All Days最新文献

{"title":"Yielded Zone Characterization While Drilling a Wellbore into Clastic Reservoirs Using Elastoplastic Modeling Approaches","authors":"Osman Hamid, H. Albahrani, Mohammed Suaid","doi":"10.56952/igs-2023-0018","DOIUrl":"https://doi.org/10.56952/igs-2023-0018","url":null,"abstract":"Drilling a wellbore into a clastic reservoir exhibits complex rock behavior, including plastic deformation and yield zone development, which can affect wellbore stability and hydrocarbon production efficiency. Elastoplastic modeling methods have been increasingly used to simulate the drilling process and predict the location, shape, and size of yielded zones in the reservoir. This study aims to characterize the yielded zones in a sandstone reservoir during a borehole lifetime using elastoplastic modeling approaches. The methodology involves developing a finite element model of the sandstone reservoir using appropriate meshing techniques and boundary conditions definition for the problem. The constitutive model used in this study is the Drucker-Prager yielded criterion, which accounts for the non-linear behavior of the material during plastic deformation and yielding. The numerical method used is the finite element method, which discretizes the reservoir into small elements and solves for the stresses and strains in each element. The drilling process is simulated using incremental loading, miming the gradual application of drilling forces on the reservoir. The stress and strain fields in the reservoir were monitored during drilling, and areas of plastic deformation and yield were identified. The results showed that the elastoplastic modeling approaches used in this study accurately predicted the size, shape, and location of yielded zones in the clastic reservoir. The location and shape of the yielded zones agreed with the field observations. Additionally, the model predicted the formation of a narrow, highly deformed zone around the wellbore, which is consistent with field observations. The size of the yielded zone depended on the drilling parameters, rock mechanical properties, and in-situ stresses. This study concludes that elastoplastic modeling approaches can be used to predict the size, shape, and location of yielded zones in sandstone reservoirs during wellbore drilling and production operations. The methodology used in this study can be used as a valuable tool for borehole planning and reservoir management. The innovation of this study lies within the use of elastoplastic modeling approaches to optimize drilling parameters and reduce the risk of wellbore instability in sandstone reservoirs. The results of this study can aid in designing drilling strategies that minimize the impact of yielded zones and improve wellbore stability, ultimately leading to increased production efficiency.","PeriodicalId":433009,"journal":{"name":"All Days","volume":"52 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139310412","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":"Simulation of Old Surface and Underground Working for Assessment of Slope Stability","authors":"T. Singh, M. Sazid","doi":"10.56952/igs-2023-0023","DOIUrl":"https://doi.org/10.56952/igs-2023-0023","url":null,"abstract":"Underground mining activities have potential influence on the surface slope stability. However, suitable attention has not yet been paid to these problems. The aim of this study is to analyze the possible influence of present and former mining activities on the selected set of physical and numerical model slope deformations in the Jharia Coalfield. In India coking coal seams are mainly confined to the Jharia coalfields of Jharkhand State. There are 19 coal seams, which were partially exploited earlier adopting the underground mining method. However, due to various complex geotechnical problems, it was not economically viable to continue the same method for coal extraction. A vast amount of coking coal remains unrecovered as they stand as pillars, collapsed materials, partings, barriers, etc. waiting to be extracted to meet the growing energy demand. In order to bridge the gap between the growing demands and supply, it is essential that the coal locked in the underground workings be recovered fully by implementing surface mining methods. As these new surface mines are planned in the areas which contain old surface and underground workings, the major problems will be the stability of slopes particularly when they meet the old underground workings, and the behavior of previously subsided material in the pit slopes. The present study was conducted to understand the effect of underground workings on the stability of new slopes using physical and numerical simulation. This paper emphasizes on the numerical simulation and further verification of the physical model results. The physical model results are well corroborated with numerical simulation study.","PeriodicalId":433009,"journal":{"name":"All Days","volume":"23 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139310536","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":"Pragmatic Methodology for Evaluation of Geomechanical Risks During Feasibility Assessment of Fields for CO2 Geological Storage","authors":"I. H. Musa, C. P. Tan, J. Leem, P. K. Tiwari","doi":"10.56952/igs-2023-0030","DOIUrl":"https://doi.org/10.56952/igs-2023-0030","url":null,"abstract":"As