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All Journal JOURNAL OF EARTH ENERGY ENGINEERING Journal of Petroleum and Geothermal Technology Scientific Contributions Oil and Gas
Aziz, Prasandi Abdul
Institut Teknologi Bandung
Chemical Engineering, Chemistry & Bioengineering Earth & Planetary Sciences Energy Engineering Materials Science & Nanotechnology

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Application of Mechanistic Modeling for Gas Lift Optimization: A General Scaling Curve for Variations of Tubing Size to Optimum Gas Injection Prasandi Abdul Aziz; Ardhi Hakim Lumban Gaol; Wijoyo Niti Daton; Steven Chandra
Journal of Earth Energy Engineering Vol. 8 No. 2 (2019): OCTOBER
Publisher : Universitas Islam Riau (UIR) Press

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (2160.322 KB) | DOI: 10.25299/jeee.2019.vol8(2).3623

Abstract

Gas Lift is currently held as one of the most prominent method in artificial lift, proudly operated flawlessly in hundreds of oil wells in Indonesia. However, gas lift optimization is still governed by the exhaustive Gas Lift Performance Curves (GLPC). This practice, albeit as established as it should be, does require repetitive calculations to be able to perform in life of well operations. Therefore, a new approach is introduced based on the mechanistic modeling. This research highlights the application of fundamental mechanistic modeling and its derivative, the Flow Pattern Map (FPM) for quick estimation of optimum injection gas rate, accompanied by a novel correction factor to account changing tubing sizes. It is hoped that this approach can be beneficial in developing a multitude of gas lift wells with changing tubing sizes.
Economic Evaluation of Fiscal Regime on EOR Implementation in Indonesia: A Case Study of Low Salinity Water Injection on Field X Adityawarman Adityawarman; Faridh Afdhal Aziz; Prasandi Abdul Aziz; Purnomo Yusgiantoro; Steven Chandra
Journal of Earth Energy Engineering Vol. 9 No. 1 (2020): APRIL
Publisher : Universitas Islam Riau (UIR) Press

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (1154.331 KB) | DOI: 10.25299/jeee.2020.4608

Abstract

There are currently two fiscal regimes designated for resource allocation in Indonesia’s upstream oil and gas industry, the Production Sharing Contract Cost Recovery (PSC) and Gross Split. The Gross Split in the form of additional percentage split is designed to encourage contractors to implement Enhanced Oil Recovery (EOR) in mature fields. Low Salinity Water Injection (LSWI) is an emerging EOR technique in which the salinity of the injected water is controlled. It has been proven to be relatively cheaper and has simpler implementations than other EOR options in several countries. This study evaluates the LSWI project’s economy using PSC and Gross Split and then to be compared to conventional waterflooding (WF) project’s economy. There are four cases on Field X that are simulated using a commercial simulator for 5 years. The cases are evaluated under PSC and Gross Split to calculate the project’s economy. The economic indicators that will be evaluated are the Net Present Value (NPV) and sensitivity analysis is also conducted to observe the change of NPV. The parameters for sensitivity analysis are Capital Expenditure (CAPEX), Operating Expenditure (OPEX), Oil Production, and Oil Price. It is found that LSWI implementation using Gross Split is more profitable than PSC. The parameters that affects NPV the most in all PSC cases are the oil production and oil price. On the other hand, in Gross Split cases, the oil production is the parameter that affects NPV the most, followed by oil price. The novelty of this study is in the comparison of project’s economy between WF and LSWI using two different fiscal regimes to see whether Gross Split is more profitable than PSC on EOR implementation, specifically the LSWI at Field X.
Risk Mitigation and Mapping on Tubular System During Microbial Huff and Puff Injection Coupled with Lean Six Sigma Approach at Field X Steven Chandra; Prasandi Abdul Aziz; Wijoyo Niti Daton; Muhammad Rizki Amrullah
Journal of Petroleum and Geothermal Technology Vol 2, No 2 (2021): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v2i2.4902

