Characterization of carbonate mudrocks of the Jurassic Tuwaiq Mountain Formation, Jafurah basin, Saudi Arabia: Implications for unconventional reservoir potential evaluation

Khalid, Asaad; Al-Mubarak, Ahmed H.; Al‐Ramadan, Khalid; Kurison, Clay; Leyva, Ivan

doi:10.1016/j.jngse.2016.04.009

Cited by 55 publications

(48 citation statements)

References 14 publications

(16 reference statements)

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“…The details of the geographic location, geology, and geochemistry can be reviewed in prior literature. [24] The four samples were selected from the same well covering a depth range of less than 250 ft.…”

Section: Methods Samplesmentioning

confidence: 99%

Multi-physics evaluation of carbonate-rich source rocks from high-resolution images

2021

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In unconventional reservoirs, the pore space is hosted by a heterogeneous matrix with various minerals and organic components. This heterogeneity complicates petrophysical interpretation during hydrocarbon exploration. A digital rock physics study of thermal and electrical conductivity was conducted using high-resolution focused ion beam scanning electron microscopy images of carbonate-rich source rocks. Finite-volume simulation results are discussed in context of the sample heterogeneity and anisotropy and supported by comparisons to empirical equations and effective medium theory. The results show how the presence of organic matter, pyrite, and pore constrictions impacts application of empirical equations and simplified models to unconventional reservoirs. Graphic abstract

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Section: Methods Samplesmentioning

confidence: 99%

Multi-physics evaluation of carbonate-rich source rocks from high-resolution images

2021

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“…Reservoirs. Because tight oil reservoirs were characterized by source generation and source accumulation in situ and it had short-term migration, the heterogeneity of the pore distribution was relatively strong [5,8,16]. e results of the permeability test using different gases were significantly different [17].…”

Section: Development Characteristics and Evaluation Difficulties Of Tmentioning

confidence: 99%

“…for Tight Oil Reservoirs. Four parameters were selected to characterize the longitudinal changes of reservoirs: (1) Average throat radius, whose distribution presents the change of reservoir seepage capacity [16]; (2) Percentage of movable uid, whose distribution explains the change of occurrence characteristics of the reservoir uid and determines the development potential of the reservoirs [21][22][23]. e movable uid of the tight reservoir corresponds to the amount of uid measured by nuclear magnetic resonance at a centrifugal force of 417 psi; (3) e start-up pressure gradient, whose distribution characterizes the di culty degree in establishing an e ective displacement system for the reservoir [24,25]; and (4) e content of clay mineral, whose distribution shows the reservoir damage su ered from water injection [26][27][28].…”

Section: Longitudinal Multiparameter Comprehensive Evaluationmentioning

confidence: 99%

Longitudinal Reservoir Evaluation Technique for Tight Oil Reservoirs

Luo

Yang

Tang

et al. 2019

Advances in Materials Science and Engineering

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Reservoir evaluation is a method for classifying reservoirs and the description of heterogeneity quantitatively. In this study, according to the characteristics of longitudinal physical properties of tight oil reservoirs, advanced experimental techniques such as nuclear magnetic resonance, high pressure mercury intrusion, and X-ray diffraction were adopted; the flow capacity, reservoir capacity, ability to build an effective displacement system, and the ability to resist damage in reservoir reconstruction were considered as evaluation indexes; average throat radius, percentage of movable fluid, start-up pressure gradient, and the content of clay minerals were taken as the evaluation parameters. On the above basis, a longitudinal evaluation technique for tight oil reservoirs was established. The reservoir was divided into four categories by using this method. The reservoirs with a depth 2306.54 m–2362.07 m were mainly type I and II reservoirs, and the reservoirs with a depth of 2362.07 m–2391.30 m were mainly reservoirs of type II and III. The most effective development was water injection in the upper section and gas injection in the lower section.

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“…9 shows the estimated relation between the intrinsic permeability and laboratory measurements under some typical Gas Research Institute (GRI) test conditions (T = 22°C; p = 100-500 psi). The power relation between measured permeability and porosity reported by Hakami et al (2016) is used for calculating the curves in the figure as an example. This is because this study has focused on carbonate source-rock samples while the relationship reported by Hakami et al (2016) was developed for a carbonate source-rock reservoir in Saudi Arabia.…”

Section: Correction Of Laboratory Permeability Measurementsmentioning

confidence: 99%

“…The power relation between measured permeability and porosity reported by Hakami et al (2016) is used for calculating the curves in the figure as an example. This is because this study has focused on carbonate source-rock samples while the relationship reported by Hakami et al (2016) was developed for a carbonate source-rock reservoir in Saudi Arabia. N 2 is assumed to be the working fluid.…”

Section: Correction Of Laboratory Permeability Measurementsmentioning

confidence: 99%

Correction of source-rock permeability measurements owing to slip flow and Knudsen diffusion: a method and its evaluation

2017

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Source-rock permeability is a key parameter that controls the gas production rate from unconventional reservoirs. Measured source-rock permeability in the laboratory, however, is not an intrinsic property of a rock sample, but depends on pore pressure and temperature as a result of the relative importance of slip flow and diffusion in gas flow in lowpermeability media. To estimate the intrinsic permeability which is required to determine effective permeability values for the reservoir conditions, this study presents a simple approach to correct the laboratory permeability measurements based on the theory of gas flow in a micro/nano-tube that includes effects of viscous flow, slip flow and Knudsen diffusion under different pore pressure and temperature conditions. The approach has been verified using published shale laboratory data. The ''corrected'' (or intrinsic) permeability is considerably smaller than the measured permeability. A larger measured permeability generally corresponds to a smaller relative difference between measured and corrected permeability values. A plot based on our approach is presented to describe the relationships between measured and corrected permeability for typical Gas Research Institute permeability test conditions. The developed approach also allows estimating the effective permeability in reservoir conditions from a laboratory permeability measurement.

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Characterization of carbonate mudrocks of the Jurassic Tuwaiq Mountain Formation, Jafurah basin, Saudi Arabia: Implications for unconventional reservoir potential evaluation

Cited by 55 publications

References 14 publications

Multi-physics evaluation of carbonate-rich source rocks from high-resolution images

Multi-physics evaluation of carbonate-rich source rocks from high-resolution images

Longitudinal Reservoir Evaluation Technique for Tight Oil Reservoirs

Correction of source-rock permeability measurements owing to slip flow and Knudsen diffusion: a method and its evaluation

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