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Ditemukan: 14 dokumenINTEGRASI PROPERTI GEOMEKANIKA DALAM OPTIMASI JARAK ANTAR KLASTER UNTUK MEMINIMALKAN EFEK STRESS SHADOW PADA SUMUR HORIZONTAL MARCELLUS SHALE
Hydraulic fracturing has become the primary stimulation technique for economically developing unconventional shale reservoirs. However, suboptimal cluster spacing can intensify stress shadow between adjacent fractures, reducing fracture conductivity and ultimately limiting hydrocarbon recovery. This study aims to quantify the influence of stress shadow on fracture conductivity, evaluate its impact on horizontal well performance through coupled geomechanics–reservoir simulation, and determine the optimum cluster spacing for a Marcellus shale reservoir. A one-dimensional Mechanical Earth Model (1D MEM) was constructed using gamma ray, bulk density, compressional sonic, and shear sonic logs acquired from the Boggess 17H vertical well. Elastic properties, including static Young's modulus and Poisson's ratio, were calculated to estimate the in-situ stress field, consisting of vertical stress, pore pressure, minimum horizontal stress, and net pressure. An analytical stress shadow model based on the Sneddon solution was subsequently employed to quantify induced stress and its effect on fracture conductivity for fracture halfheights ranging from 100 to 500 ft and cluster spacings between 0 and 500 ft. The calibrated geomechanical properties were spatially distributed into a three-dimensional reservoir model with tNavigator from RockFlowDynamics using Sequential Gaussian Simulation (SGS) and integrated with hydraulic fracture and dynamic reservoir simulations in tNavigator. Seven cluster spacing scenarios, including the base case, 15, 30, 45, 60, 75, and 90 ft, were evaluated using cumulative gas production, recovery factor, cumulative water production, gas drawdown, gas productivity index, and Estimated Ultimate Recovery (EUR). The analytical results indicate that induced stress decreases nonlinearly with increasing cluster spacing, leading to improved fracture conductivity, while the coupled simulations demonstrate that production performance is governed by the balance between stress shadow mitigation and fracture density. Among the evaluated scenarios, a cluster spacing of 45 ft yielded the highest EUR of 10.5 BSCF and representing a recovery factor of 31.85% compared with the non-hydraulic fracturing case. The proposed integrated workflow demonstrates that combining geomechanical characterization, analytical stress shadow quantification, hydraulic fracture simulation, and coupled reservoir simulation provides a technically robust framework for optimizing cluster spacing and improving completion design in unconventional shale reservoirs.
OPTIMIZING HYDRAULIC FRACTURE GEOMETRY AND CONDUCTIVITY THROUGH GEOMECHANICAL INTERPRETATION AND PROPPANT MASS SENSITIVITY: CASE STUDY OF GAOL-43 WELL IN TALANG AKAR FORMATION
Indonesia’s oil production has been declining over the past decades, meeting only about half of the national daily demand. One of the solutions is to improve the productivity of existing wells through hydraulic fracturing. This study focuses on the GAOL-43 well in the Talang Akar Formation (TAF), which is characterized by lowto- moderate permeability and high formation pressure, making it a suitable candidate for stimulation. The research methodology includes geomechanical analysis using well log data to determine mechanical rock properties such as Young’s modulus, Poisson’s ratio, and Unconfined Compressive Strength (UCS). These parameters were used to design the hydraulic fracturing treatment through simulation with proppant mass sensitivity analysis. The results, supported by Unified Fracture Design calculations, showed the best fracture geometry with an FCD of 1.605, a half-length of 106.2 ft, and a width of 0.241 in. Well productivity evaluation using the Fold of Increase (FOI) method indicated a successful productivity enhancement, with the Cinco, Samaniego & Dominguez method considered the most reliable. The results demonstrate that integrating geomechanical interpretation and proppant mass sensitivity effectively improves hydraulic fracture design and well performance. More importantly, the findings highlight the applicability of this method for optimizing oil recovery in the Talang Akar Formation and provide practical insights for its implementation in other well across Indonesia with similar characteristics.
