Interpretation最新文献

{"title":"Synchrosqueezing Voices Through Deep Neural Networks for Horizon Interpretation","authors":"Haifa Alsalmi, Yanghua Wang","doi":"10.1190/int-2023-0121.1","DOIUrl":"https://doi.org/10.1190/int-2023-0121.1","url":null,"abstract":"Horizon picking stands as a crucial element in reservoir characterisation, yet it remains a labour-intensive process. The manual interpretation of horizons across thousands of vertical seismic slices in a 3D seismic survey significantly further amplifies the time and effort invested in this task. While several automatic methods have been developed for extracting horizons in seismic images, their effectiveness can be compromised in the presence of interruptions in lateral continuity, such as faults and noise. Additionally, closely spaced horizons pose a challenge, making it even more difficult to accurately depict their exact locations. For tracking the horizon surfaces through a 3D seismic volume, it is necessary to exploit other seismic attributes extracted from the 3D seismic data. We proposed to use spectral voice components together with the original seismic amplitudes to track target horizon surfaces. We generated the time-frequency spectrum using a high-resolution method namely the synchrosqueezing wavelet transform (SWT) method, and the real part of the complex SWT spectrum is the voice component. We imported the spectral voice component and the seismic amplitude into a neural network. A framework of deep convolutional neural network (dCNN) was adopted for tracking horizon surfaces within a 3D seismic volume. We demonstrated this application on a field seismic dataset where closely spaced thin layers are within a complex faulted formation with noisy and low signal to noise ratio seismic data. The integration of amplitude and phase within the voice component attribute demonstrates its efficacy in enhancing the quality of the generated horizons, particularly when compared to using only seismic amplitude for this task. A field data example from the F3 dataset showcases the capability of our method in accurately delineating horizons across fault surfaces and in close proximity to unconformities. This surpasses the current limitations of existing horizon-picking methods.","PeriodicalId":502519,"journal":{"name":"Interpretation","volume":"60 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-05-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141121555","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Prediction of tight sandstone reservoirs by multi-wave joint prestack inversion technology: A case study of QL area in Sichuan Basin","authors":"Qiyan Chen, Kang Chen, Hongqiu Wang, Guangguang Yang, Xin Guo, Wei Wei, Guangrui Guo","doi":"10.1190/int-2023-0111.1","DOIUrl":"https://doi.org/10.1190/int-2023-0111.1","url":null,"abstract":"The Shaximiao (SXM) Formation of the Middle Triassic in central Sichuan basin is a river-lake sedimentary system, with an average burial depth of 2800 m. The channel sand bodies of SXM Formation in QL area are developed with large lateral variation and high- and medium- porosity sand. This leads to great difference in seismic response, and difficulty in predicting sand bodies and reservoirs using compressional wave (P-wave) data. We carried out well log analysis for different types of sand bodies. No. 8 sand body of high porosity can be effectively identified by P-wave impedance ( PI). Whereas for No. 7 sand body of relatively lower porosity (mainly due to the higher shale content in the 7 No. 7 sand compared to No. 8 sand), sandstone and mudstone can be distinguished by using shear wave (S-wave) impedance ( SI), and reservoirs can be recognized by P-wave to S-wave velocity ratio ( V p /V s). Based on PP-wave and P-to-S converted wave (PS-wave) (after matching) angle stacked data, prestack inversion of multicomponent data is performed. Multiwave joint inversion results ( SI and V p /V s) have better accuracy and stronger stability than PP-wave inversion in practical application. Besides, the PI of joint inversion more clearly describes the distribution and boundaries of channel sand, and better matches the prediction and drilling data in Sand 8. The SI of joint inversion can identify subtle sand bodies (weak PI contrast) that are difficult to be detected by PP-wave inversion. The distribution of reservoir predicted by V p /V s of joint inversion are clearer (No. 7 sand body) and better than that by PP-wave inversion. This study demonstrates the advantage of the multiwave joint inversion technology in tight sand identification.","PeriodicalId":502519,"journal":{"name":"Interpretation","volume":"117 8","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-05-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141126713","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Implication of Fast Shear Wave Azimuth and Critically Stressed Fractures in Coalbed Methane Reservoir","authors":"Abir Banerjee, Gautam Bhattacharya, Nawin Lugun, Aloke Das, Aditya Johri","doi":"10.1190/int-2023-0119.1","DOIUrl":"https://doi.org/10.1190/int-2023-0119.1","url":null,"abstract":"The orientation of fractures and stresses within coal seams plays a critical role in gas production from coalbed methane reservoirs. In this study, we utilized resistivity images and sonic logs to investigate these parameters, aiming to (i) establish the relationship between fracture orientations and the polarization angles of fast shear waves, and (ii) detect active fractures in the coal seam. Shear waves in anisotropic formations split into fast and