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Pavel Bedrikovetsky - One of the best experts on this subject based on the ideXlab platform.
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Effect of Suspension Fluid Chemistry on Fracture System Stimulation Using Micro-Sized Proppant Placement
SPE Asia Pacific Unconventional Resources Conference and Exhibition, 2015Co-Authors: Alireza Keshavarz, Alexander Badalyan, Themis Carageorgos, Raymond L. Johnson, Pavel BedrikovetskyAbstract:The physical model and experimental data support the beneficial technology of graded proppant injection into naturally fractured reservoirs to stimulate natural fracture permeability. Injection of particles with increasing size, at poroelastic and hydraulic Fracturing conditions, yield deeper penetration and gradual filling of natural fractures with a resulting increase in permeability. This work expands on the concepts and outlines steps to maximize the benefit of graded proppant injection to enhance coal seam gas stimulation by focusing on the effect of the chemistry of injected fluid on the overall performance and the use in conjunction with hydraulic Fracturing. Low productivity indices can be observed in many moderate- to low-permeability coal bed methane (CSG) reservoirs due to low aperture and poor connectivity of natural cleats. Graded proppant injection in CSG environments can: stimulate a stress sensitive cleat system below the Fracturing Pressure as well as enhance a Fracturing treatment by invading cleats, lowering fluid leakoff, and maintaining aperture during production. Further, periodic or remedial treatments could to counter effective stress on the cleats improving production by maintaining cleat aperture. Laboratory tests on coal core flooding by water under increasing pore Pressure with proppant injection at the maximum Pressure have been carried out under different salinities of the injected water. Proppantproppant and proppant-coal Derjaguin-Landau-Verwey-Overbeek (DLVO) total interaction energies were calculated to optimise the condition for successful proppant placement. Results on the DLVO total energy of interaction showed that conditions favourable for successful proppant placement in coal cleats are suspension ionic strengths between 0.05 M and 0.1 M NaCl. At these conditions no proppant agglomeration and proppant-coal attachment are observed, allowing deeper penetration of proppant into the natural coal cleat system. Lower suspension ionic strengths can lead to natural coal fines migration, cleat plugging and coal permeability reduction. Based on the experimental results and previously developed model a case study has been conducted to evaluate the productivity enhancement using this technique. The results show about four-fold increase in well productivity index at injections below Fracturing Pressures and may further improve the stimulated reservoir volume when used in conjunction with low permeability coal hydraulic Fracturing treatments.
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Laboratory-based mathematical modelling of graded proppant injection in CBM reservoirs
International Journal of Coal Geology, 2014Co-Authors: Alireza Keshavarz, Alexander Badalyan, Raymond L. Johnson, Yulong Yang, Pavel BedrikovetskyAbstract:Abstract The graded proppant injection into a connected cleat system of coal bed methane (CBM) reservoir allows deeper particle penetration and straining in the remote open cleats yielding higher well productivity index. The analytical model for axisymmetric flow has been derived for exponential stress–permeability relationship and accounting for permeability variation outside the stimulated zone. Laboratory proppant injections into coal cores have been performed for different proppant sizes and water salinities. It is shown that the proppant suspension based on low salinity water prevents the particle–particle and particle–coal attraction with the consequent core inlet plugging and external cake formation. However, low salinity of the injected water may cause mobilisation, migration and straining of the natural reservoir fines resulting in high formation damage. The interval where salinity is low enough for the rock inlet not to be plugged by the injected proppant, and is high enough for large formation damage due to fine migration not to occur, is proposed for the cores under investigation. The analytical model is tuned from the laboratory data and used for well index prediction. Ignoring the model matching by the laboratory results causes the overestimation of the incremental productivity index, as achieved by the graded proppant injection into coal beds below the Fracturing Pressure.
Alireza Keshavarz - One of the best experts on this subject based on the ideXlab platform.
