Optimization of Hydraulic Fracture Stages and Sequencing in Unconventional Formations

Optimization of Hydraulic Fracture Stages and Sequencing in Unconventional Formations

Author: Ahmed Alzahabi

Publisher: CRC Press

Published: 2018-07-03

Total Pages: 279

ISBN-13: 1351618229

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Shale gas and/or oil play identification is subject to many screening processes for characteristics such as porosity, permeability, and brittleness. Evaluating shale gas and/or oil reservoirs and identifying potential sweet spots (portions of the reservoir rock that have high-quality kerogen content and brittle rock) requires taking into consideration multiple rock, reservoir, and geological parameters that govern production. The early determination of sweet spots for well site selection and fracturing in shale reservoirs is a challenge for many operators. With this limitation in mind, Optimization of Hydraulic Fracture Stages and Sequencing in Unconventional Formations develops an approach to improve the industry’s ability to evaluate shale gas and oil plays and is structured to lead the reader from general shale oil and gas characteristics to detailed sweet-spot classifications. The approach uses a new candidate selection and evaluation algorithm and screening criteria based on key geomechanical, petrophysical, and geochemical parameters and indices to obtain results consistent with existing shale plays and gain insights on the best development strategies going forward. The work introduces new criteria that accurately guide the development process in unconventional reservoirs in addition to reducing uncertainty and cost.


Book Synopsis Optimization of Hydraulic Fracture Stages and Sequencing in Unconventional Formations by : Ahmed Alzahabi

Download or read book Optimization of Hydraulic Fracture Stages and Sequencing in Unconventional Formations written by Ahmed Alzahabi and published by CRC Press. This book was released on 2018-07-03 with total page 279 pages. Available in PDF, EPUB and Kindle. Book excerpt: Shale gas and/or oil play identification is subject to many screening processes for characteristics such as porosity, permeability, and brittleness. Evaluating shale gas and/or oil reservoirs and identifying potential sweet spots (portions of the reservoir rock that have high-quality kerogen content and brittle rock) requires taking into consideration multiple rock, reservoir, and geological parameters that govern production. The early determination of sweet spots for well site selection and fracturing in shale reservoirs is a challenge for many operators. With this limitation in mind, Optimization of Hydraulic Fracture Stages and Sequencing in Unconventional Formations develops an approach to improve the industry’s ability to evaluate shale gas and oil plays and is structured to lead the reader from general shale oil and gas characteristics to detailed sweet-spot classifications. The approach uses a new candidate selection and evaluation algorithm and screening criteria based on key geomechanical, petrophysical, and geochemical parameters and indices to obtain results consistent with existing shale plays and gain insights on the best development strategies going forward. The work introduces new criteria that accurately guide the development process in unconventional reservoirs in addition to reducing uncertainty and cost.

Integrated Hydraulic Fracture Placement and Design Optimization in Unconventional Gas Reservoirs

Integrated Hydraulic Fracture Placement and Design Optimization in Unconventional Gas Reservoirs

Author: Xiaodan Ma

Publisher:

Published: 2014

Total Pages:

ISBN-13:

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Unconventional reservoir such as tight and shale gas reservoirs has the potential of becoming the main source of cleaner energy in the 21th century. Production from these reservoirs is mainly accomplished through engineered hydraulic fracturing to generate fracture networks that provide the gas flow pathways from the rock matrix to the production wells. While hydraulic fracturing technology has progressed considerably in the last thirty years, designing the fracturing system primarily involves judgments from a team of engineers, geoscientists and geophysicists, without taking advantage of computational tools, such as numerical optimization techniques to improve short-term and long-term reservoir production. This thesis focuses on developing novel optimization algorithms that can be used to improve the design and implementation of hydraulic fracturing in a shale gas reservoir to increase production and the net present value of unconventional assets. In particular, we consider simultaneous perturbation stochastic approximation (SPSA) and Covariance Matrix Adaptation - Evolution Strategy (CMA-ES) algorithms, which are proven very efficient in finding nearly optimal solutions. We show that with a judicious choice of control variables (continuous or discrete) we can obtain efficient algorithms for performing hydraulic fracture optimization in unconventional reservoirs. To achieve this, the hydraulic fracture production optimization problem is divided into two aspects: fracture stages placement optimization with fix stage numbers and unknown stage numbers. After check the parameters of fracture model that could be used to simulate future reservoir behavior with a higher degree of confidence, the fracture stages optimization is scheduling the fracturing sequence, and adjusting the fracture stages intensity at different locations, which is similar to well placement problem. In addition to the detailed investigation of the new optimization technique, uncertainty quantification of reservoir properties and its implications on the optimization workflow is also considered in the shale gas reservoir model. Taking into account that shale gas reservoirs are highly heterogeneous systems, stochastic optimization methods are the most suitable framework for hydraulic fracture stages placement. The electronic version of this dissertation is accessible from http://hdl.handle.net/1969.1/151913


