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Academic literature on the topic 'Petrophysics and rock mechanics'

Author: Grafiati

Published: 10 December 2022

Last updated: 28 January 2023

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Journal articles on the topic "Petrophysics and rock mechanics"

Li, Yongyi, Lev Vernik, Mark Chapman, and Joel Sarout. "Introduction to this special section: Rock physics." Leading Edge 38, no. 5 (May 2019): 332. http://dx.doi.org/10.1190/tle38050332.1.

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Rock physics links the physical properties of rocks to geophysical and petrophysical observations and, in the process, serves as a focal point in many exploration and reservoir characterization studies. Today, the field of rock physics and seismic petrophysics embraces new directions with diverse applications in estimating static and dynamic reservoir properties through time-variant mechanical, thermal, chemical, and geologic processes. Integration with new digital and computing technologies is gradually gaining traction. The use of rock physics in seismic imaging, prestack seismic analysis, seismic inversion, and geomechanical model building also contributes to the increase in rock-physics influence. This special section highlights current rock-physics research and practices in several key areas, namely experimental rock physics, rock-physics theory and model studies, and the use of rock physics in reservoir characterizations.

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Anderson, Iain, Jingsheng Ma, Xiaoyang Wu, and Dorrik Stow. "Determining reservoir intervals in the Bowland Shale using petrophysics and rock physics models." Geophysical Journal International 228, no. 1 (August 20, 2021): 39–65. http://dx.doi.org/10.1093/gji/ggab334.

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SUMMARY An evaluation of prospective shale gas reservoir intervals in the Bowland Shale is presented using a wireline log data set from the UK's first shale gas exploration well. Accurate identification of such intervals is crucial in determining ideal landing zones for drilling horizontal production wells, but the task is challenging due to the heterogeneous nature of mudrocks. This heterogeneity leads to stratigraphic variations in reservoir quality and mechanical properties, and leads to complex geophysical behaviour, including seismic anisotropy. We generate petrophysical logs such as mineralogy, porosity, and organic content and calibrate these to the results of core studies. If ‘reservoir quality’ is defined by combined cut-offs relating to these parameters, we find that over 100 m of reservoir quality shale is present in the well, located primarily within the upper section. To examine the link between geophysical signature and rock properties, an isotropic rock physics model is developed, using effective medium theories, to recreate the elastic properties of the shale and produce forward-looking templates for subsequent seismic inversion studies. We find that the mineralogical heterogeneity in the shale has a profound impact on modelled elastic properties, obscuring more discrete changes due to porosity, organic content and water saturation and that the best reservoir quality intervals of the shale bear a distinctive response on rock physics cross-plots. Finally, we consider the density of natural fractures in the shale by developing an anisotropic rock physics model to reflect high-angle fractures observed on micro-imagery logs. We invert crack density using shear wave splitting well log data and find a crack density of up to 4 per cent which correlates well with micro-imagery observations. Our work further supports previous authors’ core-based studies in concluding that the Bowland Shale holds good reservoir characteristics, and we propose that there are multiple intervals within the shale that could be targeted with stacked horizontal wells, should those intervals’ mechanical properties also be suitable and there be adequate stress barriers between to restrict vertical hydraulic fracture growth. Finally, our rock physics templates may provide useful tools in interpreting pre-stack seismic data sets in prospective areas of the Bowland Shale and picking the best locations for drilling wells.

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Xu, Hao, Wen Zhou, Runcheng Xie, Lina Da, Christopher Xiao, Yuming Shan, and Haotian Zhang. "Characterization of Rock Mechanical Properties Using Lab Tests and Numerical Interpretation Model of Well Logs." Mathematical Problems in Engineering 2016 (2016): 1–13. http://dx.doi.org/10.1155/2016/5967159.

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The tight gas reservoir in the fifth member of the Xujiahe formation contains heterogeneous interlayers of sandstone and shale that are low in both porosity and permeability. Elastic characteristics of sandstone and shale are analyzed in this study based on petrophysics tests. The tests indicate that sandstone and mudstone samples have different stress-strain relationships. The rock tends to exhibit elastic-plastic deformation. The compressive strength correlates with confinement pressure and elastic modulus. The results based on thin-bed log interpretation match dynamic Young’s modulus and Poisson’s ratio predicted by theory. The compressive strength is calculated from density, elastic impedance, and clay contents. The tensile strength is calibrated using compressive strength. Shear strength is calculated with an empirical formula. Finally, log interpretation of rock mechanical properties is performed on the fifth member of the Xujiahe formation. Natural fractures in downhole cores and rock microscopic failure in the samples in the cross section demonstrate that tensile fractures were primarily observed in sandstone, and shear fractures can be observed in both mudstone and sandstone. Based on different elasticity and plasticity of different rocks, as well as the characteristics of natural fractures, a fracture propagation model was built.

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Will, Robert, Tom Bratton, William Ampomah, Samuel Acheampong, Martha Cather, and Robert Balch. "Time-Lapse Integration at FWU: Fluids, Rock Physics, Numerical Model Integration, and Field Data Comparison." Energies 14, no. 17 (September 2, 2021): 5476. http://dx.doi.org/10.3390/en14175476.

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We present the current status of time-lapse seismic integration at the Farnsworth (FWU) CO2 WAG (water-alternating-gas) EOR (Enhanced Oil Recovery) project at Ochiltree County, northwest Texas. As a potential carbon sequestration mechanism, CO2 WAG projects will be subject to some degree of monitoring and verification, either as a regulatory requirement or to qualify for economic incentives. In order to evaluate the viability of time-lapse seismic as a monitoring method the Southwest Partnership (SWP) has conducted time-lapse seismic monitoring at FWU using the 3D Vertical Seismic Profiling (VSP) method. The efficacy of seismic time-lapse depends on a number of key factors, which vary widely from one application to another. Most important among these are the thermophysical properties of the original fluid in place and the displacing fluid, followed by the petrophysical properties of the rock matrix, which together determine the effective elastic properties of the rock fluid system. We present systematic analysis of fluid thermodynamics and resulting thermophysical properties, petrophysics and rock frame elastic properties, and elastic property modeling through fluid substitution using data collected at FWU. These analyses will be framed in realistic scenarios presented by the FWU CO2 WAG development. The resulting fluid/rock physics models will be applied to output from the calibrated FWU compositional reservoir simulation model to forward model the time-lapse seismic response. Modeled results are compared with field time-lapse seismic measurements and strategies for numerical model feedback/update are discussed. While mechanical effects are neglected in the work presented here, complementary parallel studies are underway in which laboratory measurements are introduced to introduce stress dependence of matrix elastic moduli.

