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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 4, No 2 (2023): November" : 8 Documents clear
ANALYSIS OF CEMENTING WELLS X-1 and Y-1 USING MULTIFUNCTION ULTRASONIC IMAGING LOGGING TOOL Henk Subekti; Purnomosidi Purnomosidi; Edi Untoro; Arya Dwi Candra; Mefriadi Mefriadi
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.v4i2.10919

Abstract

By analyzing the measurement principle of the ultrasonic pulse method, a multifunctional ultrasonic image recording device and the application of the measurement technique were designed. It can perform surface imaging well in high-resolution imaging mode in open holes. Can also perform casing inspection and cement bond evaluation in full wave mode at casing holes. The proposed tool was tested in practice. This shows that this tool can evaluate geological feature information such as fractures and layered structures in open holes. Imaging casing thickness, inner and outer diameters and cement impedance can also be measured at casing holes. Cement analysis in wells Logging Tool (MUIL), cement slurry design and operations during cementing. The logging results above can be analyzed quantitatively including amplitude readings which can then determine compressive strength prices and bond index prices. Meanwhile, qualitative analysis was carried out comprehensively from VDL recordings and using the Enhanced Logging Imaging System. For analysis from a design perspective, it looks at the cement slurry planning, while from an operational perspective it looks at the suitability between planning and implementation in the field.
Evaluation of the Hydraulic Fracturing Implementation at Well WEA-01 Layer A3 Edgie Yuda Kaesti; Suwardi Suwardi; Ratna Widyaningsih; Muhammad Zakiy Yusrizal; Wijaya Ananditya Rifqi; Puji Hartoyo
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.v4i2.9834

Abstract

The WEA-01 well produces in the A3 productive layer, talangakar formation with a layer thickness of 32.80 ft with a perforation interval of 4340.55 – 4360.24 ftMD where from petrophysical data this formation is dominated by sandstone with a permeability of 3 mD which is classified as low and a tight formation (Koesoemadinata, 1980) with 10% porosity. This is the basis for the stimulation of Hydraulic Fracturing. Hydraulic fracturing that has been implemented needs to be evaluated to find out whether the implementation has been carried out optimally or not.The method to be used in the evaluation of the WEA-01 Well hydraulic fracturing implementation includes data collection, then manual calculations and evaluation with actual data. The first evaluation was to calculate the geometry of the fracture using the 2D PKN method, the second evaluation was to calculate the price increase in the productivity index using the Cinco-ley Samaniego and Dominique method and the third evaluation was to analyze the IPR curve (Inflow Performance Relationship) before fracturing using the Darcy method and after fracturing using the Pudjo Sukarno method.Based on the results of manual fracture geometry calculations using the 2D PKN method, the results obtained are fracture length (Xf) of 200.07 ft, fracture height (hf) of 32.80 ft, and fracture width (wf) of 0.23 inch, fracture conductivity of 5094.70 mD-ft, and FCD 8.5, while the results of calculating the average permeability of formations using the Howard & Fast method obtained permeability after Hydraulic Fracturing of 15.71 mD or an increase of 5.2 times from the initial conditions and calculating the productivity index using the Cinco-Ley, Samaniego & Dominique method obtained an increase in PI prices of 3.45 times and from the determination of the IPR curve, the results obtained from the comparison of the IPR curve showed an increase in the production rate from 45.00 BOPD to 330 BOPD. Based on the increase in the fluid production rate, the implementation of Hydraulic Fracturing that has been carried out can be said to be successful.Keywords – hydraulic fracturing, fracturing fluid, proppant, fracture geometry, permeability, conductivity
Improving Gas Recovery of Water Drive Gas Reservoir Marmora Titi Malinda; Sutopo Sutopo; Muhammad Taufiq Fathaddin
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.v4i2.10261

Abstract

A gas reservoir with bottom water drive has lower recovery factor compared to depletion drive gas reservoir. Along with the increase in gas demand and the majority of gas reservoirs are water-drive, a method that are still being developed to increase the recovey factor in water-drive gas reservoir is co-production method. This method reducing water influx by planned water production. In this study, a conceptual model of gas reservoir with depletion-drive and water-drive is build and being analyzed. Co-production technique is applied by adding one water production well to the water-drive gas reservoir. The recovery factor is being analyzed through some production scenarios. Sensitivity analysis are being done with parameters including: reservoir permeability, permeability anisotropy, aquifer volume, flow rate of water production, gas tubing head pressure, and gas well perforation interval Furthermore, experimental design, response surface methodology, and monte carlo simulation is used to analyze the influencing parameter of gas recovery factor. It is found from this study that co production increased gas recovery factor by 28% from water drive gas reservoir, with water production rate is the most influencing parameter.
Integrated Production Optimization of Mature Field Y Under Network Constraints Steven Chandra; Brian Tony; Rahma Widyastuti
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.v4i2.10986