Book Synopsis Integrated Hydraulic Fracture Placement and Design Optimization in Unconventional Gas Reservoirs by : Xiaodan Ma

Download or read book Integrated Hydraulic Fracture Placement and Design Optimization in Unconventional Gas Reservoirs written by Xiaodan Ma and published by . This book was released on 2014 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Unconventional reservoir such as tight and shale gas reservoirs has the potential of becoming the main source of cleaner energy in the 21th century. Production from these reservoirs is mainly accomplished through engineered hydraulic fracturing to generate fracture networks that provide the gas flow pathways from the rock matrix to the production wells. While hydraulic fracturing technology has progressed considerably in the last thirty years, designing the fracturing system primarily involves judgments from a team of engineers, geoscientists and geophysicists, without taking advantage of computational tools, such as numerical optimization techniques to improve short-term and long-term reservoir production. This thesis focuses on developing novel optimization algorithms that can be used to improve the design and implementation of hydraulic fracturing in a shale gas reservoir to increase production and the net present value of unconventional assets. In particular, we consider simultaneous perturbation stochastic approximation (SPSA) and Covariance Matrix Adaptation - Evolution Strategy (CMA-ES) algorithms, which are proven very efficient in finding nearly optimal solutions. We show that with a judicious choice of control variables (continuous or discrete) we can obtain efficient algorithms for performing hydraulic fracture optimization in unconventional reservoirs. To achieve this, the hydraulic fracture production optimization problem is divided into two aspects: fracture stages placement optimization with fix stage numbers and unknown stage numbers. After check the parameters of fracture model that could be used to simulate future reservoir behavior with a higher degree of confidence, the fracture stages optimization is scheduling the fracturing sequence, and adjusting the fracture stages intensity at different locations, which is similar to well placement problem. In addition to the detailed investigation of the new optimization technique, uncertainty quantification of reservoir properties and its implications on the optimization workflow is also considered in the shale gas reservoir model. Taking into account that shale gas reservoirs are highly heterogeneous systems, stochastic optimization methods are the most suitable framework for hydraulic fracture stages placement. The electronic version of this dissertation is accessible from http://hdl.handle.net/1969.1/151913

Modelling of Multistage Hydraulic Fracture Operations in Unconventional Resources - the Application of Geomechanics and Field Data to the Optimization of Fracture Spacing and Production

Modelling of Multistage Hydraulic Fracture Operations in Unconventional Resources - the Application of Geomechanics and Field Data to the Optimization of Fracture Spacing and Production

Author: Natalia Skomorowski

Publisher:

Published: 2016

Total Pages: 167

ISBN-13:

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Massive multistage hydraulic fracturing using horizontal wells has been an integral part of the natural resource industry in Canada. The process uses long horizontal wells divided into many stages to access large volumes of oil and gas bearing formations. Each well is divided into fracture stages. Fluids are pumped down into each stage of the well to generate a fracture which increases the porosity and permeability of the formation to allow economic resource extraction. The in situ geomechanical stresses of the formation do not remain static during the fracturing of the rock. Each fracture creates a volume change within the formation which in turn leads to alteration of the stress and strain conditions within the rock mass. There is the possibility that the alteration of stress conditions will have an effect on the initiation and propagation of subsequent stages of the multi-stage hydraulic fracture operation. This phenomenon is known as 'stress shadowing'. Stress shadowing occurs when the minimum compressive stress in the formation is increased due to the fracturing of the rock. Increasing the minimum compressive horizontal stress can have several effects, including the rotation or diversion of fracture propagation, stages that do not initiate, thinner fractures, and reduced porosity and permeability within the fracture stage. Currently, many hydraulic fracture operations do not invest in advanced mathematical models of geomechanics. Some pressure monitoring is carried out during operations, but the data are inadequate to warrant advanced numerical methods to predict stress change and its effects. This thesis presents a semi-analytical solution for the stresses around an ellipsoid (the Eshelby Solution) for use in predicting fracture geometry and stress shadow effects. The program is quick to use and can be linked to field data. A study of field data from the Montney Formation is presented. The algorithm developed in this thesis is used to evaluate stress changes within the Montney Formation and the outputs are compared to the stress changes seen in the hydraulic fracture pressure data.