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Alafnan, Saad. "The Impact of Pore Structure on Kerogen Geomechanics." Geofluids 2021 (September 15, 2021): 1–12. http://dx.doi.org/10.1155/2021/4093895.

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Production stimulation techniques such as the combination of hydraulic fracturing and lateral drilling have made exploiting unconventional formations economically feasible. Advancements in production aspects are not always in lockstep with our ability to predict and model the extent of a fracturing job. Shale is a clastic sedimentary rock composed of a complex mineralogy of clay, quartz, calcite, and fragments of an organic material known as kerogen. The latter, which consists of large chains of aromatic and aliphatic carbons, is highly elastic, a characteristic that impacts the geomechanics of a shale matrix. Following a molecular simulation approach, the objective of this work is to investigate kerogen’s petrophysics on a molecular level and link it to kerogen’s mechanical properties, considering some range of kerogen structures. Nanoporous kerogen structures across a range of densities were formed from single macromolecule units. Eight units were initially placed in a low-density cell. Then, a molecular dynamic protocol was followed to form a final structure with a density of 1.1 g/cc; the range of density values was consistent with what has been reported in the literature. The structures were subjected to petrophysical assessments including a helium porosity analysis and pore size distribution characterization. Mechanical properties such as Young’s modulus, bulk modulus, and Poisson ratio were calculated. The results revealed strong correlations among kerogen’s mechanical properties and petrophysics. The kerogen with the lowest porosity showed the highest degree of elasticity, followed by other structures that exhibited larger pores. The effect temperature and the fluid occupying the pore volume were also investigated. The results signify the impact of kerogen’s microscale intricacies on its mechanical properties and hence on the shale matrix. This work provides a novel methodology for constructing kerogen structures with different microscale properties that will be useful for delineating fundamental characteristics such as mechanical properties. The findings of this work can be used in a larger scale model for a better description of shale’s geomechanics.

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Shoemaker, Michael, Santhosh Narasimhan, Shane Quimby, and James Hawkins. "Calculating far-field anisotropic stress from 3D seismic in the Permian Basin." Leading Edge 38, no. 2 (February 2019): 96–105. http://dx.doi.org/10.1190/tle38020096.1.

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Minimum horizontal stress (Sh) is the controlling parameter when hydraulic fracture stimulating tight oil formations but is next to impossible to measure quantitatively, especially in the far field and away from the wellbore. In-situ stress differences between bedding planes control fracture containment, which defines the complexity of fracture propagation and fracture geometry including orientation, height growth, width, and length. Geomechanical rock properties define elastic behavior, influencing how the subsurface will deform under induced stress. These properties include dynamic and static Young's modulus, Poisson's ratio, and Biot's coefficient. When combined with pore pressure and overburden stress, the elastic rock properties describe the mechanical earth model (MEM), which characterizes the geomechanical behavior of the subsurface. The MEM also defines key inputs for calculating Sh using the Ben Eaton stress equation, which has been commonly used by geoscientists for decades. However, calculated Sh from this simple model historically produces uncertain results when compared to field-measured stress due to an assumed homogeneous and isotropic subsurface. This is particularly contrary to tight oil formations that represent shale (or mudrock) reservoirs that are highly laminated and therefore anisotropic. Optimal parameterization of fracture geometry models for well spacing and engineered treatment design requires an anisotropic far-field in-situ stress measurement that accurately captures vertical and lateral variability of geomechanical properties in 3D space. A method is proposed herein that achieves this by using a modified version of the anisotropic Ben Eaton stress model. The method calculates minimum Sh by substitution of inverted 3D seismic volumes directly into the stress equation, replacing the bound Poisson's ratio term with an equivalent anisotropic corrected closure stress scalar (CSS) term. The CSS seismic volume is corrected for anisotropy using static triaxial core and is calibrated to multidomain data types including petrophysics, rock physics, geomechanics, and completion and reservoir engineering field measurements.

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Zhang, Hui, Ke Xu, Binxin Zhang, Guoqing Yin, Haiying Wang, Zhimin Wang, Chao Li, Shujun Lai, and Ziwei Qian. "Influence of Stress Anisotropy on Petrophysical Parameters of Deep and Ultradeep Tight Sandstone." Applied Sciences 12, no. 22 (November 14, 2022): 11543. http://dx.doi.org/10.3390/app122211543.

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Rock mechanics parameters control the distribution of in situ stress and natural fractures, which is the key to sweet spot evaluation in reservoir engineering. Combined with the distribution of in situ stress, an experimental scheme of stress on rock physical parameters was designed. The results show that rock sonic velocity is extremely sensitive to water saturation under overburden pressure. At ultrasonic frequencies, when the water saturation increases from 0% to 80%, the P-wave velocity increases first and then decreases. When the water saturation continues to increase to 100%, the P-wave velocity increases. This is due to the effect of water saturation on the shear modulus. Saturation is negatively correlated with shear wave velocity and resistivity. Different minerals have different control effects on the rock P-S wave velocity ratio. Quartz content plays a dominant role, and the two are negatively correlated, followed by feldspar and clay, and the two are positively correlated with the P-S wave ratio. The confining pressure, axial compression, stress ratio and burial depth are positively correlated with the P-S wave and negatively correlated with the P-S wave ratio; in descending order, the influencing factors of stress on the petrophysical parameters are maximum stress ratio > confining pressure > axial pressure.

