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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
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Implementation of CO2 Source-Sinks Match Database Development. Case Study: West Java Tony, Brian; Nugraha, Fanata Yudha; Al Hakim, Muhamad Firdaus; Putra, I Putu Raditya Ambara; Chandra, Steven
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.v5i2.13432

Abstract

Carbon capture and storage (CCS) is widely recognized as a significant technology in mitigating carbon dioxide (CO2) emissions from major industrial facilities, such as power plants and refineries. CCS involves the capture of concentrated CO2 streams from point sources, followed by subsequent safe and secure storage in appropriate geological reservoirs. We developed spatial database system using Geographic Information System (GIS) tools to facilitate source-sink matching between CO2 emitter and CO2 storage to foster the implementation of CCS/CCUS technologies in Indonesia. In this study, we proposed workflow approach to determine the location of CO2 sinks/storage candidates given limited data available. Additionally, this method spatially characterizes and represents probable clusters where opportunities for CCS/CCUS implementation are present. We consider the existing pipeline route and Right of Ways (ROW) to minimize the potential cost related to transportation of CO2 using pipeline. The priority of available storage is classified based on the storage capacity, distance, and other technical criteria to determine the optimal location of potential CO2 injection. We applied the workflow to Coal Fired Power Plant in West Java as the CO2 source, and we obtained 6 depleted fields that are connected to the existing ROW with CO2 storage capacity of 42.03 MMT.
Synthesis of Synthetic Brine to Estimate Carbonate Scale Index in Oil Industry Nugraha, Fanata Yudha; Asmorowati, Dewi; Saputra, Ega Dimas; Astuti, Dian Indri; Tony, Brian; Waisnawa, I Putu Gema Bujangga
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.v5i2.13636

Abstract

The decreased oil production due to scaling in production equipment results in costs. In oil wells, ions such as calcium, barium, carbonate, sulfate, magnesium, sodium, and chloride are commonly present in formation water. Excessive solubility of ions can trigger precipitation or what is often called scale. This study focuses on creating synthetic brine with a composition resembling field formation water as an alternative solution for rapid laboratory-scale measurement of the scale index. In this study focus on carbonate and bicarbonate scale. The stages of the research involves synthetic brine preparation, physical and chemical testing of the brine, comparison with formation water, and calculation of the Stability Index (SI) using Stiff & Davis method. The results indicate that synthetic brine can be prepared based on laboratory analysis of field samples by estimating the materials and masses present in formation water, thus allowing replication using natural or chemical materials in the laboratory while considering parameters such as pressure, temperature, and pH during the manufacturing process. The pH significantly impacts the risk of scale formation, where a slightly basic pH, around pH 8, supports higher concentrations of carbonate ions (CO32-) and bicarbonate ions (HCO3-), thereby increasing the risk of scale formation.
DETERMINING WELLS CANDIDATES FOR HOLE CLEANING IN A KAMOJANG GEOTHERMAL FIELD Nugraha, Farhan; Laksmita, Riska
Journal of Petroleum and Geothermal Technology Vol. 6 No. 1 (2025): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v6i1.13106

Abstract

During the generation for more than 40 years, Kamojang wells have experienced decline in production. It directly affects steam supply to the power plant. The most important program to resolve steam availability is to drilling makeup well. Limited access and unsuccessful drilling makeup well as expected in the last 10 years becomes a problem in order to maintain long term production. Fetkovich Method has been used as guideline to simulate gas/geothermal well production performance. It has been used widely and give an accurate model of production performance. But, there is a weakness in Fetkovich Method, which is it’s difficult to understand the change of parameter stabilization production coefficient and deliverability exponent with their correlation in wellbore or reservoir.  Acuna and Pasaribu (2008) can handle this problem with anaylitical method through parameter of friction coefficient inwellbore and productivity index in reservoir. In this case, Hole cleaning aims to dissolve scaling that cause decline of production. As result total of seven wells experienced increase in production after hole cleaning. It gains approximately 8 MW. In addition, the advantages of this jetwash are reduction in cost and time as well compared.
The use of PhaseNet for Event Identification of Microearthquake Monitoring in Geothermal Field Al Hakim, Muhamad Firdaus; Ambara Putra, I Putu Raditya
Journal of Petroleum and Geothermal Technology Vol. 6 No. 1 (2025): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v6i1.13437

