The Experts below are selected from a list of 531 Experts worldwide ranked by ideXlab platform
Joseph Sangil Kwon - One of the best experts on this subject based on the ideXlab platform.
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approximate dynamic programming based control of Proppant Concentration in hydraulic fracturing
Mathematics, 2018Co-Authors: Harwinder Singh Sidhu, Prashanth Siddhamshetty, Joseph Sangil KwonAbstract:Hydraulic fracturing has played a crucial role in enhancing the extraction of oil and gas from deep underground sources. The two main objectives of hydraulic fracturing are to produce fractures with a desired fracture geometry and to achieve the target Proppant Concentration inside the fracture. Recently, some efforts have been made to accomplish these objectives by the model predictive control (MPC) theory based on the assumption that the rock mechanical properties such as the Young’s modulus are known and spatially homogenous. However, this approach may not be optimal if there is an uncertainty in the rock mechanical properties. Furthermore, the computational requirements associated with the MPC approach to calculate the control moves at each sampling time can be significantly high when the underlying process dynamics is described by a nonlinear large-scale system. To address these issues, the current work proposes an approximate dynamic programming (ADP) based approach for the closed-loop control of hydraulic fracturing to achieve the target Proppant Concentration at the end of pumping. ADP is a model-based control technique which combines a high-fidelity simulation and function approximator to alleviate the “curse-of-dimensionality” associated with the traditional dynamic programming (DP) approach. A series of simulations results is provided to demonstrate the performance of the ADP-based controller in achieving the target Proppant Concentration at the end of pumping at a fraction of the computational cost required by MPC while handling the uncertainty in the Young’s modulus of the rock formation.
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modeling of hydraulic fracturing and designing of online pumping schedules to achieve uniform Proppant Concentration in conventional oil reservoirs
Computers & Chemical Engineering, 2017Co-Authors: Prashanth Siddhamshetty, Seeyub Yang, Joseph Sangil KwonAbstract:Abstract We present a novel control framework for the closed-loop operation of a hydraulic fracturing process. Initially, we focus on the development of a first-principle model of a hydraulic fracturing process. Second, a novel numerical scheme is developed to efficiently solve the coupled partial differential equations defined over a time-dependent spatial domain. Third, a reduced-order model is constructed, which is used to design a Kalman filter to accurately estimate unmeasurable states. Lastly, model predictive control theory is applied for the design of a feedback control system to achieve uniform Proppant Concentration across the fracture at the end of pumping by explicitly taking into account the desired fracture geometry, total amount of Proppant injected, actuator limitations, and safety considerations. We demonstrate that the proposed control scheme is able to generate a spatial Concentration profile which is uniform and close to the target Concentration compared to that of the benchmark, Nolte's pumping schedule.
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optimal pumping schedule design to achieve a uniform Proppant Concentration level in hydraulic fracturing
Computers & Chemical Engineering, 2017Co-Authors: Prashanth Siddhamshetty, Seeyub Yang, Joseph Sangil KwonAbstract:Abstract We present a novel design framework of an optimal and practical pumping schedule to achieve uniform Proppant Concentration across fracture at the end of pumping. By using the average viscosity to approximate Concentration dependence of fracture propagation, a set of constant-Concentration pumping schedules is applied to the developed dynamic model, each of which is carefully chosen by taking into account the practical constraints such as the limit on the change of Proppant Concentration between pumping stages and the desired fracture geometry that has to be satisfied at the end of pumping for maximum productivity. Then, a practically-feasible target Concentration profile is obtained via linear combinations of the generated spatial Concentration profiles, and mass balance is applied to the practically-feasible target Concentration to calculate the duration of each pumping stage. We apply the generated pumping schedule to the high-fidelity hydraulic fracturing model, and the performance is compared with Nolte's pumping schedule.
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Modeling of hydraulic fracturing and developing a new pumping schedule to achieve uniform Proppant Concentration
2017 American Control Conference (ACC), 2017Co-Authors: Prashanth Siddhamshetty, Seeyub Yang, Joseph Sangil KwonAbstract:In this work, we initially focus on modeling of hydraulic fracturing processes. Then, we present a methodology for the design of a pumping schedule to achieve uniform Proppant Concentration at the end of pumping. The pumping schedule is designed by taking into account the effect of Proppant particles on fracture propagation. We generate multiple spatial Concentration profiles and approximate the target Concentration by the piecewise combination of the generated spatial Concentration profiles. As a result, a piecewise Concentration profile that best describes the target Concentration is obtained, and an inverse problem is formulated based on the law of conservation of mass to calculate the duration of each pumping stage with a specific Proppant Concentration. We show that the produced Concentration profile is closer to the target Concentration compared to Nolte's pumping schedule, which is one of the most commonly used pumping schedules. Furthermore, the proposed design scheme is optimal because it directly takes into account practical constraints such as the limit on the change of the Proppant Concentration between pumping stages and the desired fracture geometry that has to be satisfied at the end of pumping.