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Perry, Stephanie. "Technology Focus: Formation Evaluation (August 2021)." Journal of Petroleum Technology 73, no. 08 (August 1, 2021): 41. http://dx.doi.org/10.2118/0821-0041-jpt.

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Leading into the third quarter of this year, I am honored to be able to highlight and share three impactful SPE papers that demonstrate integration at its best. In reviewing the papers, five main technical themes emerged. These include * Machine learning and artificial intelligence as applied to formation evaluation * Production analysis methodologies and their effect on understanding rock characterization and behavior * Subsurface characterization primarily focused on rock typing and permeability * Tool advancements (openhole, cased-hole, or laboratory-based tools) * Subsurface-to-production integration across subdisciplines (e.g., geology, geochemistry, petrophysics, and engineering) The latter is the common thread between the three papers recommended and discussed here. In this new decade, the prevalence of integration is at the forefront of the scientific community. Every discipline, scientist, or company has a way in which they define the term “integration.” Regardless of how you define the effort that links disciplines quantitatively, the importance of constraining subsurface characterization to link it to production results and drive toward a predictive model is a critical accomplishment for our industry. As such, I’d like to highlight three papers in this feature (OTC 30644, SPE 201417, and SPE 202683) and the knowledge and workflow applications they define and demonstrate. Sharing these integrated work flows with the community aids in teaching and leads to best-practice components of integrative studies. These efforts also share and demonstrate how to bridge the gap between in-situ characterization and wellhead performance prediction and results—in other words, the static-to-dynamic link between rock and fluid properties as quantified and how they will inevitably produce hydrocarbon through the rock and fluid interactions. Recommended additional reading at OnePetro: www.onepetro.org. SPE 201334 Combined Experimental and Well-Log Evaluation of Anisotropic Mechanical Properties of Shales: An Application to Wellbore Stability in the Bakken Formation by Saeed Rafieepour, The University of Tulsa, et al. SPE 201486 A New Safe and Cost-Effective Approach to Large-Scale Formation Testing by Fluid Injection on a Wireline Formation Tester by Christopher Michael Jones, Halliburton, et al. SPE 201735 Integrated Reservoir Characterization With Spectroscopy, Dielectric, and Nuclear Magnetic Resonance T1-T2 Maps in a Freshwater Environment: Case Studies From Alaska by ZhanGuo Shi, Schlumberger, et al.

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Lavenu, Arthur P. C., Juliette Lamarche, Lisa Texier, Lionel Marie, and Bertrand D. M. Gauthier. "Background fractures in carbonates: inference on control of sedimentary facies, diagenesis and petrophysics on rock mechanical behavior. Example of the Murge Plateau (southern Italy)." Italian Journal of Geosciences 134, no. 3 (October 2015): 535–55. http://dx.doi.org/10.3301/ijg.2014.58.

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Askaripour, Mahdi, Ali Saeidi, Patrick Mercier-Langevin, and Alain Rouleau. "A Review of Relationship between Texture Characteristic and Mechanical Properties of Rock." Geotechnics 2, no. 1 (March 7, 2022): 262–96. http://dx.doi.org/10.3390/geotechnics2010012.

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The textural characteristics of rocks influence their petrophysical and mechanical properties. Such parameters largely control rock mass stability. The ability to evaluate both immediate and long-term rock behaviors based on the interaction between various parameters of rock texture, petrophysical and mechanical properties is therefore crucial to many geoengineering facilities. However, due to the common lack of high-quality core samples for geomechanics and rock texture laboratory tests, single and multivariable regression analyses are conducted between mechanical properties and textural characteristics based on experimental test data. This study presents a review of how rock texture characteristics influence the geomechanical properties of a rock, and summarizes the regression equations between two aspects. More specifically, a review of the available literature on the effects of mineralogy, grain size, grain shape, packing density, foliation index, porosity, degree of weathering, and other rock physical characteristics on geomechanics is presented. Similarly, a review of the literature discussing the failure criteria of anisotropic rocks, both continuous and discontinuous, is also presented. These reviews are accompanied by a comparison of the fundamentals of these methods, describing their equations and discussing their advantages and disadvantages. This exercise has the objective of providing better guidelines on how to use these criteria, allowing for safer underground excavations via an improved understanding of how rock texture parameters affects the mechanical behavior of rocks.

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Dissertations / Theses on the topic "Petrophysics and rock mechanics"

SANTIAGO, Karina Felícia Fischer Lima. "Determinação das constantes elásticas estáticas e dinâmicas das rochas da formação sousa, Bacia do Rio do Peixe, PB." Universidade Federal de Campina Grande, 2015. http://dspace.sti.ufcg.edu.br:8080/jspui/handle/riufcg/410.

