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Academic literature on the topic 'Facies (Geology) Analysis'

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Published: 10 December 2022
Last updated: 28 January 2023

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Journal articles on the topic "Facies (Geology) Analysis"

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Anderton, R. "Clastic facies models and facies analysis." Geological Society, London, Special Publications 18, no. 1 (1985): 31–47. http://dx.doi.org/10.1144/gsl.sp.1985.018.01.03.

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Postma, George. "The geology of fluvial deposits, sedimentary facies, basin analysis and petroleum geology." Sedimentary Geology 110, no. 1-2 (May 1997): 149–50. http://dx.doi.org/10.1016/s0037-0738(96)00081-4.

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Pendrel, John, and Henk Schouten. "Facies — The drivers for modern inversions." Leading Edge 39, no. 2 (February 2020): 102–9. http://dx.doi.org/10.1190/tle39020102.1.

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It is common practice to make facies estimations from the outcomes of seismic inversions and their derivatives. Bayesian analysis methods are a popular approach to this. Facies are important indicators of hydrocarbon deposition and geologic processes. They are critical to geoscientists and engineers. The application of Bayes’ rule maps prior probabilities to posterior probabilities when given new evidence from observations. Per-facies elastic probability density functions (ePDFs) are constructed from elastic-log and rock-physics model crossplots, over which inversion results are superimposed. The ePDFs are templates for Bayesian analysis. In the context of reservoir characterization, the new information comes from seismic inversions. The results are volumes of the probabilities of occurrences of each of the facies at all points in 3D space. The concepts of Bayesian inference have been applied to the task of building low-frequency models for seismic inversions without well-log interpolation. Both a constant structurally compliant elastic trend approach and a facies-driven method, where models are constructed from per-facies trends and initial facies estimates, have been tested. The workflows make use of complete 3D prior information and measure and account for biases and uncertainties in the inversions and prior information. Proper accounting for these types of effects ensures that rock-physics models and inversion data prepared for reservoir property analysis are consistent. The effectiveness of these workflows has been demonstrated by using a Gulf of Mexico data set. We have shown how facies estimates can be effectively used to build reasonable low-frequency models for inversion, which obviate the need for well-log interpolation and provide full 3D variability. The results are more accurate probability-based net-pay estimates that correspond better to geology. We evaluate the workflows by using several measures including precision, confidence, and probabilistic net pay.
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Saraswat, Puneet, and Mrinal K. Sen. "Artificial immune-based self-organizing maps for seismic-facies analysis." GEOPHYSICS 77, no. 4 (July 1, 2012): O45—O53. http://dx.doi.org/10.1190/geo2011-0203.1.

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Seismic facies, combined with well-log data and other seismic attributes such as coherency, curvature, and AVO, play an important role in subsurface geological studies, especially for identification of depositional structures. The effectiveness of any seismic facies analysis algorithm depends on whether or not it is driven by local geologic factors, the absence of which may lead to unrealistic information about subsurface geology, depositional environment, and lithology. This includes proper identification of number of classes or facies existing in the data set. We developed a hybrid waveform classification algorithm based on an artificial immune system and self-organizing maps (AI-SOM), that forms the class of unsupervised classification or automatic facies identification followed by facies map generation. The advantage of AI-SOM is that, unlike, a stand-alone SOM, it is more robust in the presence of noise in seismic data. Artificial immune system (AIS) is an excellent data reduction technique providing a compact representation of the training data; this is followed by clustering and identification of number of clusters in the data set. The reduced data set from AIS processing serves as an excellent input to SOM processing. Thus, facies maps generated from AI-SOM are less affected by noise and redundancy in the data set. We tested the effectiveness of our algorithm with application to an offshore 3D seismic volume from F3 block in the Netherlands. The results confirmed that we can better interpret an appropriate number of facies in the seismic data using the AI-SOM approach than with a conventional SOM. We also examined the powerful data-reduction capabilities of AIS and advantages the of AI-SOM over SOM when data under consideration were noisy and redundant.
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Coletti, Giovanni, Giulia Bosio, Alberto Collareta, John Buckeridge, Sirio Consani, and Akram El Kateb. "Palaeoenvironmental analysis of the Miocene barnacle facies: case studies from Europe and South America." Geologica Carpathica 69, no. 6 (December 1, 2018): 573–92. http://dx.doi.org/10.1515/geoca-2018-0034.

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Abstract Acorn barnacles are sessile crustaceans common in shallow-water settings, both in modern oceans and in the Miocene geological record. Barnacle-rich facies occur from polar to equatorial latitudes, generally associated with shallow-water, high-energy, hard substrates. The aim of this work is to investigate this type of facies by analysing, from the palaeontological, sedimentological and petrographical points of view, early Miocene examples from Northern Italy, Southern France and South-western Peru. Our results are then compared with the existing information on both modern and fossil barnacle-rich deposits. The studied facies can be divided into two groups. The first one consists of very shallow, nearshore assemblages where barnacles are associated with an abundant hard-substrate biota (e.g., barnamol). The second one includes a barnacle-coralline algae association, here named “barnalgal” (= barnacle / red algal dominated), related to a deeper setting. The same pattern occurs in the distribution of both fossil and recent barnacle facies. The majority of them are related to very shallow, high-energy, hard-substrate, a setting that represents the environmental optimum for the development of barnacle facies, but exceptions do occur. These atypical facies can be identified through a complete analysis of both the skeletal assemblage and the barnacle association, showing that barnacle palaeontology can be a powerful tool for palaeoenvironmental reconstruction.
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Staňová, Sidónia, Ján Soták, and Norbert Hudec. "Markov Chain analysis of turbiditic facies and flow dynamics (Magura Zone, Outer Western Carpathians, NW Slovakia)." Geologica Carpathica 60, no. 4 (August 1, 2009): 295–305. http://dx.doi.org/10.2478/v10096-009-0021-4.

