Day 2 Tue, November 01, 2022最新文献

{"title":"Seismic Motion Inversion Based on Geological Conditioning and Its Application in Thin Reservoir Prediction, Middle East","authors":"Chen Xin, Z. Min, Cui Jingbin, Q. Qunli, Yu Haisheng, Liao Xiaoliang, X. Dengyi, Chen Shuangting, Zhao Mingqiu, W. Bo, Gao Junqi, L. Qiang, P. Bo, A. Fuli, Gao Xiaoli","doi":"10.2118/211627-ms","DOIUrl":"https://doi.org/10.2118/211627-ms","url":null,"abstract":"\u0000 With the development of exploration and development, thin reservoir prediction is becoming more and more important. However, due to the limit of seismic resolution, thin reservoir prediction has always been an important challenge in the Middle East. Thin reservoir prediction based on conventional geophysical techniques is not accurate enough to meet the requirements of development. In order to improve the accuracy of thin reservoir prediction, a new thin reservoir prediction technique is proposed.\u0000 This technical workflow main includes 4 steps: (1) Sedimentary facies identification based on multidisciplinary analysis, (2) Sedimentary facies model and seismic forward modelling, (3) Seismic response characteristics analysis and seismic data conditioning under the guide of forward modelling, (4) Seismic meme inversion and thin reservoir prediction.\u0000 The new drilled wells demonstrate the successful application of the techniques in the M field in the Middle East. The 5 layers of thin sandstones reservoir can be divided into two sets of high stand systems of sand and low stand systems of incised valley deposits. Geological model seismic forward modelling shows that the most sensitive seismic dominant frequency for effectively identifying the two groups of sandstone is 35Hz (Fig.1). Through the high resolution seismic processing, the main frequency of seismic data was optimized from 25Hz to 35Hz, which improves the recognition ability for the thin sand groups (Fig.2). Seismic facies analysis based on previous and new seismic data shows that different thin reservoir layer can be effectively identified by seismic facies. Under the constraints of seismic facies, the Seismic meme inversion can effectively predict the two sand groups (Fig.3). 51 km2 of thin reservoir favourable area was discovered and 16 wells were drilled with 91% success rate based on the new seismic inversion result in the southeast part of the oilfield.\u0000 This technology can effectively integrate geological information and seismic conditioning techniques, and improve the accuracy of thin reservoir prediction results more reasonably, which can not only provide support for the exploration for thin reservoir but also efficient development. This technique is applicable not only to thin clastic reservoir but also to thin carbonate reservoir.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129400704","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":"State-Of- The Art Corrosion Inhibitor Development to Mitigate Pitting Corrosion in the Presence of Elemental Sulfur and Poly Sulfides in Sour Oil and Gas Systems","authors":"N. Obeyesekere, Douglas C. Dickey, J. Wylde","doi":"10.2118/211384-ms","DOIUrl":"https://doi.org/10.2118/211384-ms","url":null,"abstract":"\u0000 The effects of elemental sulfur on the corrosion of mild steel is a serious problem in the oil & gas industry costing millions of dollars annually in lost production and assets.\u0000 Mitigating the corrosive effects of elemental sulfur on mild steel in the oil and gas industry is a challenge and finding a viable solution would provide a more cost effective and safer working environment and as well as be environmentally conscious. Currently, there are no highly effective products for elemental sulfur corrosion in the marketplace.\u0000 More than fifty new chemical formulations were blended and screened by rotating cylinder electrode method (RCE). These formulations were tested in the presence of 0.1% elemental sulfur in mildly sour conditions. The promising candidates were identified and tested again in the presence of elemental sulfur under the same mildly sour conditions.\u0000 The most promising candidates from the initial screening were then subjected to rotating cage autoclave (RCA) testing for extended periods of time in the presence of 0.1% and 0.15% elemental sulfur. The general corrosion rates were calculated via weight loss and the metal surfaces were examined under a high-power digital microscope for pitting and localized corrosion.