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Submitted by Jesiel Ferreira Gomes (jesielgomes@ufcg.edu.br) on 2018-04-17T23:55:41Z No. of bitstreams: 1 KARINA FELÍCIA FISCHER LIMA SANTIAGO – DISSERTAÇÃO (PPGEPM) 2015.pdf: 11955651 bytes, checksum: ed2b0ddfd6604f59ef01965e640d37ac (MD5)
Made available in DSpace on 2018-04-17T23:55:41Z (GMT). No. of bitstreams: 1 KARINA FELÍCIA FISCHER LIMA SANTIAGO – DISSERTAÇÃO (PPGEPM) 2015.pdf: 11955651 bytes, checksum: ed2b0ddfd6604f59ef01965e640d37ac (MD5) Previous issue date: 2015-08-26
Capes
Neste trabalho estudam-se as propriedades físicas e mecânicas das rochas da Bacia do Rio do Peixe (BRP), provenientes do furo estratigráfico 1-BSB01-PB. Esta bacia, localizada no extremo oeste do estado da Paraíba, tem se tornado alvo de estudos exploratórios, face à ocorrência de óleo próximo a superfície, à NW da cidade de Sousa. Em sua caracterização faciológica, identificam-se cinco fácies sedimentares: calcilutito vermelho, calcilutito cinza, arenito, folhelho negro e marga. Por meio de ensaios de propagação de ondas sísmicas, experimentos de petrofísica básica, e ensaios mecânicos de compressão uniaxial com o martelo de Schmidt, determinam-se para as amostras de rochas da BRP, a porosidade, as densidades total e de grão, as velocidades sísmicas, a resistência mecânica e as constantes elásticas estáticas e dinâmicas, destacando-se o módulo de Young. Os resultados obtidos mostram que as rochas em estudo apresentam valores de porosidade entre 0,5 e 20%, resistência à compressão uniaxial de 18 a 93 MPa, módulos de Young dinâmicos entre 9 a 58 GPa, desde 1,1 até 6 vezes maiores que os correspondentes módulos estáticos. As correlações observadas para as diferentes propriedades físicas e mecânicas mostram-se fortemente influenciadas por características como presença de material carbonático, matéria orgânica, óleo e estruturas sedimentares e tectônicas, evidenciando a complexidade das rochas analisadas.
In this paper, studies on physical and mechanical properties of rocks from the stratigraphic hole 1-BSB01-PB, in the Rio do Peixe Basin (BRP), are performed. This basin, located in the far west of the state of Paraíba, has become the subject of exploration studies due to the occurrence of oil near the surface, in the NW of Sousa city. In his facies characterization is possible to identify five sedimentary facies: red calcilutite, gray calcilutite, sandstone, black shale and marl. From seismic wave propagation tests, experiments of basic petrophysics, mechanical tests on uniaxial compressive with Schmidt’s hammer, are determined for samples of BRP rocks the porosity, the bulk and grain densities, the seismic velocities, the mechanical strength and the static and dynamic elastic constants, highlighting the Young's modulus. The results obtained show that the studied rocks have porosity values between 0.5 and 20%, uniaxial compressive strength from 18 to 93 MPa, dynamic Young's modulus between 9 and 58 GPa, from 1,1 to 6 times greater than the corresponding static modules Correlations observed for the different physical and mechanical properties shows strongly influences by characteristics such as the presence of carbonate material, organic material, oil and sedimentary and tectonic structure, showing the complexity of the analyzed rocks.

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Slayman, Hadi. "Integration of rock typing with petrophysics in the Cooper Basin, Australia /." Title page, abstract and table of contents only, 2002. http://web4.library.adelaide.edu.au/theses/09SB/09sbs6319.pdf.

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Al-Harthy, Said Salim. "Laboratory investigation of petrophysical properties of sandstone rocks under true triaxial stress." Thesis, Imperial College London, 1999. http://hdl.handle.net/10044/1/8549.

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Binyatov, Elnur. "Sedimentological, Cyclostratigraphic Analysis And Reservoir Characterization Of Balakhany X Formation Within The Productive Series Azeri Field On C01 Well (offshore Azerbaijan)." Master's thesis, METU, 2008. http://etd.lib.metu.edu.tr/upload/3/12609628/index.pdf.

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The Azeri, Chirag, Gunashli (ACG) field is located offshore Azerbaijan. The reservoirs are multilayered sandstones forming traps within a major anticlinal structure. Proven crude oil reserves are estimated to contain 5.4 billion barrels of oil. In the past this area has been studied in regional detail but not at the reservoir scale with respect to the fluvio-deltaic sediments filling the northern shore of the ancient South Caspian Sea. The aim of this study is carried out the sedimentological, cyclostratigraphical analysis and reservoir characterization of Balakhany X Formation within the Productive Series which is considered to be one of the significant producing horizons. To be able to achieve this objective, a 30m thick section, which is mainly composed of siliciclastics, has been studied in detail on Balakhany X cores from C01 well Azeri field. In this study, detailed lithofacies analyses were performed and sandstone, mudstone, siltstone facies were recognized in the studied interval of the Balakhany X Formation. Litharenites and sublitharenites sandstones are the most abundant in the succession. Sedimentological analysis such as grain-size sphericity, provenance, XRD, SEM and grain surface texture were performed and their relationship with depositional environment were discussed. The grain size distribution of the samples along the succession shows distribution of fine to very fine sands. Sorting of sandstones ranges between moderately well to very well sorted. The provenance analysis of sandstones based on modal analysis of thin sections related to recycled orogen. According to interpretation of grain size parameters and grain surface textures analysis the main transporting agent of sands observed as wind, wave and river agents. High resolution cyclostratigraphy studies based on cm-m scaled cyclic occurrences of lithofacies along the measured section were performed. Milankovitch, sub-Milankovitch and millennial cycles were determined along the studied section. The petrophysical analysis revealed good to very good (18 to 24%) porosity and good permeability (10 to 538mD) in Balakhany X Formation. The porosity and permeability are affected by both textural and compositional controls. Grain size distribution along the reservoir section is fine to very fine sands. Influence of compaction was observed by the fractures and dissolutions on the sand grains. The calcite cement, grain-size variation, sorting and compaction are the main factors controlling porosity and permeability.

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Khather, Mohamed. "Experimental Evaluation of Variation in Petrophysical Properties during CO2 Injection in Carbonate Rocks: Effective Mechanisms." Thesis, Curtin University, 2018. http://hdl.handle.net/20.500.11937/73568.

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Core flooding experiments were conducted in this research to evaluate changes in petrophysical properties of a number of carbonate samples (limestone, dolostone and chalk). The experiments involved carbonated brine flooding, CO2 enhanced oil recovery (CO2-EOR), and Water-Alternating Gas (WAG) processes performed under in-situ reservoir conditions.

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Douglas, Kurt John Civil &amp Environmental Engineering Faculty of Engineering UNSW. "The shear strength of rock masses." Awarded by:University of New South Wales. School of Civil and Environmental Engineering, 2002. http://handle.unsw.edu.au/1959.4/19138.

