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Ditemukan: 6 dokumenPEMODELAN GEOMEKANIKA 1D UNTUK ESTIMASI WELLBORE COLLAPSE PRESSURE BERBASIS KRITERIA MOHR-COULOMB DAN MODIFIED-LADE BESERTA PERANCANGAN HYDRAULIC FRACTURING
Operasi pengeboran dan stimulasi di Cekungan “SHEDNA” menghadapi tantangan akibat aktivitas tektonik intensif. Ketidakpastian rezim tegasan dan tekanan pori memicu ketidakstabilan lubang bor seperti kick, blowout, dan keruntuhan dinding sumur yang menaikkan risiko serta biaya operasi. Penelitian ini mengkarakterisasi geomekanika Sumur “AMQ-036” di Cekungan “SHEDNA” untuk mitigasi risiko pengeboran sekaligus perancangan stimulasi. Model Geomekanik 1D dibangun untuk menentukan mekanisme overpressure, rezim tektonik, dan magnitudo SHmax melalui stress polygon. Jendela lumpur pengeboran ditentukan dari wellbore collapse pressure dengan kriteria Mohr-Coulomb dan Modified-Lade, lalu hydraulic fracturing Perkins-Kern-Nordgren (PKN) 2D dirancang pada lima zona target melalui optimasi grid search. Data yang digunakan berupa wireline log (gamma ray, densitas, sonik) dan citra Formation Micro Imager (FMI). Mekanisme overpressure pada Formasi B, C, dan D didominasi unloading, dengan rezim strike-slip bertransisi ke normal faulting dan orientasi SHmax sekitar N60°E-N70°E. Jendela lumpur Modified-Lade konsisten lebih lebar karena memasukkan tegasan utama menengah, dan sebagian interval overpressure menunjukkan tekanan pori melampaui collapse pressure. Pemodelan PKN menghasilkan panjang rekahan satu sayap (Xf) 213-216 m, lebar maksimum 2,806-8,844 mm, dan tekanan breakdown 6.123-10.759 psi bergantung kedalaman dan rezim tegasan lokal. Hasil ini menjadi panduan teknis terintegrasi untuk pengeboran dan stimulasi di Cekungan “SHEDNA”.
SIMULASI NUMERIK PROPAGASI REKAHAN HIDROLIK DAN ANALISIS SENSITIVITAS PARAMETER GEOMEKANIKA MENGGUNAKAN PYFRAC: STUDI KASUS PADA SUMUR A, JAWA BARAT
Hydraulic fracturing is a key stimulation technique to enhance hydrocarbon recovery in low permeability reservoirs. This study investigates fracture propagation in selected zones and the influence of geomechanical parameters on fracture behavior. Potentially productive intervals were identified through composite log interpretation, while potential fracturing zones were evaluated based on mechanical properties. Hydraulic fracturing simulations were performed using PyFrac with a PKN model to represent height-contained propagation. Simulation results include fracture geometry, pressure distribution over time, and fracture growth characteristics. The simulation of selected zone showed that fracture propagation started in a viscosity-dominated regime and shifted to PKN behavior once the fracture reached height-confining layers. The fracture performance evaluation indicates an improvement in well productivity after hydraulic fracturing compared to the pre-fracturing condition. Sensitivity analysis on geomechanical parameters showed that higher Poisson’s ratio and Young’s modulus reduced fracture width and increased breakdown pressure, while higher fracture toughness resulted in wider fractures and higher initiation pressures. These findings highlight the significant impact of rock mechanical properties on fracture propagation, providing insights for selecting favorable zones or formulating appropriate stimulation strategies based on specific geomechanical conditions.
PEMODELAN PROPAGASI REKAHAN PADA PROSES PEREKAHAN HIDRAULIK BERTAHAP MENGGUNAKAN KERANGKA PYFRAC© YANG DIMODIFIKASI: STUDI KASUS DI SUMUR X
Hydraulic fracturing is a widely applied method to improve hydrocarbon recovery in low permeability and unconventional reservoirs. Among various available tools, PyFrac© offers an open source and modifiable Python based platform for modeling fracture behavior. However, the original version of PyFrac© is limited to single stage fracture simulation, which restricts its use in field applications that involve multistage hydraulic fracturing. This study adapts PyFrac© to enable fracture propagation modelling in multistage hydraulic fracturing by incorporating depth dependent looping and trajectory based input modification. The developed framework allows the simulation of multiple fracture stages along a horizontal wellbore and enables detailed observation of fracture propagation characteristics throughout the stimulation sequence. The simulation results demonstrate that fluid viscosity significantly affects the rate and extent of fracture growth. Higher viscosity causes delayed propagation by maintaining the fracture in a viscosity dominated regime for a longer duration before transitioning to height contained propagation. In contrast, lower viscosity facilitates faster pressure transmission to the fracture tip, resulting in earlier propagation onset and increased fracture length. Variations in fracture toughness also influence the propagation response, particularly under low viscosity conditions. The adapted PyFrac© framework provides a practical approach for visualizing and quantifying fracture width, length, and propagation regimes in multistage hydraulic fracturing scenarios. This approach supports early stage fracture design and improves the understanding of fracture propagation behavior under different fluid and rock properties, especially in complex reservoir settings.