Abstract

The Y Field, a mature field experiencing declining reservoir pressure, the production of hydrocarbons is declining, leading to the need for production optimization. One crucial aspect of this optimization is the selection of suitable artificial lift methods. The choice of artificial lift methods in Field Y is dependent on the unique reservoir conditions of each well. The commonly utilized equipment for artificial lift methods in Field Y includes the Sucker Rod Pump (SRP) and the Electrical Submersible Pump (ESP).This bachelor thesis aims to develop an integrated production optimization strategy for maximizing well production in Structure X, a mature field. The study involves analyzing and optimizing artificial lift methods and integrating surface network simulation. The Inflow Performance Rate (IPR) curve is utilized to identify the production potential of each well in Structure X.By evaluating the pump performance and surface network in Structure X, it is possible to identify wells that utilize artificial lift or existing pumps and have the potential to be improved up to their maximum operating range, based on their gross flow rate (BFPD). Through optimization, adjusting the stroke per minute for the Sucker Rod Pump (SRP) and the operating frequency for the Electrical Submersible Pump (ESP) can lead to a significant increase in production. Specifically, with a design production rate of 2308.59 BFPD, an improvement of 82.23 BOPD can be achieved.
Improving Well Productivity through the Combination of Deep Penetrating Perforation and High Energy Gas Fracturing Techniques Fanata Yudha Nugraha; Brian Tony; Damar Nandiwardhana; Angelica Catharine Zefanya; Nur Ilham Tarsila
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.v4i2.10814

Abstract

Perforation operations often result in formation damage and compacted zones, which can increase skin effect and decrease well productivity. To address these issues, a combination of deep penetrating perforation and high energy gas fracturing techniques can potentially solve these problems. This study utilized commercial software to simulate perforation and fracture geometry, and evaluated productivity using parameters such as skin effect, productivity index, and inflow performance relationships. Results showed that the combination technique increased productivity by 3.34 times compared to conventional perforation and 2.45 times compared to standalone deep penetrating perforation. This suggests that the combination technique effectively improves well productivity by reducing skin effect and increasing productivity index and flow rate. Overall, the study provides promising evidence for the effectiveness of the combination technique in improving well productivity.Keywords:  deep penetrating perforation; geometry; high energy gas fracturing; inflow performance relationship (IPR); productivity index (PI); skin effect
QUALITATIVE AND QUANTITATIVE ANALYSIS OF WATER CONING AND BREAKTHROUGH TIME PREDICTION ON ZNC FIELD Aqlyna Fattahanisa; Rini Setiati; Arinda Ristawati; Puri Wijayanti
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.v4i2.10108

Abstract

Given the current public need for oil and gas as a primary energy, all oil and gas companies need to increase production to meet this demand. One of the things companies usually do to achieve this is to evaluate and analyze the productivity of each well. Of course, production decreases from time to time, so the company must try to increase its production. One of the reasons for the decline in oil production from the ZNC-1 well in the ZNC Field is the production of excessive water content. There are several factors that cause excessive water content in oil wells, and this is called water coning. The method used to determine the occurrence of the water cone problem requires qualitative and quantitative analysis. In using qualitative analysis, two analyzes were carried out, including an analysis of the production history of the well and an analysis of the Chan Diagnostic Plot showing bottom-water coning problems with late-time channeling. Meanwhile, based on the quantitative results, the critical flow rate of the ZNC-1 well calculated using the Bornazel and Jeanson method is 167 STB/D. With these results, the value of the critical flow discharge is greater than the actual discharge, which is 291.3 STB/D. Thus it can be ascertained that there has been water coning in the ZNC-1 well. After that, the breakthrough time obtained by the Bournazel and Jeanson method was 361.3 days.
Rock Mineralogy Analysis of Airbenakat Formation to Map the Characteristics of the Reservoir Rocks in each Depositional Environment Kharisma Idea; Taufan Marhaendrajana; I GB Eddy Sucipta; Sri Feni
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.v4i2.10793

Abstract

The Airbenakat Formation is a sandstone reservoir which is one of the oil reservoirs located in Sumatra and is part of the South Sumatra Basin. The mineral composition of the sandstone reservoir in the Airbenakat Formation consists of quartz minerals as rock grains, clay as matrix and is often identified as cement, while carbonate as rock cement. Based on lithofacies observations, the depositional environment of the Airbenakat Formation consists of: Volcanic Alluvial Fan, Lake, Braid Bar, Braided Channel, Braid Deltaic Environment, Mud Flat, Tidal Sand Bar, Tidal Environment, Shallow Sea, and Deep Sea. This research was conducted on 2 (two) oil fields, namely MRP dan TPN which have different depositional environments but are included in the Airbenakat Formation as part of the South Sumatra Basin.The analyzes used in this study include X-Ray Diffraction (XRD) analysis, petrography, and Scanning Electron Microscopy with Energy Dispersive X-Ray Spectroscopy (SEM/EDX). Analysis of the mineralogical content of the Airbenakat Formation will assist to determine the performance of chemical injections such as injection of anionic surfactant. The anionic surfactant used for chemical injection in Airbenakat Formations will be optimal if the content of smectite and calcite minerals can be ascertained. The presence of smectite and calcite minerals will affect the results of anionic surfactant injection. This research shows the results of anionic surfactant injection on the presence of smectite and carbonate in the injected core.
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.

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