (IPR) Composite to evaluate the reservoir well's performance. This method was used to predict production rates at specific bottomhole pressures and determine desired production rate targets. Subsequently, ESP Evaluation calculations were performed to determine the effective and efficient pump design considering various aspects, including economic value. The calculation results of the IPR Composite show the IPR Composite curve of Well KGH 32, used to assess well productivity and evaluate ESP pumps. The Q value is 4942 bfpd with a Pwf of 1714.717 bfpd. The optimum Q value is 9730.09 bfpd, derived from 80% of the Qomax value. The optimized Q value is 13,500 bfpd with a Pwf of 779.710, representing 69% of the total Q value. Qomax is 12,162.60871 bfpd with a Pwf of 951.645 bfpd. The Qt max value is 19,564.95 bfpd. Additionally, volumetric efficiency calculations for the installed pump indicate 71% efficiency for pump P-31, indicating suboptimal performance requiring optimization. Economic evaluation of the ESP considers factors such as revenue, electricity costs, water injection, chemical usage, routine expenses, and facility sharing agreements. Daily profit is calculated at Rp. 157,518,753. From this research, it is concluded that the ESP pump at Well KGH 32 needs optimization to enhance efficiency and economic feasibility, potentially achieving greater daily profits. Overall evaluations not only aid in improving operational performance and efficiency but also enable better decision-making based on a deeper understanding of well conditions and potential repair needs. Future steps may involve installing a rotary gas separator to manage excessive gas and adjusting pump designs to enhance overall performance. performance.
Evaluation of Hydraulic Fracturing Stimulation Based on Engineering and Economic Aspect at “ADN-007” Layer A3 Pramudiohadi, Eko Widi; Sholichah, Adinda Putri
Journal of Petroleum and Geothermal Technology Vol. 5 No. 2 (2024): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v5i2.12941

Abstract

The "ADN-007" is a production well located in the "APS" Field of the South Sumatra Basin, which has been operating since 1959. In 2023, a workover and hydraulic fracturing stimulation were performed at a depth of 1280 meters, precisely in the Talang Akar Formation, which consists of sandstone. The evaluation involved collecting engineering and economic data and performing calculations such as fracture geometry using the PKN 2D (Perkins-Kern-Nordgren) manual method, Fold of Increase using the Cinco-Ley Samaniego Dominique method, production prediction using the IPR Pudjo Sukarno method, and economic analysis. Based on the geometry evaluation calculations, the fracture length (xf) formed is 85.339 m, with a fracture height of 18.9 m, and an average permeability of 56.692 mD. The effective well radius (rw’) is 69.996 ft, and the total skin after hydraulic fracturing stimulation is -3.992. According to the nodal analysis results, “ADN-007” has optimal production after stimulation from 2023 to 2027, producing consecutively 330 b/d, 260 b/d, 198 b/d, 130 b/d, and 79 b/d. However, based on economic aspects, this stimulation is classified as uneconomical because the Profit to Investment Ratio value obtained is only 0.65.
FEED ZONE CHARACTERIZATION BASED ON PTS FLOWING DATA AND GEOLOGICAL DATA OF WELL DRILLING A FIELD B Phasya, Fauji Islami; Afif, Nanda Najih Habibil; Sari, Riska Laksmita; Abror, Hadziqul
Journal of Petroleum and Geothermal Technology Vol. 5 No. 2 (2024): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v5i2.13044

Abstract

Kamojang Geothermal is an active production field owned by PT Pertamina Geothermal Energy that contains 1 steam-phase fluid. This field often conducts production tests, one of which is the PTS flow test. This study aims to determine the relationship between the potential size of the feed zone and mineralogy. This research method begins with calculating and analyzing the flowing PTS. After the PTS calculation is complete, it is continued by making a composite log graph from the drilling geology data. The results show that the characteristics of reservoir mineral rocks are the appearance of epidote minerals and the caprock section is characterized by the appearance of clay minerals. In the reservoir zone, the feed zone was found at a depth of 1300 mMD and 844 mMD with mass rates of 62 t/h and 11.19 t/h, respectively. The distribution of the feed zone was found to contain epidote minerals as much as 1% of 67% of the altered andesite rock at a depth of 844 mMD and epidote minerals as much as 15% of 79% of the altered breccia rock at a depth of 1300 mMD.
Critical Factors in Injector Well Design for Carbon Capture and Storage Campaign in Field “X” Wardhana, Annisa Nur Syifa; Chandra, Steven; Tony, Brian
Journal of Petroleum and Geothermal Technology Vol. 5 No. 2 (2024): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v5i2.13144

