Experimental investigation of the effect of natural fracture size on hydraulic fracture propagation in 3D

Wan, Lihua; Chen, Mian; Hou, Bing; Kao, Jiawei; Zhang, Kunpeng; Fu, Weineng

doi:10.1016/j.jsg.2018.08.006

Cited by 34 publications

(7 citation statements)

References 15 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Salt structures within continental basins frequently form as a result of plate and intraplate tectonic deformation, often in the vicinity of prominent basement faults due to extension or shortening (Callot et al, 2012;Coleman et al, 2017;Krzywiec et al, 2019;Pichel et al, 2019;Scheck-Wenderoth et al, 2008;Vejbaek, 1997;Warren, 2008;Warsitzka et al, 2018). In the presence of a salt layer that effectively decouples the overburden from the underlying basement faulting, thin-skinned deformation can alternatively initiate the development of salt structures.…”

Section: Introductionmentioning

confidence: 99%

Structural Evolution at the Northeast North German Basin Margin: From Initial Triassic Salt Movement to Late Cretaceous‐Cenozoic Remobilization

et al. 2020

View full text Add to dashboard Cite

In this study, we investigate the regional tectonic impact on salt movement at the northeastern margin of the intracontinental North German Basin. We discuss the evolution of salt pillows in the Bay of Mecklenburg in the light of thick‐ and thin‐skinned tectonics, including gravity gliding, and differential loading using seismic imaging. Stratigraphic and structural interpretation of a 170 km long, multichannel seismic line, extending from the Bay of Mecklenburg to northeast of Rügen Island, incorporates well information of nearby onshore wells. This new high‐resolution seismic line completely images the stratigraphic and tectonic pattern of the subsurface, from the base of the Zechstein to the seafloor. Our analysis reveals that subsidence during Late Triassic to Early Cretaceous at the northeastern basin margin was associated with transtensional dextral strike slip movement within the Trans‐European Suture Zone. We reinterpret the Werre and Prerow Fault Zones west of Rügen Island as an inverted, thin‐skinned normal fault system associated with the formation of the Western Pomeranian Fault System. Salt movement in the Bay of Mecklenburg was initiated in the Late Triassic and lasted until the Early Jurassic. A second phase of salt pillow growth occurred during the Coniacian until Cenozoic and correlates with compression‐related regional basin inversion due to the onset of the Africa‐Iberia‐Europe convergence. Thin‐skinned extensional initialization of salt pillow growth and compressional salt remobilization explains salt pillow evolution in the Bay of Mecklenburg. Additionally, we discuss an impact of gravity gliding on salt pillow evolution induced by basin margin tilt.

show abstract

Section: Introductionmentioning

confidence: 99%

Structural Evolution at the Northeast North German Basin Margin: From Initial Triassic Salt Movement to Late Cretaceous‐Cenozoic Remobilization

et al. 2020

View full text Add to dashboard Cite

show abstract

“…By studying the relationship between different-sized natural fractures and 3D hydraulic fractures (Figure 5), they classified the modes of fracture propagation as arresting, bypassing, diversion, vertical extension, vertical extension, and then diversion. 98 Open fractures are generally more prone to hydraulic pressure expansion, while closed cemented fractures may present greater challenges. Researchers have also classified natural fractures into active and nonactive categories.…”

Section: Water Saturation Ofmentioning

confidence: 99%

“…3D fracture intersection criteria: (a) arresting, (b) bypassing, (c) diversion, (d) vertical extension, and (e) vertical extension and then diversion. Reprinted with permission from ref . Copyright 2018 Elsevier B.V.…”