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Markov Chain analysis of turbiditic facies and flow dynamics (Magura Zone, Outer Western Carpathians, NW Slovakia)Methods based on the Markov Chains can be easily applied in the evaluation of order in sedimentary sequences. In this contribution Markov Chain analysis was applied to analysis of turbiditic formation of the Outer Western Carpathians in NW Slovakia, although it also has broader utilization in the interpretation of sedimentary sequences from other depositional environments. Non-random facies transitions were determined in the investigated strata and compared to the standard deep-water facies models to provide statistical evidence for the sedimentological interpretation of depositional processes. As a result, six genetic facies types, interpreted in terms of depositional processes, were identified. They comprise deposits of density flows, turbidity flows, suspension fallout as well as units which resulted from syn- or post-depositional deformation.
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Gao, Dengliang. "Latest developments in seismic texture analysis for subsurface structure, facies, and reservoir characterization: A review." GEOPHYSICS 76, no. 2 (March 2011): W1—W13. http://dx.doi.org/10.1190/1.3553479.

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In exploration geology and geophysics, seismic texture is still a developing concept that has not been sufficiently known, although quite a number of different algorithms have been published in the literature. This paper provides a review of the seismic texture concepts and methodologies, focusing on latest developments in seismic amplitude texture analysis, with particular reference to the gray level co-occurrence matrix (GLCM) and the texture model regression (TMR) methods. The GLCM method evaluates spatial arrangements of amplitude samples within an analysis window using a matrix (a two-dimensional histogram) of amplitude co-occurrence. The matrix is then transformed into a suite of texture attributes, such as homogeneity, contrast, and randomness, which provide the basis for seismic facies classification. The TMR method uses a texture model as reference to discriminate among seismic features based on a linear, least-squares regression analysis between the model and the data within an analysis window. By implementing customized texture model schemes, the TMR algorithm has the flexibility to characterize subsurface geology for different purposes. A texture model with a constant phase is effective at enhancing the visibility of seismic structural fabrics, a texture model with a variable phase is helpful for visualizing seismic facies, and a texture model with variable amplitude, frequency, and size is instrumental in calibrating seismic to reservoir properties. Preliminary test case studies in the very recent past have indicated that the latest developments in seismic texture analysis have added to the existing amplitude interpretation theories and methodologies. These and future developments in seismic texture theory and methodologies will hopefully lead to a better understanding of the geologic implications of the seismic texture concept and to an improved geologic interpretation of reflection seismic amplitude.
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He, Qing Kun, and Chang Ying Shi. "Application of Electron Probe Microanalyzer (EPMA) to Depositional Environment Identification of Sedimentary Rock." Advanced Materials Research 881-883 (January 2014): 1795–98. http://dx.doi.org/10.4028/www.scientific.net/amr.881-883.1795.

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s: Electron microprobe technology is widely used to component analysis of metals, minerals and geology. Elements of sedimentary rock including B, Ga, Ba, Sr, Co, V, Cr, Mn, Fe, Ni were analyzed by EPMA respectively. It was discussed that marine faces and continental facies, oxidation environment and reducing environment, the depth of water and salinity influence on sedimentary rock, respectively. Then the influence of marine faces, continental faces, oxidation environment, reducing environment and the depth of water and salinity on sedimentary rock was discussed respectively. The results show that EPMA is a useful instrument to analyze the components of sedimentary rock.
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Verdiansyah, Okki. "A Desktop Study to Determine Mineralization Using Lineament Density Analysis at Kulon Progo Mountains, Yogyakarta and Central Java Province, Indonesia." Indonesian Journal of Geography 51, no. 1 (April 30, 2019): 31. http://dx.doi.org/10.22146/ijg.37442.

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A geological study was conducted in Kulon Progo and its surrounding areas (Kulon Progo and Purworejo Regency). It focused on regional geology, tectonic configuration, geodynamics and magmatism, lithology and volcanology, and mineralization. Although there has been considerable research of mineralization in the area—particularly in Kokap (Kulon Progo Regency), Bagelen (Purworejo Regency) and Gupit (Magelang Regency), the potential of precious metals has not been determined due to data limitations. The study combined qualitative and semi-quantitative methods using a desktop geologic analysis, which facilitates lithology interpretation, volcanic boundary system, and lineament density assessment. The geology of the region is composed of an ancient volcanic complex of the Old Andesite Formation formed during the Late Oligocene-Miocene, and the mineralization in Kokap, Bagelen, and Gupit is epithermal. Based on the analysis results, the mineralization occurs in the central to proximal facies of the paleo-volcano, and the system ranges from 2.2 to 3.8 km in diameter. The manual analysis of the lineament density showed that the main direction of the lineaments was SE-NW with a maximum density of 2025.9 m/km2 and an anomaly limit of >1800 m/km2. In the combined semi-automatic analysis, the maximum density was 8.3 km/km2. The target area of mineralization included four anomalous areas, namely Bagelen-Kokap, Salaman, Kaligesing, and Loano, associated with the central and proximal facies of each small paleo-volcano.
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Fukuda, Sojiro, and Hajime Naruse. "Shape difference of mud clasts depending on depositional facies: application of newly modified elliptic Fourier analysis to hybrid event beds." Journal of Sedimentary Research 90, no. 10 (October 1, 2020): 1410–35. http://dx.doi.org/10.2110/jsr.2020.67.