Abstract

Indonesia’s total energy supply increased nearly 60% from 2000 to 2021. However, the total energy sector emissions have grown faster than energy demand, more than doubling over the last two decades. In 2021, energy sector emissions were around 600 million tonnes of carbon dioxide (Mt CO₂) – making Indonesia the world’s ninth-largest emitter. Indonesia faces a big challenge with the target to reach net zero emissions by 2060. Carbon capture and storage (CCS) is considered as a potential solution. However, CO₂ injection wells face well integrity issues that may lead to leakage. One of the most common problems in CO₂ injection wells is corrosion. Corrosion may cause damage on the downhole equipment which leads to degradation of the well integrity. Therefore, a thorough material selection should be considered. This study examines critical factors in designing CO₂ injector wells for a CCS campaign in Field "X", a major offshore gas condensate field with a planned injection rate of 160.2 MMSCFD. This study aims to determine suitable casing schemes, tubular material selection, and corrosion analysis for CO₂ injector wells, while evaluating leakage potential based on well barrier concepts. The drilling of “X” field CO₂ injection wells is planned to be executed with an estimated five casing sections consists of 30” conductor casing, 20” surface casing, 13-3/8” intermediate casing, 9-5/8” intermediate liner and 7” production liner. Based on the analysis using ECE (Electronic Corrosion Engineer) software, ISO 15156-3 standard, and the Nippon steel chart, the most suitable tubular materials for the CO₂ injector well is Duplex Stainless Steel SM22Cr or SM25CR.
HYDRAULIC FRACTURING EVALUATION OF WELL ZAA-011 PANGKALAN SUSU FIELD, NORTH SUMATRA Pamungkas, Mohd. Wirawan Putra
Journal of Petroleum and Geothermal Technology Vol. 5 No. 2 (2024): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v5i2.13268

Abstract

Well ZAA-011 is a well located in the Pangkalan Susu field that has been depleted, where the reservoir has experienced a decrease in producing ability due to fair permeability. Well ZAA-011 produces with artificial lift in the form of a hydraulic pumping unit (HPU) and has a water cut value of 72%. The well is producing in sandstone Structure B, located at a depth of 3392 - 3412 ft MD, with a reservoir pressure of 606 psia. Well ZAA-011 has a permeability of 10 mD or fair and a productivity index of 1.084 bpd/psi. The method used to evaluate hydraulic fracturing stimulation in the ZAA-011 well is by using MFrac simulation which is an evaluation measurement in the previous hydraulic fracturing process. The fracture properties parameters are fracture half-length, fracture width, fracture height, fracture conductivity, dimensionless frac conductivity, and reservoir permeability. Production parameters are seen through pipesim simulation in the form of nodal analysis to see the optimal production rate. Economic parameters using profit indicators are calculated with the production sharing contract model cost recovery model including NPV, IRR, ROI and POT obtained. Based on the simulation using MFrac software, the hydraulic fracturing design values are fracture half-length 34.239 m, fracture width 0.37321 inch, fracture height 14.42 m, fracture conductivity 12984 mD-ft, dimensionless frac conductivity 6.4239. Permeability was found to be 37 mD and theoretically the average is about 36.7 mD and the productivity index also increased by 2.383 bpd/psi. Plus nodal analysis in the wellbore using pipesim software obtained a production rate of 238.8 BLPD (67.54 BOPD). Economic analysis using profit indicators obtained an NPV value of MUS$ $937, IRR with a value of 250.71%, ROI of 77.22% and POT obtained 0.354 years or about 4,248 months. This indicates that the redesign work on hydraulic fracturing in the ZAA-011 well is effective and optimal.

Page 6 of 9 | Total Record : 87

 4   5   6   7   8 

Filter by Year

2020 2025


Reset
Filter By Issues
All Issue Vol. 6 No. 2 (2025): November Vol. 6 No. 1 (2025): May Vol. 5 No. 2 (2024): November Vol 5, No 1 (2024): May Vol. 5 No. 1 (2024): May Vol. 4 No. 2 (2023): November Vol 4, No 2 (2023): November Vol 4, No 1 (2023): May Vol. 4 No. 1 (2023): May Vol 3, No 2 (2022): November Vol 3, No 1 (2022): May Vol 2, No 2 (2021): November Vol 2, No 1 (2021): May Vol 1, No 2 (2020): November Vol 1, No 1 (2020): May More Issue