Book Synopsis Modelling of Multistage Hydraulic Fracture Operations in Unconventional Resources - the Application of Geomechanics and Field Data to the Optimization of Fracture Spacing and Production by : Natalia Skomorowski

Download or read book Modelling of Multistage Hydraulic Fracture Operations in Unconventional Resources - the Application of Geomechanics and Field Data to the Optimization of Fracture Spacing and Production written by Natalia Skomorowski and published by . This book was released on 2016 with total page 167 pages. Available in PDF, EPUB and Kindle. Book excerpt: Massive multistage hydraulic fracturing using horizontal wells has been an integral part of the natural resource industry in Canada. The process uses long horizontal wells divided into many stages to access large volumes of oil and gas bearing formations. Each well is divided into fracture stages. Fluids are pumped down into each stage of the well to generate a fracture which increases the porosity and permeability of the formation to allow economic resource extraction. The in situ geomechanical stresses of the formation do not remain static during the fracturing of the rock. Each fracture creates a volume change within the formation which in turn leads to alteration of the stress and strain conditions within the rock mass. There is the possibility that the alteration of stress conditions will have an effect on the initiation and propagation of subsequent stages of the multi-stage hydraulic fracture operation. This phenomenon is known as 'stress shadowing'. Stress shadowing occurs when the minimum compressive stress in the formation is increased due to the fracturing of the rock. Increasing the minimum compressive horizontal stress can have several effects, including the rotation or diversion of fracture propagation, stages that do not initiate, thinner fractures, and reduced porosity and permeability within the fracture stage. Currently, many hydraulic fracture operations do not invest in advanced mathematical models of geomechanics. Some pressure monitoring is carried out during operations, but the data are inadequate to warrant advanced numerical methods to predict stress change and its effects. This thesis presents a semi-analytical solution for the stresses around an ellipsoid (the Eshelby Solution) for use in predicting fracture geometry and stress shadow effects. The program is quick to use and can be linked to field data. A study of field data from the Montney Formation is presented. The algorithm developed in this thesis is used to evaluate stress changes within the Montney Formation and the outputs are compared to the stress changes seen in the hydraulic fracture pressure data.

Automated Optimization Strategies for Horizontal Wellbore and Hydraulic Fracture Stages Placement in Unconventional Gas Reseroirs

Automated Optimization Strategies for Horizontal Wellbore and Hydraulic Fracture Stages Placement in Unconventional Gas Reseroirs

Author: Tatyana Plaksina

Publisher:

Published: 2015

Total Pages:

ISBN-13:

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In the last decades rapid advances in horizontal drilling and hydraulic fracturing technologies ensure production of commercial quantities of natural gas from many unconventional reservoirs. Reservoir management and development strategies for shale and tight gas plays have evolved from ad hoc approaches to more rigorous strategies that involve numerical optimization in presence of multiple economic and production objectives and constraints. Application of an automated integrated optimization framework for placement of horizontal wellbores and transverse hydraulic fracture stages along them has potential of increasing shale gas reserves and projects' revenue even further. This dissertation introduces a novel integrated evolutionary-based optimization framework for placement of horizontal wellbores and hydraulic fracture stages that allows enhancing production from shale gas formations and provides a solid foundation for future field-scale application once better understanding of shale petrophysics and geomechanics is developed. The proposed optimization workflow is developed and tested in stages. First, we summarize what has been done in the subject field previously by scholars and identify what is missing. Second, we present assumptions for the shale gas simulation model that make our framework and the simulation model applicable. Third, we pre-screen several economic and petrophysical parameters in order to identify the most significant for the subsequent sensitivities analysis. Forth, we develop evolutionary-based optimization strategy for placement of hydraulic fracture stages along a single horizontal wellbore. We investigate how sensitive the optimization results to changes in the key parameters pre-selected during pre-screening. Fifth, we enhance the framework to handle multiple horizontal producers, discuss the conditions when such approach is applicable, and extensively test this integrated workflow on a suite of simulation runs. Finally, we implement and apply multi-objective optimization approach (the improved non-dominated sorting genetic algorithm) to the problem of optimal HF stage placement in shale gas reservoirs and analyze the efficiency of our evolutionary-based optimization scheme in presence of multiple conflicting or non-conflicting objectives. Based on our extensive testing and rigorous formulation of the optimization problem, we find that the chosen evolutionary framework is effective in calculating the optimal number of horizontal wells, the number of HF stages, their specific locations along the wells as well as their half-length. We also conclude that further computational efficiency can be achieved if minimum stage spacing and same chromosome elimination procedure are used. The multi-objective approach has been tested on conflicting and non-conflicting objectives and proved to compute the Pareto optimal front of solutions (or production scenarios) in computationally efficient manner. The electronic version of this dissertation is accessible from http://hdl.handle.net/1969.1/155086