\u0000 A detailed analysis of the above testing yields promising results. The results from the testing show that formulations mitigate pitting in environments containing elemental sulfur. In less harsh conditions, such as low chloride brines or low CO2 environment, formulations seem to provide excellent protection against general corrosion while mitigating pitting due to elemental sulfur. In more extreme environments such as harsh brines with elevated chloride levels, high hydrogen sulfide and CO2 levels, the formulations mitigate pitting but need further development in inhibiting general corrosion The best product currently developed inhibits corrosion and pitting in the presence of elemental sulfur in various conditions and performs well against elemental sulfur in more aggressive sour systems. We are currently improving the performance against elemental sulfur and developing chemistries to mitigate polysulfide induced corrosion in sour systems.\u0000 This paper describes the development of effective inhibitors for corrosion and pitting in the presence of elemental sulfur under sour conditions. This study focuses more on pitting corrosion due to the corrosive characteristics of elemental sulfur than on uniform general corrosion. The general corrosion with the selected inhibitor was highly mitigated and was less than 3.0 mpy while yielding excellent protection against sulfur induced pitting.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"48 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133167481","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":"Alternatives to 28% Chrome for Production Tubing in Super-Giant Mediterranean Deep Water Gas Field, Zohr Field, Eni–Petrobel","authors":"Omar Yehya Abou Elseoud Ibrahim, W. Gabr, M. Kortam, Mahmoud Abdelrahman, M. Moawed, H. Elmasry","doi":"10.2118/211418-ms","DOIUrl":"https://doi.org/10.2118/211418-ms","url":null,"abstract":"\u0000 Zohr field was discovered in 2015 by the Italian energy company Eni and is the largest ever natural gas found in the Mediterranean Sea, with around (30 trillion cubic feet) total gas in place. Belaim Petroleum Company (Petrobel) (JV with ENI) is the Egyptian Petroleum Corporation arm and the owner of the project. Production started in December 2017 and since then 18 wells have been drilled for production.\u0000 This paper describes the criteria for material selection of the production strings for Zohr’s deep-water gas producers and how pre-tested and approved cost-effective alternatives are available for such a top-class project. The paper details the qualification and deployment of glass reinforced polymer (GRP) Lined Tubing as an alternative to 28%Chrome tubing, including the testing work that has been performed, and the operational aspects of running the referred-to alternative in several deep-water projects.\u0000 The choice of Duoline lined tubing results from the need for a cost-effective solution delivering the same operational requirements of 28% Chrome production strings. And since the Duoline GRE system will be integrated with the steel tubing therefore this system has to be previously fully approved and certified by the manufacturing mill of the lined tubing so there would be not even minor modifications to the specifications and the sealing performance of the premium connections and tubing body.\u0000 The paper indulges into describing the laboratory tests and the field experiences of the Duoline Lined tubing system in various fields globally, where this system has been tested in severe operating conditions with elevated levels of H2S, CO2, Salinity, dissolved Oxygen conditions to investigate the capability and service limits of the fiberglass liner at different temperatures. In addition to mentioning the erosion tests that were performed, mechanical tests such as pressure loop and make & break tests, how these various tests ended with good results and its comparison to the exotic high chrome joints performance.\u0000 This fiberglass lined tubing system has been applied in gas production wells since the 1980s, and ENI has been utilizing this technology in their production and water wells since 2005 in the north Africa, middle east, Kashagan regions and Norway offshore wells. On the other side, the technology has been successfully used world-wide in more than 55,000 wells since 1960s in various applications besides gas production strings.\u0000 The paper will present the past experience of ENI with fiberglass lined tubing, the laboratory tests, the field experiences, the economic evaluation of implementing this system in such a high-profile project, In addition to the pre-qualifications performed on this system by the OCTG mills and approvals granted to integrate this technology with the patent premium connection joints.