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The first section of this thesis (Chapter 2) describes the creation and analysis of a database on concrete and masonry dam incidents known as CONGDATA. The aim was to carry out as complete a study of concrete and masonry dam incidents as was practicable, with a greater emphasis than in other studies on the geology, mode of failure, and the warning signs that were observed. This analysis was used to develop a method of very approximately assessing probabilities of failure. This can be used in initial risk assessments of large concrete and masonry dams along with analysis of stability for various annual exceedance probability floods. The second and main section of this thesis (Chapters 3-6) had its origins in the results of Chapter 2 and the general interests of the author. It was found that failure through the foundation was common in the list of dams analysed and that information on how to assess the strength of the foundations of dams on rock masses was limited. This section applies to all applications of rock mass strength such as the stability of rock slopes. Methods used for assessing the shear strength of jointed rock masses are based on empirical criteria. As a general rule such criteria are based on laboratory scale specimens with very little, and often no, field validation. The Hoek-Brown empirical rock mass failure criterion was developed in 1980 for hard rock masses. Since its development it has become virtually universally accepted and is now used for all types of rock masses and in all stress regimes. This thesis uses case studies and databases of intact rock and rockfill triaxial tests collated by the author to review the current Hoek-Brown criterion. The results highlight the inability of the criterion to fit all types of intact rock and poor quality rock masses. This arose predominately due to the exponent a being restrained to approximately 0.5 to 0.62 and using rock type as a predictor of mi. Modifications to the equations for determining the Hoek-Brown parameters are provided that overcome these problems. In the course of reviewing the Hoek-Brown criterion new equations were derived for estimating the shear strength of intact rock and rockfill. Empirical slope design curves have also been developed for use as a preliminary tool for slope design.

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SAVELY, JAMES PALMER. "PROBABILISTIC ANALYSIS OF FRACTURED ROCK MASSES." Diss., The University of Arizona, 1987. http://hdl.handle.net/10150/184249.

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Stability analysis of rock masses composed of small, discrete rock blocks that are in-place and interlocked should consider four components of failure: (1) Sliding between blocks. (2) Shearing through rock blocks. (3) Rolling blocks in a shear zone. (4) Crushing of rock blocks. Statistical rock mass description is used to define the characteristics of the rock blocks and the block assemblage. Clastic mechanics is one method of predicting stresses produced by the arrangement of rock blocks and the loading conditions. Failure begins at a point of maximum stress behind the slope. Progression of the failure is assumed if the first block fails because adjacent blocks will become overstressed. The location of the point of maximum stress is determined from the shape and arrangement of the constituent rock blocks. Because strength is mobilized block-by-block rather than instantaneously along a continuous shear surface, sliding between blocks shows less stability than a soil rotational shear analysis or a rigid block sliding analysis. Shearing through rock blocks occurs when maximum shear stress exceeds rock shear strength. Crushing of rock blocks is predicted if the normal stress exceeds the compressive strength of the rock block. A size-strength relationship is combined with the rock block size distribution curve to estimate crushing strength. Rotating blocks in a shear zone have been observed in model studies and as a mechanism in landslides. Stability analysis assumes that the rock mass is sufficiently loosened by blasting and excavation to allow blocks to rotate. The shear strength of rolling blocks is dynamic shear strength that is less than static sliding shear strength. This rolling mechanism can explain release of slope failures where there are no other obvious structural controls. Stability of each component of rock mass failure is calculated separately using capacity-demand reliability. These results are combined as a series-connected system to give the overall stability of the rock mass. This probability of failure for the rock mass system explicitly accounts for the four components of rock mass failure. Criteria for recognizing rock mass failure potential and examples applying the proposed method are presented.

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Lock, Yick-bun. "An examination of failure criteria for some common rocks in Hong Kong /." Hong Kong : University of Hong Kong, 1996. http://sunzi.lib.hku.hk/hkuto/record.jsp?B17665164.

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Akbarnejad, Nesheli Babak. "Rock mechanics aspects of blowout self-containment." [College Station, Tex. : Texas A&M University, 2006. http://hdl.handle.net/1969.1/ETD-TAMU-1835.

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Lanaro, Flavio. "Geometry, Mechanics and Transmissivity of Rock Fractures." Doctoral thesis, Stockholm : Tekniska högsk, 2001. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-3168.

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Books on the topic "Petrophysics and rock mechanics"

Charlez, Philippe A. Rock mechanics. Paris: Technip, 1991.

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Brady, B. H. G., and E. T. Brown. Rock Mechanics. Dordrecht: Springer Netherlands, 1999. http://dx.doi.org/10.1007/978-94-015-8129-5.

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Wittke, Walter. Rock Mechanics. Berlin, Heidelberg: Springer Berlin Heidelberg, 1990. http://dx.doi.org/10.1007/978-3-642-88109-1.

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Brady, B. H. G., and E. T. Brown. Rock Mechanics. Dordrecht: Springer Netherlands, 1985. http://dx.doi.org/10.1007/978-94-011-6501-3.

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A, Hudson J., and Hudson J. A, eds. Engineering rock mechanics. Oxford: Pergamon, 2000.

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Introduction to rock mechanics. 2nd ed. New York: Wiley, 1989.

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Feng, Xia-Ting. Rock Mechanics and Engineering. Edited by Xia-Ting Feng. Leiden, The Netherlands; Boca Raton: CRC Press/Balkema, [2017]– |Includes bibliographical references and index. Contents: volume 1. Principles: CRC Press, 2017. http://dx.doi.org/10.1201/9781315364223.

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Thiel, Kazimierz. Rock mechanics in hydroengineering. Amsterdam: Elsevier, 1989.

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Ramamurthy, T. Manual on rock mechanics. New Delhi: Central Board of Irrigation & Power, 2010.

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Abbie, M. Rock mechanics: New research. Hauppauge, NY: Nova Science Publishers, 2009.

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Book chapters on the topic "Petrophysics and rock mechanics"

Cabrera S., Daniel, and Fernando Samaniego V. "Petrophysics or Geomechanics: A Branch of Mechanics." In Experimental Mechanics of Fractured Porous Rocks, 1–7. Cham: Springer International Publishing, 2022. http://dx.doi.org/10.1007/978-3-031-17738-5_1.

