Using synchrotron X-ray microtomography to characterize the pore network of reservoir rocks: A case study on carbonates

Arzilli, Fabio; Cilona, Antonino; Mancini, Lucia; Tondi, Emanuele

doi:10.1016/j.advwatres.2015.07.016

Cited by 35 publications

(20 citation statements)

References 48 publications

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“…556 In agreement with Arzilli et al (2015), studying similar grainstones of the Bolognano Fm., it is 557 assumed that the contribution of the micropores to the permeability may be negligible if compared to 558 the one of macropores. Nevertheless, the shape of imaged pores may be pixelated due to the resolution 559 of the images affecting the measured properties (i.e.…”

supporting

confidence: 53%

Fluid flow simulation and permeability computation in deformed porous carbonate grainstones

Zambrano

Tondi

Mancini

et al. 2018

Advances in Water Resources

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supporting

confidence: 53%

Fluid flow simulation and permeability computation in deformed porous carbonate grainstones

Zambrano

Tondi

Mancini

et al. 2018

Advances in Water Resources

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“…The selected rock samples were scanned at the SYRMEP (SYnchrotron Radiation for MEdical Physics) beamline of Elettra Synchrotron (Trieste, Italy), following the methodology (including image processing and quantitative analysis) described by previous authors [73][74][75], which is suitable for many types of rocks (e.g., [76][77][78][79][80]). At the SYRMEP beamline, a bending magnetic source is located 23 m from the source, allowing a nearly parallel geometry and a high spatial coherence of the X-ray beam [81,82], which takes full advantage of phase-contrast effects [83].…”

Section: X-ray Micro-ct 3d Image Analysismentioning

confidence: 99%

“…However, the permeability should be also controlled by the connectivity, which may vary in function of the cementation degree. The quantitative analysis consists of measuring the following parameters (sensu [73][74][75]):…”

Section: X-ray Micro-ct 3d Image Analysismentioning

confidence: 99%

Petrophysical Properties and Microstructural Analysis of Faulted Heterolithic Packages: A Case Study from Miocene Turbidite Successions, Italy

et al. 2019

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Geofluid reservoirs located in heterolithic successions (e.g., turbidites) can be affected by vertical and lateral compartmentalization due to interbedded fine-grained facies (i.e., shale, siltstones) and the presence of faults, respectively. A fault can behave as a conduit or barrier to fluid flow depending on its architecture and the individual hydraulic behavior of its components (i.e., fault core, damage zone). The fault core, normally composed by fault rock or smeared clay material, commonly acts as a flow inhibitor across the fault. Fault-related fractures (macro- and microscopic) in the damage zone generally increase the permeability parallel to the fault, except when they are cemented or filled with gouge material. Although macrofractures (which define the fracture porosity) dominate fluid flow, the matrix porosity (including microfractures) begins to have a more important role in fluid flow as the aperture of macrofractures is occluded, particularly at greater depth. This study investigates the variation in matrix permeability in fault zones hosted in heterolithic successions due to fault architecture and stratigraphy of host rock (i.e., sand-rich turbidites). Two key areas of well-exposed, faulted Miocene turbidites located in central and southern Italy were selected. For this study, six separate fault zones of varying offset were chosen. Each impacts heterolithic successions that formed under similar tectonic conditions and burial depths. Across the selected fault zones, an extensive petrophysical analysis was done in the field and laboratory, through air permeameter measurements, thin section, and synchrotron analysis in both host rock, damage zone, and fault core. Results suggest that the amount and distribution of clay layers in a heterolithic sequence affects fluid flow across the fault, regardless of fault offset.

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“…In general, the microscale assessment of rocks is based on two-dimensional (2D) microscopy techniques (e.g., Tondi et al, 2006;Tondi, 2007), however three-dimensional (3D) approaches such as X-ray and neutron tomography (XCT and NCT, respectively) are becoming more popular for evaluation in the oil industry due to their non-destructive nature. Recent investigations of carbonate rocks have focused on evaluating the internal architecture and their impact on fluid flow in porous samples at the microscale by the integration of X-ray microtomography image analysis (Blunt et al, 2013;Cilona et al, 2014;Ji et al, 2015;Arzilli et al, 2016;Baud et al, 2017;Voltolini et al, 2017;Zambrano et al, 2017;Kaminskaite et al, 2019;Riegel et al, 2019) and computational fluid dynamics (Zambrano et al, 2018).…”

Section: Introductionmentioning

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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Using synchrotron X-ray microtomography to characterize the pore network of reservoir rocks: A case study on carbonates

Cited by 35 publications

References 48 publications

Fluid flow simulation and permeability computation in deformed porous carbonate grainstones

Fluid flow simulation and permeability computation in deformed porous carbonate grainstones

Petrophysical Properties and Microstructural Analysis of Faulted Heterolithic Packages: A Case Study from Miocene Turbidite Successions, Italy

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

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