slow components, with Alford’s rotation method used to determine the polarization angles of the fast shear wave. We found that the fast shear wave aligns with the direction of higher fracture intensity. Subsequently, we incorporated the poroelastic strain model to estimate vertical (Sv), maximum horizontal (SH), and minimum horizontal (Sh) stresses in the wellbore. These stress magnitudes aided in identifying the faulting regime and were corroborated by vertical opening mode fractures. Validation of SH and Sh involved comparison with breakout width in image logs and closure pressure observed during hydraulic fracturing treatments. Applying Mohr’s Coulomb criteria, the stress model discerned the state of fractures, transforming stress magnitudes into shear and effective normal stress on each fracture plane. Our observations indicated that identified fractures existed in a non-critically stressed condition, suggesting a lack of interconnectivity among them. These findings correspond to the absence of gas production to date, providing insights into the dynamics of fractures and their impact on production behavior.","PeriodicalId":502519,"journal":{"name":"Interpretation","volume":"55 8","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-05-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140964930","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"AUTOMATED HIGH-PRECISION ALIGNMENT OF GEOLOGICAL MAPS WITH WELL ORIENTATION","authors":"Yue Ma, Yubing Li, Abdulmohsen M. Ali, Nasher M. AlBinHassan, Yi Luo","doi":"10.1190/int-2023-0124.1","DOIUrl":"https://doi.org/10.1190/int-2023-0124.1","url":null,"abstract":"The 3D reflection seismic interpretation entails the creation of structure maps of subsurface horizons across extensive areas, often spanning tens of thousands of square kilometers within sedimentary basins. In order to be correlated with well measurements, maps made from 3D reflection seismic are routinely assigned the correct depth at well control points. However, integrating orientation information measured from wells remains a challenge due to the absence of upscaling guidelines. We address the scale-dependent nature of geological structure and well orientation information in subsurface mapping, particularly focusing on integrating kilometer-scale seismic interpretation with centimeter-scale well-measured dip and azimuth data. Our pioneering methodology streamlines this integration process through three essential steps: first, transforming well dip and azimuth into a gradient representation; second, smoothly extending gradient differences between the map and well within a user-defined radius of influence; and third, constructing an updated horizon map by Bicubic spline interpolation to ensure automated and high-precision alignment. Additionally, a structure-oriented interpolation technique is introduced to preserve faults and local structures during orientation correction. Application of the methodology to a 3D reflection seismic horizon demonstrates its effectiveness in automating the complex task of tying subsurface maps to well orientation information. This not only reduces the need for manual interventions but also introduces a new perspective in subsurface mapping. It provides a robust framework that enhances the accuracy and reliability of geological interpretation, offering significant advancements beyond previous efforts in the literature.","PeriodicalId":502519,"journal":{"name":"Interpretation","volume":"31 4","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-05-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140970972","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Gravity Field and Crustal Structure of the Eastern Arm of Sulawesi and the Banggai Archipelago, Eastern Indonesia","authors":"Eddy Mirnanda, D. Kusnida, T. B. Nainggolan, Budi Setyanta, Subagio","doi":"10.1190/int-2023-0055.1","DOIUrl":"https://doi.org/10.1190/int-2023-0055.1","url":null,"abstract":"The occurrence of extensive ophiolite masses and the development of the Batui-Balantak foreland thrust-fold belt on the East Arm of Sulawesi can be attributed to the geological process in the Neogene period when the Sulawesi Island Arc and the Banggai-Sula collided. Following the convergence, crustal fragments were further adjusted on a regional scale. This adjustment involved the rotation of crustal fragments into strike-slip faults on Sulawesi Island and the formation of extensional faults in the Banggai Archipelago. The analyses of the gravity field in the region of the eastern Sulawesi and Banggai Archipelago have yielded models that can potentially be interpreted as the representation of the underlying crustal structure in the region. The models can also be understood in a way that has consequences for tectonics. The tectonic episodes have played a significant role in the formation and development of sedimentary basins within the region. The primary objective of this study was to investigate the crustal structures of the eastern arm of Sulawesi and the Banggai Archipelago by means of analyzing gravity profiles. The findings of the analysis suggest that there is a slight thickening observed in the crustal block beneath the central portion of the eastern arm region. Additionally, this area exhibits significant fracturing and severe attenuation. Furthermore, it appeared that the crustal block has dipped north-eastward trend in response to the descent of the Molucca Sea oceanic crust.","PeriodicalId":502519,"journal":{"name":"Interpretation","volume":"54 