Academic literature on the topic 'Petroleum exploration; Petrophysics; Lithology'
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Journal articles on the topic "Petroleum exploration; Petrophysics; Lithology"
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Zhang, Yuanzhong, Sicheng Jin, Hao Jiang, Yuwei Wang, and Pengyu Jia. "Review of Well Logs and Petrophysical Approaches for Shale Gas in Sichuan Basin, China." Open Petroleum Engineering Journal 8, no. 1 (August 19, 2015): 316–24. http://dx.doi.org/10.2174/1874834101508010316.
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China has vast reserves of shale gas. Currently, shale gas is one of the focuses of the unconventional reservoir. Well logs play an import role in shale gas production, and it is the bridge connecting geology, geophysics and petroleum engineering. In the exploration stage, well logs are used to identify lithology, evaluate the parameters of mineral types and compositions, total organic carbon (TOC), porosity, permeability, gas content, and the potential resources quantity. In the development stage, well logs offer various parameters of geological and engineering for horizontal drilling and production, evaluate the mechanical properties and calculate the magnitude and orientation of the in-situ stress for hydraulic fracturing stimulation. We reviewed current well logs for shale gas in China and discussed the development trend in the paper. A case history in Sichuan Basin presented to analyze the logs response characteristics and parameters calculation for a shale gas well. The difficulty and the future attention focus are also discussed.
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Nguyen, Chuc Dinh, Xuan Van Tran, Kha Xuan Nguyen, Huy Nhu Tran, and Tan Thanh Mai. "The forming mechanisms of Oligocene combination/stratigraphic traps and their reservoir quality in southeast Cuu Long Basin offshore of Vietnam." Science and Technology Development Journal 22, no. 1 (April 10, 2019): 185–95. http://dx.doi.org/10.32508/stdj.v22i1.1216.
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To date, most of the oil and gas production in Cuu Long Basin (CLB) is contributed from structural traps, making them more and more depleted after years of exploitation. Exploration activities in CLB, therefore, are shifting towards other traps, including stratigraphic and/or combination ones. The results of exploration and appraisal activities in recent years have increasingly discovered more hydrocarbons in the Oligocene section; some of them were discovered in combination/ stratigraphic traps. Many studies on Oligocene targets in Southeast CLB have been carried out but only a few mention nonstructural traps. This leads to uncertainty about the forming mechanisms and distribution, as well as unevaluated hydrocarbon potential of these traps. An integrated approach- utilizing methods of seismic sequence stratigraphy, seismic attribute interpretation, and petrophysical/ petrographical analysis- was applied in this research to identify the forming mechanisms of Oligocene combination/ stratigraphic traps in southeast area of CLB and to evaluate their reservoir quality. The research results show that the key forming factor for stratigraphic traps of sand body is lithology change and the one for pinch-out stratigraphic traps is tapering off of sand layers landward or toward the horsts. The reservoir quality of these traps ranges from moderate to good. By integratedly applying the methods, the forming mechanisms and reservoir quality of Oligocene stratigraphic traps could be delineated. In order to optimize the next-stage exploration strategy in CLB, detailed studies on petroleum system, especially top and bottom seals, and the hydrocarbon potential of these stratigraphic traps, need to be carried out.
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Yale, David P. "Recent advances in rock physics." GEOPHYSICS 50, no. 12 (December 1985): 2480–91. http://dx.doi.org/10.1190/1.1441879.