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Cabrera S., Daniel, and Fernando Samaniego V. "Petrophysical Classification of Rocks." In Experimental Mechanics of Fractured Porous Rocks, 9–20. Cham: Springer International Publishing, 2022. http://dx.doi.org/10.1007/978-3-031-17738-5_2.

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Gullco, Robert S., and Malcolm Anderson. "Petrophysics review." In Elements of Rock Physics and Their Application to Inversion and AVO Studies, 3–15. London: CRC Press, 2021. http://dx.doi.org/10.1201/9781003261773-2.

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Hutchinson, D. Jean, and Mark Diederichs. "Rock Mechanics." In Encyclopedia of Earth Sciences Series, 1–3. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-319-12127-7_245-1.

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Liu, Hongqi. "Rock Mechanics." In Principles and Applications of Well Logging, 237–69. Berlin, Heidelberg: Springer Berlin Heidelberg, 2016. http://dx.doi.org/10.1007/978-3-662-53383-3_8.

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Liu, Hongqi. "Rock Mechanics." In Principles and Applications of Well Logging, 237–69. Berlin, Heidelberg: Springer Berlin Heidelberg, 2017. http://dx.doi.org/10.1007/978-3-662-54977-3_8.

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Hutchinson, D. Jean, and Mark Diederichs. "Rock Mechanics." In Encyclopedia of Earth Sciences Series, 796–98. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-319-73568-9_245.

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Perkins, Dexter, Kevin R. Henke, Adam C. Simon, and Lance D. Yarbrough. "Rock Mechanics." In Earth Materials, 493–513. Leiden, The Netherlands : CRC Press/Balkema, [2019]: CRC Press, 2019. http://dx.doi.org/10.1201/9780429197109-16.

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Brady, B. H. G., and E. T. Brown. "Blasting mechanics." In Rock Mechanics, 466–90. Dordrecht: Springer Netherlands, 1999. http://dx.doi.org/10.1007/978-94-015-8129-5_17.

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Brady, B. H. G., and E. T. Brown. "Blasting mechanics." In Rock Mechanics, 433–58. Dordrecht: Springer Netherlands, 1985. http://dx.doi.org/10.1007/978-94-011-6501-3_17.

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Conference papers on the topic "Petrophysics and rock mechanics"

M Shah, Jamari, Sigit Sutiyono, Nur Athirah M Dahlan, and Noor Faezah Ramly. "Permanent Caprock Abandonment P&A Assessment Incorporating Rock Mechanics Analysis: Petrophysics Perspective." In SPE Symposium: Decommissioning and Abandonment. Society of Petroleum Engineers, 2018. http://dx.doi.org/10.2118/193950-ms.

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Kumar Shahi, Anup, Anil Kumar, Kumar Hemant Singh, and Ranjith Pathegama Gamage. "Improved Upscaling Methods for Carbonate Rock Image Data." In 56th U.S. Rock Mechanics/Geomechanics Symposium. ARMA, 2022. http://dx.doi.org/10.56952/arma-2022-2204.

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ABSTRACT Volumetric image data of rocks often need sophisticated image processing steps in any rock physics and petrophysics workflow. While the segmentation is highly dependent on the quality of data, a trade-off between resolution and field of view is inevitable. This work attempts to resolve this using multiple-point statistics that have long been used for generating synthetic images, though mostly applied to sandstone rocks where the heterogeneity is significantly less than that of carbonates. These algorithms work by sequentially populating a grid to emulate the observed image. However, finding the optimum kernel parameters is crucial to capturing the spatial characteristics of the data. Also, when dealing with multiple images, finding a single set of kernel parameters might not be a trivial task. Further these methods work by computing a covariance kernel that scales as the third power with the number of training examples, thus not scaling well with the more data. Therefore, we seek to design a single image-based upscaling method that would help alleviate these difficulties. We test the proposed methodology on carbonate rock sample data which are known for their complexities at various scales. In this study images of 4 samples are considered. An upsample-deblur is developed that consistently works better than the conventional bicubic interpolation based upsampling technique. For this, a low-resolution 2D image sample is extracted from an X-ray microtomography dataset which was then subjected to a Random Forest based upsampling algorithm. It is found that the data from low scale could be improved to form a single super-resolution image. The algorithm produces an image that is always better than the bicubic algorithm. We anticipate this strategy would help design advanced algorithms where the amount of training examples is less. 1. INTRODUCTION Digital Rock Physics workflow has gained significant attention from researchers due to its promising accuracy to characterize rocks and predict desired properties through numerical simulation (Andrä et al., 2013a, 2013b). Digital rock physics is a numerical workflow to compute and simulate various rock properties such as permeability, electrical conductivity, and elastic moduli based on high-resolution representations of the complex pore geometry obtained from imaging (Andrä et al., 2013a, 2013b; Arns et al., 2019; Devarapalli et al., 2017; Mehmani et al., 2020; Wildenschild & Sheppard, 2013).

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Xie, Jinyang, Luo Zuo, Bing Hou, Yifan Dai, Jiaxin Li, Li Zhuang, and Derek Elsworth. "Influencing Factors of Acid Etching Fracture Conductivity of Tuff Reservoir in Northeastern Sichuan Block." In 56th U.S. Rock Mechanics/Geomechanics Symposium. ARMA, 2022. http://dx.doi.org/10.56952/arma-2022-1007.