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ABSTRACT Hybrid event beds are the deposits from sediment gravity flows that change their rheological behavior through their passage, entraining muddy sediments and damping turbulence. Muddy facies of hybrid event beds are often associated with abundant mud clasts which show a wide variety of size and shape. The variation of clast occurrence in hybrid event beds is expected to preserve the information of entrainment and transport processes of muddy sediments in submarine density currents. However, previous analyses of hybrid event beds have focused on describing the overall clast occurrence rather than the statistical size and shape analyses because traditional shape parameters are incapable of characterizing the complex shape of mud clasts. Here, a new quantitative grain-shape analysis of mud clasts is conducted and allows visualization of the spatial variation of clast size and shape, which suggests the wide variety of origin and transport systems of entrained mud clasts. This new method revises the traditional elliptic Fourier analysis, substituting Fourier power spectra (FPS) for traditional elliptic Fourier descriptors to overcome the mirror-wise shape problem. Further, principal-component analysis is shown to capture significant shape attributes more effectively than traditional shape parameters. The proposed method is applied to mud clasts in sediment-gravity-flow deposits in the lower Pleistocene Otadai Formation, central Japan. Results imply that there are distinctive shape and size differences of mud clasts that are strongly associated with depositional facies rather than the distance from the source. The clasts have a higher angularity than other facies in the debrite intervals in hybrid event beds. It is also shown that clasts in sandy, structureless facies have different characteristics in shapes based on elongation and convexity compared to laminated facies. Comparison between different shape-analysis methods demonstrates that none of the traditional methods are able to visualize these trends as effectively as the method presented herein. These results highlight the importance of the quantitative shape analysis of sediment grains and the effectiveness of FPS-based elliptic Fourier analysis.
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Dissertations / Theses on the topic "Facies (Geology) Analysis"

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Elwerfalli, Hamed Omar. "Facies analysis of early Tertiary carbonates of northeast Libya." Thesis, University of Southampton, 1997. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.242780.

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Garnes, William Thomas. "Subsurface Facies Analysis of the Devonian Berea Sandstone in Southeastern Ohio." Bowling Green State University / OhioLINK, 2014. http://rave.ohiolink.edu/etdc/view?acc_num=bgsu1415920946.

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Higgs, R. "A facies analysis of the Bude Formation (Lower Westphalian), SW England." Thesis, University of Oxford, 1986. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.371512.

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Morin, Jean. "Facies analysis of Lower Permian cyclic carbonates, west-central Ellesmere Island, Canadian Arctic." Thesis, University of Ottawa (Canada), 1992. http://hdl.handle.net/10393/7553.

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At least 36 decametre-scale, largely symmetric high-frequency cycles spanning approximately 15 Ma make up the carbonate-dominated succession of Lower Permian sequence 3 of the Sverdrup Basin in Fosheim and Hamilton peninsulas. These cycles record a rift pulse caracterized by the uplift, passive subsidence, collapse and passive subsidence of the Fosheim-Hamilton subbasin and show that during the rifting phase of the Sverdrup Basin deposition of conformity-bounded sequences was tectonically rather than eustatically controlled. The active rifting-phase of the Sverdrup Basin comprises four unconformity-bounded sequences that range in age from Visean to Kungurian. The third-sequence in Fosheim and Hamilton peninsulas area, west central Ellesmere Island comprises six formations. The Canyon Fiord Formation is composed of lithofacies ranging from basin margin fluvial to marine siliciclastics. The Belcher Channel, Antoinette, Tanquary and Nansen formations are made up of inner- to midshelf carbonates that encompass the Mount Bayley Formation, a thick evaporite succession deposited within the Fosheim-Hamilton subbasin. Petrographic analysis of the carbonate-dominated facies in sequence 3 has delimited nineteen platformal facies representing lagoonal, barrier and shoal, reefal and non-reefal mid-shelf depositional environments. These facies are organized into high-frequency depositional cycles that record the interplay between eustasy, tectonism and sediment supply. In order to facilitate their regional analysis, cycles were grouped into five idealized cycles. From proximal to distal, these cycles include: Sandstone-Grainstone; Grainstone-Palaeoaplysinid; Packstone-Phylloid; Wackestone; and Anhydrite cycles. These high-frequency cycles are grouped into a Pre-, Syn- and Post-evaporite cyclic assemblages, each of which possess an unique stacking pattern. The Pre-evaporite Assemblage comprises 9 cycles characterized by relatively similar thickness and composition. High-frequency cyclicity within this assemblage was controlled by glacio-eustatic oscillations with only local tectonic influence. (Abstract shortened by UMI.)
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Cripps, David W. "A facies analysis of the upper great oolite group in central and eastern England." Thesis, Aston University, 1986. http://publications.aston.ac.uk/14357/.

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Banjade, Bharat. "Subsurface Facies Aanalysis of the Cambrian Conasauga Formation and Kerbel Formation in East - Central Ohio." Bowling Green State University / OhioLINK, 2011. http://rave.ohiolink.edu/etdc/view?acc_num=bgsu1322525944.

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Harwood, C. "A facies analysis of shale-nodular limestone cycles from the Upper Ordovician of the Oslo region, Norway." Thesis, University of Liverpool, 1985. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.356265.

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Stouten, Craig A. "Subsurface Facies Analysis of the Clinton Sandstone, Located in Perry, Fairfield, and Vinton Counties." Bowling Green State University / OhioLINK, 2014. http://rave.ohiolink.edu/etdc/view?acc_num=bgsu1416147053.