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The need to extract more information about the subsurface from geophysical and petrophysical measurements has led to a great interest in the study of the effect of rock and fluid properties on geophysical and petrophysical measurements. Rock physics research in the last few years has been concerned with studying the effect of lithology, fluids, pore geometry, and fractures on velocity; the mechanisms of attenuation of seismic waves; the effect of anisotropy; and the electrical and dielectric properties of rocks. Understanding the interrelationships between rock properties and their expression in geophysical and petrophysical data is necessary to integrate geophysical, petrophysical, and engineering data for the enhanced exploration and characterization of petroleum reservoirs. The use of amplitude offsets, S‐wave seismic data, and full‐waveform sonic data will help in the discrimination of lithology. The effect of in situ temperatures and pressures must be taken into account, especially in fractured and unconsolidated reservoirs. Fluids have a strong effect on seismic velocities, through their compressibility, density, and chemical effects on grain and clay surfaces. S‐wave measurements should help in bright spot analysis for gas reservoirs, but theoretical considerations still show that a deep, consolidated reservoir will not have any appreciable impedance contrast due to gas. The attenuation of seismic waves has received a great deal of attention recently. The idea that Q is independent of frequency has been challenged by experimental and theoretical findings of large peaks in attenuation in the low kHz and hundreds of kHz regions. The attenuation is thought to be due to fluid‐flow mechanisms and theories suggest that there may be large attenuation due to small amounts of gas in the pore space even at seismic frequencies. Models of the effect of pores, cracks, and fractures on seismic velocity have also been studied. The thin‐crack velocity models appear to be better suited for representing fractures than pores. The anisotropy of seismic waves, especially the splitting of polarized S‐waves, may be diagnostic of sets of oriented fractures in the crust. The electrical properties of rocks are strongly dependent upon the frequency of the energy and logging is presently being done at various frequencies. The effects of frequency, fluid salinity, clays, and pore‐grain geometry on electrical properties have been studied. Models of porous media have been used extensively to study the electrical and elastic properties of rocks. There has been great interest in extracting geometrical parameters about the rock and pore space directly from microscopic observation. Other models have focused on modeling several different properties to find relationships between rock properties.
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Nguyen, Duy, Nadege Rollet, Emmanuelle Grosjean, Dianne S. Edwards, Steve Abbott, Claire Orlov, George Bernardel, et al. "The Roebuck Basin, Beagle and Barcoo Sub-basin well folio." APPEA Journal 59, no. 2 (2019): 920. http://dx.doi.org/10.1071/aj18053.
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The Roebuck Basin and the adjoining Beagle and Barcoo sub-basins are underexplored areas on Australia’s North West Shelf that are undergoing renewed exploration interest since the discovery of oil at Phoenix South 1 in 2014 and subsequent hydrocarbon discoveries in the Bedout Sub-basin. A well folio of 24 offshore wells across the Beagle, Bedout, Rowley and Barcoo sub-basins has been compiled as part of Geoscience Australia’s hydrocarbon prospectivity assessment across the region. It consists of composite well log plots and well correlations that summarise lithology, lithostratigraphy, Geoscience Australia’s newly acquired biostratigraphic and geochemical data as well as results of petrophysical analysis. A revised sequence-stratigraphic interpretation, key petroleum system elements and drilling results are also documented. The wells dominantly target Triassic shoreward facies (Keraudren Formation) as the primary reservoir objective and Jurassic fluvial-deltaic (Depuch Formation) and/or Lower Cretaceous sandy deltaic facies as the secondary objective. The Keraudren Formation sandstones are sealed intra-formationally either by discontinuous units and/or by the regional Cossigny Member. The Jurassic Depuch Formation sandstones are sealed by regional Lower Cretaceous mudstones. Both charge and structure have been identified as critical issues in the Roebuck Basin. In the Beagle Sub-basin, seal integrity and migration pathways are also considered high risk. Well correlations have identified differences in the basin history and provide insights into the distribution of facies and other characteristics of the Jurassic and Triassic successions.
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Zhang, Xiaojun, Haodong Han, Jun Peng, and Yingchun Gou. "Multifractal Analysis of Pore Structure and Evaluation of Deep-Buried Cambrian Dolomite Reservoir with Image Processing: A Case from Tarim Basin, NW China." Geofluids 2020 (September 21, 2020): 1–18. http://dx.doi.org/10.1155/2020/7131573.
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Reservoir pore space assessment is of great significance for petroleum exploration and production. However, it is difficult to describe the pore characteristics of deep-buried dolomite reservoirs with the traditional linear method because these rocks have undergone strong modification by tectonic activity and diagenesis and show significant pore space heterogeneity. In this study, 38 dolostone samples from 4 Cambrian formations of Tarim Basin in NW China were collected and 135 thin section images were analyzed. Multifractal theory was used for evaluation of pore space heterogeneity in deep-buried dolostone based on thin section image analysis. The physical parameters, pore structure parameters, and multifractal characteristic parameters were obtained from the digital images. Then, the relationships between lithology and these parameters were discussed. In addition, the pore structure was classified into four categories using K-means clustering analysis based on multifractal parameters. The results show that the multifractal phenomenon generally exists in the pore space of deep-buried dolomite and that multifractal analysis can be used to characterize the heterogeneity of pore space in deep-buried dolomite. For these samples, multifractal parameters, such as αmin, αmax, ΔαL, ΔαR, Δf, and AI, correlate strongly with porosity but only slightly with permeability. However, the parameter Δα, which is usually used to reveal heterogeneity, does not show an obvious link with petrophysical properties. Of dolomites with different fabrics, fine crystalline dolomite and medium crystalline dolomite show the best petrophysical properties and show significant differences in multifractal parameters compared to other dolomites. More accurate porosity estimations were obtained with the multifractal generalized fractal dimension, which provides a new method for porosity prediction. The various categories derived from the K-means clustering analysis of multifractal parameters show distinct differences in petrophysical properties. This proves that reservoir evaluation and pore structure classification can be accurately performed with the K-means clustering analysis method based on multifractal parameters of pore space in deep-buried dolomite reservoirs.