Abstract

Geothermal energy is a sustainable energy source that requires continuous microseismic monitoring to assess reservoir integrity and geomechanical behavior. Traditional phase identification methods are challenged by noisy environments and complex waveforms, especially in geothermal fields. This study explores the efficacy of PhaseNet, a deep learning neural network model, in detecting P and S wave arrival times for micro-earthquake events. The PhaseNet model was retrained using local seismic data from a geothermal field and tested for its performance in identifying seismic phases. The results were validated against a manual seismic catalog, with additional clustering and association analysis conducted using GaMMA and hypocenter locations determined with NonLinLoc. The findings demonstrate that PhaseNet, combined with GaMMA, provides robust phase detection capabilities, essential for early-stage monitoring in geothermal development.
Gas Production Optimization with the Addition of Infill Wells through an Integrated Pipeline Scenario Model in Field Y Ayuningtyas, Rivanya
Journal of Petroleum and Geothermal Technology Vol. 6 No. 1 (2025): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v6i1.13574

Abstract

The Y natural gas field was awarded a 10-year gas sales contract with a production target of 11 MMSCFD. Three infill wells were drilled to meet the production target. The pipeline network for these wells is then determined through an optimization scenario. The pipeline network scenario for infill wells is an optimization approach that aims to provide recommendations for modeling pipelines from infill wells that produce the largest volume of gas with the smallest bottlenecking effect, and the pressure drop that occurs can be minimized. The surface production network optimization scenario is then divided into three scenarios based on the productivity of each well. The Y Field production system was modeled using a reservoir simulator, a well simulator, and a total system simulator. Based on the simulation results, scenario 3 was identified as being able to produce the largest gas volume and the scenario with the smallest bottlenecking effect. Since the difference in gas volume and bottlenecking between scenario 2 and scenario 3 is insignificant at 0.06%, scenario 2 is recommended as the preferred pipeline modeling scenario for infill wells in Y Field.
Production Capacity Optimization By Silica Crust Analysis “TB-001” and “TB-002” Wells Sorik Marapi Geothermal Field Wahyuzar, Dirga
Journal of Petroleum and Geothermal Technology Vol. 6 No. 1 (2025): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v6i1.13623

Abstract

The Sorik Marapi located in Mandailing Natal Regency, North Sumatra. Silica scale production wells “TB-001” and “TB-002” makes pipe diameter smaller, inhibits fluid flow, reduces energy output, and increases cost of cleaning even replacing pipes. The research expected to produce efforts to prevent silica scale thus production capacity optimized. Method used is Silica Saturation Index (SSI) with amorphous and quartz silica types. Temperature and pressure are important where appropriate settings can minimize silica scale. Study focused on the wellhead and separator part of the well. Furthermore, comprehensive feasibility evaluation of production well was conducted. Cap rock smectite - hematite mineral about 20° - 240°C and reservoir illite - epidote mineral about 240° - 340°C. Geothermal fluid is dominated by chloride water. Both wells have the potential silica scale in separator with SSI >1 and not in wellhead with SSI<1. The treatment to prevent the silica scale is to use hydrofluoric acid (HF) solution with concentration of 15% and immersion time of 15 minutes, where the effectiveness value is about 46-47%.Keywords: Geothermal; Production Wells; Silica Crust; Sorik Marapi; SSI 
The Effect of Salinity on the Effectiveness of CO2 Injection in the CO2 Storage Project in Bunter Field Fitri, Syahri Fani
Journal of Petroleum and Geothermal Technology Vol. 6 No. 1 (2025): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v6i1.13754

Abstract

The increase in CO₂ concentration in the atmosphere has contributed to global warming. Reducing CO₂ emissions can be achieved through Carbon Capture Storage (CCS) projects, optimized by selecting appropriate formation water salinity for CO₂ injection. High salinity can impede CO₂ movement and cause mineral deposits, potentially clogging rock pores and reducing CO₂ solubility. This paper aims to analyze the impact of salt concentration in brine on CO₂ solubility and storage capacity in saline aquifers. In this study, a sensitivity simulation was conducted on an existing saline aquifer dataset to analyze the effects of varying formation water salinity using a CO₂ sequestration method with a reservoir simulator. Simulation results showed that different salinity levels in formation water yield varying CO₂ solubility rates; for instance, in a formation with water salinity of 1000 ppm, CO₂ solubility increased with a storage capacity of 910.283 MMscf, whereas at 100.000 ppm salinity, CO₂ solubility decreased, and the CO₂ storage capacity was slightly lower at 652.440 MMscf. Formations with lower salinity are considered more ideal for CCS projects as they can maintain higher CO₂ storage capacity and long-term stability. This study is expected to provide additional insights into enhancing the CO₂ solubility mechanism in saline aquifers.
Probabilistic Estimation of Geothermal Reserves in Dieng Field with JIWA Power Density and JIWA Volumetric Sholikhuddin, Mukhammad; Fahri, Dzakhi; Sihotang, Novanto; Wardana, Raka Sudira
Journal of Petroleum and Geothermal Technology Vol. 6 No. 1 (2025): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v6i1.14387