part of on-going efforts to reduce the impact of climate change, carbon dioxide (CO2) emission is captured and reinjected into underground formations as part of carbon capture and storage (CCS) projects. Geomechanical risks assessment which is part of CCS feasibility study was conducted in Field A. The pragmatic methodology for geomechanical risk assessment in Field A begins with selection of wells with adequate data for 1D geomechanical models construction. Once the models have been generated, rock mechanical properties, pore pressure and stresses are extracted as inputs for caprock integrity analysis. Taking into account the impact of pore pressure increase on horizontal stress changes in the reservoir and caprock, maximum injection pressure at the formations of interest is determined. Fault stability analysis is then performed on the faults in the field which show that all the faults remained stable throughout CO2 injection. The resultant seabed uplift assessed is low at the end of injection period. The feasibility study has move to storage development plan stage which involved 4D coupled geomechanics dynamic modeling.","PeriodicalId":433009,"journal":{"name":"All Days","volume":"32 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139310554","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":"Novel Fresh Water-Based Mud System in Highly Reactive Shale Formation: Experimental and Case Studies","authors":"Mohammed Ba Geri, Demond Kauffman, Daryl Cullum","doi":"10.56952/igs-2023-0288","DOIUrl":"https://doi.org/10.56952/igs-2023-0288","url":null,"abstract":"This paper investigates a novel water-based mud (NWBM) system for drilling in reactive shale formations. Laboratory experiments were conducted to evaluate the performance of NWBM with the Novel Polymeric Additive (NPA). Tests measured rheology, shale swelling, and high temperature/high pressure (HTHP) filtration loss. The results showed that NWBM with NPA significantly reduced mud filtration loss by over 78% compared to traditional water-based mud (TWBM). It also inhibited shale swelling by 40% and increased the rate of penetration by 28%. A case study in Bahrain demonstrated the successful field application of NWBM in reactive anhydrite formations. Despite wellbore stability challenges, the NWBM system enabled faster drilling with zero non-productive time (NPT). This research indicates that NWBM with NPA is a promising drilling fluid for reactive shale drilling. It can enhance drilling performance, reduce risks, and achieve operational efficiency. Further work is needed to optimize NWBM formulations for specific shale plays and evaluate environmental impacts. Field trials in different shale formations will help demonstrate the technology. This study provides a comprehensive overview of NWBM for drilling in reactive shales. The fluid system has great potential to overcome issues like wellbore instability, fluid loss, and NPT in challenging shale wells.","PeriodicalId":433009,"journal":{"name":"All Days","volume":"66 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139310779","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 New Technology of Combined Network Fracturing for Shale Oil Reservoir in Jiyang Depression","authors":"Haiyan Zhu, Chuhao Huang, Xuanhe Tang, Lei Tao, Peng Zhao, Zhaopeng Zhang, Jiandong Wang, Liaoyuan Zhang, Guangqing Zhou","doi":"10.56952/igs-2023-0021","DOIUrl":"https://doi.org/10.56952/igs-2023-0021","url":null,"abstract":"The resources of Paleogene shale oil reservoirs in Jiyang depression of Bohai Bay are very rich. However, compared with other shale oil reservoirs, Jiyang Depression has a deeper burial depth, complex structure, stronger heterogeneity, more developed bedding fractures, and poor crude oil mobility. Conventional fracturing technology generally has low fracturing efficiency, leading to low production and fast attenuation after fracturing. In general, there are the following scientific problems: 1) it is difficult to evaluate the fracturing sweet spot of reservoirs with high stress, high plasticity, and strong heterogeneity reservoirs, and it is difficult to effectively guide the well and fracturing section selection; 2) it is difficult for hydraulic fractures to cross through multiple shale layers in reservoirs with developed bedding fractures; 3) It is difficult for conventional continuous sanding fracturing to meet the special demand of high viscous crude oil for high conductivity of fracture network. To solve the problems, a new technology of combined network fracturing is proposed. The technology has been applied to shale oil reservoirs in Jiyang Depression, and has continuously broken the record for the highest daily production of shale oil in China, which supports the construction of the \"Jiyang Depression Shale Oil National Demonstration Zone\".","PeriodicalId":433009,"journal":{"name":"All Days","volume":"269 1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139310950","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":"High Temperature Influence in Pore Pressure Prediction – Case Study in Offshore Malaysia","authors":"Nik M Fadhlan Nik Kamaruddin, Kevin Teng Ging Ern","doi":"10.56952/igs-2023-0162","DOIUrl":"https://doi.org/10.56952/igs-2023-0162","url":null,"abstract":"Pore pressure studies are key components for well design engineering and