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Bailey, Adam H. E., Amber J. M. Jarrett, Liuqi Wang, David N. Dewhurst, Lionel Esteban, Shane Kager, Ludwig Monmusson, Lidena K. Carr, and Paul A. Henson. "Exploring for the Future geomechanics: breaking down barriers to exploration." APPEA Journal 61, no. 2 (2021): 579. http://dx.doi.org/10.1071/aj20039.
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Exploring for the Future (EFTF) is an Australian Government initiative focused on gathering new data and information about potential mineral, energy and groundwater resources across Australia. The energy component of EFTF, initially focussed on northern Australia, aims to improve our understanding of the petroleum potential of frontier Australian basins. Building an understanding of geomechanical rock properties is key to understanding both conventional and unconventional petroleum systems as well as carbon storage and sedimentary geothermal systems. Under EFTF, Geoscience Australia has undertaken geomechanical work including stress modelling, shale brittleness studies and the acquisition of new rock property data through extensive testing on samples from the Paleo- to Mesoproterozoic South Nicholson region of Queensland and the Northern Territory, and the Paleozoic Kidson Sub-basin of Western Australia. Work in these regions demonstrates regional stress orientations in broad agreement with previously modelled, continent-scale stress orientations and stress magnitudes that vary through the basin with depth and by lithology. Rock testing highlights potentially brittle shales and demonstrates variable rock properties in line with lithology. These analyses are summarised herein. Providing baseline geomechanical data in frontier basins is essential as legacy data coverage can often be inadequate for making investment decisions, particularly where unconventional plays are a primary exploration target. As EFTF increases in scope, Geoscience Australia anticipates expanding these studies to encompass further underexplored regions throughout Australia, lowering the barrier to entry and encouraging greenfield exploration.
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Alkhayyat, Raniah S., Fadhil S. Kadhim, and Yousif khalaf Yousif. "The Use of Nuclear Magnetic Resonance (NMR) Measurements and Conventional Logs to Predict Permeability for a Complex Carbonate Formation." Journal of Petroleum Research and Studies 11, no. 3 (September 19, 2021): 82–98. http://dx.doi.org/10.52716/jprs.v11i3.534.
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Permeability is one of the most important property for reservoir characterization, and its prediction has been one of the fundamental challenges specially for a complex formation such as carbonate, due to this complexity, log analysis cannot be accurate enough if it’s not supported by core data, which is critically important for formation evaluation. In this paper, permeability is estimated by making both core and log analysis for five exploration wells of Yammama formation, Nasiriyah oil field. The available well logging recorders were interpreted using Interactive Petrophysics software (IP) which used to determine lithology, and the petrophysical properties. Nuclear Magnetic Resonance (NMR) Measurements is used for laboratory tests, which provide an accurate, porosity and permeability measurements. The results show that the main lithology in the reservoir is limestone, in which average permeability of the potential reservoir units’ values tend to range from 0.064275 in zone YA to 20.74 in zone YB3, and averaged porosity values tend to range from 0.059 in zone YA to 0.155 in zoneYB3. Zone YB3 is found to be the best zone in the Yammama formation according to its good petrophysical properties. The correlation of core-log for permeability and porosity produce an acceptable R^2 equal to 0.618, 0.585 respectively
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Burnett, T. L. "Petroleum Exploration Risk Reduction Using New Geoscience Technology." Energy Exploration & Exploitation 14, no. 6 (December 1996): 507–34. http://dx.doi.org/10.1177/014459879601400602.