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Kassos, Gabriel Philip Steltenpohl Mark G. "Structural, isotropic, and kinematic analysis of eclogite-facies shear zones and associated structures, Lofoten, North Norway." Auburn, Ala, 2008. http://repo.lib.auburn.edu/EtdRoot/2008/SUMMER/Geology_and_Geography/Thesis/Kassos_Gabriel_39.pdf.

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Nwaodua, Emmanuel Chukwukamadu. "Subsurface Facies Analysis of the Rose Run Sandstone Formation in south eastern Ohio." Bowling Green State University / OhioLINK, 2008. http://rave.ohiolink.edu/etdc/view?acc_num=bgsu1213202313.

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Books on the topic "Facies (Geology) Analysis"

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P, Anadon, Cabrera Ll, and Kelts K. R, eds. Lacustrine facies analysis. Oxford: Blackwell Scientific Publications, 1991.

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Diessel, C. F. K. Coal-bearing depositional systems. Berlin: Springer-Verlag, 1992.

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Eiríksson, Jón. Facies analysis of the Breidavík Group sediments on Tjörnes, north Iceland. Reykjavík: Iceland Museum of Natural History, 1985.

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The geology of fluvial deposits: Sedimentary facies, basin analysis, and petroleum geology. Berlin: Springer, 1996.

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Miall, Andrew D. The geology of fluvial deposits: Sedimentary facies, basin analysis, and petroleum geology. 4th ed. Berlin: Springer, 2011.

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G, Reading H., ed. Sedimentary environments: Processes, facies, and stratigraphy. 3rd ed. Cambridge, Mass: Blackwell Science, 1996.

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Morton, Robert A. Depositional history, facies analysis, and production characteristics of hydrocarbon-bearing sediments, offshore Texas. Austin, Tex: Bureau of Economic Geology, University of Texas at Austin, 1985.

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Meijer-Drees, N. C. Sedimentology and facies analysis of Devonian rocks, southern District of Mackenzie, Northwest Territories, Canada. [Utrecht: Instituut voor Aardwetenschappen der Rijksuniversiteit Utrecht, 1989.

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Guy, Plint A., and Reading H. G, eds. Sedimentary facies analysis: A tribute to the research and teaching of Harold G. Reading. Oxford, England: Blackwell Science, 1995.

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Graese, Anne M. Facies analysis of the Ordovician Maquoketa Group and adjacent strata in Kane County, northeastern Illinois. Champaign, Ill: Illinois State Geological Survey, 1991.

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Book chapters on the topic "Facies (Geology) Analysis"

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Wilmsen, Markus, Marisa Storm, Franz Theodor Fürsich, and Mahmoud Reza Majidifard. "Integrated Stratigraphy and Facies Analysis of the Upper Albian–Turonian (Cretaceous) Debarsu Formation (Yazd Block, Central Iran)." In Springer Geology, 623–27. Cham: Springer International Publishing, 2014. http://dx.doi.org/10.1007/978-3-319-04364-7_120.

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Benvenuti, Antonio, and Andrea Moscariello. "Seismic Geometry and Facies Analysis of a Quaternary Tunnel Glacial Valley Infill in the Dutch North Sea: Preliminary Results." In Springer Geology, 781–85. Cham: Springer International Publishing, 2014. http://dx.doi.org/10.1007/978-3-319-04364-7_147.

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Wilmsen, Markus, and Emad Nagm. "Integrated Stratigraphy (Bio- and Sequence Stratigraphy) and Facies Analysis of the Upper Cenomanian–Turonian (Lower Upper Cretaceous) in the Eastern Desert, Egypt." In Springer Geology, 619–22. Cham: Springer International Publishing, 2014. http://dx.doi.org/10.1007/978-3-319-04364-7_119.

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Pacht, Jory A., Bruce Bowen, Bernard L. Shaffer, and William R. Pottorf. "Systems Tracts, Seismic Facies, and Attribute Analysis Within a Sequence-Stratigraphic Framework—Example from the Offshore Louisiana Gulf Coast." In Frontiers in Sedimentary Geology, 21–38. New York, NY: Springer New York, 1993. http://dx.doi.org/10.1007/978-1-4757-0160-9_2.

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Dim, Chidozie Izuchukwu Princeton. "Regional Geology, Basin Forming Tectonics and Basin Fills of Southern Benue Trough and Anambra Basin in Afikpo Area." In Facies Analysis and Interpretation in Southeastern Nigeria's Inland Basins, 9–17. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-68188-3_2.

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Wong, H. Kin. "Use of Multivariate Statistical Analysis in Geology — Two Examples." In Facets of Modern Biogeochemistry, 74–80. Berlin, Heidelberg: Springer Berlin Heidelberg, 1990. http://dx.doi.org/10.1007/978-3-642-73978-1_8.

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Dim, Chidozie Izuchukwu Princeton. "Outcrop-Based Field Geologic Studies and Description of Measured Stratigraphic Successions." In Facies Analysis and Interpretation in Southeastern Nigeria's Inland Basins, 19–38. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-68188-3_3.

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Linol, Bastien, Maarten J. de Wit, Erika Barton, Francois Guillocheau, Michiel C. J. de Wit, and Jean-Paul Colin. "Facies Analyses, Chronostratigraphy and Paleo-Environmental Reconstructions of Jurassic to Cretaceous Sequences of the Congo Basin." In Geology and Resource Potential of the Congo Basin, 135–61. Berlin, Heidelberg: Springer Berlin Heidelberg, 2014. http://dx.doi.org/10.1007/978-3-642-29482-2_8.