REDESAIN PERLAKUAN HYDRAULIC FRACTURING BERDASARKAN SENSITIVITAS PADA RESERVOIR KARBONAT LEPAS PANTAI BERPERMEABILITAS RENDAH
XX-16 is an offshore oil production well located in the YY Field, East Java, Indonesia, targeting the Tuban carbonate formation. The well was previously drilled and completed as a water injection well in December 2012 and was later converted into a production well through a workover in early November 2017. Post-conversion testing indicated low oil production from the Tuban Carbonate intervals. Acidizing stimulation was previously performed; however, the response was insignificant due to silica and clay minerals domination from XRD analysis. Subsequently, hydraulic fracturing was implemented as an alternative stimulation method, however still resulting low productivity index remained which largely suspected by the cause of overestimated permeability in the initial design. This study aims to address the limitations of the previous stimulation attempts by evaluating and redesigning the hydraulic fracturing treatment for XX-16. This study involves sensitivity on selecting fracturing fluid and proppant to achieve optimum performance based on the Productivity Index (PI). The permeability sensitivity is performed to make sure the design is safe and remains applicable to the permeability uncertainties. Additionally, drainage area sensitivity is also performed to indicate its influence on the productivity index on the best scenario. As a result, the redesign shows significant improvement by the Productivity Index of 0.975 and Fold of Increase (FOI) of 3.8.
OPTIMIZED HYDRAULIC FRACTURE DESIGN USING A PREDICTIVE SIMULATED APPROACH: A CASE STUDY OF “X-3” WELL
Hydraulic fracturing is one of the effective methods of well stimulation that is widely used to enhance hydrocarbon production for wells experiencing a decline in production and having unconventional potential reserves that is unattainable through other stimulation methods. The purpose of a hydraulic treatment is to increase the productivity of a well. “X-3” oil well, located in Field “X” which is a mature oil field, is a candidate for hydraulic fracturing treatment due to its low productivity and reserves within a tight sand reservoir in TAF-1 formation which consists of low permeability shale-sand layers. This study aims to create a relevant interpretation of the targeted formation through geomechanics interpretation and design an optimum hydraulic fracture treatment based on the formation model. Geomechanics interpretation is conducted by analyzing a set well logging data to calculate elastic properties which is an important parameter of rock mechanics. Empirical approaches are used to create a permeability prediction model due to lack of data from core sample. The selection of fracturing fluid and proppant is based on existing guidelines that is adjusted to the case. The design of fracture geometry and treatment is based on the calculation of Unified Fracture Design which is set as an ideal reference for optimum geometry. A simulated approach using commercial fracturing software is conducted to generate a near-actual fracture model based on the calculated optimum geometry. The resulting accepted fracture geometry is analyzed to identify the increase of productivity through Folds of Increase determination and a 1-year production forecast.
OPTIMIZED HYDRAULIC FRACTURE DESIGN USING A PREDICTIVE SIMULATED APPROACH: A CASE STUDY OF “X-3” WELL
Hydraulic fracturing is one of the effective methods of well stimulation that is widely used to enhance hydrocarbon production for wells experiencing a decline in production and having unconventional potential reserves that is unattainable through other stimulation methods. The purpose of a hydraulic treatment is to increase the productivity of a well. “X-3” oil well, located in Field “X” which is a mature oil field, is a candidate for hydraulic fracturing treatment due to its low productivity and reserves within a tight sand reservoir in TAF-1 formation which consists of low permeability shale-sand layers. This study aims to create a relevant interpretation of the targeted formation through geomechanics interpretation and design an optimum hydraulic fracture treatment based on the formation model. Geomechanics interpretation is conducted by analyzing a set well logging data to calculate elastic properties which is an important parameter of rock mechanics. Empirical approaches are used to create a permeability prediction model due to lack of data from core sample. The selection of fracturing fluid and proppant is based on existing guidelines that is adjusted to the case. The design of fracture geometry and treatment is based on the calculation of Unified Fracture Design which is set as an ideal reference for optimum geometry. A simulated approach using commercial fracturing software is conducted to generate a near-actual fracture model based on the calculated optimum geometry. The resulting accepted fracture geometry is analyzed to identify the increase of productivity through Folds of Increase determination and a 1-year production forecast.