Abstract

Geothermal energy is a renewable energy source that is environmentally friendly and can be utilized for power generation. This study aims to estimate geothermal reserves in Dieng Field using Monte Carlo simulation to overcome uncertainty in the calculation of geothermal resources. The methods used include the Power Density and Volumetric Stored Heat approaches by considering geophysical, geological, and well logging data. Monte Carlo simulation produces probabilistic estimates categorized into P10, P50, and P90 scenarios. The results show that the potential geothermal reserves in Dieng Field range from 56.91 MW (P10) to 113.41 MW (P90) based on the Volumetric method and between 64.22 MW (P10) to 111.22 MW (P90) based on the Power Density method. These results provide a comprehensive picture of the geothermal potential that can be utilized, and support decision-making in the sustainable development of geothermal energy.
Challenges in Cement Integrity in Geothermal Wells : A Study of Dieng Geothermal Field Asra, Fauzan Azmi
Journal of Petroleum and Geothermal Technology Vol. 6 No. 1 (2025): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v6i1.14567

Abstract

Cement integrity plays a crucial role in geothermal well construction, ensuring zonal isolation, casing support, and long-term well stability. The Dieng Geothermal Field presents unique challenges in maintaining cement integrity due to extreme reservoir temperatures exceeding 300°C, highly permeable volcanic formations, and the presence of corrosive gases such as CO₂ and H₂S. These conditions can lead to thermal stress, chemical degradation, and loss circulation, all of which compromise cement performance over time. This study examines the key challenges affecting cement integrity in the Dieng Geothermal Field and evaluates potential mitigation strategies. Advanced cement formulations with silica-enhanced additives, acid-resistant materials, and stage cementing techniques are essential in improving cement stability under high-temperature conditions. Additionally, real-time monitoring tools such as cement bond logs (CBL) and ultrasonic imaging technologies are critical for assessing cement integrity and identifying early failure indicators. The findings of this study emphasize the necessity of a tailored cementing approach to address the specific geological and operational challenges of geothermal wells. By implementing optimized cementing techniques and monitoring systems, operators can enhance the longevity and reliability of geothermal wells, ensuring sustainable energy production from the Dieng Geothermal Field.
A Design Analysis of Shell and Tube Type Recuperator in Organic Rankine Cycle Power Plant with Low-Temperature Geothermal Steam Source MUHAMMAD RIFQI DWI SEPTIAN; Fitri Rusmaladewi; Friska Hasugian; Rozi Afdi; Dwi Miftha Kurnia; Stevy Canny Louhenapessy; Randy Yusuf Kurniawan; Setiadi Wira Buana
Journal of Petroleum and Geothermal Technology Vol. 6 No. 1 (2025): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v6i1.15142

Abstract

Organic Rankine Cycle (ORC) power generation systems offer an effective means to harness low-grade geothermal heat. A crucial component in improving ORC thermal performance is the recuperator, which recovers residual heat from the turbine outlet to preheat the working fluid. This study focuses on the design and evaluation of a shell and tube recuperator using R-600a as the working fluid, through thermodynamic and heat transfer analyses. Key parameters such as LMTD (32.38 °F), effectiveness (0.434), and heat transfer area (60.35 m²) were calculated. Pressure drops were within acceptable limits (tube side: 4.46 psi; shell side: 0.475 psi), and the dirt factor of 0.0038 indicates good resistance to fouling. The results support the feasibility of implementing the proposed design in small to medium-scale geothermal ORC applications. Keywords: geothermal; ORC; recuperator; shell and tube; thermal analysis

Page 7 of 9 | Total Record : 87

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