Book Synopsis Automated Optimization Strategies for Horizontal Wellbore and Hydraulic Fracture Stages Placement in Unconventional Gas Reseroirs by : Tatyana Plaksina

Download or read book Automated Optimization Strategies for Horizontal Wellbore and Hydraulic Fracture Stages Placement in Unconventional Gas Reseroirs written by Tatyana Plaksina and published by . This book was released on 2015 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: In the last decades rapid advances in horizontal drilling and hydraulic fracturing technologies ensure production of commercial quantities of natural gas from many unconventional reservoirs. Reservoir management and development strategies for shale and tight gas plays have evolved from ad hoc approaches to more rigorous strategies that involve numerical optimization in presence of multiple economic and production objectives and constraints. Application of an automated integrated optimization framework for placement of horizontal wellbores and transverse hydraulic fracture stages along them has potential of increasing shale gas reserves and projects' revenue even further. This dissertation introduces a novel integrated evolutionary-based optimization framework for placement of horizontal wellbores and hydraulic fracture stages that allows enhancing production from shale gas formations and provides a solid foundation for future field-scale application once better understanding of shale petrophysics and geomechanics is developed. The proposed optimization workflow is developed and tested in stages. First, we summarize what has been done in the subject field previously by scholars and identify what is missing. Second, we present assumptions for the shale gas simulation model that make our framework and the simulation model applicable. Third, we pre-screen several economic and petrophysical parameters in order to identify the most significant for the subsequent sensitivities analysis. Forth, we develop evolutionary-based optimization strategy for placement of hydraulic fracture stages along a single horizontal wellbore. We investigate how sensitive the optimization results to changes in the key parameters pre-selected during pre-screening. Fifth, we enhance the framework to handle multiple horizontal producers, discuss the conditions when such approach is applicable, and extensively test this integrated workflow on a suite of simulation runs. Finally, we implement and apply multi-objective optimization approach (the improved non-dominated sorting genetic algorithm) to the problem of optimal HF stage placement in shale gas reservoirs and analyze the efficiency of our evolutionary-based optimization scheme in presence of multiple conflicting or non-conflicting objectives. Based on our extensive testing and rigorous formulation of the optimization problem, we find that the chosen evolutionary framework is effective in calculating the optimal number of horizontal wells, the number of HF stages, their specific locations along the wells as well as their half-length. We also conclude that further computational efficiency can be achieved if minimum stage spacing and same chromosome elimination procedure are used. The multi-objective approach has been tested on conflicting and non-conflicting objectives and proved to compute the Pareto optimal front of solutions (or production scenarios) in computationally efficient manner. The electronic version of this dissertation is accessible from http://hdl.handle.net/1969.1/155086

Experimental Investigation of Geomechanical Aspects of Hydraulic Fracturing Unconventional Formations

Experimental Investigation of Geomechanical Aspects of Hydraulic Fracturing Unconventional Formations

Author: Emad Abbad alabbad

Publisher:

Published: 2014

Total Pages: 330

ISBN-13:

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Understanding the mechanisms that govern hydraulic fracturing applications in unconventional formations, such as gas-bearing shales, is of increasing interest to the petroleum upstream industry. Among such mechanisms, the geomechanical interactions between hydraulic fractures and pre-existing fractures on one hand, and simultaneous multiple hydraulic fractures on the other hand are seen of high importance. Although the petroleum engineering and related literature contains a number of studies that discusses such topics of hydraulic fracture interactions, there still remain some aspects that require answers, validations, or further supporting data. Particularly, experimental evidence is fairly scarce and keenly needed to solidify the understanding of such complex applications. In this work, the investigation methodology uses a series of hydraulic fracturing laboratory tests performed on synthetic rocks made of gypsum-based cements such as hydrostone and plaster in various experimental set ups. Those laboratory tests aim to closely investigate hydraulic fracture intersection with pre-existing fractures by assessing some factors that govern its outcomes. Specifically, the roles of the pre-existing fracture cementation, aperture, and relative height on the intersection mode are examined. The results show dominant effect of the cement-fill type relative to the host-rock matrix in determining whether hydraulic fracture crossing the pre-existing interface may occur. Similarly, hydraulic fracture height relative to the height of the pre-existing fracture may dictate the intersection results. However, the intersection mode seems to be insensitive of the pre-existing fracture aperture. Moreover, simultaneous multi-fracture propagation is examined and found to be impacted by the interference of the stresses induced from each fracturing source on neighboring fracturing sources. Such stress interference increases as the number of the propagating hydraulic fractures increase. While hydraulic fractures initiating from fracturing sources located in the middle of the fracturing stage seem to have inhibited propagation, outer hydraulic fractures may continue propagating with outward curvatures. Overall, the experimental results and analyses offer more insights for understanding hydraulic fracture complexity in unconventional formations.