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Collins, D. R., and J. H. Doveton. "Automated Correlation Based On Markov Analysis Of Vertical Successions And Walther's Law." In Computers in Geology - 25 Years of Progress. Oxford University Press, 1994. http://dx.doi.org/10.1093/oso/9780195085938.003.0015.

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Walther's Law of Facies (1894) states that facies overlying one another comformably were formed in geographically contiguous environments. This vertical-lateral linkage is the basis for our automated method of stratigraphic correlation. The probabilities of vertical adjacency of different lithologies are estimated by embedded Markov chain analysis of sequences to be correlated. These probabilities are transformed to dissimilarities and used as elements within a dynamic programming sequence comparison. Trajectory tracking of cumulative thicknesses between the two sequences provides an auxiliary criterion to incorporate factors of sedimentation rate and compaction. Stratigraphic correlation is simultaneously simple and complex. The operation is fundamentally one of pattern recognition, whose principles can be grasped easily by any geology student. One source of complexity is caused by the fact that most successions are composed of a relatively small number of distinctive rock types. Within each succession, they are ordered as a linear chain in which loosely repetitive sequences are often perceived as "cycles" or "rhythms." As a result, the correlation between two adjacent successions may be ambiguous, so that several competing alternatives may be equally valid candidates for the "true" correlation. The situation is made still more disma! by the knowledge that erosional events may have removed entire stratigraphic segments and that periods of non-deposition may have caused gaps. In the opinion of Ager (1973), the gap is more important than the record. Even if a "complete" lithology record were available, it is unlikely that the successions in two separate locations would be identical. Lateral facies changes result in differences of lithology within correlative intervals. Equivalence or "similarity" of rock type is not the only criterion used in correlation. Thicknesses are a secondary source of information for correlation decisions. Similarity in thickness of equivalent lithologies between successions often implies a greater likelihood of their correlation. However, exceptions to this rule commonly are observed in the lateral thinnings and thickenings caused by both lateral facies changes and differential compaction. The simpler aspects of correlation suggest that practical automated correlation procedures are both feasible and desirable. Even if programmed decisions cannot be characterized absolutely as "objective," they can at least be made consistent.
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Chaves, H. A. F. "Characteristic Analysis As An Oil Exploration Tool." In Computers in Geology - 25 Years of Progress. Oxford University Press, 1994. http://dx.doi.org/10.1093/oso/9780195085938.003.0013.

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Characteristic analysis is well known in mineral resources appraisal and has proved useful for petroleum exploration. It also can be used to integrate geological data in sedimentary basin analysis and hydrocarbon assessment, considering geological relationships and uncertainties that result from lack of basic geological knowledge, A generalization of characteristic analysis, using fuzzy-set theory and fuzzy logic, may prove better for quantification of geologic analogues and also for description of reservoir and sedimentary facies. Characteristic analysis is a discrete multivariate procedure for combining and interpreting data; Botbol (1971) originally proposed its application to geology, geochemistry, and geophysics. It has been applied mainly in the search for poorly exposed or concealed mineral deposits by exploring joint occurrences or absences of mineralogical, lithological, and structural attributes (McCammon et al., 1981). It forms part of a systematic approach to resource appraisal and integration of generalized and specific geological knowledge (Chaves, 1988, 1989; Chaves and Lewis, 1989). The technique usually requires some form of discrete sampling to be applicable—generally a spatial discretization of maps into cells or regular grids (Melo, 1988). Characteristic analysis attempts to determine the joint occurrences of various attributes that are favorable for, related to, or indicative of the occurrence of the desired phenomenon or target. In geological applications, the target usually is an economic accumulation of energy or mineral resources. Applying characteristic analysis requires the following steps: 1) the studied area is sampled using a regular square or rectangular grid of cells; 2) in each cell the favorabilities of the variables are expressed in binary or ternary form; 3) a model is chosen that indicates the cells that include the target (Sinding-Larsen et al, 1979); and 4) a combined favorability map of the area is produced that points out possible new targets. The favorability of individual variables is expressed either in binary form— assigning a value of +1 to favorable and a value of 0 to unfavorable or unevaluated variables—or in ternary form if the two states represented by 0 are distinguishable—the value +1 again means favorable, the value —1 means unfavorable, and the value 0 means unevaluated.
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Conference papers on the topic "Facies (Geology) Analysis"

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Bertozzi, G., W. Paltrinieri, D. Di Biase, A. Artoni, and E. Mutti. "Integration of Outcrop, Core and Wireline-Log Facies Analysis for Reservoir." In EAGE Conference on Geology and Petroleum Geology of the Mediterranean and Circum-Mediterranean Basins. European Association of Geoscientists & Engineers, 2000. http://dx.doi.org/10.3997/2214-4609.201406056.

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Talarico, Erick, Dario Grana, Leandro Figueiredo, and Sinesio Pesco. "Analysis of multiple solutions in seismic facies inversion for complex geology." In International Congress of the Brazilian Geophysical Society&Expogef. Brazilian Geophysical Society, 2019. http://dx.doi.org/10.22564/16cisbgf2019.037.

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Das, S., A. Wray, and R. Das. "Geo-mechanical Electro-facies Analysis Using High-resolution Unconfined Compressive Strength Derived from High-res Mechanical Property Image." In Fourth EAGE Borehole Geology Workshop. European Association of Geoscientists & Engineers, 2021. http://dx.doi.org/10.3997/2214-4609.2021626016.

