Fracture characteristics in Cretaceous platform and overlying ramp carbonates: An outcrop study from Maiella Mountain (central Italy)

Rustichelli, Andrea; Torrieri, Stefano; Tondi, Emanuele; Laurita, Salvatore; Strauss, Christoph; Agosta, Fabrizio; Balsamo, Fabrizio

doi:10.1016/j.marpetgeo.2016.05.020

Cited by 36 publications

(11 citation statements)

References 41 publications

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“…A large-scale survey was carried out by means of the digital line-drawing of bedding surfaces and fractures, enabling the definition of the outcrops fracture stratigraphy, defined as the subdivision of the analysed outcrop based upon the observed fracture attributes variations [29]. Data gathering was focussed on the so-called throughgoing fractures which can reach tens of meters of height, playing a crucial role in fluid flow processes in a fractured carbonate reservoir, by linking together different fracture systems, otherwise isolated to each other and guaranteeing the vertical linkage of the network [79,80]. In this contest, primary heterogeneities provided by bed interfaces can, potentially, act as mechanical boundaries, inhibiting the vertical propagation and forming mechanical units at different scales [81].…”

Section: Large-scale Analysismentioning

confidence: 99%

Discrete Fracture Network Modelling in Triassic–Jurassic Carbonates of NW Lurestan, Zagros Fold-and-Thrust Belt, Iran

et al. 2019

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In this study, discrete fracture network (DFN) modelling was performed for Triassic–Jurassic analogue reservoir units of the NW Lurestan region, Iran. The modelling was elaborated following a multi-scale statistical sampling of the fracture systems characterising the analysed succession. The multi-scale approach was performed at two different observation scales. At the macro-scale, a digital outcrop analysis was carried out by means of a digital line-drawing based on camera-acquired images, focussing on the distribution of major throughgoing fractures; at the meso-scale, the scan line method was applied to investigate the background fractures of the examined formations. The gathered data were statistically analysed in order to estimate the laws governing the statistical distribution of some key fracture set attributes, namely, spacing, aperture, and height. The collected dataset was used for the DFN modelling, allowing the evaluation of the relative connectivity of the fracture systems and, therefore, defining the architecture and the geometries within the fracture network. The performed fracture modelling, confirmed, once again, the crucial impact that large-scale throughgoing fractures have on the decompartmentalization of a reservoir and on the related fluid flow migration processes. The derived petrophysical properties distribution showed in the models, defined the Kurra Chine Fm. and, especially, the Sehkaniyan Fm. as good-quality reservoir units, whereas the Sarki Fm was considered a poor-quality reservoir unit.

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Section: Large-scale Analysismentioning

confidence: 99%

Discrete Fracture Network Modelling in Triassic–Jurassic Carbonates of NW Lurestan, Zagros Fold-and-Thrust Belt, Iran

et al. 2019

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“…10 µm (Zambrano et al, 2018). These rocks experienced a maximum burial depth between 0.5 and 3 km (Ori et al, 1986;Graham et al, 2003;Rustichelli et al, 2016).…”

Section: Samplesmentioning

confidence: 99%

Implementation of Dynamic Neutron Radiography and Integrated X-Ray and Neutron Tomography in Porous Carbonate Reservoir Rocks

et al. 2019

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The textural and geometrical properties of the pore networks (i.e., such as pore size distribution, pore shape, connectivity, and tortuosity) provides a primary control on the fluid storage and migration of geofluids within porous carbonate reservoirs. These properties are highly variable because of primary depositional conditions, diagenetic processes and deformation. This issue represents an important challenge for the characterization and exploitation plan in this type of reservoirs. In this study, the complementary properties of neutrons and X-ray experiments are carried out to better understand the effects of pore network properties on the hydraulic behavior of porous carbonates. Neutrons have unique properties and are particularly suitable for this study due to the sensitivity of neutrons to hydrogen-based fluids. The used methodology combines dynamic neutron radiography (NR), integrated X-ray and neutron tomography (XCT, NCT), and computational fluid dynamics simulations (lattice-Boltzmann method) of porous carbonate reservoir analogs from central and southern Italy. Dynamic 2D NR images provide information regarding the fluid transport and the wetting front dynamics related to the effect of heterogeneities (e.g., fractures and deformation bands) at the microscale. The combination of NCT (dry and wet samples) and XCT (dry), generates more information regarding the effective pore space contribution to fluid flow. The fluid flow simulations generate information about the connected pore network and the permeability evaluated rock sample at saturated condition.

