Quantitative Evaluation on the Elastic Property of Oil-Bearing Mudstone/Shale from a Chinese Continental Basin

Li, Junqian; Lu, Shuangfang; Xue, Haitao; Xie, Lijuan; Zhang, Pengfei

doi:10.1260/0144-5987.33.6.851

Cited by 17 publications

(8 citation statements)

References 53 publications

(74 reference statements)

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“…Seemingly, the strength of any subsurface earth material is inversely correlated to porosity, which means that the ability of formation to support shear deformation and resist compression decrease with increasing porosity. The mechanical properties play a significant role in hydraulic fracturing of tight reservoirs, in terms of initiation and propagation of the hydraulic fracture (Josh et al 2012;Li et al 2015). Zones with high moduli strength and lower porosities would yield narrow fractures during hydraulic fracturing, whereas intervals with low moduli and high porosities would yield wider fractures.…”

Section: Resultsmentioning

confidence: 99%

Rock physics and geomechanical application in the interpretation of rock property trends for overpressure detection

Eyinla

Oladunjoye

Olayinka

et al. 2020

J Petrol Explor Prod Technol

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One of the complexities of geomechanical study is in the classification of rock’s properties and overpressured intervals—a knowledge which is not only essential for well safety and cost-effective drilling, but crucial in evaluating exploration risk factors and ensuring a successful hydraulic fracturing program. In this study, a more robust prediction of reservoir pressure regime is presented, where the geomechanical distributions of the rock give a distinct correlation. Three wells from the Niger Delta Basin were studied using empirical equations to estimate the elastic properties, wave velocities and the rock physics parameters for each well. From the results obtained, the velocities of compressional wave (Vp) and shear wave (Vs) decrease as porosity increases. Also, a linear correlation exists between Poisson’s ratio and Vp/Vs, where both variables showed distinct behavior and similar trend serving as useful tools for lithology identification. Another significant observation is the acoustic impedance of the materials which decreases with increasing porosity. Meanwhile, the depth plot of the impedance showed divergence and scattering away from the supposed linear trend. While inhomogeneity of the rock materials and disequilibrium compaction of sediments may account for this scattering, the variation of geomechanical distributions in this study revealed that pore pressure has a first order effect on the elastic strength of formations, also, under normal pore pressure conditions, acoustic impedance increases linearly with depth.

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Section: Resultsmentioning

confidence: 99%

Rock physics and geomechanical application in the interpretation of rock property trends for overpressure detection

Eyinla

Oladunjoye

Olayinka

et al. 2020

J Petrol Explor Prod Technol

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show abstract

“…L were divided into four categories: clay minerals, felsic minerals (quartz and feldspar), calcareous minerals (calcite, aragonite, dolomite, and iron dolomite), and other minerals (pyrite, siderite, and gypsum) according to the properties of each mineral in the MS. The MS were classified based on its mineral content [43]. MS with a clay mineral content > 50% were defined as clay-rich MS.…”

Section: (A)) the Clay Minerals In Esmentioning

confidence: 99%

“…(1) Impact of Material Composition on Brittleness. The mechanical properties (Young's modulus) of different minerals are extremely different and are closely related to the nature of the minerals [43]. Even for the same mineral, the contribution to brittleness in different regions may have completely opposite effects.…”

Section: Brittleness Evaluation Based On Mineral Compositionmentioning

confidence: 99%

“…Even for the same mineral, the contribution to brittleness in different regions may have completely opposite effects. The calcite in the Dongying Sag in eastern China has a degradative effect on the shale brittleness [43]. However, the calcite in the Barnett shale of North Texas is an essential contributor to effective reservoir fracturing [48].…”

Section: Brittleness Evaluation Based On Mineral Compositionmentioning

confidence: 99%

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Coupling Relationship between Lithofacies and Brittleness of the Shale Oil Reservoir: A Case Study of the Shahejie Formation in the Raoyang Sag