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Gaillot, Jérémie, A. Virgone, B. Caline, and G. Frébourg and F. Gisquet. "The Khuff Formation in the Middle East: New Insight into Regional Stratigraphy and Palaeoenvironmental Reconstruction using Bio-assemblages and Facies Analysis." In Third Arabian Plate Geology Workshop. Netherlands: EAGE Publications BV, 2011. http://dx.doi.org/10.3997/2214-4609.20144045.

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Boyd, Melissa D., Craig S. Feibel, Frederick Kyalo Manthi, Carol V. Ward, and J. Michael Plavcan. "WHY LOMEKWI? THE GEOLOGY AND DEPOSITIONAL CONTEXT OF THE LOMEKWI 3 ARCHAEOLOGICAL SITE IN KENYA: A SEDIMENTARY FACIES ANALYSIS." In GSA Annual Meeting in Denver, Colorado, USA - 2016. Geological Society of America, 2016. http://dx.doi.org/10.1130/abs/2016am-284611.

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Asedegbega, Jerome, Oladayo Ayinde, and Alexander Nwakanma. "Application of Machine Learniing For Reservoir Facies Classification in Port Field, Offshore Niger Delta." In SPE Nigeria Annual International Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/207163-ms.

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Abstract Several computer-aided techniques have been developed in recent past to improve interpretational accuracy of subsurface geology. This paradigm shift has provided tremendous success in variety of Machine Learning Application domains and help for better feasibility study in reservoir evaluation using multiple classification techniques. Facies classification is an essential subsurface exploration task as sedimentary facies reflect associated physical, chemical, and biological conditions that formation unit experienced during sedimentation activity. This study however, employed formation samples for facies classification using Machine Learning (ML) techniques and classified different facies from well logs in seven (7) wells of the PORT Field, Offshore Niger Delta. Six wells were concatenated during data preparation and trained using supervised ML algorithms before validating the models by blind testing on one well log to predict discrete facies groups. The analysis started with data preparation and examination where various features of the available well data were conditioned. For the model building and performance, support vector machine, random forest, decision tree, extra tree, neural network (multilayer preceptor), k-nearest neighbor and logistic regression model were built after dividing the data sets into training, test, and blind test well data. Results of metric score for the blind test well estimated for the various models using Jaccard index and F1-score indicated 0.73 and 0.82 for support vector machine, 0.38 and 0.54 for random forest, 0.78 and 0.83 for extra tree, 0.91 and 0.95 for k-nearest neighbor, 0.41 and 0.56 for decision tree, 0.63 and 0.74 for logistic regression, 0.55 and 0.68 for neural network, respectively. The efficiency of ML techniques for enhancing the prediction accuracy and decreasing the procedure time and their approach toward the data, makes it importantly desirable to recommend them in subsurface facies classification analysis.
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Rizkiaputra, R. "Delivering A Successful Acid Fracturing Job Through Integrated GGR Analysis and Stimulation Study, Case Study of A Tight Gas-Condensate Reservoir In Central Kalimantan, Indonesia." In Digital Technical Conference. Indonesian Petroleum Association, 2020. http://dx.doi.org/10.29118/ipa20-e-115.

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The biggest challenge for producing a tight (<0.1 mD) gas-condensate reservoir is its low deliverability. Therefore, it is important to consider well stimulation in the field development program. There are several types of stimulation, and one of the types which has the most impact is acid fracturing. However, thorough study needs to be carried out to ensure its compatibility with the specific reservoir condition. This paper will describe in detail how the geology, geophysics and reservoir (GGR) analysis and the stimulation study play its role to create a successful acid fracturing job in Indonesia, specifically in Central Kalimantan. The study begins with the understanding of reservoir geological concept and its characterization using multiple seismic attributes and core sedimentology. This geology and geophysical (G&G) analysis is further enhanced by performing dynamic analysis such as pressure transient analysis (PTA), rate transient analysis (RTA), and flowing material balance (FMB). Following this, feasibility of acid fracturing is assessed by performing the geomechanical analysis and acid solubility test. Moreover, the fracture geometry is also simulated to make sure the resulting fracture is able to penetrate the good reservoir quality. Then, performance projection using reservoir simulation is performed to quantify the expected incremental gain from the job. The geological concept differentiates this platform carbonate into six depositional elements, in which all of the production wells are located in the Reef Complex. It is further defined using the combination of seismic attributes, petrophysical analysis, and production performance, which are able to map the reservoir quality distribution. From the dynamic analysis, it shows that each well has massive connected gas initial in place (GIIP) with several wells are having poor facies nearby that act as the barrier. The study is followed by a stimulation study which shows that the reservoir has hard rock characteristics (Young Modulus up to 3.2 million psi) and high acid solubility (up to 95%), suitable for acid fracturing job. Simulated fracture geometry shows that it could penetrate nearby poor facies and achieve the good facies target. Then, the reservoir simulation also shows that significant production gain could be obtained from the job. Following up on the encouraging result of GGR & stimulation study, the first acid fracturing campaign in this field is sanctioned and performed safely & successfully. It delivers a very encouraging result in which one of the wells shows a productivity increase of up to 200%. Production forecast shows that post-fracturing well performance could sustain the plateau rate up to two and a half years and provide an addition of 25 BSCF of proved developed producing reserves. Material enough for increasing the field profitability and optimizing future development plans. This study shows that understanding the reservoir by doing integrated GGR analysis has significant benefit to reveal the upside potential of the field. Moreover, the excellent result on acid fracturing feasibility study and fracture design prior to the job ensures that it could be performed safely, successfully, and significantly increase the well productivity.
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Pourpak, Hamid, Eider Hernandez, Maxime Higelin, Maysaa Jaber, Khalid Mansoor, Luther Sullivan, Emmanuelle Baud, et al. "Integrated Reservoir, Geology and Geomechanical Characterization for Unconventional Development: Application to the Diyab Play." In ADIPEC. SPE, 2022. http://dx.doi.org/10.2118/211030-ms.