Book Synopsis Experimental Investigation of Geomechanical Aspects of Hydraulic Fracturing Unconventional Formations by : Emad Abbad alabbad

Download or read book Experimental Investigation of Geomechanical Aspects of Hydraulic Fracturing Unconventional Formations written by Emad Abbad alabbad and published by . This book was released on 2014 with total page 330 pages. Available in PDF, EPUB and Kindle. Book excerpt: Understanding the mechanisms that govern hydraulic fracturing applications in unconventional formations, such as gas-bearing shales, is of increasing interest to the petroleum upstream industry. Among such mechanisms, the geomechanical interactions between hydraulic fractures and pre-existing fractures on one hand, and simultaneous multiple hydraulic fractures on the other hand are seen of high importance. Although the petroleum engineering and related literature contains a number of studies that discusses such topics of hydraulic fracture interactions, there still remain some aspects that require answers, validations, or further supporting data. Particularly, experimental evidence is fairly scarce and keenly needed to solidify the understanding of such complex applications. In this work, the investigation methodology uses a series of hydraulic fracturing laboratory tests performed on synthetic rocks made of gypsum-based cements such as hydrostone and plaster in various experimental set ups. Those laboratory tests aim to closely investigate hydraulic fracture intersection with pre-existing fractures by assessing some factors that govern its outcomes. Specifically, the roles of the pre-existing fracture cementation, aperture, and relative height on the intersection mode are examined. The results show dominant effect of the cement-fill type relative to the host-rock matrix in determining whether hydraulic fracture crossing the pre-existing interface may occur. Similarly, hydraulic fracture height relative to the height of the pre-existing fracture may dictate the intersection results. However, the intersection mode seems to be insensitive of the pre-existing fracture aperture. Moreover, simultaneous multi-fracture propagation is examined and found to be impacted by the interference of the stresses induced from each fracturing source on neighboring fracturing sources. Such stress interference increases as the number of the propagating hydraulic fractures increase. While hydraulic fractures initiating from fracturing sources located in the middle of the fracturing stage seem to have inhibited propagation, outer hydraulic fractures may continue propagating with outward curvatures. Overall, the experimental results and analyses offer more insights for understanding hydraulic fracture complexity in unconventional formations.

Unconventional Reservoir Geomechanics

Unconventional Reservoir Geomechanics

Author: Mark D. Zoback

Publisher: Cambridge University Press

Published: 2019-05-16

Total Pages: 495

ISBN-13: 1107087074

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A comprehensive overview of the key geologic, geomechanical and engineering principles that govern the development of unconventional oil and gas reservoirs. Covering hydrocarbon-bearing formations, horizontal drilling, reservoir seismology and environmental impacts, this is an invaluable resource for geologists, geophysicists and reservoir engineers.


Book Synopsis Unconventional Reservoir Geomechanics by : Mark D. Zoback

Download or read book Unconventional Reservoir Geomechanics written by Mark D. Zoback and published by Cambridge University Press. This book was released on 2019-05-16 with total page 495 pages. Available in PDF, EPUB and Kindle. Book excerpt: A comprehensive overview of the key geologic, geomechanical and engineering principles that govern the development of unconventional oil and gas reservoirs. Covering hydrocarbon-bearing formations, horizontal drilling, reservoir seismology and environmental impacts, this is an invaluable resource for geologists, geophysicists and reservoir engineers.