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As economics of the oil and gas industry become more restrictive, the need for new means of improving exploration risks and reducing expenses is becoming more acute. Partnerships between industry and academia are making significant improvements in four general areas: Seismic acquisition, reservoir characterization, quantitative structural modeling, and geochemical inversion. In marine seismic acquisition the vertical cable concept utilizes hydrophones suspended at fixed locations vertically within the water column by buoys. There are numerous advantages of vertical cable technology over conventional 3-D seismic acquisition. In a related methodology, ‘Borehole Seismic,’ seismic energy is passed between wells and valuable information on reservoir geometry, porosity, lithology, and oil saturation is extracted from the P-wave and S-wave data. In association with seismic methods of determining the external geometry and the internal properties of a reservoir, 3-dimensional sedimentation-simulation models, based on physical, hydrologic, erosional and transport processes, are being utilized for stratigraphic analysis. In addition, powerful, 1-D, coupled reaction-transport models are being used to simulate diagenesis processes in reservoir rocks. At the regional scale, the bridging of quantitative structural concepts with seismic interpretation has lead to breakthroughs in structural analysis, particularly in complex terrains. Such analyses are becoming more accurate and cost effective when tied to highly advanced, remote-sensing, multi-spectral data acquisition and image processing technology. Emerging technology in petroleum geochemistry enables geoscientists to infer the character, age, maturity, identity and location of source rocks from crude oil characteristics (‘Geochemical Inversion’) and to better estimate hydrocarbon-supply volumetrics, which can be invaluable in understanding petroleum systems and in reducing exploration risks and associated expenses.
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Zhou, Kaibo, Jianyu Zhang, Yusong Ren, Zhen Huang, and Luanxiao Zhao. "A gradient boosting decision tree algorithm combining synthetic minority oversampling technique for lithology identification." GEOPHYSICS 85, no. 4 (May 8, 2020): WA147—WA158. http://dx.doi.org/10.1190/geo2019-0429.1.
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Lithology identification based on conventional well-logging data is of great importance for geologic features characterization and reservoir quality evaluation in the exploration and production development of petroleum reservoirs. However, there are some limitations in the traditional lithology identification process: (1) It is very time consuming to build a model so that it cannot realize real-time lithology identification during well drilling, (2) it must be modeled by experienced geologists, which consumes a lot of manpower and material resources, and (3) the imbalance of labeled data in well-log data may reduce the classification performance of the model. We have developed a gradient boosting decision tree (GBDT) algorithm combining synthetic minority oversampling technique (SMOTE) to realize fast and automatic lithology identification. First, the raw well-log data are normalized by maximum and minimum normalization algorithm. Then, SMOTE is adopted to balance the number of samples in each class in training process. Next, a lithology identification model is built by GBDT to fit the preprocessed training data set. Finally, the built model is verified with the testing data set. The experimental results indicate that the proposed approach improves the lithology identification performance compared with other machine-learning approaches.
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Imran, Qazi Sohail, Numair Ahmad Siddiqui, Abdul Halim Abdul Latif, Yasir Bashir, Almasgari Abdalsalam Abduh Saeed Ali, and Muhammad Jamil. "Integrated Well Data And 3D Seismic Inversion Study For Reservoir Delineation And Description." Bulletin Of The Geological Society Of Malaysia 70, no. 1 (November 30, 2020): 209–20. http://dx.doi.org/10.7186/bgsm70202016.
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Offshore petroleum systems are often very complex and subtle because of a variety of depositional environments. Characterizing a reservoir based on conventional seismic and well-log stratigraphic analysis in intricate settings often leads to uncertainties. Drilling risks, as well as associated subsurface uncertainties can be minimized by accurate reservoir delineation. Moreover, a forecast can also be made about production and performance of a reservoir. This study is aimed to design a workflow in reservoir characterization by integrating seismic inversion, petrophysics and rock physics tools. Firstly, to define litho facies, rock physics modeling was carried out through well log analysis separately for each facies. Next, the available subsurface information is incorporated in a Bayesian engine which outputs several simulations of elastic reservoir properties, as well as their probabilities that were used for post-inversion analysis. Vast areal coverage of seismic and sparse vertical well log data was integrated by geostatistical inversion to produce acoustic impedance realizations of high-resolution. Porosity models were built later using the 3D impedance model. Lastly, reservoir bodies were identified and cross plot analysis discriminated the lithology and fluid within the bodies successfully.
Dissertations / Theses on the topic "Petroleum exploration; Petrophysics; Lithology"
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Alborzi, Mahmood. "Application of neural networks to real-time log interpretation in oil well drilling." Thesis, Brunel University, 1996. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.309502.