Seeyub Yang - One of the best experts on this subject based on the ideXlab platform.
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modeling of hydraulic fracturing and designing of online pumping schedules to achieve uniform Proppant Concentration in conventional oil reservoirs
Computers & Chemical Engineering, 2017Co-Authors: Prashanth Siddhamshetty, Seeyub Yang, Joseph Sangil KwonAbstract:Abstract We present a novel control framework for the closed-loop operation of a hydraulic fracturing process. Initially, we focus on the development of a first-principle model of a hydraulic fracturing process. Second, a novel numerical scheme is developed to efficiently solve the coupled partial differential equations defined over a time-dependent spatial domain. Third, a reduced-order model is constructed, which is used to design a Kalman filter to accurately estimate unmeasurable states. Lastly, model predictive control theory is applied for the design of a feedback control system to achieve uniform Proppant Concentration across the fracture at the end of pumping by explicitly taking into account the desired fracture geometry, total amount of Proppant injected, actuator limitations, and safety considerations. We demonstrate that the proposed control scheme is able to generate a spatial Concentration profile which is uniform and close to the target Concentration compared to that of the benchmark, Nolte's pumping schedule.
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optimal pumping schedule design to achieve a uniform Proppant Concentration level in hydraulic fracturing
Computers & Chemical Engineering, 2017Co-Authors: Prashanth Siddhamshetty, Seeyub Yang, Joseph Sangil KwonAbstract:Abstract We present a novel design framework of an optimal and practical pumping schedule to achieve uniform Proppant Concentration across fracture at the end of pumping. By using the average viscosity to approximate Concentration dependence of fracture propagation, a set of constant-Concentration pumping schedules is applied to the developed dynamic model, each of which is carefully chosen by taking into account the practical constraints such as the limit on the change of Proppant Concentration between pumping stages and the desired fracture geometry that has to be satisfied at the end of pumping for maximum productivity. Then, a practically-feasible target Concentration profile is obtained via linear combinations of the generated spatial Concentration profiles, and mass balance is applied to the practically-feasible target Concentration to calculate the duration of each pumping stage. We apply the generated pumping schedule to the high-fidelity hydraulic fracturing model, and the performance is compared with Nolte's pumping schedule.
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Modeling of hydraulic fracturing and developing a new pumping schedule to achieve uniform Proppant Concentration
2017 American Control Conference (ACC), 2017Co-Authors: Prashanth Siddhamshetty, Seeyub Yang, Joseph Sangil KwonAbstract:In this work, we initially focus on modeling of hydraulic fracturing processes. Then, we present a methodology for the design of a pumping schedule to achieve uniform Proppant Concentration at the end of pumping. The pumping schedule is designed by taking into account the effect of Proppant particles on fracture propagation. We generate multiple spatial Concentration profiles and approximate the target Concentration by the piecewise combination of the generated spatial Concentration profiles. As a result, a piecewise Concentration profile that best describes the target Concentration is obtained, and an inverse problem is formulated based on the law of conservation of mass to calculate the duration of each pumping stage with a specific Proppant Concentration. We show that the produced Concentration profile is closer to the target Concentration compared to Nolte's pumping schedule, which is one of the most commonly used pumping schedules. Furthermore, the proposed design scheme is optimal because it directly takes into account practical constraints such as the limit on the change of the Proppant Concentration between pumping stages and the desired fracture geometry that has to be satisfied at the end of pumping.
Prashanth Siddhamshetty - One of the best experts on this subject based on the ideXlab platform.