OPTIMIZED HYDRAULIC FRACTURE DESIGN USING A PREDICTIVE SIMULATED APPROACH: A CASE STUDY OF “X-3” WELL
Hydraulic fracturing is one of the effective methods of well stimulation that is widely used to enhance hydrocarbon production for wells experiencing a decline in production and having unconventional potential reserves that is unattainable through other stimulation methods. The purpose of a hydraulic treatment is to increase the productivity of a well. “X-3” oil well, located in Field “X” which is a mature oil field, is a candidate for hydraulic fracturing treatment due to its low productivity and reserves within a tight sand reservoir in TAF-1 formation which consists of low permeability shale-sand layers. This study aims to create a relevant interpretation of the targeted formation through geomechanics interpretation and design an optimum hydraulic fracture treatment based on the formation model. Geomechanics interpretation is conducted by analyzing a set well logging data to calculate elastic properties which is an important parameter of rock mechanics. Empirical approaches are used to create a permeability prediction model due to lack of data from core sample. The selection of fracturing fluid and proppant is based on existing guidelines that is adjusted to the case. The design of fracture geometry and treatment is based on the calculation of Unified Fracture Design which is set as an ideal reference for optimum geometry. A simulated approach using commercial fracturing software is conducted to generate a near-actual fracture model based on the calculated optimum geometry. The resulting accepted fracture geometry is analyzed to identify the increase of productivity through Folds of Increase determination and a 1-year production forecast.
OPTIMIZED HYDRAULIC FRACTURE DESIGN USING A PREDICTIVE SIMULATED APPROACH: A CASE STUDY OF “X-3” WELL
Hydraulic fracturing is one of the effective methods of well stimulation that is widely used to enhance hydrocarbon production for wells experiencing a decline in production and having unconventional potential reserves that is unattainable through other stimulation methods. The purpose of a hydraulic treatment is to increase the productivity of a well. “X-3” oil well, located in Field “X” which is a mature oil field, is a candidate for hydraulic fracturing treatment due to its low productivity and reserves within a tight sand reservoir in TAF-1 formation which consists of low permeability shale-sand layers. This study aims to create a relevant interpretation of the targeted formation through geomechanics interpretation and design an optimum hydraulic fracture treatment based on the formation model. Geomechanics interpretation is conducted by analyzing a set well logging data to calculate elastic properties which is an important parameter of rock mechanics. Empirical approaches are used to create a permeability prediction model due to lack of data from core sample. The selection of fracturing fluid and proppant is based on existing guidelines that is adjusted to the case. The design of fracture geometry and treatment is based on the calculation of Unified Fracture Design which is set as an ideal reference for optimum geometry. A simulated approach using commercial fracturing software is conducted to generate a near-actual fracture model based on the calculated optimum geometry. The resulting accepted fracture geometry is analyzed to identify the increase of productivity through Folds of Increase determination and a 1-year production forecast.
DESAIN REKAHAN HIDRAULIK UNTUK SUMUR SR-16 DENGAN SENSITIVITAS MASSA PROPAN : STUDI KASUS UNTUK MENGATASI KERUSAKAN DISEKITAR LUBANG BOR DAN ZONA PERMEABILITAS RENDAH
A declining performance an oil well production can be influenced by several factors, such as the reservoir's decreased ability to flow fluids into the oil well due to low permeability in the perforated zone and high skin in the formation. To solve this problem, an effective method is needed to increase permeability and reduce skin to enhance productivity. This study focuses on the hydraulic fracturing design for well SR-16 with proppant mass sensitivity. The objective is to bypass the near wellbore low permeability and damage zone to make connectivity between the wellbore and the porous zone. The study used P3D fracture geometry model to develop simultaneous lateral and vertical fracture migration. Based on mass proppant sensitivity by optimum CFD value, the braddy 20/40 proppant type with an optimum mass of 47 klb was selected to achieve an optimum CFD value of 1.6. The fracture design results obtained half-fracture length of 131.8 feet and a fracture width of 0.197 inch. The effective conductivity value with a 47 klb proppant mass is 1076 mD.ft, and the skin value after fracturing is -5.27391. The fold of increase in productivity after hydraulic fracturing is 2.721317. The value of fold of increase show that this method is effective in enhancing well productivity 2.721317 times than before.
