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 7 Documents
 1 
Search results for , issue "Vol. 5 No. 1 (2024): May" : 7 Documents clear
LOW SALINITY WATER INJECTION EVALUATION AND MATURE FIELD DEVELOPMENT AT ANGGORO SHALLOW SAND, SANGASANGA FIELD Novriyandi, Dani
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.v5i1.9827

Abstract

AbstractAnggoro's shallow sand was perforated at well ANG-1033 (D4-N1 layer). Oil production in this well increased from an average of 15 BOPD to 170 BOPD. That the perforated layer was affected by low salinity water injection (salinity < 3000 ppm). Evaluation of water injection sweep efficiency was carried out using the Dykstra-Parson method, vertical efficiency of about 0.3, area efficiency of 0.7, and displacement efficiency of 0.3. The Estimated Ultimate Recovery (EUR) of this well provides is 197 MBbls with an additional RF of around 20 %. This increase is due to the low salinity water injection sweep mechanism that occurs. The clay content plays an important role in the mechanism that occurs in this layer, these mechanisms fines migration, increase in pH, multi ion exchange, double layer effect, and salting in which these mechanisms result in increased oil recovery. Seeing the production results from the D4-N1 layer and oil production in this layer can still be maximized, in the future this layer can be developed with several programs such as reactivation, workover, and development drilling.Keywords: Low salinity water injection, shallow layer, efficiency
EVALUATING CUTTING TRANSPORT ON 12 ¼” SECTION WELL TM-1 Widyaningsih, Ratna; Idea, Kharisma; Utami, Ayu; Putradianto, Ristiyan Ragil; Jati, Dhika Permana; Dzulfiansyah, Pratama; Hartoyo, Puji
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.
OVERCOMING THE SAND PROBLEM USING THE GRAVEL PACK METHOD IN WELL X IN THE FIELD OF KALREZ PETROLEUM (SERAM) LTD Lanongko, Wa Riska
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
The Selection of Optimal Gas Production Rate using Dynamic Reservoir Simulation in Field X Pratama, Rahmad Laksamana; Nirmala, Gerry Sasanti; Untoro, Edi; Sugiantoro, Jatmianto Jayeng; R.A, Muhammad Ghazian
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.v5i1.11084

Abstract

Indonesian government has targeted a gas production rate of 12 BSCFD by 2030 to balance the energy demands and the carbon emission reduction. To achieve this goal, a comprehensive evaluation of a gas field will be carried out regarding Recovery Factor, Stable Production Period (Plateau Time), Total Production Period, and Profits using simulation programme. Dynamic Reservoir Simulation is an integrated field development simulation that combines physics, mathematics, reservoir engineering, and computer programming to analyze and predict the wells performance or how fluid flows through reservoir rocks to the surface over time under various operating conditions. There are stages in the simulation include Reservoir Model Creation, Initialization, History Matching, and Production Performance Forecasting. This research is a continuation of static reservoir modeling research done by LEMIGAS, which started by reinitializing the model and ended by forecasting the production performance of field X using several gas production flowrate scenarios to find out the optimal gas production flowrate for Field X in ten years period. The simulation result showed that the best gas production flowrate for a ten-year period is 3 mmscfd. It gives 78,505% recovery factors, with cumulative profit of $40,915,872 USD over a plateau period of 6.6 years.
Analysis of Scale Problem Using Acidizing Stimulation in Field Z Kalrez Petroleum (Seram) LTD Idrus, Sumina
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.v5i1.11085

Abstract

The annual decrease in production at well Z occurs due to scale deposits that impede fluid flow. Scale is a production problem due to the mixing of two types of water with different properties so that the solubility limit of the compound in the formation water is exceeded. To overcome the scale, stimulation is carried out with an acidizing method using a type of acid (HCL 10%). Evaluation was conducted to determine the effect of acidizing stimulation on scale based on productivity index (PI), inflow performance relationship (IPR) curve and comparison of stimulation methods. Evaluation of test results after acidizing stimulation of well Z experienced an increase in production. Productivity Index increased from 4.748 bbl/psi to 9.036 bbl/psi. Based on the IPR curve before acidizing, the maximum flow rate (Q max) = 324,107 bpd, increased to Qmax = 769,021 bpd.Keywords: Cost Benefit, Productivity Index, Scale, Acidizing Stimulation
Analysis of the Use of Sand Pump Control Pumps in Overcoming Sand Problem in Sucker Rod Pump (SRP) in Sp Wells In the Kawengan Field Sopacua, Putri
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.v5i1.11283

Abstract

The sand problem is a common challenge in the oil and gas industry. PT Pertamina EP Asset 4 Cepu Field in the Kawengan Field has rock which is a ngrayoung formation and the type of sandstone can cause sand to enter into the well bour when oil is produced for a long time. Therefore, we need the right tool to be able to overcome the problem of sandiness. In this case PT Pertamina EP Asset 4 Cepu Field in the Kawengan Field uses a sand control pump in an effort to overcome the sand problem. Thus, this research was conducted by analyzing the appropriate pump size from the sand rate calculation, fluid flow rate before and after using the sand control pump, as well as economic analysis. The results of the pump size analysis show that the right pump size to use is 2 joint mud anchors. The results of the subsequent analysis show an increase in the rate of fluid production after using a sand control pump. The results of the economic analysis show that the use of a sand control pump on a sucker rod pump (SRP) in the SP well is feasible because it has economic value with an oil price of 45 US$ / bbl, an NPV of 221,709 USD is obtained, and project success (IRR) reaches 106 %, as well as the value of pay out time for 1.83 years. Keywords: Economy, Flow Rate, Sand Problem, Sand Control Pump, Sand Rate.
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) Bukit, Boy Utama
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.

Page 1 of 1 | Total Record : 7

 1 

Filter by Year

2024 2024


Reset
Filter By Issues
All Issue 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