Full textBooks on the topic "Petroleum exploration; Petrophysics; Lithology"
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Harrison, Bob, and Martin Kennedy. Practical Petrophysics (Handbook of Petroleum Exploration and Production). Elsevier Science, 2008.
Find full textBook chapters on the topic "Petroleum exploration; Petrophysics; Lithology"
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Gill, D., and M. Levinger. "Information Management And Mapping System For Subsurface Stratigraphic Analysis." In Computers in Geology - 25 Years of Progress. Oxford University Press, 1994. http://dx.doi.org/10.1093/oso/9780195085938.003.0014.
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An information management and mapping system combining a series of interactive computer programs for stratigraphic, lithofacies, paleogeographic, and structural analysis interfaced with a comprehensive database on subsurface geology produces contour maps of quantitative variables including structure maps, isopach maps, and maps of lithofacies parameters; detailed lithologic and stratigraphic logs; and printouts of lithofacies parameters for all levels of the lithostratigraphic subdivision. Users communicate by means of simple, on-screen, menu-driven dialogues controlled by FORTRAN programs. The system runs on DEC/Micro VAX II computers operating under VMS. This information management and mapping system for subsurface stratigraphic analysis is an integration of a comprehensive database on the subsurface geology of Israel and a series of computer programs for stratigraphic, lithofacies, paleogeographic, and structural analysis. Development of the system, referred to as "ATLAS -RELIANT," was sponsored by OEIL [Israel Oil Exploration (Investment) Ltd.). The system serves primarily as a storage and retrieval facility for information on the subsurface geology of Israel. Users can obtain printouts of lithologic and stratigraphic logs, contour maps, and value maps. The system originally was developed to run on a CDC machine under the NOS/BE operating system. Later OEIL expanded the database to include many additional items of information [inventory of cores and petrophysical logs, results of production tests, results of petrophysical analyses, geochemical analyses of recovered fluids (water samples and hydrocarbons), and results of quantitative analyses of petrophysical logs] and the system was modified to run on DEC/Micro VAX II computers under the VMS operating system (Shertok, 1969). Among other things, the ATLAS-RELIANT system was instrumental in the regional stratigraphic analysis of the subsurface geology of Israel performed by OEIL during 1968-1988 (OEIL, 1966; Cohen et al., 1990). The database, dubbed "ATLAS," is about 16 MB in size and contains information on 320 petroleum exploration and development boreholes, 50 deep water wells, and 100 columnar sections of outcrops.
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CARTER, MELVAN D., John E. Beitzel, and Eric P. Mason. "Depth Conversion Monitoring Using a Normalized Velocity Lithology Correlation." In Stratigraphic Analysis Utilizing Advanced Geophysical, Wireline and Borehole Technology for Petroleum Exploration and Productioni: 17th Annual, 51–58. SOCIETY OF ECONOMIC PALEONTOLOGISTS AND MINERALOGISTS, 1996. http://dx.doi.org/10.5724/gcs.96.17.0051.
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Scheihing, Mark H., and Gary L. White. "Computer-Based Rock Description for Development and Exploration Geology." In The Integration of Geology, Geophysics, Petrophysics and Petroleum Engineering in Reservoir Delineation, Description and Management. American Association of Petroleum Geologists, 1991. http://dx.doi.org/10.1306/sp535c26.
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Jordan, Douglas W., Roger M. Slatt, Robert H. Gillespie, Anthony E. D’Agostino, and Mark H. Scheihing. "Applications of Outcrop Gamma-Ray Logging to Field Development and Exploration." In The Integration of Geology, Geophysics, Petrophysics and Petroleum Engineering in Reservoir Delineation, Description and Management. American Association of Petroleum Geologists, 1991. http://dx.doi.org/10.1306/sp535c9.
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Mallon, Kenneth M. "Managing a Technical Cooperation Team for Hydrocarbon Exploration and Development in the People’s Republic of China." In The Integration of Geology, Geophysics, Petrophysics and Petroleum Engineering in Reservoir Delineation, Description and Management. American Association of Petroleum Geologists, 1991. http://dx.doi.org/10.1306/sp535c29.
Full textConference papers on the topic "Petroleum exploration; Petrophysics; Lithology"
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Guo, Jiru, Zhiwen Deng, Junyong Zhang, Wei Tan, Guowen Chen, Qiao Shi, Yaling Wang, and Qian Zhao. "Application of Sh S-Wave Data in Lithologic Trap Identification." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21796-ms.