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-05-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140970684","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A Fresh Approach to Understanding the Genesis and Distribution of Widespread Reservoirs at the Basin Edge: A Case Study of Gas-Bearing Sandstone in the Sangonghe Formation of the Jurassic Period, Qianshao Area, Junggar Basin, China","authors":"Ling Wang, Tingbin Sun, Peng Liu, Zichuan Wang, Wen Yin, Tao Xu, Yihe Wei, Qian Gao","doi":"10.1190/int-2023-0104.1","DOIUrl":"https://doi.org/10.1190/int-2023-0104.1","url":null,"abstract":"A 20m-thick sandstone drilled in the second member of the Sangonghe Formation in the Qianshao area of the Junggar Basin has been identified to be a high-quality gas-bearing reservoir. However, the recent missions reveal an uncertainty on reservoir distribution and bring high risk to the subsequent gas development, although the gas-bearing reservoir has been encountered by several drillings and proved to be widespread. To investigate the accurate distribution and reveal the evolution of the reservoir, we reconstructed the stratigraphic framework and depositional stages by high-revolution sequence stratigraphic method, effectively identified the gas-bearing reservoir by seismic attributes refusion and seismic stratigraphic slices, and finally mapped the distribution strata distribution at different stages. The results show that the landward onlap phenomenon in the seismic data indicates a retrogradational stratigraphic structure during the water level rise rather than the equal-thickness stratigraphic pattern under stable water conditions. According to retrogradational stratigraphic structure, the real driver for the widespread characteristic of gas-bearing reservoir is the backward staggered movement of multi-stage sand-bodies during the transgressive process, rather than single-stage deposition. The fusion of seismic Acoustic Impedance and Main frequency attributes provides an effective survey to identify the accurate distribution of the reservoir, by which interpretation of a stratigraphic slice long the vertical centerline of the reservoir extracted in the multi-attribute fusion survey can present the distribution and evolution of the three stages on only one map. Achieved by the appropriate interpretation on the map, two sandy debris flow bodies were identified to be deposited on the bottom successively during the first two transgressive stages, they were completely staggered in the source direction with a clear boundary between well Qs9 and Qs7.","PeriodicalId":502519,"journal":{"name":"Interpretation","volume":" 11","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-05-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140997243","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Characterization of seismic-scale petrofacies variability in the Arbuckle Group using supervised machine learning: Wellington Field, Kansas","authors":"A. Caf, D. Lubo-Robles, K. Marfurt, H. Bedle, M. Pranter","doi":"10.1190/int-2023-0093.1","DOIUrl":"https://doi.org/10.1190/int-2023-0093.1","url":null,"abstract":"The Arbuckle Group in southern Kansas has been investigated for carbon geosequestration-related studies. In this study, we evaluated seismic-scale petrophysically defined facies variability of the Arbuckle Group at the Wellington Field, Kansas, using quantitative seismic interpretation and a supervised Random Forest classification approach. We first defined three petrophysics-based rock types (petrofacies) from core-derived porosity and permeability measurements using the flow-zone indicator (FZI) approach. Then, using the artificial neural network (ANN), we classified these petrofacies in non-cored intervals. We observed that petrofacies 1 corresponds to medium and coarse-grained dolomitic packstone, wackestone, and dolomitic breccia with up to 8% porosity and Darcy-scale permeability values. Whereas petrofacies 2 and 3 correspond to argillaceous and fine-grained micritic dolomites and dolomitic mudstones with lower permeability values for a given porosity, with respect to petrofacies 1. Using the common reflection-point gathers, we performed pre-stack seismic inversion and calculated various amplitude-versus-offset (AVO) attribute volumes. We used these elastic properties and AVO attribute volumes as input for estimating supervised seismic-scale 3D petrofacies and petrofacies probability volumes using the Random Forest algorithm. Results reveal the complex distribution of petrofacies in the candidate injection and baffle zones in the study area, where petrofacies 1 is mainly prevalent within the lower and upper portions of the Arbuckle group, while petrofacies 2 and 3 are mainly present in the middle Arbuckle interval. The workflow we present through this study provides spatial variability of facies distribution that is reflective of actual lithology and petrophysical properties of the Arbuckle group in the study area with limited well control.","PeriodicalId":502519,"journal":{"name":"Interpretation","volume":" 4","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-05-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140995439","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"FAULT-TRANSFORMER: AN AUTOMATIC FAULT DETECTION ALGORITHM ON SEISMIC IMAGES USING A TRANSFORMER ENHANCED NEURAL NETWORK","authors":"Tong Zhou, Yue Ma, Yuhan Sui, Nasher M. AlBinHassan","doi":"10.1190/int-2023-0120.1","DOIUrl":"https://doi.org/10.1190/int-2023-0120.1","url":null,"abstract":"Seismic fault detection is a key step in seismic interpretation and reservoir