DESAIN REKAHAN HIDRAULIK UNTUK SUMUR SR-16 DENGAN SENSITIVITAS MASSA PROPAN : STUDI KASUS UNTUK MENGATASI KERUSAKAN DISEKITAR LUBANG BOR DAN ZONA PERMEABILITAS RENDAH
A declining performance an oil well production can be influenced by several factors, such as the reservoir's decreased ability to flow fluids into the oil well due to low permeability in the perforated zone and high skin in the formation. To solve this problem, an effective method is needed to increase permeability and reduce skin to enhance productivity. This study focuses on the hydraulic fracturing design for well SR-16 with proppant mass sensitivity. The objective is to bypass the near wellbore low permeability and damage zone to make connectivity between the wellbore and the porous zone. The study used P3D fracture geometry model to develop simultaneous lateral and vertical fracture migration. Based on mass proppant sensitivity by optimum CFD value, the braddy 20/40 proppant type with an optimum mass of 47 klb was selected to achieve an optimum CFD value of 1.6. The fracture design results obtained half-fracture length of 131.8 feet and a fracture width of 0.197 inch. The effective conductivity value with a 47 klb proppant mass is 1076 mD.ft, and the skin value after fracturing is -5.27391. The fold of increase in productivity after hydraulic fracturing is 2.721317. The value of fold of increase show that this method is effective in enhancing well productivity 2.721317 times than before.
DESAIN REKAHAN HIDRAULIK UNTUK SUMUR SR-16 DENGAN SENSITIVITAS MASSA PROPAN : STUDI KASUS UNTUK MENGATASI KERUSAKAN DISEKITAR LUBANG BOR DAN ZONA PERMEABILITAS RENDAH
A declining performance an oil well production can be influenced by several factors, such as the reservoir's decreased ability to flow fluids into the oil well due to low permeability in the perforated zone and high skin in the formation. To solve this problem, an effective method is needed to increase permeability and reduce skin to enhance productivity. This study focuses on the hydraulic fracturing design for well SR-16 with proppant mass sensitivity. The objective is to bypass the near wellbore low permeability and damage zone to make connectivity between the wellbore and the porous zone. The study used P3D fracture geometry model to develop simultaneous lateral and vertical fracture migration. Based on mass proppant sensitivity by optimum CFD value, the braddy 20/40 proppant type with an optimum mass of 47 klb was selected to achieve an optimum CFD value of 1.6. The fracture design results obtained half-fracture length of 131.8 feet and a fracture width of 0.197 inch. The effective conductivity value with a 47 klb proppant mass is 1076 mD.ft, and the skin value after fracturing is -5.27391. The fold of increase in productivity after hydraulic fracturing is 2.721317. The value of fold of increase show that this method is effective in enhancing well productivity 2.721317 times than before.
DESAIN REKAHAN HIDRAULIK UNTUK SUMUR SR-16 DENGAN SENSITIVITAS MASSA PROPAN : STUDI KASUS UNTUK MENGATASI KERUSAKAN DISEKITAR LUBANG BOR DAN ZONA PERMEABILITAS RENDAH
A declining performance an oil well production can be influenced by several factors, such as the reservoir's decreased ability to flow fluids into the oil well due to low permeability in the perforated zone and high skin in the formation. To solve this problem, an effective method is needed to increase permeability and reduce skin to enhance productivity. This study focuses on the hydraulic fracturing design for well SR-16 with proppant mass sensitivity. The objective is to bypass the near wellbore low permeability and damage zone to make connectivity between the wellbore and the porous zone. The study used P3D fracture geometry model to develop simultaneous lateral and vertical fracture migration. Based on mass proppant sensitivity by optimum CFD value, the braddy 20/40 proppant type with an optimum mass of 47 klb was selected to achieve an optimum CFD value of 1.6. The fracture design results obtained half-fracture length of 131.8 feet and a fracture width of 0.197 inch. The effective conductivity value with a 47 klb proppant mass is 1076 mD.ft, and the skin value after fracturing is -5.27391. The fold of increase in productivity after hydraulic fracturing is 2.721317. The value of fold of increase show that this method is effective in enhancing well productivity 2.721317 times than before.
DESAIN REKAHAN HIDRAULIK UNTUK SUMUR SR-16 DENGAN SENSITIVITAS MASSA PROPAN : STUDI KASUS UNTUK MENGATASI KERUSAKAN DISEKITAR LUBANG BOR DAN ZONA PERMEABILITAS RENDAH
A declining performance an oil well production can be influenced by several factors, such as the reservoir's decreased ability to flow fluids into the oil well due to low permeability in the perforated zone and high skin in the formation. To solve this problem, an effective method is needed to increase permeability and reduce skin to enhance productivity. This study focuses on the hydraulic fracturing design for well SR-16 with proppant mass sensitivity. The objective is to bypass the near wellbore low permeability and damage zone to make connectivity between the wellbore and the porous zone. The study used P3D fracture geometry model to develop simultaneous lateral and vertical fracture migration. Based on mass proppant sensitivity by optimum CFD value, the braddy 20/40 proppant type with an optimum mass of 47 klb was selected to achieve an optimum CFD value of 1.6. The fracture design results obtained half-fracture length of 131.8 feet and a fracture width of 0.197 inch. The effective conductivity value with a 47 klb proppant mass is 1076 mD.ft, and the skin value after fracturing is -5.27391. The fold of increase in productivity after hydraulic fracturing is 2.721317. The value of fold of increase show that this method is effective in enhancing well productivity 2.721317 times than before.