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"41 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127418505","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":"Shell Autonomous Integrity Recognition - Machine Vision Application for Inspections","authors":"David Blom, I. Berchenko, F. Samie, Darian Frajberg","doi":"10.2118/211838-ms","DOIUrl":"https://doi.org/10.2118/211838-ms","url":null,"abstract":"\u0000 Shell Autonomous Integrity Recognition (AIR) on C3 AI Platform is an Artificial Intelligence (AI) application that allows pressure equipment and structural steel inspectors to quickly and easily make use of automated image capture and evaluation to support execution of external integrity inspections. By processing data in the cloud coming from inspections carried out with handheld devices, drones and robots, this application enables inspectors to objectively evaluate issues, identify items that may have been overlooked, reduce the time needed to generate reports, and improve inputs to maintenance planning. By using Shell Autonomous Integrity Recognition on C3 AI Platform, users can improve the quality, efficiency, and standardization of visual inspections.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"116 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124135465","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":"Deep-Set Velocity String for Liner Deliquification","authors":"Amira Salim Hajri, B. Ghaempanah, Ahmed Rashidi, C. Veeken, Kamran Awan","doi":"10.2118/211324-ms","DOIUrl":"https://doi.org/10.2118/211324-ms","url":null,"abstract":"\u0000 The installation of a smaller size tubing or velocity string inside an existing tubing completion is a well-known deliquification technique. The velocity string comes in various designs providing different functionalities for deliquification. Typically, velocity strings are installed to the top of the producing reservoir interval. In case multiple reservoirs produce across significant liner length (the liner here is the length/area between the two reservoirs), this \"shallow\" velocity string does not provide deliquification across the reservoir liner section. Depending on the size and length of the reservoir liner and the inflow performance of the producing reservoirs, the liquid loading across the liner can have significant adverse impact on production in which case deliquification by means of a \"deep\" velocity string installed across the reservoir liner becomes essential. This paper shares different designs, a modeling methodology and real-life assessment cases of such deep-set velocity strings, to achieve deliquification across the tubing completion above the reservoir and the liner completion straddling the reservoir. The proposed designs provide different flow options by changing the setting of sliding side doors (SSD's) embedded in the design or isolating the two zones by packers. The proposed modeling methodology helps to compare the performance of different flow options for shallow and deep velocity string designs. This paper continues by sharing three field cases of deep-set VS for the assessment of its real-life application.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"46 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124436823","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":"Foredeep Prospectivity in a Compressional Tectonic Regime, the Pabdeh Group, Ras Al Khaimah","authors":"P. Swire, G. Firpo, Michael Hibbert, T. Burckhart","doi":"10.2118/211702-ms","DOIUrl":"https://doi.org/10.2118/211702-ms","url":null,"abstract":"\u0000 \u0000 \u0000 The Pabdeh Group of Tertiary Paleocene to Oligocene age was deposited in a foredeep basin created by an obducted compressional thrust front that extends from Northwestern Oman into the Northern Emirates. The unit is represented by marls interbedded by thin calciturbidites and sandstones, the latter of which become more frequent in the Oligocene. The maximum thickness of the Pabdeh in the basin depocentre is ~3.5 km. The hydrocarbon play is proven in the Hamidiyah oilfield, located in Ajman, and is being pursued in Ras Al Khaimah utilizing recently acquired 3D seismic and legacy well data.\u0000 \u0000 \u0000 \u0000 Modern Play Based Exploration techniques including interpretation and integration of 3D seismic, Full Tensor Gravity (FTG), local well information, integration of biostratigraphic data, and geochemical analysis of source rocks was used to delineate the Pabdeh play area. The identification of delta fronts, channels, and basinal fans on seismic was linked to the complex interplay between tectonic and eustatic base level changes. Seismic morphologies were then supplemented by seismic amplitude analyses, and outcrop studies in the Emirate of Ras Al Khaimah (RAK). Ductile compressional folding due to closure of the Neo Tethys Basin is proven to have also effected sedimentation patterns with ponded fans also developing on the paleo-shelf.