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incorporation of sustainability in process control of hydraulic fracturing in unconventional reservoirs
Chemical Engineering Research & Design, 2018Co-Authors: Priscille Etoughe, Prashanth Siddhamshetty, Rajib Mukherjee, Joseph Sangii KwonAbstract:Abstract Typically, the term shale oil refers to natural oil trapped in rock of low porosity and ultra-low permeability. What has made the recovery of shale oil and gas economically viable is the extensive use of hydraulic fracturing and horizontal drilling. Research on the relationship between the distribution of propping agent, called Proppant, and shale well performance indicates that uniformity of Proppant bank height and suspended Proppant Concentration across the fracture at the end of pumping determines the productivity of produced wells. However, it is important to note that traditional fracturing fluid pumping schedules have not considered the environmental and economic impacts of the post-fracturing process such as treatment and reuse of flowback water from fractured wells. Motivated by this consideration, a control framework is proposed to integrate sustainability considerations of the post-fracturing process into the hydraulic fracturing process. In this regard, a dynamic model is developed to describe the flow rate and the Concentration of total dissolved solids (TDS) in flowback water from fractured wells. Thermal membrane distillation is considered for the removal of TDS. An optimization problem is formulated to find the optimal process that consists of hydraulic fracturing, storage, transportation, and water treatment, through minimizing annualized cost and water footprint of the process. The capabilities of the proposed approach are illustrated through the simulation results of different scenarios that are performed to examine effects of water availability on the productivity of stimulated wells. Finally, the environmental impact of flowback water treatment is evaluated using TRACI, a tool for the reduction and assessment of chemical and other environmental impacts.
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approximate dynamic programming based control of Proppant Concentration in hydraulic fracturing
Mathematics, 2018Co-Authors: Harwinder Singh Sidhu, Prashanth Siddhamshetty, Joseph Sangil KwonAbstract:Hydraulic fracturing has played a crucial role in enhancing the extraction of oil and gas from deep underground sources. The two main objectives of hydraulic fracturing are to produce fractures with a desired fracture geometry and to achieve the target Proppant Concentration inside the fracture. Recently, some efforts have been made to accomplish these objectives by the model predictive control (MPC) theory based on the assumption that the rock mechanical properties such as the Young’s modulus are known and spatially homogenous. However, this approach may not be optimal if there is an uncertainty in the rock mechanical properties. Furthermore, the computational requirements associated with the MPC approach to calculate the control moves at each sampling time can be significantly high when the underlying process dynamics is described by a nonlinear large-scale system. To address these issues, the current work proposes an approximate dynamic programming (ADP) based approach for the closed-loop control of hydraulic fracturing to achieve the target Proppant Concentration at the end of pumping. ADP is a model-based control technique which combines a high-fidelity simulation and function approximator to alleviate the “curse-of-dimensionality” associated with the traditional dynamic programming (DP) approach. A series of simulations results is provided to demonstrate the performance of the ADP-based controller in achieving the target Proppant Concentration at the end of pumping at a fraction of the computational cost required by MPC while handling the uncertainty in the Young’s modulus of the rock formation.
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modeling of hydraulic fracturing and designing of online pumping schedules to achieve uniform Proppant Concentration in conventional oil reservoirs
Computers & Chemical Engineering, 2017Co-Authors: Prashanth Siddhamshetty, Seeyub Yang, Joseph Sangil KwonAbstract:Abstract We present a novel control framework for the closed-loop operation of a hydraulic fracturing process. Initially, we focus on the development of a first-principle model of a hydraulic fracturing process. Second, a novel numerical scheme is developed to efficiently solve the coupled partial differential equations defined over a time-dependent spatial domain. Third, a reduced-order model is constructed, which is used to design a Kalman filter to accurately estimate unmeasurable states. Lastly, model predictive control theory is applied for the design of a feedback control system to achieve uniform Proppant Concentration across the fracture at the end of pumping by explicitly taking into account the desired fracture geometry, total amount of Proppant injected, actuator limitations, and safety considerations. We demonstrate that the proposed control scheme is able to generate a spatial Concentration profile which is uniform and close to the target Concentration compared to that of the benchmark, Nolte's pumping schedule.
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optimal pumping schedule design to achieve a uniform Proppant Concentration level in hydraulic fracturing
Computers & Chemical Engineering, 2017Co-Authors: Prashanth Siddhamshetty, Seeyub Yang, Joseph Sangil KwonAbstract:Abstract We present a novel design framework of an optimal and practical pumping schedule to achieve uniform Proppant Concentration across fracture at the end of pumping. By using the average viscosity to approximate Concentration dependence of fracture propagation, a set of constant-Concentration pumping schedules is applied to the developed dynamic model, each of which is carefully chosen by taking into account the practical constraints such as the limit on the change of Proppant Concentration between pumping stages and the desired fracture geometry that has to be satisfied at the end of pumping for maximum productivity. Then, a practically-feasible target Concentration profile is obtained via linear combinations of the generated spatial Concentration profiles, and mass balance is applied to the practically-feasible target Concentration to calculate the duration of each pumping stage. We apply the generated pumping schedule to the high-fidelity hydraulic fracturing model, and the performance is compared with Nolte's pumping schedule.