OPTIMIZING WELL SELECTION CANDIDATE AND HYDRAULIC FRACTURING TREATMENT IN SOFT ROCK AND HARD ROCK FORMATION: CASE STUDIES IN FIELDS X AND Y.
Currently, 66.67% of the global daily oil production and 90% of Indonesia's oil production are derived from mature fields, whose capacity has gradually declined. Governments, oil corporations, and service providers must devise strategies to effectively address society's energy needs in daily life and ensure the business's financial stability. Hydraulic fracturing has proven to be a cost-efficient method for improving productivity in mature oil fields. Nevertheless, these operations require substantial financial resources, including engaging in high-risk activities and dealing with uncertainty. This study aims to thoroughly examine the process of identifying appropriate candidates for hydraulic fracturing operations by focusing on rock mechanics analysis, enhancing the efficiency of hydraulic fracturing operations, and evaluating post-job analysis to find which well gives the highest investment return after the operations are performed. A geomechanics analysis is first conducted as a screening parameter for well-candidate selection. The analysis results include Poisson's ratio, Young's modulus, and Minimum horizontal stress, giving us information about the in-situ stress condition at the zone of interest, which we can predict where and how the fracture goes. Subsequently, by utilizing the Stimplan-NSI simulator, we may better understand the hydraulic fracture formed concerning the specific characteristics of the reservoir and the rock formation. Finally, after adjusting specific treatment parameters to reach the desired outcome for both hard rock and soft rock formations, nodal analysis is conducted to identify the most optimal candidate for fracturing operations. Ultimately, a highly effective ranking system for potential candidates is achieved with various recommendations, such as conducting a study or test before main-frac operations, setting clear objectives for fracturing design in both soft and hard rock formations, and optimal treatment involves controlling the injection rate, proppant mass, pad volume, and gel loading of fracturing fluids within the desired range. The project's profitability is likely to grow, and uncertainties are projected to decrease by selecting a promising candidate and implementing an optimal treatment strategy.
OPTIMIZING WELL SELECTION CANDIDATE AND HYDRAULIC FRACTURING TREATMENT IN SOFT ROCK AND HARD ROCK FORMATION: CASE STUDIES IN FIELDS X AND Y.
Currently, 66.67% of the global daily oil production and 90% of Indonesia's oil production are derived from mature fields, whose capacity has gradually declined. Governments, oil corporations, and service providers must devise strategies to effectively address society's energy needs in daily life and ensure the business's financial stability. Hydraulic fracturing has proven to be a cost-efficient method for improving productivity in mature oil fields. Nevertheless, these operations require substantial financial resources, including engaging in high-risk activities and dealing with uncertainty. This study aims to thoroughly examine the process of identifying appropriate candidates for hydraulic fracturing operations by focusing on rock mechanics analysis, enhancing the efficiency of hydraulic fracturing operations, and evaluating post-job analysis to find which well gives the highest investment return after the operations are performed. A geomechanics analysis is first conducted as a screening parameter for well-candidate selection. The analysis results include Poisson's ratio, Young's modulus, and Minimum horizontal stress, giving us information about the in-situ stress condition at the zone of interest, which we can predict where and how the fracture goes. Subsequently, by utilizing the Stimplan-NSI simulator, we may better understand the hydraulic fracture formed concerning the specific characteristics of the reservoir and the rock formation. Finally, after adjusting specific treatment parameters to reach the desired outcome for both hard rock and soft rock formations, nodal analysis is conducted to identify the most optimal candidate for fracturing operations. Ultimately, a highly effective ranking system for potential candidates is achieved with various recommendations, such as conducting a study or test before main-frac operations, setting clear objectives for fracturing design in both soft and hard rock formations, and optimal treatment involves controlling the injection rate, proppant mass, pad volume, and gel loading of fracturing fluids within the desired range. The project's profitability is likely to grow, and uncertainties are projected to decrease by selecting a promising candidate and implementing an optimal treatment strategy.