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All Journal Al-MIKRAJ: Jurnal studi Islam dan Humaniora
Aprilno Alfa Kumasela
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Economics, Econometrics & Finance Education Languange, Linguistic, Communication & Media Law, Crime, Criminology & Criminal Justice Social Sciences

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Penilaian Dan Optimalisasi Konfigurasi Rekahan Hidraulik Sumur “HE-04” di Lapangan “S” Dharma Arung Laby; Abdi Suprayitno; Amiruddin; Aprilno Alfa Kumasela; Hizkia Erick Sualang; Darmiyati, Iin
AL-MIKRAJ Jurnal Studi Islam dan Humaniora (E-ISSN 2745-4584) Vol. 2 No. 2 (2022): Al-Mikraj, Jurnal Studi Islam dan Humaniora
Publisher : Pascasarjana Institut Agama Islam Sunan Giri Ponorogo

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.37680/almikraj.v2i2.7344

Abstract

Well “HE-04” in Field “S” is a hydrocarbon production well located in a reservoir with relatively low permeability, measured at 10.80 mD. This low permeability results in a low productivity index (PI). To enhance well productivity, hydraulic fracturing was performed to create conductivity between the reservoir and the wellbore, with the objective of increasing the PI. Hydraulic fracturing involves injecting fluid at high pressure to create fractures in the formation, followed by the placement of proppant to keep the fractures open. However, post-fracturing results indicated that the dimensionless fracture conductivity (FCD), which represents the fracture conductivity, remained low. Therefore, evaluation and optimization of the fracture geometry are necessary to achieve optimal conductivity and improve PI. This study evaluates the PI using the Prats method and optimizes the fracture geometry by redesigning the initial fracture using the Unified Fracture Design (UFD) method within the Perkins-Kern-Nordgren (PKN) geometry model. The process begins with an evaluation of the actual PI, followed by redesigning the fracture geometry to determine the maximum fracture dimensions. This maximum geometry is then optimized using the UFD method to obtain the most effective geometry. The optimization results show that the maximum fracture volume that can be generated is 685.51 m³, with a resulting FCD value of 8.37. The fold of increase (FOI) reached 8.54, an improvement of 5.43 compared to the actual FOI. This indicates that the optimized PI increased by 8.54 times from its initial value. Thus, the optimized fracture geometry design proves to be effective in enhancing the productivity of well “HE-04”.
Study Of Critical Flow Rate As A Water Coning Indicator In “Volve” Wells In Norway Production Fields Dharma Arung Laby; Abdi Suprayitno; Amiruddin; Aprilno Alfa Kumasela; Abdul Gafar Karim; Darmiyati, Iin
AL-MIKRAJ Jurnal Studi Islam dan Humaniora (E-ISSN 2745-4584) Vol. 2 No. 1 (2021): Studi Keislaman dan Humaniora
Publisher : Pascasarjana Institut Agama Islam Sunan Giri Ponorogo

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.37680/almikraj.v2i1.7347

Abstract

Oil wells with water drive propulsion, if produced then water will move towards the well hole to form a cone. Under certain conditions, water will break into the well and begin to be produced along with oil and this phenomenon is called water coning, therefore a critical flow rate calculation is carried out to determine the limit of the flow rate allowed by the well to produce without water coning. The purpose of this final project research is to determine the value of the critical flow rate in the methods used, namely the Mayer Gardner and Pirson method and also the Schols method, and the calculation of time to brekthrought with the Sobicinski and Cornelius method is carried out to determine the time needed for water to reach bottom perforation. The results of calculating the flow rate with the Mayer Gardner and Pirson method of 5.21 STB / day, then obtained time to breakthrough for 82437,02 days, and at the flow rate with the schools method of 0.23 STB / day obtained a flow rate of 4729678 days and if the well is produced at the actual rate of 86.5684 STB / day then the time to breakthrough is obtained for 418 days.
Production Optimization Through Horizontal Well Geometry : Toe-Up Vs Toe-Down Dharma Arung Laby; Abdi Suprayitno; Amiruddin; Aprilno Alfa Kumasela; Abdul Gafar Karim; Darmiyati, Iin
AL-MIKRAJ Jurnal Studi Islam dan Humaniora (E-ISSN 2745-4584) Vol. 2 No. 1 (2021): Studi Keislaman dan Humaniora
Publisher : Pascasarjana Institut Agama Islam Sunan Giri Ponorogo

