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All Journal Journal of Petroleum and Geothermal Technology International Journal of Industrial Innovation and Mechanical Engineering
RATNA WIDYANINGSIH
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Astronomy Computer Science & IT Earth & Planetary Sciences Energy Engineering

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Evaluation of the Hydraulic Fracturing Implementation at Well WEA-01 Layer A3 Edgie Yuda Kaesti; Suwardi Suwardi; Ratna Widyaningsih; Muhammad Zakiy Yusrizal; Wijaya Ananditya Rifqi; Puji Hartoyo
Journal of Petroleum and Geothermal Technology Vol 4, No 2 (2023): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v4i2.9834

Abstract

The WEA-01 well produces in the A3 productive layer, talangakar formation with a layer thickness of 32.80 ft with a perforation interval of 4340.55 – 4360.24 ftMD where from petrophysical data this formation is dominated by sandstone with a permeability of 3 mD which is classified as low and a tight formation (Koesoemadinata, 1980) with 10% porosity. This is the basis for the stimulation of Hydraulic Fracturing. Hydraulic fracturing that has been implemented needs to be evaluated to find out whether the implementation has been carried out optimally or not.The method to be used in the evaluation of the WEA-01 Well hydraulic fracturing implementation includes data collection, then manual calculations and evaluation with actual data. The first evaluation was to calculate the geometry of the fracture using the 2D PKN method, the second evaluation was to calculate the price increase in the productivity index using the Cinco-ley Samaniego and Dominique method and the third evaluation was to analyze the IPR curve (Inflow Performance Relationship) before fracturing using the Darcy method and after fracturing using the Pudjo Sukarno method.Based on the results of manual fracture geometry calculations using the 2D PKN method, the results obtained are fracture length (Xf) of 200.07 ft, fracture height (hf) of 32.80 ft, and fracture width (wf) of 0.23 inch, fracture conductivity of 5094.70 mD-ft, and FCD 8.5, while the results of calculating the average permeability of formations using the Howard & Fast method obtained permeability after Hydraulic Fracturing of 15.71 mD or an increase of 5.2 times from the initial conditions and calculating the productivity index using the Cinco-Ley, Samaniego & Dominique method obtained an increase in PI prices of 3.45 times and from the determination of the IPR curve, the results obtained from the comparison of the IPR curve showed an increase in the production rate from 45.00 BOPD to 330 BOPD. Based on the increase in the fluid production rate, the implementation of Hydraulic Fracturing that has been carried out can be said to be successful.Keywords – hydraulic fracturing, fracturing fluid, proppant, fracture geometry, permeability, conductivity
Unveiling Heterogeneity's Reservoar Impact: A Reservoir Simulation Odyssey Into Cyclic Waterflooding Dynamics Ratna Widyaningsih; Edgie Yuda Kaesti; Dhika Permana Jati; Fahrur Rozi; Suwardi Suwardi; Adam Raka Ekasara
International Journal of Industrial Innovation and Mechanical Engineering Vol. 2 No. 3 (2025): August: International Journal of Industrial Innovation and Mechanical Engineeri
Publisher : Asosiasi Riset Ilmu Teknik Indonesia

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.61132/ijiime.v2i3.335

Abstract

Reservoir heterogeneity has long been recognized as a critical factor influencing the efficiency of enhanced oil recovery (EOR) methods. Among the techniques applied, cyclic waterflooding is considered one of the promising approaches due to its relatively simple operational design and potential to improve sweep efficiency. This method involves alternating water injection in specific cycles to mobilize trapped oil and redistribute reservoir pressure. However, the variation in geological properties such as porosity, permeability, and fluid saturation creates challenges in achieving uniform displacement, especially in reservoirs with high heterogeneity. Understanding the role of heterogeneity is therefore crucial for optimizing cyclic waterflooding applications. This study applies a literature review approach by synthesizing findings from previous experimental and field studies that evaluated cyclic waterflooding under different reservoir conditions. The analysis compares the performance of cyclic water injection periods across reservoirs characterized by varying levels of heterogeneity. Parameters such as injection rate, water breakthrough time, and oil recovery factor were considered in evaluating the effectiveness of this method. The results highlight that reservoirs with high heterogeneity often experience uneven fluid distribution, leading to early water breakthrough and reduced oil recovery. In contrast, reservoirs with relatively low heterogeneity tend to respond better to cyclic waterflooding, resulting in improved sweep efficiency and higher incremental recovery. Moreover, the optimization of cycle timing and water injection intervals appears to significantly mitigate the negative effects of heterogeneity. In conclusion, the study emphasizes that reservoir heterogeneity plays a decisive role in determining the success of cyclic waterflooding. Tailoring injection strategies based on geological variability is essential to maximize recovery efficiency. Future research should focus on integrating advanced reservoir characterization techniques with adaptive cyclic flooding models to further enhance oil production outcomes.
Co-Authors Dhika Permana Jati Edgie Yuda Kaesti Edgie Yuda Kaesti Ekasara, Adam Raka Fahrur Rozi Muhammad Zakiy Yusrizal Puji Hartoyo Suwardi Suwardi Suwardi Suwardi Wijaya Ananditya Rifqi