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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 8 Documents
 1 
Search results for , issue "Vol. 5 No. 2 (2024): November" : 8 Documents clear
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.
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.

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