Flowback and Produced Waters

Flowback and Produced Waters

Author: National Academies of Sciences, Engineering, and Medicine

Publisher: National Academies Press

Published: 2017-02-27

Total Pages: 101

ISBN-13: 0309452651

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Produced waterâ€"water from underground formations that is brought to the surface during oil and gas productionâ€"is the greatest volume byproduct associated with oil and gas production. It is managed by some combination of underground injection, treatment and subsequent use, treatment and discharge, or evaporation, subject to compliance with state and federal regulations. Management of these waters is challenging not only for industry and regulators, but also for landowners and the public because of differences in the quality and quantity of produced water, varying infrastructure needs, costs, and environmental considerations associated with produced water disposal, storage, and transport. Unconventional oil and gas development involves technologies that combine horizontal drilling with the practice of hydraulic fracturing. Hydraulic fracturing is a controlled, high-pressure injection of fluid and proppant into a well to generate fractures in the rock formation containing the oil or gas. After the hydraulic fracture procedure is completed, the injected fluid is allowed to flow back into the well, leaving the proppant in the newly created fractures. As a result, a portion of the injected water returns to the surface and this water is called "flowback water" which initially may mix with the naturally occurring produced water from the formation. The chemistry and volume of water returning to the surface from unconventional oil and gas operations thus changes during the lifetime of the well due to the amount of fluid used in the initial stage of well development, the amount of water naturally occurring in the geologic formation, the original water and rock chemistry, the type of hydrocarbon being produced, and the way in which production is conducted. The volume and composition of flowback and produced waters vary with geography, time, and site-specific factors. A workshop was conducted by the National Academies of Sciences, Engineering, and Medicine to highlight the challenges and opportunities associated in managing produced water from unconventional hydrocarbon development, and particularly in the area of potential beneficial uses for these waters. This publication summarizes the presentations and discussions from the workshop.


Book Synopsis Flowback and Produced Waters by : National Academies of Sciences, Engineering, and Medicine

Download or read book Flowback and Produced Waters written by National Academies of Sciences, Engineering, and Medicine and published by National Academies Press. This book was released on 2017-02-27 with total page 101 pages. Available in PDF, EPUB and Kindle. Book excerpt: Produced waterâ€"water from underground formations that is brought to the surface during oil and gas productionâ€"is the greatest volume byproduct associated with oil and gas production. It is managed by some combination of underground injection, treatment and subsequent use, treatment and discharge, or evaporation, subject to compliance with state and federal regulations. Management of these waters is challenging not only for industry and regulators, but also for landowners and the public because of differences in the quality and quantity of produced water, varying infrastructure needs, costs, and environmental considerations associated with produced water disposal, storage, and transport. Unconventional oil and gas development involves technologies that combine horizontal drilling with the practice of hydraulic fracturing. Hydraulic fracturing is a controlled, high-pressure injection of fluid and proppant into a well to generate fractures in the rock formation containing the oil or gas. After the hydraulic fracture procedure is completed, the injected fluid is allowed to flow back into the well, leaving the proppant in the newly created fractures. As a result, a portion of the injected water returns to the surface and this water is called "flowback water" which initially may mix with the naturally occurring produced water from the formation. The chemistry and volume of water returning to the surface from unconventional oil and gas operations thus changes during the lifetime of the well due to the amount of fluid used in the initial stage of well development, the amount of water naturally occurring in the geologic formation, the original water and rock chemistry, the type of hydrocarbon being produced, and the way in which production is conducted. The volume and composition of flowback and produced waters vary with geography, time, and site-specific factors. A workshop was conducted by the National Academies of Sciences, Engineering, and Medicine to highlight the challenges and opportunities associated in managing produced water from unconventional hydrocarbon development, and particularly in the area of potential beneficial uses for these waters. This publication summarizes the presentations and discussions from the workshop.

Advances in Fluid-Solid Coupling Processes between Fractures and Porous Rocks: Experimental and Numerical Investigation

Advances in Fluid-Solid Coupling Processes between Fractures and Porous Rocks: Experimental and Numerical Investigation

Author: Shiming Wei

Publisher: Frontiers Media SA

Published:

Total Pages: 122

ISBN-13: 2832541658

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Hydraulic fracturing is the key measure for improving recovery of unconventional oil and gas reservoirs. Prediction of fracture morphology and productivity after fracturing is critical for fracturing design and optimization. The hydraulic fracturing process is to open porous rocks by artificially injecting highly compressed fluid, and the hydraulic fracture will be closed under the compaction of in-situ stress during the production process. In this regard, hydraulic fracturing and production processes are both fluid-solid coupling processes involving fractures and porous rocks. This Research Topic aims to gather the latest studies addressing how to improve the prediction accuracy of hydraulic fracturing morphology and post-fracturing productivity through experimental and numerical investigation. The experimental research shall underline hydraulic fracturing and fracture conductivity experiments and associated experimental methods, while the numerical research shall pay particular attention to discrete fracture network models, including the calculation efficiency and accuracy as well as the applicability.