OPTIMIZATION OF HYDRAULIC FRACTURING DESIGN THROUGH PROPPANT MASS SENSITIVITY ANALYSIS AND ECONOMIC EVALUATION BASED ON PSC COST RECOVERY: CASE STUDY OF WELL X
Hydraulic fracturing is a well stimulation technique that enhances hydrocarbon production by creating conductive pathways in low-permeability formations through high-pressure fluid injection and proppant placement. The success of this treatment largely depends on optimal proppant selection and placement, which directly influences fracture conductivity and well productivity. This study evaluates the optimization of hydraulic fracturing design through proppant mass sensitivity analysis in Well X, an offshore well located in East Java Province, Indonesia. Six scenarios with varying proppant masses ranging from 25,000 to 250,000 lb were analyzed to determine the most profitable design while considering Production Sharing Contract (PSC) Cost Recovery mechanisms. The research methodology integrates hydraulic fracturing simulation, production performance analysis through nodal analysis, and economic evaluation. The fracturing simulation results show improvements in fracture geometry and conductivity with increasing proppant mass, with Scenario 6 achieving the largest fracture half-length of 374.3 ft and conductivity of 3,100 ft.md. Nodal analysis reveals significant production enhancement, with oil rates increasing from 1,193.80 STB/D in Scenario 1 to 2,511.44 STB/D in Scenario 6. Economic evaluation under PSC terms indicates that Scenario 6 yields the highest NPV of 6.15 MMUSD with an IRR of 41% and the shortest payback period of 1.93 years (23 months). The study concludes that higher proppant mass treatments, despite increased initial investments, generate superior economic returns through enhanced production rates. Keywords: Hydraulic Fracturing, Proppant Mass Sensitivity, Nodal Analysis, Production Sharing Contract (PSC) Cost Recovery, Economic Evaluation.
OPTIMALISASI PENGEMBANGAN RESERVOIR DENGAN RESISTIVITAS RENDAH MELALUI REKAHAN HIDROLIK: STUDI KASUS DI LAPANGAN
In this era, oil and gas industry have a crucial role for economic growth and energy demand in Indonesia. In the other hand, the production has aging in many fields due to the maturation. It means the industry must have a way to enhance this production. To address this, focusing on low resistivity zones that previously overlooked due to economic concerns and high watercut, offers a potential solution. These low resistivity reservoirs typically have low permeability, making fluid extraction challenging. One of well stimulation method, hydraulic fracturing, are used in this study which has shown promise in boosting production rates. In this study, reservoir modelling was carried out using tNav software to achieve the objective of the study. There were three cases that were modelled in this software, the first case is a base case without fracturing, the second case involves hydraulic fracturing in the first year, and the third case uses natural flow for the first five years, followed by hydraulic fracturing in the last five years. The objectives of this study are to evaluate the effectiveness of hydraulic fracturing in low resistivity zones, determine the best scenario for hydraulic fracturing in these zones, and identify the optimum scenario for economic profitability for both the contractor and the government. Based on the modelled, the cumulative oil production from every case is 1.3 mmstb, 2.2 mmstb, and 2.1 mmstb, respectively. Also, the results for economic evaluation that contractor and government generated in every case are 19.7 million USD and 19.9 million USD, 41.5 million USD and 42.3 million USD, and 29.8 million USD and 30.4 million USD, respectively. The study concludes that hydraulic fracturing is effective in low resistivity zones, boosting production rates and economic profitability. The best scenario is Case 2, where fracturing is applied in the first year. This case yields the highest oil and lowest water production, resulting in the highest Net Present Value (NPV).
OPTIMASI PRODUKSI PADA MATURE FIELD: SCREENING KANDIDAT SUMUR UNTUK STIMULASI HYDRAULIC FRACTURING
Saat ini produksi minyak di Indonesia terus mengalami penurunan karena banyak lapangan yang telah melewati puncak produksinya sehingga banyak sumur yang telah idle atau laju alirnya kecil. Dalam kondisi ini, diperlukan upaya untuk meningkatkan produksi minyak guna memenuhi kebutuhan energi nasional. Upaya tersebut adalah stimulasi sumur, salah satunya menggunakan hydraulic fracturing. Namun, diperlukan seleksi untuk memilih kandidat sumur yang dapat distimulasi karena biaya operasi yang tinggi untuk memaksimalkan produksi. Studi dilakukan pada lapangan Y yang merupakan lapangan minyak dengan formasi sandstone dengan jumlah sumur sebanyak 30 sumur produksi dan injeksi. Pemilihan kandidat sumur dillakukan menggunakan metode heterogeneity index menggunakan data produksi, penentuan recoverable reserve dengan decline curve analysis dan cum-cum plot, identifikasi data sumuran seperti permeabilitas dan skin, dan analisis evaluasi performa sumur menggunakan IPR Pudjo Sukarno (1986). Dari total 30 sumur, didapatkan 2 kandidat sumur untuk stimuasi hydraulic fracturing. Sumur yang kandidat stimulasi adalah TM-20 dan TM-25. Stimulasi hydraulic fracturing dilakukan pada kedua sumur tersebut dengan menggunakan model geometri rekahan PKN dan KGD. Model geometri KGD menunjukkan peningkatan laju alir yang paling tinggi dengan panjang rekahan untuk TM-20 adalah 200 ft, tinggi rekahan 42 ft, dan lebar rekahan 0.205 in., sedangkan untuk TM-25 panjang rekahan yang didapat adalah 250 ft, tinggi rekahan 34 ft, dan lebar rekahan 0.242 in. Dengan model geometri ini, didapat AOF minyak pada TM-20 sebesar 63.7 STB/day dan TM-25 adalah 264.1 STB/day. Studi yang dilakukan menunjukkan bahwa screening dan optimasi yang dilakukan dapat meningkatkan produksi sumur di lapangan tua.