A Practical Guide to Modern Diversion Technology

Domelen, Mary Susan Van

doi:10.2118/185120-ms

Cited by 40 publications

(4 citation statements)

References 13 publications

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“…In the past years, the petroleum engineers have tried many methods in the multistage hydraulic fracturing treatment to promote simultaneous growth. The two most widely used technologies are the limited entry method (Lecampion & Desroches, 2015) and fluid diverting (Van Domelen, 2017). In the limited entry method, engineers will produce a high inlet pressure loss by controlling the effective inlet size, so as to offset the uneven fluid supplies to some extent.…”

Section: 1029/2019jb017942mentioning

confidence: 99%

Numerical Simulation of Simultaneous Hydraulic Fracture Growth Within a Rock Layer: Implications for Stimulation of Low‐Permeability Reservoirs

Chen

Zhao

et al. 2019

JGR Solid Earth

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Multistage multicluster hydraulic fracturing is currently the most effective method to stimulate low‐permeability hydrocarbon reservoirs. The desired result of this stimulation technique is highly uniform growth of multiple closely spaced hydraulic fractures. In order to deepen our understanding on the competitive growth of these fractures, we have investigated the growth behaviors of multiple hydraulic fractures under different conditions. A fully coupled model with a 3‐D influence coefficient is presented for fracture growth in a rock layer, based on a combination of boundary element method and finite volume method. It is validated against classic solutions and lab experiments. The parametric analyses of dimensionless arguments to quantify the uniformity of fracture growth are performed, with varying fracture geometries and geotechnical conditions including preexisting natural fractures. The results demonstrate that fracture competition is controlled by the dimensionless toughness, the initial fracture geometric settings, and the ratio of fracture spacing to height. A higher fluid viscosity, a smaller initial length offset, and a larger spacing benefit simultaneous fracture growth for conventional bi‐wing hydraulic fractures. By contrast, single wing ones exhibit a remarkably better performance in long‐time simultaneous fracture growth at a small separation, especially at low dimensionless toughness. Under certain conditions, the closely spaced single‐wing fractures are prone to grow simultaneously and uniformly in less energy consumption. The simultaneous growth is found to be insensitive to the interference from small‐scale natural fractures. The uniform single‐wing fracture growth from the perspective of geomechanics will provide a new insight for both reservoir stimulation and formation of vein and dike swarms.

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Section: 1029/2019jb017942mentioning

confidence: 99%

Numerical Simulation of Simultaneous Hydraulic Fracture Growth Within a Rock Layer: Implications for Stimulation of Low‐Permeability Reservoirs

Chen

Zhao

et al. 2019

JGR Solid Earth

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“…Considering the interstitial space between particles, the particle size distribution of TPA can be optimized using the "ideal packing theory" [4]. Since fractures are filled with proppants, the size of TPA should be based on the median particle size of the proppants [5]. Typical combinations of TPA have a bimodal distribution [6].…”

Section: Introductionmentioning

confidence: 99%

Experimental Study of Plugging Agent Particle Size and Concentration on Temporary Plugging Fracturing in Shale Formation

Yang,

Qian,

et al. 2024

Processes

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During the temporary plugging fracturing (TPF) process, the pressure response and pumping behavior significantly differ from those observed during conventional fracturing fluid pumping. Once the temporary plugging agent (TPA) forms a plug, subsequent fracture initiation and propagation become more intricate due to the influence of the TPA and early fractures. Factors such as concentration, particle size, and ratio of the TPA notably affect the effectiveness of TPF. This study employs a true triaxial hydraulic fracturing simulation system to conduct TPF experiments with varying particle size combinations and concentrations at both in-fracture and in-stage locations. The impact of different TPA parameters on the plugging effectiveness is assessed by analyzing the morphology of the induced fractures and the characteristics of pressure curves post experiment. Results indicate that combining dfferent particle sizes enhances plugging effectiveness, with a combination of smaller and larger particles exhibiting superior plugging effectiveness, resulting in a pressure increase of over 25.9%. As the concentration of the TPA increases, the plugging fracture pressure rises, accompanied by rapid pressure response and significant plugging effects, leading to more complex fracture morphology. For shale reservoirs, the density of bedding planes (BPs) influences the morphology and width of conventional hydraulic fractures, thereby affecting the effectiveness of subsequent refracturing. Rock samples with a relatively low BP density demonstrate effective plugging initiation both in-fracture and in-stage, facilitating the formation of complex fracture networks. Conversely, specimens with a relatively high BP density exhibit superior plugging effectiveness in-stage compared to in-fracture plugging.