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ABSTRACT: With the continuous depth breakthrough of two ultra-deep exploration wells in northeastern Sichuan block, tuff reservoir was finally discovered at the depth of 6700-7300 m. It belongs to ultra-deep tight gas reservoir with low brittle mineral content and high clay content. Hydraulic fracturing is hard to be reformed this special reservoir, easy to appear hydration expansion and other problems. However, the research and development of such tight tuff reservoir with high temperature and high pressure are relatively low in the domestic and overseas until now. Therefore, it is of great significance to carry out experimental research on relevant reservoir reconstruction methods of such rocks and explore the factors of fracture conductivity here. In this study, the influence of acid type, sanding concentrations, proppant size was research by a new experimental installation. The factors of fracture conductivity are analyzed by experimental data and the reconstitution of fracture surface. The results show that before the abnormal point, the acid etching effect of crosslinked acid on tuff is better than that of gelling acid. At the condition of closure pressure is lower 30 MPa, the higher sanding concentrations, the higher fracture conductivity, then narrowed the gap among them. Meanwhile, the larger proppant size, the higher fracture conductivity in low closure pressure. With increasing closure pressure, fracture conductivity of smaller size proppant decreased slowly. In conclusion, it is also convenient for the field operation to choose the best acid and proppant parameters. 1. INTRODUCTION As an important new field of exploration and development of oil and gas resources in the world, igneous reservoir have gradually received extensive attention from geological and petroleum researchers all over the world. The exploration and research on the igneous reservoir has a history of more than 130 years. Now, some igneous reservoir have been exploited in the United States, Indonesia, Japan, Brazil, Australia and other countries (Tang, et al. 2020). Its oil and gas mainly come from athrogenic rock reservoir. Athrogenic rock is a transitional type between magmatic rocks and sedimentary rocks, and it is also one of the important reservoir rock types. It has the advantages of thick pay information and large reserves (Li, et al. 2015). The tuff reservoir is very complex and special and has both lithologic characteristics in terms of petrophysics and diagenesis (ZHANG, et al. 2012). The low degree of development of original porosity and poor connectivity of pore throats indicate that such reservoir is tight reservoir (Zeng, et al. 2021). At present, the well known athrogenic rock reservoir in the world including East Anatolia Basin in Turkey (Gecer-Buyukutku, et al. 2005), Bohai Bay in China (Zhao, et al. 1996), Erlian (Guo, et al. 2013) and Hailar (Yu, et al. 2013) basins.

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Vincke, O. "An estimation of bulk moduli of sandstones as a function of confining pressure using their petrographic and petrophysic description." In Rock Mechanics in Petroleum Engineering. Society of Petroleum Engineers, 1994. http://dx.doi.org/10.2118/28038-ms.

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Da Fies, G., D. Peck, M. Dutko, and G. Mishuris. "On Averaging of Toughness Heterogeneity When Modelling Hydraulic Fracture Evolution." In 56th U.S. Rock Mechanics/Geomechanics Symposium. ARMA, 2022. http://dx.doi.org/10.56952/arma-2022-2135.

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ABSTRACT: In this paper we describe various approaches used to capture heterogeneity within the reservoir undergoing hydraulic fracturing treatment and their implication on modelling of fracture propagation. In highly laminated reservoirs with soft and/or weak layers, capturing heterogeneity at an appropriate resolution is the key for successful prediction fracture growth and other crucial treatment parameters. Our focus is on studying several strategies to average fracture toughness and assess their suitability for use in advanced computational methods such as FE/BEM. In practice the well log and petrophysical data deduced from various measurements and observations are upscaled and/or homogenized to the spatial approximation size. The fracture toughness is one of the most delicate physical parameters and application of the homogenization techniques are rather uncertain, hence any proposed averaging will depend on process conditions and the toughness distribution. We propose and analyse a notion of an average toughness and show that it is a process dependent variable and provide some recommendations how to implement the defined measure into the numerical modelling. As an example, we use periodic distributions and consider model without leak off that allows us straightforward handling different regimes (toughness/viscosity). 1. INTRODUCTION Typically, when using computational methods such as Finite Element Method, the well log and petrophysical data obtained from various measurements and observations are upscaled and/or "homogenized" to the element size. From all in-situ parameters, toughness is one of the most delicate physical parameters to handle, as application of the homogenization techniques are rather questionable here as commented on by Caiulo and Kachanov (2010) and Kachanos (1994). Compared to other types of fracture evolution, hydraulic fracturing is probably the most stable crack propagation process and thus, fortunately, some estimates can be provided here. We estimate errors introduced by various strategies to incorporate heterogeneous fracture toughness into numerical modelling (Dontsov and Suarez-Rivera (2021), Da Fies et al. (2021)). We use periodic distributions and consider model without leak off that allows us straightforward handling different regimes (toughness/viscosity). For the simulations, we use an extremely effective in house-built time – space adaptive solver utilizing main ideas from those reported by Wrobel and Mishuris (2015). The solver is capable to compute rather arbitrary distribution of the toughness.

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El Sherbeny, Wael I. A., Ashraf Rushdi Baghdady, Lobna Mohamed Sharaf, Ali El Sayed Farag, Mohamed Yousef Rizk, and Abbas Khaksar. "Petrophysical Characteristics and Implications on Both Wellbore Strengthening and Wellbore Stability: A Case Study, Balsam Field, Nile Delta, Egypt." In SPE Asia Pacific Oil & Gas Conference and Exhibition. SPE, 2022. http://dx.doi.org/10.2118/210728-ms.