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Abstract The biogas lithologic reservoirs in Sanhu Area of the Qaidam Basin has a broad exploration prospect, however, the demands of structural implementation and reservoir prediction can hardly be met with the existing P-wave seismic data due to the thin thickness of single sandstone layers, the rapid lateral changes and the low prediction accuracy of lithologic reservoirs. The SH-wave data has a higher resolution ability in lithology prediction. I can better reflect the lateral change features of formations. Because few SH-wave logging data are available and they are in accurate in the current study area, the SH-wave velocity is estimated through petrophysical modeling and the calibration and horizon interpretation of the SH-wave data are realized combined with the P- and SH-wave matching technology. Through the inversion of S-wave data,the lithological distribution of formations are predicted in combination with the comrehensive analysis of P-wave data, which provides a favorable basis for the survey of lithologic gas reservoir in the research area and achieves a good good result. In this way,a set of reservoir prediction methods and processes suitable for the shallow biogas lithological exploration in the Sanhu Area have formed initially.
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Saxena, Vimal, and Thomas Dale McDonald. "Exploration Petrophysics For Intra-Salt Carbonates In Ultra Saline Environment." In International Petroleum Technology Conference. International Petroleum Technology Conference, 2009. http://dx.doi.org/10.2523/iptc-13332-ms.
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Saxena, Vimal, and Thomas Dale McDonald. "Exploration Petrophysics For Intra-Salt Carbonates In Ultra Saline Environment." In International Petroleum Technology Conference. International Petroleum Technology Conference, 2009. http://dx.doi.org/10.2523/13332-ms.
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Saxena, V., and T. McDonald. "Exploration Petrophysics for Intra-Salt Carbonate in Ultra Saline Environment." In IPTC 2009: International Petroleum Technology Conference. European Association of Geoscientists & Engineers, 2009. http://dx.doi.org/10.3997/2214-4609-pdb.151.iptc13332.
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Spirina, Anastasiia, and Evgeniy Cherepanov. "Petroelastic Modeling of Complex Lithology Fields: Case Study." In SPE Symposium: Petrophysics XXI. Core, Well Logging, and Well Testing. SPE, 2021. http://dx.doi.org/10.2118/208423-ms.
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Abstract The present-day growth of petroleum reserves, maintaining and enhancing of oil production is associated with involving of complex fields into production (Uspenskaya, 2014). The complex structure of the study areas of the Urai Region (facies variability, formation replacement, fracturing, crushing and cleavage zones, complicated structure of the pore space) makes conventional forecast of reservoir properties ineffective. Moreover, the pay formations are highly exhausted with high production water cut. Therefore, the search of prospective targets is relevant in the Urai Region. The article shows generalized results of petroelastic modeling of several fields of the Urai Region for solving the following tasks: ○ Lithology, saturation and poroperm properties forecast of reservoir rocks from log and seismic data; ○ Development of 1D mechanical earth models (MEM) of horizontal well sections and their maintenance while drilling horizontal wells. The approach is based on the principles of integrating different-scale geological and geophysical studies. The lithological division of rocks was carried out, the saturation behavior and point-by-point interpretation of the data of geophysical methods of well logging (WL) were identified. 3D component models were built with taking into account the lithological features of the section using core sample studies. Effective models for the environment of sediments of interest were selected and petroelastic modeling was carried out.
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Pirker, C. "Successful Lithology and Fluid Prediction Based Exploration in East Africa-Tanzania, Block2." In First EAGE Eastern Africa Petroleum Geoscience Forum. Netherlands: EAGE Publications BV, 2015. http://dx.doi.org/10.3997/2214-4609.201414448.
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Liu, Zongbin, Zuobin Lv, Jiatao Wen, Hao Yan, and Zhicheng Yang. "Application of Geological Modeling Technique Based on Seismic Frequency Division Processing and Fluids Substitution Forward Modeling in Lithologic Gas Reservoir Risk Assessment." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21211-ms.