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“…The effectiveness of fluid displacement was evaluated and proven by fiber-optic distributed temperature sensors (DTS). Since then, temporary plugging fracturing has attracted research interests and has been deployed to almost all unconventional resource basins. − …”

Section: Introductionmentioning

confidence: 99%

“…Gomma et al and McCartney and Kennedy both presented the optimized particle size distribution and concentrations of the diverter system for bridging and reducing permeability of various fracture widths. Van Domelen summarized the recommended diverter particle sizes for various proppant sizes and discussed the guidelines for choosing the amount of diverter material required for operations in the Williston Basin. Although most of the experiments conducted are specifically for some certain types of rock samples, all of the above laboratory studies could provide a general guidance for conducting numerical simulations.…”

Section: Introductionmentioning

confidence: 99%

Modeling Temporary Plugging Agent Transport in the Wellbore and Fracture with a Coupled Computational Fluid Dynamics–Discrete Element Method Approach

et al. 2021

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As the consumption of oil and gas resources is increasing, secondary exploitation in old wells and unconventional oil and gas exploitation methods are becoming increasingly important. As a result of complex reservoir environments and the reservoir properties, such as ultralow porosity and permeability, hydraulic fracturing is an important means to achieve effective recovery. Temporary plugging fracturing is currently an efficient fracturing technology and is suitable for refracturing of old wells and multi-stage fracturing in unconventional reservoirs, which is conducive to constructing complex fracture networks and increasing production. Recently, in the field of temporary plugging fracturing, how to design the operation parameters of temporary plugging fracturing still remains ambiguous and empirical. In this paper, a numerical simulation study of the liquid–solid two-phase flow of the temporary plugging agents and the fracturing fluid was conducted using two physical models: a wellbore flow model and a wellbore–fracture temporary plugging model. The transport processes of the temporary plugging agents along with fracturing fluid in a vertical wellbore, in a horizontal wellbore, and at a fracture position were simulated. Simulations that coupled computational fluid dynamics and the discrete element method were used in the simulation process. The effects of the temporary plugging agent concentration, particle size, particle size ratio, fracturing fluid rate, and fracturing fluid viscosity on the migration process of the temporary plugging agent were investigated. The simulation results show that a higher concentration and viscosity of a temporary plugging agent help to sustain the flow stability in the vertical wellbore, while the viscosity and flow rate of the fracturing fluid have an impact on whether sedimentation of the temporary plugging agent occurred in the horizontal wellbore. In addition, the particle size ratio and concentration of the temporary plugging agent are the key factors for a successful bridging and plugging. For a specific field application in Longmaxi Formation, Sichuan Province, the operation parameters of temporary plugging fracturing have been designed and achieved a successful refracturing treatment.

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A Practical Guide to Modern Diversion Technology

Cited by 40 publications

References 13 publications

Numerical Simulation of Simultaneous Hydraulic Fracture Growth Within a Rock Layer: Implications for Stimulation of Low‐Permeability Reservoirs

Numerical Simulation of Simultaneous Hydraulic Fracture Growth Within a Rock Layer: Implications for Stimulation of Low‐Permeability Reservoirs

Experimental Study of Plugging Agent Particle Size and Concentration on Temporary Plugging Fracturing in Shale Formation

Modeling Temporary Plugging Agent Transport in the Wellbore and Fracture with a Coupled Computational Fluid Dynamics–Discrete Element Method Approach

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