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

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Analisa Keekonomian Pada Proyek Injeksi Surfaktan Sumur 04 Lapangan Delima Dengan Menggunakan Psc Cost Recovery Erika Maulina; Firdaus; Eka Megawati; Ali Muchammad; Abdi Suprayitno; Kartika Choriah; Darmiyati, Iin
AL-MIKRAJ Jurnal Studi Islam dan Humaniora (E-ISSN 2745-4584) Vol. 3 No. 2 (2023): 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.v3i2.7159

Abstract

The role of fossil energy such as oil, natural gas, and coal in various economic activities is currently irreplaceable and has become a major need for the Indonesian people. The increasing needs of the community are sometimes not proportional to the results of the amount of production, as happened at Well 04 in the Delima Field, need surfactant injection because the production flow rate is decreasing. The purpose of conducting an economic analysis on this surfactant injection project is to detrmine whether choosing a surfactant injection method will produce appropriate profits. The system used in this economic analysis is PSC Cost Recovery using economic indicators NPV, IRR, POT, and Benefit to Cost. For sensitivity analysis using NPV Contractor, IRR Contractor, Contractor Take, and Government Take. Based on the results of calculations that have been carried out, the net profit value received by the contractor is 13.359.765 US$ and that received by the government is 16.420.258 US$. While the results of the sensitivity analysis that has been carried out, it is known that the most influential parameters are cumulative production and oil prices which are directly proportional.
Peramalan Produksi Hidrokarbon Berdasarkan Decline Curve Analysis (DCA) Dengan Metode Levenberg-Marquardt Algorithm (LMA) Pada Sumur HS-0105 Lapangan AG Hasnawi Hs; Dharma Arung Laby; Abdi Suprayitno; Abdul Gafar Karim; Amiruddin; Luthfiyah Atisa Fadhilah
AL-MIKRAJ Jurnal Studi Islam dan Humaniora (E-ISSN 2745-4584) Vol. 4 No. 1 (2023): 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.v4i1.7164

Abstract

Hydrocarbon production forecasting is the process of projecting oil or gas production over a period of time. One commonly used method is production modeling with Decline Curve Analysis (DCA). Many previous studies have used the Trial Error and Chisquare test method in DCA. However, this method has limitations including: long calculation time, modeling is done manually and not automatically, and the fit of the production curve with the data is often inaccurate. To overcome these limitations, a method that is fast, automatic and produces accurate curves with data is needed. One of them is the Levenberg-Marquardt Algorithm (LMA) numerical optimization approach. The Levenberg-Marquardt Algorithm method is an iterative method used to solve nonlinear optimization problems. The Levenberg Marquardt Algorithm method has advantages such as: reliability, fast convergence, and has been widely applied in engineering optimization problems. This study aims to forecast hydrocarbon production, calculate EUR (Estimated Ultimate Recovery) and ERR (estimated remaining reserve) at well HS-0105 AG field. First, a DCA program based on LMA was developed with the MATLAB programming language. After that, the production data is inputted into the LMA program to do production modeling until the optimum curve is obtained. After obtaining the optimum DCA curve, a comparison was made with the curve resulting from trial and error. From the results of DCA curve optimization with LMA, the RMSE (Root Mean Square Error) value = 101,756, R2 (R-squared) value = 0,574, computation time 2-3 seconds in the Levenberg-Marquardt Algorithm (LMA) method while the Trial Error and Chisquare test method RMSE (Root Mean Square Error) value 128.905 R2 (R squared) value = 0.569 and long computation time. From the comparison results, the Levenberg-Marquardt Algorithm (LMA) method is much better than Trial Error and is recommended for use. Based on the Decline Curve Analysis with the Levenberg-Marquardt Algorithm (LMA) method, the EUR (Estimated Ultimate Recovery) value is 14339,525 STB and the ERR (estimated remaining reserve) value is 7693,091 STB at the HS-0105 well in the AG field. With the results of this projection, it is expected that the production of the HS-0105 well in the AG field can be stimulated to withstand the rate of decline in production and even increase.
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 (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.v2i1.7349

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 Abdul Gafar Karim Ali Muchammad Amiruddin Aprilno Alfa Kumasela Baiq Maulinda Ulfah Darmiyati, Iin Dharma Arung Laby Eka Megawati Erika Maulina Firdaus Hasnawi Hs Hizkia Erick Sualang Kartika Choriah Luthfiyah Atisa Fadhilah Risna