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Abstract JZ Gasfield is an offshore sublacustrine fan lithologic gas field located in Bohai Bay Basin, in China, with a buried depth of about 1750m. It is currently in the stage of overall development plan preparation. Two exploration wells have been drilled. They show that the gas field has characteristics of rapid lateral change in reservoir, complex distribution range and connectivity of sand bodies. In addition, the few drilling data, large well spacing and low resolution of seismic data in the evaluation stage make it extremely challenging to establish an accurate geological model of gas reservoir. In order to solve the above problems, in this paper, an integrated geological modeling method based on seismic frequency division processing and fluid substitution forward modeling is proposed. There are four key aspects to this method. (1) Using seismic sedimentology, the lateral distribution ranges of sublacustrine fan sand bodies are described by seismic frequency division processing and interpretation technique and seismic variance attribute. (2) Based on markers of single-well, logging and seismic faceis, the average instantaneous frequency attribute is selected by optimizing the seismic attributes in the dominant frequency band, and then the distribution ranges of three subfacies including inner fan, middle fan and outer fan of the sublacustrine fan are characterized, and the fine sedimentary pattern of the sublacustrine fan is established. (3) Based on an understanding of the sedimentary pattern, fluid substitution forward modeling is carried out, and the superposition and connectivity of the sublacustrine fan sand body are described. (4) A 3D geological model of the sublacustrine fan sand body is established by using a new four-step modeling method including the concept of facies-in-facies modeling: 1) A model of the distribution of the sand body is established through a deterministic modeling method; 2) Within the sand body, according to the division results of subfacies, the distribution model of sub-facies is established; 3) A fine lithofacies model is established by combining stochastic simulation with deterministic modeling and hierarchical modeling from rough to fine under the constraint of a seismic attribute; 4) Petrophysical models are established by lithofacies control, which provide a more accurate geological model for preparation of the gas field development plan. Based on this comprehensive study, it is concluded that there is a great possibility of reservoir disconnection between the inner fan and the middle fan, where the gas reservoir is located, and the inner fan in the updip position of the structure has the risk of no gas accumulation, and the drilling risk in the development stage is greater than the potential. Based on this geological understanding, the available reserves of the gas field are reduced by nearly 40%.
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Weili, Ke, Zhang Guangya, Liu Aixiang, Zheng Yonglin, and Yu Yongjun. "Petroleum Exploration Potential on Abu Gabra Formations in Fula Sub-basin, Muglad Basin, Sudan." In SPE/AAPG Africa Energy and Technology Conference. SPE, 2016. http://dx.doi.org/10.2118/afrc-2565579-ms.
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ABSTRACT Fula sub-basin is one of chasmic structure units with rich petroleum accumulation within Muglad basin. In the past, thick sandstones of Bentiu was considered as main petroleum accumulation targets sealed by faults and anticlines, and most petroleum generated by AG source kitchen has migrated to upper formations along big faults, and furthermore, sandstones inside AG formation of are thin with poor permeability and porosity caused by compaction. Recently, some works have been done specially on AG formation, including small fault interpretation, seismic sedimentary analysis and thin layer inversion, resulting in new petroleum discoveries within middle AG formation, which reveals that AG formation has also good petroleum accumulation abilities. Comprehensive study shows that there developed many small faults within AG period, which could seal sandstones of AG formation laterally, forming effective faulted block within AG formation. Sandstones of delta and sub-water channel could be found. Within AG4 and AG2 formations, there are mainly lacustrine facies. Channel sandstones occurred regression and the area of alluvium fan decreased AG shale has high matter abundance, high hydrocarbon generating potential and kerogen type I, II with middle to high mature, showing good hydrocarbon generation ability. Although sandstones of AG formation have relatively low permeability and porosity, these sandstone have good logging response on hydrocarbon could be sealed by local surrounding mudstones and. All above reveals that AG combination is near-source reservoir combination. Low-amplitude anticline and structure-lithology reservoir models are favorite reservoir models in Fula sub-basin. In the west slope, especially the lower places of the slope are the areas of huge sedimentary accumulation should be favorite prospects. As for the east slope, low-amplitude anticline bounded by small faults that developed during AG period should be the favorite area for exploration, which has been proved by successful drilling activities. In Fula sub-basin, AG structure-lithology complex reservoir combination should be the favorite type for drilling as per under these two key factors, the petroleum could be well accumulated. Currently, there have two important petroleum discoveries of channel sandstone and delta sheet sandstone in AG formation, proving that AG formation still has good potential for drilling.
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Nguyen, Son T. T., Tan N. N. Nguyen, Hung N. T. N. T. Tran, and Quan A. A. Ngo. "Integration of 3D Geological Modeling and Fault Seal Analysis for Pore Pressure Characterization of a High Pressure and High Temperature Exploration Well in Nam Con Son Basin, a Case Study Offshore Vietnam." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21797-ms.