Song

et al. 2022

Geofluids

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Analyzing the characteristics of rock brittleness in low-permeability mudstone and shale (MS) formations is imperative for efficient hydraulic fracturing stimulation. Rock brittleness depends on the mineral composition, organic matter abundance, and bedding structure. Based on the MS from Shahejie Formation mineral composition (clay mineral, felsic mineral, and calcareous mineral contents), total organic content, and bedding structure (laminated, laminar, and massive), six types of lithofacies were identified: clay-rich MS, felsic-rich MS, calcareous-rich MS, clay MS, felsic MS, and calcareous MS. The quartz, feldspar, calcite, and dolomite of the Shahejie Formation are brittle minerals. Consequently, lithofacies with high felsic and calcareous mineral contents are more brittle. In addition, laminated and laminar MS are also conducive to hydraulic fracturing. Therefore, laminated, organic-rich, and calcareous-rich MS are the dominant lithofacies for hydraulic fracturing in the Shahejie Formation. The lithofacies and brittleness index were predicted by the response characteristics between mineral compositions and logging curves. The 3521–3552 m section of well B11x is dominated by calcareous-rich MS with developed laminae, representing a favorable section for hydraulic fracturing. Fragile minerals and oil are widely developed in the lower part of the lower 1st member of the Shahejie Formation (Es1L) in the southwestern part of Zhaohuangzhuang-Suning, where hydraulic fracturing can be used to increase shale oil production.

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“…The initiation and propagation of hydraulic fracturing in carbonate reservoirs are significantly affected by the reservoir's mechanical properties [78,79]. For instance, during hydraulic fracturing operation, the layers with high Young's modulus and low porosity would cause narrow fractures, while the layers with low Young's modulus and high porosity would yield wider fractures.…”

Section: Candidate Zone Selection For Simulating Hydraulic Fracturingmentioning

confidence: 99%

Joint Application of Diagenetic, Petrophysical and Geomechanical Data for Selecting Hydraulic Fracturing Candidate Zone

Bakhshi¹,

Shahrabadi²,

Golsanami

et al. 2021

Int. J. Petrol. Technol.

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The more comprehensive information on the reservoir properties will help to better plan drilling and design production. Herein, diagenetic processes and geomechanical properties are notable parameters that determine reservoir quality. Recognizing the geomechanical properties of the reservoir as well as building a mechanical earth model play a strong role in the hydrocarbon reservoir life cycle and are key factors in analyzing wellbore instability, drilling operation optimization, and hydraulic fracturing designing operation. Therefore, the present study focuses on selecting the candidate zone for hydraulic fracturing through a novel approach that simultaneously considers the diagenetic, petrophysical, and geomechanical properties. The diagenetic processes were analyzed to determine the porosity types in the reservoir. After that, based on the laboratory test results for estimating reservoir petrophysical parameters, the zones with suitable reservoir properties were selected. Moreover, based on the reservoir geomechanical parameters and the constructed mechanical earth model, the best zones were selected for hydraulic fracturing operation in one of the Iranian fractured carbonate reservoirs. Finally, a new empirical equation for estimating pore pressure in nine zones of the studied well was developed. This equation provides a more precise estimation of stress profiles and thus leads to more accurate decision-making for candidate zone selection. Based on the results, vuggy porosity was the best porosity type, and zones C2, E2 and G2, having suitable values of porosity, permeability, and water saturation, showed good reservoir properties. Therefore, zone E2 and G2 were chosen as the candidate for hydraulic fracturing simulation based on their E (Young’s modulus) and ν (Poisson’s ratio) values. Based on the mechanical earth model and changes in the acoustic data versus depth, a new equation is introduced for calculating the pore pressure in the studied reservoir. According to the new equation, the dominant stress regime in the whole well, especially in the candidate zones, is SigHmax>SigV>Sighmin, while according to the pore pressure equation presented in the literature, the dominant stress regime in the studied well turns out to be SigHmax>Sighmin>SigV.

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Quantitative Evaluation on the Elastic Property of Oil-Bearing Mudstone/Shale from a Chinese Continental Basin

Cited by 17 publications

References 53 publications

Rock physics and geomechanical application in the interpretation of rock property trends for overpressure detection

Rock physics and geomechanical application in the interpretation of rock property trends for overpressure detection

Coupling Relationship between Lithofacies and Brittleness of the Shale Oil Reservoir: A Case Study of the Shahejie Formation in the Raoyang Sag

Joint Application of Diagenetic, Petrophysical and Geomechanical Data for Selecting Hydraulic Fracturing Candidate Zone

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