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.37680/almikraj.v2i1.7348

Abstract

Horizontal wells are wells that are widely used in the oil and gas industry considering their effectiveness in increasing the productivity of a well. In field V, horizontal wells are not completely horizontal (90 degrees). Due to deviations in the geological formation, the drilled wells follow the formation dip. This study aims to determine the most optimal well model from several scenarios (toe-up, horizontal, or toe-down) and identify the dominant flow regime in the well. In this study, the author models well productivity and flow regimes with several scenarios. Such as the original scenario, true horizontal (90 degrees), toe-up (95 and 100 degrees) and toe-down (80 and 85 degrees). In each scenario, several different flow patterns or flow regimes can occur such as dispersed bubble flow, plug flow, annular flow, and slug flow. After comparing the productivity of each scenario, the results show that the toe-up scenario (100 degrees) has the highest oil production rate of 9401.8 STB/day, the original scenario 8599.7 STB/day, and the toe-down scenario (80 degrees) with 8237.6 STB/day has the lowest oil production rate. Therefore, toe-up (100 degrees) is the optimal well model used for horizontal wells in the V field compared to other scenarios. The gradient matching results for all well scenarios show a bubble flow pattern along the horizontal section of the well.
Multiphase Flow Behavior And Production Efficiency In Devuated Horizontal Wells Baiq Maulinda Ulfah; Abdi Suprayitno; Risna; Aprilno Alfa Kumasela; Abdul Gafar Karim; Darmiyati, Iin
AL-MIKRAJ Jurnal Studi Islam dan Humaniora Vol. 2 No. 1 (2021): Studi Keislaman dan Humaniora
Publisher : Pascasarjana Institut Agama Islam Sunan Giri Ponorogo

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.37680/almikraj.v2i1.7349

Abstract

In oil and gas production, horizontal wells are increasingly used to enhance reservoir performance by placing a longer wellbore section within the reservoir. These wells often adopt specific inclinations either upward-sloping or downward-sloping terminal sections to align with formation dip and minimize issues such as liquid loading. However, undulating trajectories in horizontal wells may lead to challenges such as liquid accumulation in downward-sloping sections and gas entrapment in upward-sloping sections, potentially reducing production efficiency. This study aims to predict fluid production rates and analyze multiphase flow behavior in horizontal wells with varying wellbore inclinations using a production simulator. Four scenarios were modeled: Original, True Horizontal, Upward-Inclined End (95° and 100° inclination), and Downward-Inclined End (80° and 85° inclination). The study utilized 20 deviation survey data points from Well F-14 in Field ‘V’ to construct the well trajectory models, adhering to the simulator’s input limitations. Simulation results indicate that the upward-inclined configuration with a 100° inclination achieved the highest oil production rate (9401.8 STB/day), outperforming other scenarios in both oil and gas flow rates. The enhanced performance is attributed to gravitational assistance in fluid movement and reservoir pressure expansion. In contrast, the downward-inclined geometry yielded the lowest production due to higher liquid holdup. Gradient matching was employed to identify dominant flow patterns and slip velocities, revealing bubble flow dominance in horizontal sections and transition to slug flow in mid-well segments. These findings highlight the importance of well trajectory design in optimizing multiphase fluid flow and maximizing production in horizontal wells.
Co-Authors Abdi Suprayitno Abdul Gafar Karim Amiruddin Baiq Maulinda Ulfah Darmiyati, Iin Dharma Arung Laby Hizkia Erick Sualang Risna