Abstract

Increasing demand of oil in Indonesia is in contrast with the decreasing oil production every year. Enhanced oil recovery (EOR) has become one of the most favorable method in maximizing the production of mature fields with various applications and research has been done on each type, especially microbial EOR (MEOR). “X” field is a mature oil field located in South Sumatra that has been actively producing for more than 80 years and currently implementing MEOR using huff and puff injection. However, there are some potential risks regarding MEOR processes that may inhibit the production by damaging the well’s tubular system, particularly microbially induced corrosion (MIC). This study reviews the risk mitigation and mapping to prevent corrosion on tubular system during MEOR huff and puff processes, equipped with the approach of Lean Six Sigma.The mitigation and mapping process follow the framework of define, measure, analyze, improve, and control (DMAIC). It starts with defining the problem using supplier-input-process-output-customer (SIPOC) diagram after all the field data necessary has already been collected, then measuring the corrosion rate model using ECE™ software as well as conducting sensitivity analysis of the fluid rates. The analyze phase involves constructing fishbone diagram to identify the root causes, comparison with industry’s specification and standard, and analysis of chromium effect on corrosion rates. Further simulation is conducted to support the analysis and to ensure the improvements and sustainability of the design selection.Based on the simulation results, the normal corrosion rate ranging from 0.0348 – 0.039 mm/year and the pH is around 4.03 – 5.25, while the ±30% fluid rate sensitivity results shown that the change of water flowrate is more sensitive than oil flowrate with the corrosion rate approximately 0.0275 – 0.048 mm/year. The fishbone diagram identifies that material selection and environmental condition as the main root causes, then corrosion resistant alloy (CRA) is used in the tubing string to prevent corrosion in the future by using super 13Cr martensitic steel (modified 2Ni-5Mo-13Cr) as the most suitable material. Further simulation on chromium content supports the selection that corrosion rate can be reduced by adding the chromium content in the steel. The completion design is then capped with choosing the Aflas® 100S/100H fluoro-elastomer as the optimum material for packer and sealing. Overall, the Lean Six Sigma approach has been successfully applied to help the analysis in this study.
Techno-Economic Solution For Extending Ccus Application In Natural Gas Fields: A Case Study Of B Gas Field In Indonesia Prasandi Abdul Aziz; Mohammad Rachmat; Steven Chandra; Wijoyo Niti Daton; Brian Tony
Scientific Contributions Oil and Gas Vol 46 No 1 (2023)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.46.1.1321

Abstract

The application of carbon trading has been applied since 2005 in Northern America, has been adapted in Indonesia with pilot scale implementation namely as Carbon Capture and Storage. One of the biggest issue is the lack of financial incentive in conducting the CCS. Therefore, Carbon Capture, Utilization and Storage (CCUS) serves as an alternative to increase the economic value of the injected CO2. This study presents a new approach of CCUS studied in B Field in Indonesia, a natural gas producer with high CO2 and H2S content. By injecting CO2 as a mean of pressure maintenance, 5.8% of incremental gas production is achieved whilst being able to sequester 2.7 million tonnes of CO2 for 10 years operation. This study should become a pioneer in continuing researches related to enhanced CCS methods by increasing the value of CO2 as well as reducing dependency in expensive chemical EOR injection in the future
The Effect of Co2-Brine-Rock Interaction Towards Sand Onset Modeling in Dolomite-Rich Sandstone: A Case Study in Air Benakat Formation, South Sumatera, Indonesia Prasandi Abdul Aziz; Bagus Endar Bachtiar Nurhandoko; Taufan Marhaendrajana; Utjok W.R. Siagian; Tutuka Ariadji
Scientific Contributions Oil and Gas Vol 47 No 3 (2024)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.47.3.1682