\u0000 \u0000 \u0000 \u0000 The Pabdeh Group is a thick monotonous unit that requires high resolution biostratigraphy with seismic guided sequence stratigraphy, to identify mappable units and unconformities across the foredeep basin. The Middle Eocene Pabdeh Fm. Is the primary reservoir target in the Hamidiyah Field. Pabdeh calciturbidites represent lowstand sedimentation basinward of major incisions. These calciturbidites were deposited as debris flows originating from deltas near the thrust front. Submarine channels were cut into the shelf edge along the compressional thrusting front (in the present near offshore of RAK), and basinal fans can be observed in the present-day offshore 3D seismic. The calciturbidite facies has been identified in several wells with clear hydrocarbon shows and successful tests. Structural traps can be defined in tight ductile folds with a N-S trend, along with potential for stratigraphic traps. Main risk factors are around reservoir effectiveness and clearly defined migration pathways.\u0000 \u0000 \u0000 \u0000 For the first time the detailed sequence stratigraphy of the Pabdeh Group has been used to determine prospectivity in RAK and is now being expanded across the Northern Emirates using modern 3D seismic and Play Based Exploration (PBE) techniques.\u0000","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"255 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114362644","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":"Re Configuring and Restaging Centrifugal Compressors for Depleting Reservoir Pressures","authors":"Roy Sahadevan","doi":"10.2118/211326-ms","DOIUrl":"https://doi.org/10.2118/211326-ms","url":null,"abstract":"\u0000 Compressor stations are essential to export natural gas through pipelines. Gas reservoirs deplete over the years, as a consequence, gas compressor stations experience a lower-than-normal suction pressure. Hence it becomes increasingly difficult for the existing compressor hardware to export gas to destination.\u0000 Variable speed compressors are designed with certain amount of flexibility to accommodate changes in inlet pressure conditions. However significant changes in inlet operating conditions, because of reservoir depletion, adversely affect natural gas export through centrifugal gas compressors.\u0000 This prompts operating companies to develop alternate solutions to export low pressure gas. In the process, compressor modification opportunities need to be identified, developed and be applied to facilitate gas export at revised inlet conditions, either by changing pressure ratio across the compressor or gas flow rate or both. Rearranging parallel compressors to series operation is one of the likely methods of achieving higher pressure ratio for gas export. Restaging of existing compressor may also be required to optimize compressor operation.\u0000 Cost effective projects are delivered by lining up the compressors differently and by changing compressor internal stator and rotor components to suit new operating conditions, avoiding off-design operation, and allowing the modified compressor to operate in an envelope with increased operational efficiency. This is also known as upgrade or re-rating of compressors.\u0000 The paper is about rearranging and restaging existing gas compressors in onshore gas compressor stations, to export natural gas, when the gas wells experiencing significant pressure depletion.\u0000 The paper explain method of establishing maximum gas export rate, highest pipeline back pressure for gas export and the compressor discharge pressures at battery limits. The adequacy checks are performed on compressors, motors, and all associated auxiliary systems.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"2014 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114484446","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":"An Innovative Wellbore Cleanup Solution for Non-Cemented Lower Completions Saves 27 Million$ in ADNOC Onshore","authors":"E. Varma, P. Mwansa, M. Husien, Abdul Raman Bin Bahrom, Raymond Saragi, Ali Sulaiman Ahmed BinSumaida, Musabbeh Khamis Al Samahi, El Walid Ben Mohamed El Moumni, Juma Sulaiman Al Shamsi, Ahmad Othman Alshaigy, Anchit Gaurav, Khaled Abdelhalim","doi":"10.2118/211548-ms","DOIUrl":"https://doi.org/10.2118/211548-ms","url":null,"abstract":"\u0000 The long-term development of any mature field requires a fresh perspective of long MRC (Maximum reservoir contact) wells and increased well accessibility. To improve well accessibility the deployment of lower completion has been a mandate. Onshore UAE Field demands drilling Slim hole (6″ /6-1/8″ ) laterals and Slim Hole ERD (Extended reach drilling) wells with 4.5″ Uncemented Lower Completion. This paper highlights the innovative wellbore cleanout procedure prior installation of Lower Completions.