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All Journal Jurnal Offshore: Oil, Production Facilities, and Renewable Energy Scientific Contributions Oil and Gas
Hariyadi
UPN Veteran Yogyakarta
Chemical Engineering, Chemistry & Bioengineering Earth & Planetary Sciences Energy Engineering Mechanical Engineering

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Carbon Dioxide (CO2) Injection Planning Using Reservoir Simulation: A Review Dedi Kristanto; Hariyadi; Aditya Kurniawan; Eko Widi Pramudyohadi; Unggul Setiadi Nursidik; Muhammad Iqbal Arizzqi Nuzli; Fadli Ramdhani
Jurnal Offshore: Oil, Production Facilities and Renewable Energy Vol. 10 No. 1 (2026): Jurnal Offshore: Oil, Production Facilities and Renewable Energy
Publisher : Universitas Proklamasi 45

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.30588/jo.v10i1.2580

Abstract

Carbon dioxide (CO2) injection planning using reservoir simulation has become a significant method in improving oil recovery (EOR) and simultaneously reducing CO2 emissions to the environment. CO2 injection divided into two mechanism, immiscible and miscible injection, both of which depend on the injection pressure as well as reservoir characteristics. This study reviews various CO2 injection mechanisms and their effectiveness through reservoir simulations. In CO2 injection, a compositional reservoir simulation is used that takes into account the hydrocarbon composition and its equation in pressure, volume, temperature (PVT) analysis. The simulation was used to evaluate the storage capacity, CO2 migration, and optimize the injection strategy. Results show that CO2 injection can increase oil recovery, especially in tight reservoirs. Reservoir simulation provides a deeper understanding of reservoir behavior post-CO2 injection and enables more optimal planning in maximizing hydrocarbon recovery. Overall, this study emphasizes the importance of using reservoir simulation in CO2 injection planning and optimization. With the right approach, this technology can significantly increase oil recovery while aiding climate change mitigation through underground CO2 storage.
Reducing Uncertainty in Idle Well Reactivation: A Novel Integrated Screening Framework for Mature Oil Fields Sayoga Heru Prayitno; Hariyadi; Indah Widiyaningsih; Ndaru Cahyaningtyas; Mia Ferian Helmy; Bintang Pramuditha
Scientific Contributions Oil and Gas Vol 49 No 2 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i2.2089

Abstract

Mature oil fields are increasingly challenged by declining reservoir performance, resulting in a growing number of idle wells with remaining hydrocarbon potential. Despite their strategic importance, reactivation efforts are frequently constrained by high uncertainty in candidate selection due to fragmented evaluation practices, where production behaviour, well integrity, and reservoir quality are often assessed independently. This limitation often leads to suboptimal decision-making and unsuccessful reactivation programs.This study proposes an integrated screening framework to reduce uncertainty in idle well reactivation by systematically combining production diagnostics, well integrity evaluation, and reservoir characterization within a unified workflow.The proposed methodology integrates Water-Oil Ratio (WOR) trend analysis and WOR derivative analysis for water-production diagnostics, Cement Bond Log (CBL) interpretation for cement integrity and zonal isolation assessment, and petrophysical evaluation to determine reservoir quality and hydrocarbon potential. These parameters are incorporated into structured screening criteria to enable consistent classification of reactivation potential. The framework was applied to Well BP-16 in an Indonesian mature oil field as a representative case study. The results indicate that excessive water production and poor cement bonding are the dominant factors contributing to well inactivity. The integrated evaluation also identified a previously overlooked interval at 693–696 m with favourable reservoir properties and lower water-production risk.Compared with conventional single-domain evaluations, the proposed approach provides a more comprehensive understanding of subsurface conditions by linking production behaviour, well integrity, and reservoir characteristics within a single evaluation framework. This integration improves the reliability of reactivation candidate selection and supports more effective reactivation planning. The proposed framework offers a practical and field-applicable approach for optimizing idle well utilization, improving production efficiency, and extending the economic life of mature oil fields.
Integrated Logging, Production, and Geological Analysis for Bypassed Oil Identification in CNA Field, Central Sumatra Basin Karina Larasati; Dimas Suryo Wicaksono; Dedi Kristanto; Hariyadi; Rahajeng Suryo Rahmadhini; Carin Nova Azzaria
Scientific Contributions Oil and Gas Vol 49 No 2 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i2.2099

Abstract

The Central Sumatra Basin’s CNA Field has been producing hydrocarbons since 1974 and is now considered a mature oil field. The field contains six Long Term Closed (LTC) wells and two Plug and Abandonment wells, providing an opportunity to enhance hydrocarbon recovery by identifying and reactivating residual productive zones. The study is based on two LTC wells, CNA-01 and CNA-03, which are suspected to contain bypassed oil potential. Integrated evaluation of wireline logging data, production history, and geological correlation was performed to identify prospective bypassed oil zones. As a first step in the analysis, resistivity and permeability cut-off values were determined, followed by qualitative log interpretation to identify hydrocarbon-bearing intervals. The identified zones were then confirmed using production test data, structural correlation, and historical production performance. Moreover, Chan’s Diagnostic Plot was used to analyze the water production behavior and to identify the dominant water influx mechanism. Results indicated a total of nine potential bypassed oil intervals, with five intervals identified in well CNA-01 and four intervals identified in well CNA-03, within the BKA and BKB sand units. The main factors affecting bypassed oil are reservoir heterogeneity, variation in vertical permeability, channeling and discontinuous sand distribution. The integrated analysis suggests several workover strategies, including additional perforation in uncompleted hydrocarbon-bearing zones, reducing intervals affected by excessive water production, and squeeze cementing to isolate non-productive intervals. The results presented here demonstrate the value of integrated reservoir evaluation in identifying remaining hydrocarbon potential and aiding mature field redevelopment.
Co-Authors Aditya Kurniawan Azhar Faari Fatahillah Bintang Pramuditha Cahyaningtyas, Ndaru Carin Nova Azzaria Dedi Kristanto Dian Indri Astuti Dimas Suryo Wicaksono Eko Widi Pramudyohadi Fadli Ramdhani Fanata Yudha Nugraha Indah Widiyaningsih Karina Larasati Karina Larasti Mia Ferian Helmy Muhammad Iqbal Arizzqi Nuzli Rahajeng Suryo Rahmadhini Sayoga Heru Prayitno Unggul Setiadi Nursidik