economics consideration to safely reach deep petroleum resources. However, in deeper reservoirs, additional geological processes are favorable for secondary overpressure mechanisms which may lead to uncertainty in pore pressure prediction. Analyses conducted are interpreted together with petrophysical, stress and pressure plots such as depth-based velocity-density, porosity-effective vertical stress, field data (formation and temperature) and observations (stress and pressure measurements). The results show the highest uncertainties in predictions versus actual measurements are often observed at 80 to 140 degree Celsius. This temperature range is often related to less predictable fluid properties and pressure due to probable complex geological processes such as hydrocarbon generation, diagenesis, metagenesis, chemical compaction and alteration. For each temperature range, the estimation errors are plotted and assessed based on field observations. The paper highlights the differences between estimation of pore pressure and actual measurements at a range of temperatures and the evaluation of uncertainties associated with temperature in pore pressure prediction. The origins of overpressure and associated geological processes are important in providing thorough and improved understanding on the effects of temperature and the pore pressure prediction reliability. The paper presents an improved methodology and workflow in pore pressure prediction coupled with petrophysical analysis for range of temperatures which provides additional insights for timely decision making. It also aims to encourage the community and industry to consider the replication and potentially improving the workflow for determining uncertainty and increasing understanding in pore pressure prediction at elevated temperatures.","PeriodicalId":433009,"journal":{"name":"All Days","volume":"156 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139311060","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":"Investigation of Fault Activation Mechanisms in Carbon (CO2) Storage","authors":"A. Mortazavi, T. Maratov","doi":"10.56952/igs-2023-0009","DOIUrl":"https://doi.org/10.56952/igs-2023-0009","url":null,"abstract":"Due to heavy industrialization and ongoing fossil fuel burning, CO2 emissions have been a major contributor to climate change and enhanced greenhouse gases. The growing public concern motivates considerable study towards discovering an efficient technique of managing and lowering the emission amounts, and CO2 collection and subterranean storage have been presented as viable alternative. In order to assess the geomechanical behavior of the multilayered In Salah CO2 storage site, a two-dimensional finite element model of fault activation processes in the context of CO2 storage was conducted. It is 4 km wide and 2 km deep and includes the key domains and formations (overburden, main caprock, lower caprock, and underburden). The simulation results suggest that the influence of fault reactivation under base pressure of 32 MPa causes peak vertical deformation of 0.044 m in the caprock and 0.015 - 0.020 m displacement at the surface layers. The obtained modelling results are in agreement with InSAR monitoring results conducted at the site. The geomechanical model was moderately sensitive to a decrease in the effective stress ratio and fault dip angle. The scenario with k = 0.5 performed a considerable displacement reduction compared to the benchmark run. The simulation with a 30° fault angle demonstrated a more pessimistic outcome with a larger displacement field, which could heighten the risks associated with the low-angle faults in the areas of high horizontal stress distribution.","PeriodicalId":433009,"journal":{"name":"All Days","volume":"2021 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139311075","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":"Advanced Hole Cleaning Monitoring in Real-time Improves Drilling Performance in Highly Deviated and Horizontal MRC (Maximum Reservoir Contact) Wells Drilled in the Lower Cretaceous Formations","authors":"M. Al-Sawafi, A. Hamouda, K. Ousdidene, V. Parmeshwar, W. Louati, S. Sharma, M. Farouk, A. Bahgat","doi":"10.56952/igs-2023-0056","DOIUrl":"https://doi.org/10.56952/igs-2023-0056","url":null,"abstract":"Hole cleaning and wellbore instability remain key challenges while drilling highly deviated or horizontal wells. Inadequate hole cleaning or excess cuttings generated due to wellbore instability leads to incidents like stuck pipes due to well packing off and increasing Non-Productive Time (NPT). In addition, problems such as premature bit wear, high torque, and drag due to improper hole cleaning reduce the drilling rates and increase drilling costs. The two case studies presented in this paper demonstrate the use of the advanced hole-cleaning monitoring approach in the horizontal section of Maximum Reservoir Contact wells across the Lower Cretaceous horizon. Data acquired in real-time from the hole-cleaning equipment provided actionable information that permitted timely optimization of drilling parameters for improved hole condition. These remedial actions avoided unplanned events such as hole pack-off and excessive reaming. The wells were drilled efficiently within the schedule, with the minimal risk associated with cuttings loading of the well due