characterization that often requires a large amount of human labor and interpretation time. Therefore, automatic seismic fault detection is critical for improving the efficiency of seismic data processing and interpretation. Existing AI methods are mostly based on convolutional neural networks (CNNs) with a U-shaped encoder-decoder structure, known as the U-net. However, the convolution is limited in modeling long-range correlative features. Instead, Transformers, utilizing self-attention mechanisms, avoid the local nature of the convolution, which has the potential to extract long-distance correlations. Transformers are proven to perform well in natural language processing, image classification, and segmentation tasks in precision and recall. Here, we develop a new deep neural network with transformers and a U-net-like structure: Fault-Transformer, to perform the fault detection task. The new network outperforms traditional U-net in the application with synthetic data sets.","PeriodicalId":502519,"journal":{"name":"Interpretation","volume":"109 4","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-05-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141001877","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The depositional evolution and associated controls on reservoir property in the Permian Upper Urho Formation, Southern Zhongguai Rise, Junggar Basin, NW China","authors":"Hongfei Chen, Xiongqi Pang, Liyin Bao, Zhiqi Wu, Naixiang He, Jun Gao","doi":"10.1190/int-2023-0110.1","DOIUrl":"https://doi.org/10.1190/int-2023-0110.1","url":null,"abstract":"The Permian strata in southern Zhongguai Rise are famous for their abundant petroleum reservoirs. The depositional evolution of the Upper Urho Formation has been studied analyzing the interactions between the sedimentary environments and the diagenetic evolution based on the comprehensive analysis of geological and geophysical datasets. The obtained results have shown that fan delta deposits, overlain by lacustrine deposits, were deposited. Proceeding upwards, the fan delta succession is characterized by retrogradational patterns, including both sandstone facies and conglomeratic facies. These facies have shown different clay mineralogic composition, porosity and physical properties. The sandstone facies shows well-sorted and well-rounded sedimentological textures, with good physical properties. In contrast, the conglomeratic facies shows poorly-sorted and poorly-rounded sedimentological textures, with poor physical properties. All these characteristics leading to reservoir heterogeneity result from sedimentary facies and diagenesis.","PeriodicalId":502519,"journal":{"name":"Interpretation","volume":"49 4","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-05-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141017059","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Seismic net-to-gross estimation for a geological model update: A case study from a turbidite lobe reservoir in the deep-water of the Niger Delta","authors":"O. Olagundoye, Emmanuel Akhajeme, Moyosoluwa Yusuf, C. Chizea, Vincenzo Spina, T. Joubert, Ali Parsa, M. Fashanu, C. Enuma, Jeffrey Jaiyeola, E. Epelle, Temitope Olabiyi","doi":"10.1190/int-2023-0112.1","DOIUrl":"https://doi.org/10.1190/int-2023-0112.1","url":null,"abstract":"Geological model updates are routinely performed in mature fields to obtain improved descriptions of facies distributions and reservoir properties such as volume of shale, net-to-gross (NTG), porosity, etc., for better understanding of the static and dynamic behaviors of reservoirs for effective well placement, improved production, and monitoring. A simple but integrated seismic NTG estimation approach, using detuned seismic amplitudes was employed in guiding NTG modeling during the geological model update of a thin turbidite lobe reservoir in a mature oil field in the deep offshore Niger Delta. The objective was to address NTG overestimation and gross rock volume (GRV) uncertainty in a previous model arising from seismic amplitude tuning effects. A seismic NTG approach was chosen relative to sophisticated deterministic or stochastic inversion techniques to avoid tuning effects which usually bias NTG estimates in thin turbidite reservoirs. The primary dataset was a 2019 reprocessed Prestack Depth Migrated (PSDM) seismic data vintage which had better resolution, higher signal-to-noise ratio (SNR), and more appropriate angle-stack apertures for amplitude versus angle (AVA) fidelity, than the older 2011 PSDM seismic data that was used in the previous geological model. The methodology involved rock physics analysis, seismic data quality checks, tuned area determination, detuning of composite seismic amplitudes of the top and base reservoir, and their direct calibration to NTG at wells. Good correlations were obtained between the detuned composite seismic amplitudes and NTG at wells. The seismic NTG map showed good calibrations at wells and provided a robust trend for net sand modelling in the oil pool and aquifer. Static model QCs and dynamic simulations proved that the seismic NTG attribute addressed the GRV uncertainty in the earlier model, thus giving confidence for use of the updated model for the planning and geosteering of infill wells, sand completions, reservoir monitoring, and production.","PeriodicalId":502519,"journal":{"name":"Interpretation","volume":"25 2","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-05-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141014699","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}