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

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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%.
A Simulation Study on Polymer Mobility Design Strategies and Their Impact on Oil Recovery Efficiency and Displacement Mechanisms Ndaru Cahyaningtyas; Boni Swadesi; Mahruri Sanmurjana; Muhammad Rizky Rahmadsyah Lubis; Dedi Kristanto; Indah Widiyaningsih
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.v48i2.1661

Abstract

Polymer flooding is an effective enhanced oil recovery (EOR) technique, particularly when waterflooding alone proves insufficient in improving oil recovery. It is prominent to acquaint the principle of mobility control to understand the ability of polymer to overcome the oil displacement inefficiency of waterflooding, a requirement for a better sweep efficiency. This paper presents a comparative study of mobility control methods as critical parameters for polymer design. This paper investigates a simulation study of different simulation model to optimize polymer mobility design by comparing various mobility control methods. In this study, a compositional simulation model was built based on previous laboratory experiments validated by matching simulation results. Furthermore, to visualize the polymer displacement process, this study performs 1D, 2D, and 3D simulation models. The results indicates that polymer mobility design could affect the upstream viscosity, leading to high sweep efficiency and higher oil recovery. The study also suggests that the unit mobility ratio from the existing concept of conventional mobility control has invalid criteria to distinguish favourable and unfavourable conditions. The comparison with various mobility design methods reveals differences in recovery factors, influenced by some factors such as underlying assumptions and the specific conditions favoured by each method.
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.
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.
Determination of An Appropriate Method and Economic Cost Estimation for Plug and Abandonment of H-11 Well in The Tambun Field Luky Agung Yusgiantoro; Dedi Kristanto; Dimas Suryo Wicaksono; Karina Larasati; Vania Raina Stephanie; Gondo Irawan
Scientific Contributions Oil and Gas Vol 49 No 3 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i3.2141

Abstract

In accordance with Indonesian regulations, oil and gas wells approaching the end of their productive life and no longer economically viable must undergo plug and abandon (P&A) operations. The associated costs are the responsibility of the operating company. Therefore, operator must conduct technical and economic assessments to ensure that P&A operations are performed cost-effectively while complying with safety requirements, operational standards, and applicable national regulations. This study compares two plugs and abandonment methods for a directional well by evaluating the technical and economic performance of the SNI 13-6910-2002 and NORSOK Standard D-010. The Tambun field comprises several production wells, including the H-11 well, which was selected as the reference case  for planning permanent abandonment after reaching its economic limit. The P&A design was developed by identifying the well sections requiring cement isolation and calculating the required volumes of  cement, additives, and completion fluids using the rig-based abandonment method. The results provide an appropriate abandonment strategy and costs estimate for the tH-11 well based on both standards. The estimated abandonment cost is USD 505,737.59 using SNI 13-6910-2002, compared with USD 1,170,558.11 using NORSOK Standard D-010. Based on the comprehensive technical assessment, operational safety considerations, regulatory compliance, and economic evaluation, SNI 13-6910-2002 is recommended as the most suitable method for the permanent plug and abandonment of the H-11 well in Tambun field.
Co-Authors Aditya Kurniawan Boni Swadesi Cahyaningtyas, Ndaru Carin Nova Azzaria Dewi Asmorowati Dimas Suryo Wicaksono Eko Widi Pramudyohadi Fadli Ramdhani Gondo Irawan Hariyadi Hariyadi Hariyadi Indah Widiyaningsih Indah Widiyaningsih Karina Larasati Luky Agung Yusgiantoro Mahruri Sanmurjana Muhammad Iqbal Arizzqi Nuzli Muhammad Rizky Rahmadsyah Lubis Rahajeng Suryo Rahmadhini Unggul Setiadi Nursidik Unggul Setiadi Nursidik Vania Raina Stephanie