Book Synopsis Advances in Fluid-Solid Coupling Processes between Fractures and Porous Rocks: Experimental and Numerical Investigation by : Shiming Wei

Download or read book Advances in Fluid-Solid Coupling Processes between Fractures and Porous Rocks: Experimental and Numerical Investigation written by Shiming Wei and published by Frontiers Media SA. This book was released on with total page 122 pages. Available in PDF, EPUB and Kindle. Book excerpt: Hydraulic fracturing is the key measure for improving recovery of unconventional oil and gas reservoirs. Prediction of fracture morphology and productivity after fracturing is critical for fracturing design and optimization. The hydraulic fracturing process is to open porous rocks by artificially injecting highly compressed fluid, and the hydraulic fracture will be closed under the compaction of in-situ stress during the production process. In this regard, hydraulic fracturing and production processes are both fluid-solid coupling processes involving fractures and porous rocks. This Research Topic aims to gather the latest studies addressing how to improve the prediction accuracy of hydraulic fracturing morphology and post-fracturing productivity through experimental and numerical investigation. The experimental research shall underline hydraulic fracturing and fracture conductivity experiments and associated experimental methods, while the numerical research shall pay particular attention to discrete fracture network models, including the calculation efficiency and accuracy as well as the applicability.

Simulating Gas Production from Hydraulic Fracture Networks

Simulating Gas Production from Hydraulic Fracture Networks

Author: Jennifer Lynn Reese

Publisher:

Published: 2007

Total Pages:

ISBN-13:

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The Barnett shale has become an extremely successful unconventional natural gas development, mainly due to the optimization of hydraulic fracturing treatments. The ideal stimulation job for the Barnett is a slickwater treatment with low proppant concentrations, because this type of waterfrac is believed to create longer and more complex fracture networks, contacting much greater surface areas of the reservoir while minimizing the fracture face damage through the use of low viscosity fluids with no gel solids. Fracture mapping research in the Barnett shale has shown that the hydraulic fracturing of vertical wells produces an extremely complex network of fractures, and the work presented here focuses on modeling these fracture networks to gain a better understanding of how hydraulic fractures perform in the Barnett. Over one hundred simulation runs were conducted with models of varying fairway sizes, aspect ratios, fracture spacings, total network lengths, and fracture conductivities in an effort to better understand the impact each parameter has on well performance. Results were analyzed according to the classic parameters of stimulated reservoir volume, fracture spacing and total fracture network length. Observed trends and production plateaus in the simulation data establish a way to optimize the stimulation treatment and production for a given well. Fracture conductivity is considered to be of secondary importance in the hydraulic fracturing of very low permeability formations, but the extensive network structures of the Barnett shale are so large that fracture conductivity becomes important again. Since small increases in fracture conductivity can yield significant production increases, operators in the Barnett shale can focus on fracture conductivity as a way to optimize stimulation jobs and yield efficient production wells. The simulation results were compared to field data gathered from a production database, and showed that the simulation model can duplicate both the shape and range of the cumulative production profiles observed in the field, thus validating the simulation modeling process. The fact that the simulation runs model the observed field production provides further evidence that Barnett shale wells actually produce from a complex fracture network and not from a single planar fracture.


Book Synopsis Simulating Gas Production from Hydraulic Fracture Networks by : Jennifer Lynn Reese

Download or read book Simulating Gas Production from Hydraulic Fracture Networks written by Jennifer Lynn Reese and published by . This book was released on 2007 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: The Barnett shale has become an extremely successful unconventional natural gas development, mainly due to the optimization of hydraulic fracturing treatments. The ideal stimulation job for the Barnett is a slickwater treatment with low proppant concentrations, because this type of waterfrac is believed to create longer and more complex fracture networks, contacting much greater surface areas of the reservoir while minimizing the fracture face damage through the use of low viscosity fluids with no gel solids. Fracture mapping research in the Barnett shale has shown that the hydraulic fracturing of vertical wells produces an extremely complex network of fractures, and the work presented here focuses on modeling these fracture networks to gain a better understanding of how hydraulic fractures perform in the Barnett. Over one hundred simulation runs were conducted with models of varying fairway sizes, aspect ratios, fracture spacings, total network lengths, and fracture conductivities in an effort to better understand the impact each parameter has on well performance. Results were analyzed according to the classic parameters of stimulated reservoir volume, fracture spacing and total fracture network length. Observed trends and production plateaus in the simulation data establish a way to optimize the stimulation treatment and production for a given well. Fracture conductivity is considered to be of secondary importance in the hydraulic fracturing of very low permeability formations, but the extensive network structures of the Barnett shale are so large that fracture conductivity becomes important again. Since small increases in fracture conductivity can yield significant production increases, operators in the Barnett shale can focus on fracture conductivity as a way to optimize stimulation jobs and yield efficient production wells. The simulation results were compared to field data gathered from a production database, and showed that the simulation model can duplicate both the shape and range of the cumulative production profiles observed in the field, thus validating the simulation modeling process. The fact that the simulation runs model the observed field production provides further evidence that Barnett shale wells actually produce from a complex fracture network and not from a single planar fracture.