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Effect of Suspension Fluid Chemistry on Fracture System Stimulation Using Micro-Sized Proppant Placement
SPE Asia Pacific Unconventional Resources Conference and Exhibition, 2015Co-Authors: Alireza Keshavarz, Alexander Badalyan, Themis Carageorgos, Raymond L. Johnson, Pavel BedrikovetskyAbstract:The physical model and experimental data support the beneficial technology of graded proppant injection into naturally fractured reservoirs to stimulate natural fracture permeability. Injection of particles with increasing size, at poroelastic and hydraulic Fracturing conditions, yield deeper penetration and gradual filling of natural fractures with a resulting increase in permeability. This work expands on the concepts and outlines steps to maximize the benefit of graded proppant injection to enhance coal seam gas stimulation by focusing on the effect of the chemistry of injected fluid on the overall performance and the use in conjunction with hydraulic Fracturing. Low productivity indices can be observed in many moderate- to low-permeability coal bed methane (CSG) reservoirs due to low aperture and poor connectivity of natural cleats. Graded proppant injection in CSG environments can: stimulate a stress sensitive cleat system below the Fracturing Pressure as well as enhance a Fracturing treatment by invading cleats, lowering fluid leakoff, and maintaining aperture during production. Further, periodic or remedial treatments could to counter effective stress on the cleats improving production by maintaining cleat aperture. Laboratory tests on coal core flooding by water under increasing pore Pressure with proppant injection at the maximum Pressure have been carried out under different salinities of the injected water. Proppantproppant and proppant-coal Derjaguin-Landau-Verwey-Overbeek (DLVO) total interaction energies were calculated to optimise the condition for successful proppant placement. Results on the DLVO total energy of interaction showed that conditions favourable for successful proppant placement in coal cleats are suspension ionic strengths between 0.05 M and 0.1 M NaCl. At these conditions no proppant agglomeration and proppant-coal attachment are observed, allowing deeper penetration of proppant into the natural coal cleat system. Lower suspension ionic strengths can lead to natural coal fines migration, cleat plugging and coal permeability reduction. Based on the experimental results and previously developed model a case study has been conducted to evaluate the productivity enhancement using this technique. The results show about four-fold increase in well productivity index at injections below Fracturing Pressures and may further improve the stimulated reservoir volume when used in conjunction with low permeability coal hydraulic Fracturing treatments.
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Laboratory-based mathematical modelling of graded proppant injection in CBM reservoirs
International Journal of Coal Geology, 2014Co-Authors: Alireza Keshavarz, Alexander Badalyan, Raymond L. Johnson, Yulong Yang, Pavel BedrikovetskyAbstract:Abstract The graded proppant injection into a connected cleat system of coal bed methane (CBM) reservoir allows deeper particle penetration and straining in the remote open cleats yielding higher well productivity index. The analytical model for axisymmetric flow has been derived for exponential stress–permeability relationship and accounting for permeability variation outside the stimulated zone. Laboratory proppant injections into coal cores have been performed for different proppant sizes and water salinities. It is shown that the proppant suspension based on low salinity water prevents the particle–particle and particle–coal attraction with the consequent core inlet plugging and external cake formation. However, low salinity of the injected water may cause mobilisation, migration and straining of the natural reservoir fines resulting in high formation damage. The interval where salinity is low enough for the rock inlet not to be plugged by the injected proppant, and is high enough for large formation damage due to fine migration not to occur, is proposed for the cores under investigation. The analytical model is tuned from the laboratory data and used for well index prediction. Ignoring the model matching by the laboratory results causes the overestimation of the incremental productivity index, as achieved by the graded proppant injection into coal beds below the Fracturing Pressure.
Al-homadhi E.s. - One of the best experts on this subject based on the ideXlab platform.
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The effect of the initial rock permeability on the extent of injectivity reduction due to brine injection through fractured formation
Editions Technip, 2001Co-Authors: Al-homadhi E.s.Abstract:The injectivity reduction with time is an important aspect in designing water injection projects. One of the main factors that affect the injectivity, due to particle invasion, is the matrix initial permeability. This factor had been experimentally investigated and evaluated by many researchers, but all of their experimental works were based on linear core flow tests. However, in some field injection projects, there was a much less reduction in the injectivity with time than what was predicted by the experimental models. This incompatibility was related to the induction of fractures caused by injection at a Pressure higher than the formation Fracturing Pressure. This study was conducted to investigate experimentally the effect of the matrix initial permeability on the extent of injectivity reduction caused by brine injection through a rock matrix with a single fracture. The injected brine contained solid particles less than 6 mm or less than 20 mm in size at a concentration of 9 mg/l. The early results show experimentally the huge difference in the injectivity reduction extent between flow tests carried out with closed and open fracture injection. Then, the results are presented as an injectivity index at a certain injected pore volume versus initial permeability. The slope of this relation is called reduction rate. This rate was evaluated for different cases. For the case of brine suspensions that contain small particles, the reduction rate of the injectivity index due to initial permeability variation in the case of open fracture tests was much less than that of the closed fracture tests. For the case of fracture injection of the large particles suspensions, the reduction rate was threefold higher than that of the small particles suspension. This proves that the particle size factor has an important role in determining the extent of the initial rock permeability effect on the injectivity index in fracture injectionCorresponding Author: Mr. E.S.Al-Homadhi, Petroleum Engineering Department, College of Engineering, King Saud University, PO Box 800, Riyadh, Saudi Arabia. Email: ehomadhi@ksu.edu.s