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Abstract The Diyab Formation is an organic-rich carbonate rock with low permeabilities and is one of the first unconventional targets to emerge in the Middle East. Vertical and horizontal exploration wells were drilled during the past years with proven productivity in the United Arab Emirates (UAE). Coupled geomechanical and reservoir characterizations of the Diyab formation are crucial for the successfulness of Stimulated Rock Volume (SRV) Creation and hydraulic fracturing operations which can have a direct impact on production performance. The objective of this study was to perform a full characterization of the Diyab formation based on extensive datasets that include logs and cores. The outcome of this integrated characterization work is used to assess the behavior of the Diyab formation across the concession block. First, we present the geology and general context of the studied area. Next, we detail the current understanding of the structural lineaments and natural fractures across the block. Then, based on full characterization work originating from data acquired on exploration and appraisal wells, we show how the results of geomechanical characterization together with the analysis of reservoirs quality/geological data allow us to suggest a vertical sub-division for Diyab formation. We explain further how the reservoir/geology, geomechanical parameters and natural fractures change laterally between wells. Reservoir characterization work concluded that there are some lateral variabilities in Diyab formation such as the change in the thickness/mineralogy of the carbonate bench and thickness of the porous wackestone. Some lateral variations in geomechanical/SRV parameters are observed within the block, resulted mainly from change in natural fractures density and properties of the carbonate bench and porous wackestone. This work is the first result of the integration of the current available data and the knowledge on Diyab formation, which could potentially evolve with the acquisition of new data and analyses. The combination of a full geomechanical characterization with a reservoir quality and structural geology study allows to propose a detailed reservoir and geomechanical sub-division for the Diyab formation. This approach will aid to better understand the lateral variability of facies, reservoir quality and geomechanical properties within the block which are crucial for successful development of this unconventional play.
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Pandey, Vikram Kumar, Permanand Dhermeshwar Thankur, Setiyo Pamungkas, Tony Thomas, Redha Al Lawatia, Magdy Samir, Talha Zubair, and Abdul Bari. "Vertical Interference Testing as a Gateway to Permeability Anisotropy Demystification and Understanding Fluid Displacement in Carbonates." In SPE Reservoir Characterisation and Simulation Conference and Exhibition. SPE, 2023. http://dx.doi.org/10.2118/212646-ms.

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Abstract Carbonates are infamous for their complex intrinsic heterogeneity, exaggerated due to stratification and layered geology. Characterization and correlation of this heterogeneity with recovery mechanisms becomes critical pertaining to Lower Cretaceous reservoir ‘A’ with over 4 decades of production/injection history. Hence, it is pertinent to systematically reduce the uncertainties associated with reservoir characterization by delineating high permeability streaks, permeability-contrasts, links between geological and petrophysical facies and their impact on field scale production/injection strategies. Emphasis was put on capturing downhole dynamic Kv/Kh profile across sub layers of the reservoir ‘A’, to enable assignment of representative values into reservoir simulation model with associated reservoir zonation. Vertical interference testing (VIT) was designed in a crestal location well with a history of near-by waterflooding, integrating simulator-based outputs with petrophysical and borehole image logs of an offset. Drawdown-buildup cycle was performed across source probe or packer, while simultaneous monitoring of pressure at observation probe. To reduce uncertainty and incorporate statistical sense into the data, multiple cycles of drawdown-buildup were conducted for vertical connectivity evaluation. In total, eleven VIT tests conducted with formation tester tool utilizing dual-straddle-packer and two-probe modules were interpreted implementing a systematic approach considering vertical communication as a function of geological facies and textural aspects from borehole images, geological information on fractures/faults, and surfaces. Interpretation involves identification of flow-units based on available logs, followed by identification of flow regimes (spherical/radial) to history-match data for estimation of horizontal and vertical permeabilities of each layer. Resultant analysis yielded insights on anisotropy by validating vertical communication through stylolite and across dense layers. Integration of VIT analysis results (Kh,Kv,Kv/Kh) with petrophysical logs led to the establishment of water flood advancement mechanism in this observation well at the crestal location of field. This establishes a critical link between integrated geological, textural and facies analysis in context of sedimentology, layering and rock quantified fabric permeability indicators visible on high vertical and horizontal resolution borehole image. Thereby, allowing derivation of scalable answer products and workflows. Subsequently, explaining water flood mechanism and enabling updating of simulation model for enhanced reservoir characterization. Furthermore, this also allows for field development augmentation and injection strategy optimization through linking of dynamic results to reservoir description of two major sub-layers of this giant carbonate field. Integration and analysis of key insights on vertical communication and carbonate anisotropy with major geological/petrophysical features aided in characterizing 3D static and dynamic models. This would allow improved trajectory planning of future wells, leading to improvement in recovery efficiency through guided injection strategy. Additionally, proactive data aggregation and insightful interpretation to help accelerate realization of value from field development strategy was highlighted.
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Masoud, Mohamed, W. Scott Meddaugh, Masoud Eljaroshi, and Khaled Elghanduri. "Enhanced and Rock Typing-Based Reservoir Characterization of the Palaeocene Harash Carbonate Reservoir-Zelten Field-Sirte Basin-Libya." In SPE Annual Technical Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/205971-ms.

