Reservoir heterogeneity and fracture parameter determination using electrical image logs and petrophysical data (a case study, carbonate Asmari Formation, Zagros Basin, SW Iran)

Aghli, Ghasem; Moussavi‐Harami, Reza; Mohammadian, Ruhangiz

doi:10.1007/s12182-019-00413-0

Cited by 62 publications

(23 citation statements)

References 30 publications

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“…When combined with tracer tests, such tools can be used for time‐lapse monitoring of electrically conductive tracers penetrating fractures and interrogating fracture mechanical opening (see Aghli et al. [2020] for case study). Finally, since the 2000s (Murdoch et al., 2003), hydro‐mechanical well testing has been refined, using probes that allow the local downhole direct measurement of fractures opening and shear displacement while pressurizing it between two sealing inflatable packers (Guglielmi et al., 2014; Schweisinger et al., 2009).…”

Section: Field Observations and Experimentsmentioning

confidence: 99%

From Fluid Flow to Coupled Processes in Fractured Rock: Recent Advances and New Frontiers

Viswanathan

Ajo‐Franklin

Birkhölzer

et al. 2022

Reviews of Geophysics

113

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Quantitative predictions of natural and induced phenomena in fractured rock is one of the great challenges in the Earth and Energy Sciences with far‐reaching economic and environmental impacts. Fractures occupy a very small volume of a subsurface formation but often dominate fluid flow, solute transport and mechanical deformation behavior. They play a central role in CO2 sequestration, nuclear waste disposal, hydrogen storage, geothermal energy production, nuclear nonproliferation, and hydrocarbon extraction. These applications require predictions of fracture‐dependent quantities of interest such as CO2 leakage rate, hydrocarbon production, radionuclide plume migration, and seismicity; to be useful, these predictions must account for uncertainty inherent in subsurface systems. Here, we review recent advances in fractured rock research covering field‐ and laboratory‐scale experimentation, numerical simulations, and uncertainty quantification. We discuss how these have greatly improved the fundamental understanding of fractures and one's ability to predict flow and transport in fractured systems. Dedicated field sites provide quantitative measurements of fracture flow that can be used to identify dominant coupled processes and to validate models. Laboratory‐scale experiments fill critical knowledge gaps by providing direct observations and measurements of fracture geometry and flow under controlled conditions that cannot be obtained in the field. Physics‐based simulation of flow and transport provide a bridge in understanding between controlled simple laboratory experiments and the massively complex field‐scale fracture systems. Finally, we review the use of machine learning‐based emulators to rapidly investigate different fracture property scenarios and accelerate physics‐based models by orders of magnitude to enable uncertainty quantification and near real‐time analysis.

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Section: Field Observations and Experimentsmentioning

confidence: 99%

From Fluid Flow to Coupled Processes in Fractured Rock: Recent Advances and New Frontiers

Viswanathan

Ajo‐Franklin

Birkhölzer

et al. 2022

Reviews of Geophysics

113

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“…Previous studies have tended to categorize bedding fractures as a part of structural fractures or diagenetic fractures [5][6][7][8]. Regarding the origin of bedding fractures, assumptions include tectonic origin [9][10][11], hydrocarbon generation-acid expulsion-dissolution [10,12], pressure fracturing of authigenic fluids inside reservoirs [13,14], and tectonic plus hydrocarbon generation-acid expulsion [15,16].…”

Section: Introductionmentioning

confidence: 99%

“…For the commercial development of tight oil, the enrichment and development of fractures is of fatal significance. The fractures in reservoirs, as both important oil and gas storage spaces and seepage channels, are an important determinant for the mobility of oil and gas [6,7,11]. The presence of natural fractures is conducive to oil and gas accumulation [1-3, 7, 8] and to the formation of sweet spots in tight oil reservoirs.…”

Section: Introductionmentioning

confidence: 99%

Research on the Oil-Bearing Difference of Bedding Fractures: A Case Study of Lucaogou Formation in Jimsar Sag

