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All Journal Journal of Petroleum and Geothermal Technology Journal of Applied Sciences, Management and Engineering Technology (JASMET)
Tony, Brian
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Civil Engineering, Building, Construction & Architecture Decision Sciences, Operations Research & Management Earth & Planetary Sciences Energy Engineering Industrial & Manufacturing Engineering Materials Science & Nanotechnology

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Journal : Journal of Petroleum and Geothermal Technology

 1 
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.
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.
Co-Authors Aiman, Muhammad Naufal Alfathony Krisnabudhi Ardine, Joseph Emmanuel Astuti, Dian Indri Chandra, Steven Dani Mardiati, S.T., M.Eng. Dewi Asmorowati Farisan, Ardhan Isnani, Desi Kumala Muhamad Firdaus Al Hakim Nugraha, Fanata Yudha Pratomo, Septyo Uji Putra, I Putu Raditya Ambara Rizky, Aga Saputra, Ega Dimas Sugeng Widada Waisnawa, I Putu Gema Bujangga Wardhana, Annisa Nur Syifa