Section: The Influence Of Geological Factors On Fracture Propagationmentioning

confidence: 99%

Main Control Factors of Fracture Propagation in Reservoir: A Review

Liu,

Han,

Yang

et al. 2023

ACS Omega

View full text Add to dashboard Cite

The fracture distribution and internal control factors after the fracturing of unconventional oil and gas reservoirs determine the reservoir reforming effect to a large extent. Based on the research of global scholars on the influencing factors of fracture propagation, comprehensive theoretical model, and numerical simulation, this Review systematically discusses the influence of internal geological factors and external engineering factors of unconventional oil and gas reservoir on fracture propagation behavior and summarizes the current problems and development trends in fracture research. The results show the following: (1) The fracture propagation is a comprehensive process constrained by lithology and mineral composition, water saturation, nonhomogeneity, natural weak surface, and ground stress. (2) External engineering factors have a meaningful control effect on fracture propagation; the type and temperature of fracturing fluids can also change the mechanical properties of different rocks, thus affecting the fracture propagation pattern. (3) The existing fracture propagation models have certain limitations, and their computational reliability still needs to be further verified. (4) Numerical simulation can break through the limitations of physical simulation, but different simulation methods have different shortcomings and applicability. In the future, we should focus on: (1) finding parameters to quantitatively characterize heterogeneity at the 3D level, which is an important direction to study the effect of heterogeneity on fracture propagation; (2) introducing computerized methods to establish a geological model that considers multiple factors and combining it with numerical simulation software to study fracture propagation; (3) considering the characteristics of fluid–liquid–solid phase comprehensively, establishing a suitable THL coupling equation; (4) how the interaction mode of fracturing fracture is combined with the natural fracture geometry, and how the fracture is affected by fracturing engineering parameters such as fluid injection rate and viscosity of fracturing fluid; and (5) geology-engineering dynamic integration, which is an important direction to be carried out in the future.

show abstract

“…When the orientation angle of natural fractures remains the same, the density and length of the natural fractures are positively correlated with the complexity of the fracture network . The length of the natural fracture affects the behavior of the hydraulic fracture meeting or bypassing it. , Some studies have reported the quantitative length of natural fractures; for example, when the natural fracture length is less than 10 m, the hydraulic fracture will bypass the natural fracture; otherwise, when the natural fracture length is greater than 20 m, the natural fracture will prevent the propagation of hydraulic fractures …”

Section: Introductionmentioning

confidence: 99%

Numerical Analysis for Dynamic Propagation and Intersection of Hydraulic Fractures and Pre-existing Natural Fractures Involving the Sensitivity Factors: Orientation, Spacing, Length, and Persistence

et al. 2021

View full text Add to dashboard Cite

Pre-existing natural fractures in a fractured reservoir will intersect with the hydraulic fractures and propagate dynamically during the hydrofracturing process, which has a significant impact on the morphology of the fracture network and subsequent gas production. If the representative properties of the natural fractures cannot be accurately extracted and appropriate numerical models are not established to describe the propagation and intersection behaviors of the fractures, it is difficult to determine the fracturing scheme for naturally fractured reservoirs and to obtain the expected fracture network and gas production. In this study, the combined finite element-discrete element method and discrete fracture network model were used to simulate the hydrofracturing process of naturally fractured reservoirs by controlling different sensitivity factors (orientation, spacing, length, and persistence) of natural fractures. To investigate the sensitivity factors, typical numerical cases were carefully designed and established, and the results of the dynamic propagation and intersection of hydraulic fractures and pre-existing natural fractures were derived. Two typical types of fracture network morphologies are detected when hydraulic fractures intersect the natural fractures: center-type (intersection of hydraulic fractures and the crossed cluster of the natural fractures) and edge-type (intersection of hydraulic fractures and the edge of the natural fractures). The quantitative results of the length and volume of the fracture networks and gas production in enhanced permeability fractured reservoirs were analyzed. The mechanisms by which the sensitivities of natural fractures affect and control the optimal fracturing behaviors are well understood; the conditions of small fracture spacing, large fracture length, or small fracture persistence of natural fractures are conducive for hydraulic fractures to intersect with the natural fractures and form a complex center-type fracture network and improve gas production.

show abstract

Experimental investigation of the effect of natural fracture size on hydraulic fracture propagation in 3D

Cited by 34 publications

References 15 publications

Structural Evolution at the Northeast North German Basin Margin: From Initial Triassic Salt Movement to Late Cretaceous‐Cenozoic Remobilization

Structural Evolution at the Northeast North German Basin Margin: From Initial Triassic Salt Movement to Late Cretaceous‐Cenozoic Remobilization

Main Control Factors of Fracture Propagation in Reservoir: A Review

Numerical Analysis for Dynamic Propagation and Intersection of Hydraulic Fractures and Pre-existing Natural Fractures Involving the Sensitivity Factors: Orientation, Spacing, Length, and Persistence

Contact Info

Product

Resources

About