Zhang

Zeng

et al. 2021

Geofluids

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Lucaogou formation in Jimsar sag is host to large quantities of bedding fractures which are known to play a critical role in the enrichment, accumulation, and efficient development of tight oil. In this paper, we examine and finely characterize the development of the bedding fractures found in the upper and lower sweet spots of Lucaogou formation of tight oil reservoir through field outcrop and core observation, cast thin section analysis, and imaging log recognition and investigate the factors affecting their differentiated oil-bearing by means of inclusion temperature measurement, TOC testing, physical property testing, high-pressure mercury injection, and physical simulation experiment. By comparison with the linear density, bedding fractures are more developed in the lower sweet spot. These fractures occur in parallel to the formation boundary and have small aperture. Most of bedding fractures are unfilled fractures. Among the few types of fractures found there, bedding fractures have the best oil-bearing property, but the oil-bearing can differ from one bedding fracture to another. The factors affecting the differentiated oil-bearing of bedding fractures include the temporal coupling of the formation of these fractures with the hydrocarbon generation of the source rocks and the spatial coupling of the bedding fractures with the source rocks. In terms of temporal coupling, mass hydrocarbon generation in Jimsar sag began in Late Jurassic. Inclusion temperature measurement indicates that the bedding fractures there formed in or after Early Cretaceous. Hence, by matching the mass hydrocarbon generation period of the source rocks with the formation period of the bedding fractures, we discovered that the bedding fractures formed within the mass hydrocarbon generation period, which favored the oil-bearing of these fractures. The spatial coupling is manifested in TOC, porosity, permeability, and pore throat, with TOC being the main controlling factor. For TOC, the higher the formation TOC, the better the oil-bearing property of the bedding fractures. For porosity, subject to the TOC level, if the TOC is adequate, the larger the porosity, the larger the chloroform asphalt “A,” accordingly the higher the oil content of the formation, and the better the oil-bearing property of the bedding fractures developed therein. In this sense, in terms of spatial coupling, TOC constitutes the main controlling factor of the oil-bearing property of bedding fractures.

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“…Tectonic fractures are important reservoir spaces and seepage channels. − In reservoirs with tectonic fractures, reservoir permeability can often increase by 1–3 orders of magnitude. Therefore, tectonic fractures correspond to more favorable petrophysical properties of carbonate reservoirs and a higher oil and gas production capacity and have great practical significance for oil and gas field exploration and development. , …”

Section: Introductionmentioning

confidence: 99%

“…Therefore, tectonic fractures correspond to more favorable petrophysical properties of carbonate reservoirs and a higher oil and gas production capacity and have great practical significance for oil and gas field exploration and development. 8,9 Tectonic stress is the cause of the formation of tectonic fractures in carbonate reservoirs, which controls the interaction, extension direction, geometry, and mechanical properties of the fractures. For areas that have experienced strong tectonic stress, tectonic fractures are widely distributed with strong regularity.…”

Section: Introductionmentioning

confidence: 99%

Tectonic Fracture Formation and Distribution in Ultradeep Marine Carbonate Gas Reservoirs: A Case Study of the Maokou Formation in the Jiulongshan Gas Field, Sichuan Basin, Southwest China

Qin

Zhang

et al. 2020

Energy Fuels

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Tectonic fractures are the key factors affecting hydrocarbon migration and accumulation in ultradeep marine carbonate gas reservoirs. Taking the Maokou Formation in the Jiulongshan Gas Field as an example, tectonic fracture formation and distribution are quantitatively characterized by the outcrops, cores, Fullbore Formation MicroImager (FMI) imaging logging, acoustic emission experiments, fluid inclusion experiments, and burial–thermal evolution history analysis. The formation stage of the tectonic fractures in the study area can generally be divided into three stages: the Indosinian stage, the early middle Yanshanian stage, and the late Yanshanian–Himalayan stage. The key stages are the early middle Yanshanian stage and the late Yanshanian–Himalayan stage. According to the theory of tectonic geomechanics, the evolution pattern of different stages of tectonic fractures and faults in the Maokou Formation is established. The finite element method was used to simulate the three-dimensional paleotectonic stress field during the key stages of fracture formation, and a rock failure criterion (η) was used to quantitatively predict the development and distribution of the tectonic fracture. In the early middle Yanshanian stage, the fracture degree was relatively small, and the highly fractured areas were mainly concentrated in the areas near the northern fault zone and the high part of the anticline, with the highest rock failure proximity of 1.118. In the late Yanshanian–early Himalayan stage, the highly fractured areas are distributed in the northeast and northwest, near the E–W fault rupture zone, the high parts of the Jiulongshan and Tadongping areas, and the local tectonic high parts. The degree of rock failure mainly concentrated between 0.890 and 1.127. There is a good positive correlation between the fracture density and the degree of rock failure.

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Reservoir heterogeneity and fracture parameter determination using electrical image logs and petrophysical data (a case study, carbonate Asmari Formation, Zagros Basin, SW Iran)

Cited by 62 publications

References 30 publications

From Fluid Flow to Coupled Processes in Fractured Rock: Recent Advances and New Frontiers

From Fluid Flow to Coupled Processes in Fractured Rock: Recent Advances and New Frontiers

Research on the Oil-Bearing Difference of Bedding Fractures: A Case Study of Lucaogou Formation in Jimsar Sag

Tectonic Fracture Formation and Distribution in Ultradeep Marine Carbonate Gas Reservoirs: A Case Study of the Maokou Formation in the Jiulongshan Gas Field, Sichuan Basin, Southwest China

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