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Modeling of hydraulic fracturing and developing a new pumping schedule to achieve uniform Proppant Concentration
2017 American Control Conference (ACC), 2017Co-Authors: Prashanth Siddhamshetty, Seeyub Yang, Joseph Sangil KwonAbstract:In this work, we initially focus on modeling of hydraulic fracturing processes. Then, we present a methodology for the design of a pumping schedule to achieve uniform Proppant Concentration at the end of pumping. The pumping schedule is designed by taking into account the effect of Proppant particles on fracture propagation. We generate multiple spatial Concentration profiles and approximate the target Concentration by the piecewise combination of the generated spatial Concentration profiles. As a result, a piecewise Concentration profile that best describes the target Concentration is obtained, and an inverse problem is formulated based on the law of conservation of mass to calculate the duration of each pumping stage with a specific Proppant Concentration. We show that the produced Concentration profile is closer to the target Concentration compared to Nolte's pumping schedule, which is one of the most commonly used pumping schedules. Furthermore, the proposed design scheme is optimal because it directly takes into account practical constraints such as the limit on the change of the Proppant Concentration between pumping stages and the desired fracture geometry that has to be satisfied at the end of pumping.
Tharaka Dilanka Rathnaweera - One of the best experts on this subject based on the ideXlab platform.
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improved understanding of Proppant embedment behavior under reservoir conditions a review study
Powder Technology, 2019Co-Authors: K.m.a.s. Bandara, P G Ranjith, Tharaka Dilanka RathnaweeraAbstract:Abstract Proppant embedment, which occurs at depths in rock formations, is a key Proppant downhole mechanism which can result in rapid decline in hydrocarbon production. The current review study reveals that both rock formation characteristics and Proppant characteristics significantly determine the embedment mechanism. Importantly, the review shows that embedment can occur in any formation, whatever the type of rock, leading to conductivity loss in siltstone of 78.42%, in mudstone of 81.89%, in conglomerate of 91.55%, and in shale of 78.05%. The present study investigated the importance of the creep phenomenon (a function of confinement and temperature), the percentage of clay content, and surface roughness on Proppant embedment. Other dynamics, such as time, temperature and fracture fluid, can also impact the rate of Proppant embedment as they help to alter the softness (young's modulus) of the fracture surface. This study reveals that curable resin-coated sand (embedment of 44 μm) is very tolerant of the embedment process compared with lightweight ceramics (113 μm) and uncoated fracture sand (106 μm). Similarly, higher Proppant Concentration, greater Proppant size, uniform Proppant distribution and a greater number of Proppant layers can minimize the embedment process to a great extent, ensuring the effective extraction of oil/gas from hydraulically fractured wells. This paper also reviews some existing numerical and analytical models on Proppant embedment which enable forecasting of the fracture conductivity loss undergone in downhole fracture treatments. Finally, the paper summarizes some of the case studies emphasized on Proppant embedment effect and various research recommendations are suggested to minimize the Proppant embedment.
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influences of Proppant Concentration and fracturing fluids on Proppant embedment behavior for inhomogeneous rock medium an experimental and numerical study
Spe Production & Operations, 2018Co-Authors: Y Tang, M S A Perera, P G Ranjith, Tharaka Dilanka RathnaweeraAbstract:Proppant plays a vital role in hydraulic fracturing in tight oil/gas production because it helps to keep the fractures open during the production process. However, it is common for Proppant embedment, the main type of Proppant degradation, to occur under high compression load, which greatly reduces the fracture conductivity, and consequently reduces the production rate. During the process of hydraulic fracturing, the fracturing fluid only has the chance to contact and infiltrate the fractures that are in the top surface of the rock medium because of ultralow rock permeability and the short time of fluid existence, whereas the condition of other parts of the rock remain unchanged, creating inhomogeneity within the rock medium. Therefore, the present study conducted a comprehensive experimental and numerical evaluation to investigate the behavior of Proppant for inhomogeneous rock media, considering the factors (effective stress, Proppant Concentration, and fracturing fluid) that affect Proppant performance. According to the experimental results, increasing the Proppant Concentration reduces the Proppant embedment, and, interestingly, the optimal Proppant Concentration is approximately 150% coverage. Furthermore, the influence of fracturing fluid on Proppant embedment is more significant for high Proppant Concentrations, and the embedment under water-saturated conditions is higher than that under oil-saturated conditions. The numerical simulation achieved the same result as the experimental study, showing that 150% Proppant coverage is the optimal Proppant Concentration to achieve the minimum Proppant embedment. In addition, numerical modeling indicated that the inhomogeneity of the rock formation can also considerably enhance Proppant embedment through differential settlement during compression.