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The effect of the initial rock permeability on the extent of injectivity reduction due to brine injection through fractured formation
Editions Technip, 2001Co-Authors: Al-homadhi E.s.Abstract:The Effect of the Initial Rock Permeability on the Extent of Injectivity Reduction Due to Brine Injection through Fractured Formation-The injectivity reduction with time is an important aspect in designing water injection projects. One of the main factors that affect the injectivity, due to particle invasion, is the matrix initial permeability. This factor had been experimentally investigated and evaluated by many researchers, but all of their experimental works were based on linear core flow tests. However, in some field injection projects, there was a much less reduction in the injectivity with time than what was predicted by the experimental models. This incompatibility was related to the induction of fractures caused by injection at a Pressure higher than the formation Fracturing Pressure. This study was conducted to investigate experimentally the effect of the matrix initial permeability on the extent of injectivity reduction caused by brine injection through a rock matrix with a single fracture. The injected brine contained solid particles less than 6 μm or less than 20 μm in size at a concentration of 9 mg/l. The early results show experimentally the huge difference in the injectivity reduction extent between flow tests carried out with closed and open fracture injection. Then, the results are presented as an injectivity index at a certain injected pore volume versus initial permeability. The slope of this relation is called reduction rate. This rate was evaluated for different cases. For the case of brine suspensions that contain small particles, the reduction rate of the injectivity index due to initial permeability variation in the case of open fracture tests was much less than that of the closed fracture tests. For the case of fracture injection of the large particles suspensions, the reduction rate was threefold higher than that of the small particles suspension. This proves that the particle size factor has an important role in determining the extent of the initial rock permeability effect on the injectivity index in fracture injection.King Saud Universit
Alexander Badalyan - One of the best experts on this subject based on the ideXlab platform.
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Effect of Suspension Fluid Chemistry on Fracture System Stimulation Using Micro-Sized Proppant Placement
SPE Asia Pacific Unconventional Resources Conference and Exhibition, 2015Co-Authors: Alireza Keshavarz, Alexander Badalyan, Themis Carageorgos, Raymond L. Johnson, Pavel BedrikovetskyAbstract:The physical model and experimental data support the beneficial technology of graded proppant injection into naturally fractured reservoirs to stimulate natural fracture permeability. Injection of particles with increasing size, at poroelastic and hydraulic Fracturing conditions, yield deeper penetration and gradual filling of natural fractures with a resulting increase in permeability. This work expands on the concepts and outlines steps to maximize the benefit of graded proppant injection to enhance coal seam gas stimulation by focusing on the effect of the chemistry of injected fluid on the overall performance and the use in conjunction with hydraulic Fracturing. Low productivity indices can be observed in many moderate- to low-permeability coal bed methane (CSG) reservoirs due to low aperture and poor connectivity of natural cleats. Graded proppant injection in CSG environments can: stimulate a stress sensitive cleat system below the Fracturing Pressure as well as enhance a Fracturing treatment by invading cleats, lowering fluid leakoff, and maintaining aperture during production. Further, periodic or remedial treatments could to counter effective stress on the cleats improving production by maintaining cleat aperture. Laboratory tests on coal core flooding by water under increasing pore Pressure with proppant injection at the maximum Pressure have been carried out under different salinities of the injected water. Proppantproppant and proppant-coal Derjaguin-Landau-Verwey-Overbeek (DLVO) total interaction energies were calculated to optimise the condition for successful proppant placement. Results on the DLVO total energy of interaction showed that conditions favourable for successful proppant placement in coal cleats are suspension ionic strengths between 0.05 M and 0.1 M NaCl. At these conditions no proppant agglomeration and proppant-coal attachment are observed, allowing deeper penetration of proppant into the natural coal cleat system. Lower suspension ionic strengths can lead to natural coal fines migration, cleat plugging and coal permeability reduction. Based on the experimental results and previously developed model a case study has been conducted to evaluate the productivity enhancement using this technique. The results show about four-fold increase in well productivity index at injections below Fracturing Pressures and may further improve the stimulated reservoir volume when used in conjunction with low permeability coal hydraulic Fracturing treatments.