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Abstract The pore pressure profile of an exploration well in high pressure and high temperature (HPHT) A-Field of Nam Con Son Basin was initially predicted along the wellpath in tandem with the analogy to an offset well to design a drilling program of penetrating the unreachable sedimentary formation. The scheme had driven mud weight to encounter the pressure ramp but resulted in underbalance and influx into the wellbore that incurred downtime for well control. Subsequently, formation pressure measurement conceded the substantial disparity over the offset well so the post-drill study was conducted towards with 3D geological modeling and fault seal analysis to gain insight into overpressure generation mechanisms of the field. Seismic interval velocity, density, resistivity data are applied for generating the validated pore pressure profile of exploration well on both Eaton and Bowers methods with calibration on formation pressure measurement for Middle and Lower Miocene Sequences. Besides, the cutting edge 3D modeling is approached to construct a robust structural and fault framework as well as to condition and upscale ultimate shale volume, pressure gradient, and overburden stress for facies and pressure distribution. The sealing capacity of a fault is quantified in terms of the pressure acting on the fault surface that is required to be exceeded for the fault to become unstable and slip including simulations of formation juxtaposition mapping, fault clay content prediction, fault flow indicators, and transmissibility. Upon completion of the 3D model, the fault surfaces which are mapped by shale volume could provide a detailed geometry and lithology juxtaposition analysis for the fault planes. The results of the high Shale Gouge Ratio (SGR), very low fault permeability, and relatively high fault rock thickness imply that the studied faults act as a baffle to fluid flow. However, from juxtaposition observation, the displacement broadens with depth in some parts of faults and the lateral stress increases through the sync-rift stage of Middle Miocene could be a cause of overpressure in this studied area. The 3D pore pressure and stress regime integrated with fault seal analysis in the model are generally obtained to provide both vertical and spatial overpressure characterization and advantages for well drilling plan and reservoir production. From the drilling aspect, a fault stability study can optimize the maximum allowable mud weight to not exceed while drilling so that fault reactivation does not take place. From a depletion perspective, understanding of stress variations due to lowering reservoir pressure with time can be incorporated with fault seal analysis.
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Hadiyanto, Imam Fikri, Dina Hanifah, and Wildan Nur Hamzah. "Distribution of Volcanic Rocks Porosity of Dissected Kromong Paleovolcano: Analogue of Volcanic Reservoir." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21240-ms.
Full textAbstract:
Abstract The potentiality of unconventional play on the volcanic reservoir was evaluated for the purpose to deliver an integrated evaluation of shallow reservoir target associated with the Northwest Java Basin (NWJB). This study provides basis discovery for further exploration and dissemination of volcanic reservoir by presenting an overview of geometric and porosity type analysis of Kromong paleo-volcano complex deposits associated with the NWJB comprehensively. Furthermore, reservoir lithofacies and pore space deployment of Kromong volcanic deposits were studied. The detailed lithofacies analysis was carried out based on field observations from several dissected- and obscure dipping-outcrops in Kromong area associated with NWJB. Following this, a set of outcrop samples were processed for megascopic description integrated with thin-section analysis by using the polarized light microscope and XRF, respectively to assess different types of reservoir pore spaces and structure. Subsequently, the physical properties-porosity measurement was conducted using ImageJ software tools to understand the potentiality of high-quality reservoir formation. The results of this study show that rocks in Kromong area associated with NWJB can be comprehensively classified into reefal limestone for carbonate deposit and into 4 categories, including volcaniclastic lava, sheeting joint lava, pyroclastic breccia, volcanic intrusion, for volcanic deposits. The proposed volcanic reservoirs of volcanic play in this study are lithologically composed of autobreccia lava, sheeting joint lava, pyroclastic breccia to andesitic- and andescitic-dikes, which comprises explosive facies and intrusive facies. Pyroclastic breccia reservoirs are primary pore-type reservoirs with devitrified micropores as main reservoir space. Whilst volcanic dikes reservoirs are mainly porous-fractured-type reservoirs with cooling fracture porosity. In conclusion, following factors that control the presence of a volcanic reservoir are lithology, lithofacies, tectonism and vulcanism. Despite worldwide discoveries of volcanic reservoirs, neither the detailed potentiality evaluation nor the postulated assumption of volcanic reservoir development in NWJB field has been examined sufficiently. This contribution offers knowledge benefits by discussing the potentiality of the Cenozoic-Quarternary volcanic reservoir of the NWJB field and providing a reference for future exploration in the petroleum industry.