Hydraulic Fracturing in Naturally Fractured Reservoirs and the Impact of Geomechanics on Microseismicity

Hydraulic Fracturing in Naturally Fractured Reservoirs and the Impact of Geomechanics on Microseismicity

Author: Himanshu Yadav

Publisher:

Published: 2011

Total Pages: 188

ISBN-13:

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Hydraulic fracturing in tight gas and shale gas reservoirs is an essential stimulation technique for production enhancement. Often, hydraulic fracturing induces fracture patterns that are more complex than the planar geometry that has been assumed in the past models. These complex patterns arise as a result of the presence of planes of weakness, faults and/or natural fractures. In this thesis, two different 3D geomechanical models have been developed to simulate the interaction between the hydraulic fracture and the natural fractures, and to observe the impact of geomechanics on the potential microseismicity in these naturally fractured formations. Several cases were studied to observe the effects of natural fracture geometry, fracturing treatment, mechanical properties of the sealed fractures, etc. on the propagation path of the hydraulic fracture in these formations, and were found to be consistent with past experimental results. Moreover, the effects of several parameters including cohesiveness of the sealed natural fractures, mechanical properties of the formation, treatment parameters, etc. have been studied from the potential microseismicity standpoint. It is shown that the impact of geomechanics on potential microseismicity is significant and can influence the desired fracture spacing. In this thesis, the presented model quantifies the extent of potential microseismic volume (MSV) resulting from hydraulic fracturing in unconventional reservoirs. The model accounts for random geometries of the weak planes (with different dip and strike) observed in the field. The work presented here shows, for the first time, a fracture treatment can be designed to maximize the MSV, when the fractures form a complicated network of fractures, and in turn influence the desired fracture spacing in horizontal wells. Our work shows that by adjusting the fluid rheology and other treatment parameters, the spatial extent of MSV and the desired fracture spacing can be optimized for a given set of shale properties.


Book Synopsis Hydraulic Fracturing in Naturally Fractured Reservoirs and the Impact of Geomechanics on Microseismicity by : Himanshu Yadav

Download or read book Hydraulic Fracturing in Naturally Fractured Reservoirs and the Impact of Geomechanics on Microseismicity written by Himanshu Yadav and published by . This book was released on 2011 with total page 188 pages. Available in PDF, EPUB and Kindle. Book excerpt: Hydraulic fracturing in tight gas and shale gas reservoirs is an essential stimulation technique for production enhancement. Often, hydraulic fracturing induces fracture patterns that are more complex than the planar geometry that has been assumed in the past models. These complex patterns arise as a result of the presence of planes of weakness, faults and/or natural fractures. In this thesis, two different 3D geomechanical models have been developed to simulate the interaction between the hydraulic fracture and the natural fractures, and to observe the impact of geomechanics on the potential microseismicity in these naturally fractured formations. Several cases were studied to observe the effects of natural fracture geometry, fracturing treatment, mechanical properties of the sealed fractures, etc. on the propagation path of the hydraulic fracture in these formations, and were found to be consistent with past experimental results. Moreover, the effects of several parameters including cohesiveness of the sealed natural fractures, mechanical properties of the formation, treatment parameters, etc. have been studied from the potential microseismicity standpoint. It is shown that the impact of geomechanics on potential microseismicity is significant and can influence the desired fracture spacing. In this thesis, the presented model quantifies the extent of potential microseismic volume (MSV) resulting from hydraulic fracturing in unconventional reservoirs. The model accounts for random geometries of the weak planes (with different dip and strike) observed in the field. The work presented here shows, for the first time, a fracture treatment can be designed to maximize the MSV, when the fractures form a complicated network of fractures, and in turn influence the desired fracture spacing in horizontal wells. Our work shows that by adjusting the fluid rheology and other treatment parameters, the spatial extent of MSV and the desired fracture spacing can be optimized for a given set of shale properties.