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Abstract The Harash Formation was previously known as the Ruaga A and is considered to be one of the most productive reservoirs in the Zelten field in terms of reservoir quality, areal extent, and hydrocarbon quantity. To date, nearly 70 wells were drilled targeting the Harash reservoir. A few wells initially naturally produced but most had to be stimulated which reflected the field drilling and development plan. The Harash reservoir rock typing identification was essential in understanding the reservoir geology implementation of reservoir development drilling program, the construction of representative reservoir models, hydrocarbons volumetric calculations, and historical pressure-production matching in the flow modelling processes. The objectives of this study are to predict the permeability at un-cored wells and unsampled locations, to classify the reservoir rocks into main rock typing, and to build robust reservoir properties models in which static petrophysical properties and fluid properties are assigned for identified rock type and assessed the existed vertical and lateral heterogeneity within the Palaeocene Harash carbonate reservoir. Initially, an objective-based workflow was developed by generating a training dataset from open hole logs and core samples which were conventionally and specially analyzed of six wells. The developed dataset was used to predict permeability at cored wells through a K-mod model that applies Neural Network Analysis (NNA) and Declustring (DC) algorithms to generate representative permeability and electro-facies. Equal statistical weights were given to log responses without analytical supervision taking into account the significant log response variations. The core data was grouped on petrophysical basis to compute pore throat size aiming at deriving and enlarging the interpretation process from the core to log domain using Indexation and Probabilities of Self-Organized Maps (IPSOM) classification model to develop a reliable representation of rock type classification at the well scale. Permeability and rock typing derived from the open-hole logs and core samples analysis are the main K-mod and IPSOM classification model outputs. The results were propagated to more than 70 un-cored wells. Rock typing techniques were also conducted to classify the Harash reservoir rocks in a consistent manner. Depositional rock typing using a stratigraphic modified Lorenz plot and electro-facies suggest three different rock types that are probably linked to three flow zones. The defined rock types are dominated by specifc reservoir parameters. Electro-facies enables subdivision of the formation into petrophysical groups in which properties were assigned to and were characterized by dynamic behavior and the rock-fluid interaction. Capillary pressure and relative permeability data proved the complexity in rock capillarity. Subsequently, Swc is really rock typing dependent. The use of a consistent representative petrophysical rock type classification led to a significant improvement of geological and flow models.
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Reports on the topic "Facies (Geology) Analysis"

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Lacerda Silva, P., G. R. Chalmers, A. M. M. Bustin, and R. M. Bustin. Gas geochemistry and the origins of H2S in the Montney Formation. Natural Resources Canada/CMSS/Information Management, 2022. http://dx.doi.org/10.4095/329794.

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The geology of the Montney Formation and the geochemistry of its produced fluids, including nonhydrocarbon gases such as hydrogen sulfide were investigated for both Alberta and BC play areas. Key parameters for understanding a complex petroleum system like the Montney play include changes in thickness, depth of burial, mass balance calculations, timing and magnitudes of paleotemperature exposure, as well as kerogen concentration and types to determine the distribution of hydrocarbon composition, H2S concentrations and CO2 concentrations. Results show that there is first-, second- and third- order variations in the maturation patterns that impact the hydrocarbon composition. Isomer ratio calculations for butane and propane, in combination with excess methane estimation from produced fluids, are powerful tools to highlight effects of migration in the hydrocarbon distribution. The present-day distribution of hydrocarbons is a result of fluid mixing between hydrocarbons generated in-situ with shorter-chained hydrocarbons (i.e., methane) migrated from deeper, more mature areas proximal to the deformation front, along structural elements like the Fort St. John Graben, as well as through areas of lithology with higher permeability. The BC Montney play appears to have hydrocarbon composition that reflects a larger contribution from in-situ generation, while the Montney play in Alberta has a higher proportion of its hydrocarbon volumes from migrated hydrocarbons. Hydrogen sulphide is observed to be laterally discontinuous and found in discrete zones or pockets. The locations of higher concentrations of hydrogen sulphide do not align with the sulphate-rich facies of the Charlie Lake Formation but can be seen to underlie areas of higher sulphate ion concentrations in the formation water. There is some alignment between CO2 and H2S, particularly south of Dawson Creek; however, the cross-plot of CO2 and H2S illustrates some deviation away from any correlation and there must be other processes at play (i.e., decomposition of kerogen or carbonate dissolution). The sources of sulphur in the produced H2S were investigated through isotopic analyses coupled with scanning electron microscopy, energy dispersive spectroscopy, and mineralogy by X-ray diffraction. The Montney Formation in BC can contain small discrete amounts of sulphur in the form of anhydrite as shown by XRD and SEM-EDX results. Sulphur isotopic analyses indicate that the most likely source of sulphur is from Triassic rocks, in particular, the Charlie Lake Formation, due to its close proximity, its high concentration of anhydrite (18-42%), and the evidence that dissolved sulphate ions migrated within the groundwater in fractures and transported anhydrite into the Halfway Formation and into the Montney Formation. The isotopic signature shows the sulphur isotopic ratio of the anhydrite in the Montney Formation is in the same range as the sulphur within the H2S gas and is a lighter ratio than what is found in Devonian anhydrite and H2S gas. This integrated study contributes to a better understanding of the hydrocarbon system for enhancing the efficiency of and optimizing the planning of drilling and production operations. Operators in BC should include mapping of the Charlie Lake evaporites and structural elements, three-dimensional seismic and sulphate ion concentrations in the connate water, when planning wells, in order to reduce the risk of encountering unexpected souring.
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