Abstract

Carbon Capture Utilization Storage (CCUS) into geological storage (e.g., Enhanced Oil or Gas Recovery) provides a solution to reduce CO2 emissions yet remains a potential operational problem, such as sand problem phenomena in producer well. This study performs several experimental works (i.e., time-lapse dry mass measurements, , X-Ray Diffraction (XRD), Scanning Electron Microscope (SEM) and elastic wave measurements) by using CO2-brine-rock batch experimental setup to observe mineral dissolution, pore structures alteration as well as rock physics alteration due to CO2-brine-rock interactions.This study used an outcrop sample of dolomite-rich sandstone from Air Benakat formation, South Sumatera, Indonesia. Our experimental works observed dolomite dissolution, secondary porosity development as well as rock strength reduction indirectly due to CO2-brine-rock interactions. The results of elastic wave velocity measurements (i.e. P & S waves) were then used to modify a considerable sand onset prediction model. Thus, the modified model demonstrates that considering CO2-brine-rock interactions could help to design better sand management strategy in producer well.
A Techno-Economic Approach to Optimizing CCS Fiscal Parameters in Indonesia: A Case Study of Integrated Oil and Gas Development in CO2-Rich Areas Najeela Faza Ramadhani; Dedy Irawan; Sudono; Prasandi Abdul Aziz
Scientific Contributions Oil and Gas Vol 48 No 3 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i3.1809

Abstract

This study introduces a techno-economic approach to optimizing storage fees for CCS integrated with oil and gas development. The analysis adopts the production sharing contract cost recovery model in accordance with the implementation of Ministerial Regulation of Energy and Mineral Resources No. 16 of 2024, which addresses CCS-related parameters. Technical assessment confirms the studied reservoir’s suitability for long-term CO₂ injection through 5 injection wells, while oil and gas development are supported by 10 oil wells and 8 gas wells. The project’s economic viability under baseline conditions shows an IRR of 10.14% and POT of 15.73 years. Sensitivity analysis across fiscal parameters, such as investment credit, FTP, contractor split, CCS service fee and storage fee, CAPEX, royalty, and tax, identifies the storage fee as the most influential factor for viability. To achieve a commercially viable IRR of 15%, the project requires a minimum CCS service fee of 55 US$/MT and a storage fee of at least 35 US$/MT. The study underscores the need for clear regulations on fiscal incentives, CO₂ pricing, storage fees, and PSC integration to enhance CCS economic viability, while also offering a replicable framework for CO₂ assessments under dynamic fiscal regimes.
CO2 Storage Screening Criteria Based on Seal Capacity in Indonesia Destiana, Syifa; Dedy Irawan; Prasandi Abdul Aziz; Ika Merdekawati
Scientific Contributions Oil and Gas Vol 48 No 4 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i4.1829

Abstract

CO2 storage screening ensuring the long-term containment of injected CO2 and the integrity of carbon capture and storage. In Indonesia, robust seal evaluation is constrained by the limited availability of caprock core data. This study develops a dimensionless Caprock Quality Index (CQI) as a practical CO2 storage screening tool based on displacement pressure (Pd) and caprock thickness (h). Displacement pressure is estimated using an empirical Pd equation derived from existing caprock core data. The CQI provides a quantitative classification of seal quality within the 0-1 range, where values closer to 1 indicate better caprock quality. Based on the data availability of this study, the results show that the Banggai and Salawati basins currently exhibit the highest CQI, indicating strong suitability for CO₂ storage. This study provides a framework for conducting preliminary CO₂ storage screening, particularly valuable in settings where caprock core data are sparse and contributes to the development of a more efficient, data-driven framework for future CCS planning and implementation.
Co-Authors Adityawarman Adityawarman Ardhi Hakim Lumban Gaol Bagus Endar Bachtiar Nurhandoko Brian Tony Brian Tony Daton, Wijoyo Niti Dedy Irawan Dedy Irawan Prihandoko Destiana, Syifa Faridh Afdhal Aziz Ika Merdekawati Mohammad Rachmat Mohammad Rachmat Muhammad Rizki Amrullah Najeela Faza Ramadhani Steven Chandra Steven Chandra Steven Chandra Steven Chandra, Sudono Taufan Marhaendrajana Tutuka Ariadji Utjok W.R. Siagian Wijoyo Niti Daton Yusgiantoro, Purnomo