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All Journal Scientific Contributions Oil and Gas
Indah Widiyaningsih
UPN Veteran Yogyakarta
Chemical Engineering, Chemistry & Bioengineering Energy

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Optimization of CO2 Injection Through Cyclic Huff and Puff to Improve Oil Recovery Dedi Kristanto; Hariyadi Hariyadi; Eko Widi Pramudyohadi; Aditya Kurniawan; Unggul Setiadi Nursidik; Dewi Asmorowati; Indah Widiyaningsih; Ndaru Cahyaningtyas
Scientific Contributions Oil and Gas Vol 48 No 2 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i2.1659

Abstract

One of the Enhanced Oil Recovery (EOR) strategies in the petroleum industry is CO2 injection using the huff and puff method. The method is performed on one well that acts as an injection and a production well. The method works by injecting a certain volume of carbon dioxide (CO2) gas into the reservoir and then closing the well for a period of time. This injection cycle can take place over several cycles. Production can be carried out after one or more cycles according to the design. In this study, CO2 injection optimization with the huff and puff method is carried out with reservoir simulation (GEM-CMG) by taking data from one of the oil and gas wells in Indonesia, with carbonate rock characteristics that are water wet. The simulation work steps include inputting data (fluid, rock properties, and production), initialization, history matching, and CO2 injection optimization with the huff and puff method. The optimization scenarios include optimization of injection pressure and number of cycles. The injection pressure scenario uses a range of 500 - 3000 psi, based on the simulation results obtained that the injection pressure of 500 psi produces the highest recovery factor (RF) of 22.2%. Then, the cyclic scenario was carried out at the optimum injection pressure (500 psi) with the number of cycles 2 - 6 cycles. From the simulation results, it is found that the number of cycles for this carbonate reservoir condition does not have a significant effect, as evidenced by the RF values ranging from 22.1 - 22.3%.
Impact of Rhamnolipid Biosurfactants on Chemical Composition, Rheology, and Imbibition Performance of Crude Oils Harry Budiharjo Sulistyarso; Indah Widiyaningsih; Yulius Deddy Hermawan; Joko Pamungkas; Sayoga Heru Prayitno
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.v48i3.1859

Abstract

The application of biosurfactants in enhanced oil recovery (EOR) has generated significant interest owing to their biodegradability, low toxicity, and effectiveness in modifying oil–rock–brine interactions. Rhamnolipids—glycolipid biosurfactants synthesized by bacterial species—exhibit a distinctive amphiphilic structure that can alter the characteristics of crude oil at both molecular and macroscopic levels. This study offers a novel integrative evaluation of rhamnolipid-induced alterations in chemical composition, rheological properties, and imbibition efficacy of medium and light crude oils. The study utilizes gas chromatography–mass spectrometry (GC–MS) to clarify compositional changes in hydrocarbon fractions, viscosity assessments to measure rheological alterations in oil-biosurfactant mixtures, IFT measurements, and spontaneous imbibition experiments to analyze wettability changes and recovery efficacy. This study simultaneously examines compositional, viscosity, IFT, and capillarity-driven displacement mechanisms across two distinct crude oil categories, contrasting with prior research that focused solely on either compositional or interfacial properties within a single crude oil type, thereby offering comparative insights into biosurfactant–hydrocarbon interactions. The results are anticipated to enhance comprehension of biosurfactant-mediated enhanced oil recovery mechanisms, refine rhamnolipid application methodologies, and connect molecular-level alterations with core-scale oil recovery efficacy. This integrated method provides a novel framework for customizing biosurfactant formulations to particular crude oil varieties, thus improving recovery while preserving environmental sustainability.
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.
Co-Authors Aditya Kurniawan Bintang Pramuditha Dedi Kristanto Dewi Asmorowati Eko Widi Pramudyohadi Hariyadi Hariyadi Hariyadi Harry Budiharjo Sulistyarso Joko Pamungkas Mia Ferian Helmy Ndaru Cahyaningtyas Ndaru Cahyaningtyas Sayoga Heru Prayitno Unggul Setiadi Nursidik Yulius Deddy Hermawan