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Laboratory-based mathematical modelling of graded proppant injection in CBM reservoirs
International Journal of Coal Geology, 2014Co-Authors: Alireza Keshavarz, Alexander Badalyan, Raymond L. Johnson, Yulong Yang, Pavel BedrikovetskyAbstract:Abstract The graded proppant injection into a connected cleat system of coal bed methane (CBM) reservoir allows deeper particle penetration and straining in the remote open cleats yielding higher well productivity index. The analytical model for axisymmetric flow has been derived for exponential stress–permeability relationship and accounting for permeability variation outside the stimulated zone. Laboratory proppant injections into coal cores have been performed for different proppant sizes and water salinities. It is shown that the proppant suspension based on low salinity water prevents the particle–particle and particle–coal attraction with the consequent core inlet plugging and external cake formation. However, low salinity of the injected water may cause mobilisation, migration and straining of the natural reservoir fines resulting in high formation damage. The interval where salinity is low enough for the rock inlet not to be plugged by the injected proppant, and is high enough for large formation damage due to fine migration not to occur, is proposed for the cores under investigation. The analytical model is tuned from the laboratory data and used for well index prediction. Ignoring the model matching by the laboratory results causes the overestimation of the incremental productivity index, as achieved by the graded proppant injection into coal beds below the Fracturing Pressure.
Raymond L. Johnson - One of the best experts on this subject based on the ideXlab platform.
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Effect of Suspension Fluid Chemistry on Fracture System Stimulation Using Micro-Sized Proppant Placement
SPE Asia Pacific Unconventional Resources Conference and Exhibition, 2015Co-Authors: Alireza Keshavarz, Alexander Badalyan, Themis Carageorgos, Raymond L. Johnson, Pavel BedrikovetskyAbstract:The physical model and experimental data support the beneficial technology of graded proppant injection into naturally fractured reservoirs to stimulate natural fracture permeability. Injection of particles with increasing size, at poroelastic and hydraulic Fracturing conditions, yield deeper penetration and gradual filling of natural fractures with a resulting increase in permeability. This work expands on the concepts and outlines steps to maximize the benefit of graded proppant injection to enhance coal seam gas stimulation by focusing on the effect of the chemistry of injected fluid on the overall performance and the use in conjunction with hydraulic Fracturing. Low productivity indices can be observed in many moderate- to low-permeability coal bed methane (CSG) reservoirs due to low aperture and poor connectivity of natural cleats. Graded proppant injection in CSG environments can: stimulate a stress sensitive cleat system below the Fracturing Pressure as well as enhance a Fracturing treatment by invading cleats, lowering fluid leakoff, and maintaining aperture during production. Further, periodic or remedial treatments could to counter effective stress on the cleats improving production by maintaining cleat aperture. Laboratory tests on coal core flooding by water under increasing pore Pressure with proppant injection at the maximum Pressure have been carried out under different salinities of the injected water. Proppantproppant and proppant-coal Derjaguin-Landau-Verwey-Overbeek (DLVO) total interaction energies were calculated to optimise the condition for successful proppant placement. Results on the DLVO total energy of interaction showed that conditions favourable for successful proppant placement in coal cleats are suspension ionic strengths between 0.05 M and 0.1 M NaCl. At these conditions no proppant agglomeration and proppant-coal attachment are observed, allowing deeper penetration of proppant into the natural coal cleat system. Lower suspension ionic strengths can lead to natural coal fines migration, cleat plugging and coal permeability reduction. Based on the experimental results and previously developed model a case study has been conducted to evaluate the productivity enhancement using this technique. The results show about four-fold increase in well productivity index at injections below Fracturing Pressures and may further improve the stimulated reservoir volume when used in conjunction with low permeability coal hydraulic Fracturing treatments.
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Laboratory-based mathematical modelling of graded proppant injection in CBM reservoirs
International Journal of Coal Geology, 2014Co-Authors: Alireza Keshavarz, Alexander Badalyan, Raymond L. Johnson, Yulong Yang, Pavel BedrikovetskyAbstract:Abstract The graded proppant injection into a connected cleat system of coal bed methane (CBM) reservoir allows deeper particle penetration and straining in the remote open cleats yielding higher well productivity index. The analytical model for axisymmetric flow has been derived for exponential stress–permeability relationship and accounting for permeability variation outside the stimulated zone. Laboratory proppant injections into coal cores have been performed for different proppant sizes and water salinities. It is shown that the proppant suspension based on low salinity water prevents the particle–particle and particle–coal attraction with the consequent core inlet plugging and external cake formation. However, low salinity of the injected water may cause mobilisation, migration and straining of the natural reservoir fines resulting in high formation damage. The interval where salinity is low enough for the rock inlet not to be plugged by the injected proppant, and is high enough for large formation damage due to fine migration not to occur, is proposed for the cores under investigation. The analytical model is tuned from the laboratory data and used for well index prediction. Ignoring the model matching by the laboratory results causes the overestimation of the incremental productivity index, as achieved by the graded proppant injection into coal beds below the Fracturing Pressure.