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Abstract Improper drilling fluid formulation still trigger the wellbore stability challenges and the main reason is the incompatibility of drilling fluids with formations characteristics. Thus, it is important to understand the interaction between rock and drilling fluids. This case study represents an approach of utilizing the petrophysics evaluation of both Abu Madi and Qawasim formations in providing an additional tool to understand the drilling challenges root causes and provide a mitigation plan. A petrophysical evaluation constructed for three wells in Balsam field with focus on petrophysical parameters related to both wellbore stability and wellbore strengthening such as shale volume (Vsh), porosity (phi), permeability (k), formation water salinity besides the litho-facies and the clay types and mineralogy. For the same selected wells, both drilling and geomechanics events delineated from both the daily drilling reports (DDR's) and drilling fluids report (DMR's) plotted against the petrophysics log parameters to understand the relationship between formation characteristics and drilling challenges as a part of pre-drill risk assessment considering the petrophysics parameters. Tight spots, pack off and differential sticking were the major drilling challenges through the studied three wells. The study concluded that some of fluid types/chemistry were not adequate to interact with both shale of both Abu Madi and Qawasim formations, moreover the study revealed that the wellbore strengthening package need to be modified. Shale volume (Vsh), clay mineralogy from petrophysics analysis linked with wellbore stability events as a part of risk assessment phase using petrophysical parameters. The same information will help the drilling fluids team to formulate the clay inhibitive recipe of the utilized fluids, optimize the water activity (Aw) using the optimum mud salinity to minimize the pressure transmission and potential time-dependent failures. The other petrophysics parameters such as porosity, permeability and pore throat size utilized for dual functions; the first function was in risk assessment to delineate the troublesome zones that could be related to potential invasion, downhole losses, differential sticking and reservoir damages meanwhile the second function was useful in wellbore strengthening simulation as an input data with other well general information to optimize the wellbore strengthening additives based on reservoir characterization using a specific wellbore strengthening software. Utilizing the petrophysics information can help in both pre-drill risk assessment and for better understanding the mechanisms of subsurface challenges. Moreover, the petrophysical data will adequately assist drilling fluids team to optimize/customize both wellbore stability and wellbore strengthening additives and all related mud parameters to efficiently stabilize the troublesome formations physically and chemically in additions to the mechanical action through exact geomechanics mud window.

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Zhou, Yuhai, Wenyu Zhang, and Ding Zhu. "Well Stimulation Evaluation in Horizontal Wells with Emphasis on Petrophysics and Rock Mechanics: A Case Study in Deep, Tight Carbonate Formation." In International Petroleum Technology Conference. International Petroleum Technology Conference, 2019. http://dx.doi.org/10.2523/19118-ms.

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Prochnow, Shane J., Ronald Brown, Jarrad Paul Rexilius, and Michael J. Fields. "Linking Rock Mechanic Petrophysics to Proppant Selection in the Wolfcamp: Capitalizing on Log Based Value of Information." In SPE/CSUR Unconventional Resources Conference – Canada. Society of Petroleum Engineers, 2014. http://dx.doi.org/10.2118/171606-ms.

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Sankaranarayanan, Bhuvaneswari, Aria Abubakar, David F. Allen, and Ivan Diaz Granados. "Automating the Log Interpretation Workflow Using Machine Learning." In SPE Annual Technical Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/205950-ms.

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Abstract Log interpretation is the task of analyzing and processing well logs to generate the subsurface properties around wells. A direct application of machine learning (ML) to this task is to train an ML model for predicting properties in target wells given well logs (data) and properties (labels) in a set of training wells in the same field and/or region. Our ML model of choice for predicting the desired properties is the decision tree-based learning algorithm called random forests (RF). We also devise a mechanism to automatically tune the hyperparameters of this algorithm depending on the data in the training wells. This eliminates the tedious task of carefully tuning the hyperparameters for every new set of training wells and provides a one-click solution. In addition to predicting the properties, we compute the uncertainty in the predicted properties in the form of prediction intervals using the concept of quantile regression forests (QRF). We test our workflow on two use cases. First, we consider a petrophysics use case on an unconventional land dataset to predict the petrophysical properties such as water saturation, total porosity, volume of clay, and total organic carbon from petrophysics logs. Then, we consider a geomechanics use case on a conventional offshore dataset to predict the lithology, pore pressure, and rock mechanical properties. We obtain a good prediction performance on both use cases. The uncertainty estimates also complement the ML model's prediction of the properties by explaining the various correlations that are found to be existing among them based on domain knowledge. The entire workflow of automating the tuning of hyperparameters and training the ML model to predict the properties along with its estimate of uncertainty provide a complete solution to apply the ML workflow for automated log interpretation.

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Reports on the topic "Petrophysics and rock mechanics"

Francke, C., and S. Saeb. Rock mechanics activities at the Waste Isolation Pilot Plant. Office of Scientific and Technical Information (OSTI), December 1996. http://dx.doi.org/10.2172/515494.

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Plesha, Michael E., and Bezalel C. Haimson. An Investigation of the Mechanics of Discontinuities in Rock. Fort Belvoir, VA: Defense Technical Information Center, March 1990. http://dx.doi.org/10.21236/ada220244.

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Hardy, R. D. Event triggered data acquisition in the Rock Mechanics Laboratory. Office of Scientific and Technical Information (OSTI), March 1993. http://dx.doi.org/10.2172/10177063.

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Udd, J. E. An overview of developments in rock mechanics in Canada - 1983-1987. Natural Resources Canada/CMSS/Information Management, 1987. http://dx.doi.org/10.4095/328600.

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Hedley, D. G. H., and J. E. Udd. Index of rock mechanics research reports: CANMET/mining research laboratories, 1964-1984. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 1986. http://dx.doi.org/10.4095/305053.

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Hardy, R. D. Event triggered data acquisition in the Rock Mechanics Laboratory upgrades and revisions. Office of Scientific and Technical Information (OSTI), June 1997. http://dx.doi.org/10.2172/505267.

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Joseph, P. G., H. H. Einstein, and R. V. Whitman. A Literature Review of Geotechnical Centrifuge Modeling with Particular Emphasis on Rock Mechanics. Fort Belvoir, VA: Defense Technical Information Center, June 1988. http://dx.doi.org/10.21236/ada213793.

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Francois Heuze, Peter Smeallie, Derek Elsworth, and Joel L. Renner. Rock Mechanics and Enhanced Geothermal Systems: A DOE-sponsored Workshop to Explore Research Needs. Office of Scientific and Technical Information (OSTI), October 2003. http://dx.doi.org/10.2172/910628.

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Aston, T. R. C. Sixth international congress on rock mechanics, 1987 - post congress tour information, Sydney Coalfield, N.S. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 1986. http://dx.doi.org/10.4095/304871.

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Michael S. Bruno. Fundamental Research on Percussion Drilling: Improved rock mechanics analysis, advanced simulation technology, and full-scale laboratory investigations. Office of Scientific and Technical Information (OSTI), December 2005. http://dx.doi.org/10.2172/886017.

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