\u0000 Conventionally, using Water Based Mud (WBM) with high friction factors in 6″ Horizontal Hole (HH), two trips were required to reduce the friction factor prior running the Lower Completion. The optimized solution allowed wellbore clean-up and displacement of brine in one trip with drilling assembly (BHA). This innovative technique eliminated one dedicated trip for wellbore cleanout and thus saved millions in CAPEX and Business Plan days.\u0000 The T&D data for 5 wells with dedicated cleanout trip were compared to clean-out with 6″ drilling BHA with viscous-lubricated brine. The 6″ BHA was optimized to fit with innovative dormant drilling scrapper and lubricated viscous brine was displaced in the Open Hole. A thorough hole cleaning procedure was formulated and was applied to all the wells.\u0000 After analyzing over 5 wells, it was observed that in both runs, the one with 6″ BHA compared to dedicated cleanout-trip, the torque and drag values were similar and the effective reduction in friction factor was similar. This supported the elimination of planned dedicated cleanout trip and saved average 2 days/well and 27MM$ for year 2022.\u0000 This optimized BHA design with enhanced hole cleaning procedure was a keystone in deploying slim 4-1/2″ lower completion in WBM system. This practice led to successful deployment of First Slim Hole ERD in UAE with 15000ft of 4-1/2″ lower completion with WBM system. This was a one-of-a-kind achievement in UAE.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"26 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114507494","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":"Wells Operations Data Visualization Through GIS Mapping Software","authors":"Saif Al Aufi, Asif Ismail, Maadh Al Mamari, Mahra Al Ruwaishdi, Rafael Cruz, Ishaq Haddabi, Khamis Al Bulushi, F. Khatri, Hamed Al Manhi, A. Kalbani, Saif Al Yaroubi, Jawad Hashmi, Abdullah Mashrafi","doi":"10.2118/211830-ms","DOIUrl":"https://doi.org/10.2118/211830-ms","url":null,"abstract":"\u0000 PDO has grown rapidly over the past few years and is seen as an innovative organisation and a leading company within the Middle East when it comes to applying best practice, adding value to the economical and societal development of the Sultanate of Oman\u0000 In the highly volatile oil business market, it is very crucial to having information on fingertip, making informed decisions, visualization of the area where the task is been carried out, to know who owns and operates, liable route network adhering to the HSE policies and safety, availability of assets and resources thus helping the workforce to connect, collaborate and deli ver the business KPIs seamlessly.\u0000 Current ways of operating was the field resources have to navigate to different standalone systems, offline data or maps, excels and data sources to sketch out the needed information which was time consuming, indecorous infor mation, non availabilty of SME to validate and authenticate the data, information is especially valuable for PDO business.\u0000 As PDO understand the value of data decided to embark the journey through which allows PDO personnel's to connect data of different forms like Products, Assets, Devices, Location, Resources and to use the same in rationalized useful value to reveal the benefit of data value in PDO Business.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114917091","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":"Subtle Fault Prediction Technique Based on the Integration of Deep Learning and Seismic Spectral Decomposition","authors":"Li Qiang, Chen Xin, X. Dengyi, Z. Min, Q. Qunli, Yang Jianfang, Liao Xiaoliang, P. Bo, A. Fuli, W. Bo, Gao Xiaoli, Yang Chen","doi":"10.2118/211631-ms","DOIUrl":"https://doi.org/10.2118/211631-ms","url":null,"abstract":"\u0000 Faults often control the movement and aggregation of oil and gas. With the development of oil fields, the role of subtle faults is becoming more and more important. The accuracy of fault interpretation directly affects the direction of exploration and development. However, due to the limitation of the seismic resolution, it is hard to identify these faults according to routine methods such as coherence, variance, curvature, etc. To overcome such kind of challenge and better match the demand for fine fault identification, a method integrated deep learning and spectral decomposition was proposed.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"57 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115089875","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}