Wei Zhang - One of the best experts on this subject based on the ideXlab platform.
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performance of enhanced geothermal system egs in fractured geothermal reservoirs with co2 as working fluid
Applied Thermal Engineering, 2019Co-Authors: Facheng Gong, Xiaozhi Wang, Zhanqing Qu, Wei ZhangAbstract:Abstract Creating an open, connected fracture by hydraulic stimulation is vital to heat mining in an enhanced geothermal system (EGS). The existence of natural fractures, which seriously affects the development pattern, can complicate the hydraulic fractures. Different fracture propagation patterns of hydraulic fracturing can be achieved through different fracturing processes under certain natural fracture scales. Besides, CO2 has attracted a lot of attention as working fluid because of its superior hydrothermal properties and CO2 geological storage. At present, the study of EGS for fractured geothermal reservoirs with CO2 as working fluid is quite limited. In this paper, we firstly presented a three-dimensional (3D) thermal–hydraulic-mechanical (THM) coupled model to analyze performance of EGS in fractured geothermal reservoirs with different natural fractures scales, reservoir stimulation scales, and working fluids (water and CO2), aimed to guide reservoir stimulation and fracture parameter design. The results are showed as follows: If not forming connected fractures, the existence of natural fractures would cause fluid loss, an increase in natural fracture density by 0.4%, and the heat extraction rate decreases 0.06 MW on average; Forming connected fractures in the foundation of natural fractures would increase the output flow rate, so the reservoir stimulation scale increases by 0.85% and the heat extraction rate increases 0.2 MW; CO2 has better heat extraction properties than water due to its lower viscosity, greatly improving the production efficiency. Combining the hydraulic fracture conductivity tests creatively, the sensitivity analysis of fracturing parameters is studied. The heat extraction rate decreases with the increase in fracture aperture and fracture permeability. Under certain closure pressure (40 MPa in this paper), the best ceramsite Proppant Concentration and Proppant size are 5 kg/m2 and 100 mesh, respectively, and the corresponding fracture conductivity is 1.6 μm2•cm.
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performance of enhanced geothermal system egs in fractured geothermal reservoirs with co2 as working fluid
Applied Thermal Engineering, 2019Co-Authors: Tiankui Guo, Facheng Gong, Xiaozhi Wang, Qiang Lin, Wei ZhangAbstract:Abstract Creating an open, connected fracture by hydraulic stimulation is vital to heat mining in an enhanced geothermal system (EGS). The existence of natural fractures, which seriously affects the development pattern, can complicate the hydraulic fractures. Different fracture propagation patterns of hydraulic fracturing can be achieved through different fracturing processes under certain natural fracture scales. Besides, CO2 has attracted a lot of attention as working fluid because of its superior hydrothermal properties and CO2 geological storage. At present, the study of EGS for fractured geothermal reservoirs with CO2 as working fluid is quite limited. In this paper, we firstly presented a three-dimensional (3D) thermal–hydraulic-mechanical (THM) coupled model to analyze performance of EGS in fractured geothermal reservoirs with different natural fractures scales, reservoir stimulation scales, and working fluids (water and CO2), aimed to guide reservoir stimulation and fracture parameter design. The results are showed as follows: If not forming connected fractures, the existence of natural fractures would cause fluid loss, an increase in natural fracture density by 0.4%, and the heat extraction rate decreases 0.06 MW on average; Forming connected fractures in the foundation of natural fractures would increase the output flow rate, so the reservoir stimulation scale increases by 0.85% and the heat extraction rate increases 0.2 MW; CO2 has better heat extraction properties than water due to its lower viscosity, greatly improving the production efficiency. Combining the hydraulic fracture conductivity tests creatively, the sensitivity analysis of fracturing parameters is studied. The heat extraction rate decreases with the increase in fracture aperture and fracture permeability. Under certain closure pressure (40 MPa in this paper), the best ceramsite Proppant Concentration and Proppant size are 5 kg/m2 and 100 mesh, respectively, and the corresponding fracture conductivity is 1.6 μm2•cm.