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“…Fault zone architecture, evolution and fracture patterns in carbonates have recently received significant attention (e.g. Billi et al, 2003;Micarelli et al, 2006;Ferrill and Morris 2008;Bastesen and Braathen 2010;Molli et al, 2010;Ferrill et al, 2011;Michie et al, 2014;Agosta et al, 2015;Bussolotto et al, 2015;Fondriest et al, 2015;Rustichelli et al, 2016). Also, research has recently been conducted on the deformation mechanisms and microstructures of carbonate fault rocks (Bastesen et al, 2009;Rath et al, 2011;Michie 2015;Schröckenfuchs et al, 2015;Cooke et al, 2018;Ferraro et al, 2018;Kaminskaite et al, 2019).…”

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confidence: 99%

“…However, there is surprisingly little data on the porosity and permeability of carbonate fault rocks (e.g. Agosta et al, 2007;Bastesen et al, 2009;Haines et al, 2016;Michie and Haines 2016;Tondi et al, 2016;Cooke et al, 2020;Kaminskaite et al, 2020). By the time of this publication, authors were aware of only one publicly available documented study where petrophysical data has been used in a predictive sense for calculation of carbonate fault rock permeability and transmissibility multipliers in a cellular model (Michie et al, 2018).…”

mentioning

confidence: 99%

“…The mechanisms vary according to host texture and composition as well as the stress conditions at the time of faulting (Kaminskaite et al, 2019). Despite the variation in mechanisms, deformation bands generally show a decrease in porosity and permeability from the host, varying as a function of evolution (Rath et al, 2011;Antonellini et al, 2014;Tondi et al, 2016;Kaminskaite et al, 2019). Deformation mechanisms and microstructures of fault rocks in highly porous carbonates, with throws larger than deformation bands, are less well documented (e.g.…”

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confidence: 99%

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Key controls on the hydraulic properties of fault rocks in carbonates

Michie

Cooke

Kaminskaite

et al. 2020

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A significant knowledge gap exists when analysing and predicting the hydraulic behaviour of faults within carbonate reservoirs. To improve this, a large database of carbonate fault rock properties has been collected from 42 exposed faults, from 7 countries. Faults analysed cut a range of lithofacies, tectonic histories, burial depths and displacements. Porosity and permeability measurements from c.400 samples have been made, with the goal of identifying key controls on the flow properties of fault rocks in carbonates. Intrinsic and extrinsic factors have been examined, such as host lithofacies, juxtaposition, host porosity and permeability, tectonic regime, displacement, maximum burial depth as well as the depth at the time of faulting. The results indicate which factors may have the most significant influence on fault rock permeability, improving our ability to predict the sealing or baffle behaviour of faults in carbonate reservoirs. Intrinsic factors, such as host porosity, permeability and texture, appear to play the most important role in fault rock development. Extrinsic factors, such as displacement and kinematics, have shown lesser or, in some instances, a negligible control on fault rock development. This conclusion is, however, subject to two research limitations: lack of sufficient data from similar lithofacies at different displacements, and a low number of samples from thrust regimes.Thematic collection: This article is part of the Fault and top seals collection available at: https://www.lyellcollection.org/cc/fault-and-top-seals-2019

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Fracture characteristics in Cretaceous platform and overlying ramp carbonates: An outcrop study from Maiella Mountain (central Italy)

Cited by 36 publications

References 41 publications

Discrete Fracture Network Modelling in Triassic–Jurassic Carbonates of NW Lurestan, Zagros Fold-and-Thrust Belt, Iran

Discrete Fracture Network Modelling in Triassic–Jurassic Carbonates of NW Lurestan, Zagros Fold-and-Thrust Belt, Iran

Implementation of Dynamic Neutron Radiography and Integrated X-Ray and Neutron Tomography in Porous Carbonate Reservoir Rocks

Key controls on the hydraulic properties of fault rocks in carbonates

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