to improper hole cleaning.","PeriodicalId":433009,"journal":{"name":"All Days","volume":"54 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139311204","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":"Geomechanical Integration Maximizes the Value for Polymer Full Field Decision for Clastic Reservoir Field in South of Oman","authors":"R. Zadjali, Z. Rawahi, O. Riyami, A. Rawahi, N. Mandhari, A. Hadhrami, M. Ghannami","doi":"10.56952/igs-2023-0425","DOIUrl":"https://doi.org/10.56952/igs-2023-0425","url":null,"abstract":"Integration between different disciplines is a key to the success of any field development plans (FDP) and well, reservoir and facility management (WRFM). For a proposed waterflood development, the injection strategy is to inject under matrix conditions (i.e. below fracture pressure limit) at an optimal rate to improve sweep efficiency and hence maximize oil recovery. Therefore, injection rate was constrained at maximum operating injection Tubing head pressure (THP) based on analogue data and correlation. After several years, the reservoir pressure showed significant depletion. As a consequence, the field experienced drastic oil rate drops with a gas development in localized area. In addition, moving to polymerflood, it was realized through simulation that economical injection rates can only be achieved under controlled fracture injection. Therefore, for both developments understanding the fracture pressure, depletion impact on fracture pressure gradient and fracture growth is a key. This paper demonstrates Geomechanics key role in integration with subsurface and surface discipline to optimize waterflood performance and land on key project decisions of polymerflood full field development project for a clastic reservoir field in south of Oman. The current injection strategy in the field is to inject under matrix condition and to maximize injection by injecting up to the fracture pressure. The downhole pressure should not exceed the fracture pressure to avoid inducing fractures. Step rate tests (SRTs) were available for this field but did not provide a conclusive interpretation. A mini-frac test was conducted later, in the most depleted area, which provides reliable estimate of fracture pressure. The selected candidate well covers the reservoir two main units (A) representing the depleted case and (B) close to virgin pressure. As a follow up surveillance monitoring, more recent SRTs were planned, executed, and monitored through a Fiber Optic (FO) data acquisition consisting of Distributed Temperature Sensing (DTS) and Distributed Acoustic Sensing (DAS). For polymer flood on the other hand fracture growth was estimated using analogue field data in absence of actual long term polymerflood fracture injection data. Analysis of available old Step Rate Tests (SRT) indicated injectivity improvement at THP ~4000 - 6000 kPa at rates varies between 200-500 m3/day. However, the SRT data could be influenced by near wellbore condition and added wellbore skin due to near wellbore damage and/or due to fines plugging the wellbore. A mini-frac test was conducted in 2019 which is in the most depleted area. This provided reliable estimate for fracture pressures for input to optimal injection pressure. Fracture pressure for the A/B intervals was interpreted to be in the range of 13500 to 15100 kPa (15 – 16 kPa/m at ~ 900 mTVDbdf at a reservoir pressure of~ 4000 kPa in unit A). From this data the interpreted safe THP limit for the field injectors to operate under matr","PeriodicalId":433009,"journal":{"name":"All Days","volume":"108 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139311236","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 Role of Geomechanics on Hydrogen Extraction","authors":"Osman Hamid, Nora Alsudairi","doi":"10.56952/igs-2023-0131","DOIUrl":"https://doi.org/10.56952/igs-2023-0131","url":null,"abstract":"The role of geomechanics in hydrogen extraction processes is crucial for understanding the behavior of subsurface formations and optimizing extraction techniques. This paper focuses on the modeling and rock testing aspects of geomechanics to investigate the influence of rock properties on hydrogen extraction efficiency and safety. The objective of this study is to explore the role of geomechanical modeling and rock testing in assessing reservoir behavior, wellbore stability, and storage integrity for hydrogen extraction projects. The methodology involves a comprehensive analysis of geomechanical modeling techniques and laboratory rock testing methods. Geomechanical modeling techniques, such as finite element analysis and discrete element modeling, provide valuable insights into the behavior of subsurface formations under different stress and fluid flow conditions. These models can simulate the mechanical response of the reservoir during hydrogen extraction, enabling the prediction of deformations, stress distributions, and potential failure mechanisms. The results highlight the significance of geomechanical modeling and rock testing in assessing the behavior of subsurface formations during hydrogen extraction. Geomechanical models help identify potential geomechanical risks, such as fault reactivation, induced seismicity, and wellbore instability, allowing operators to design optimal extraction strategies and implement appropriate mitigation measures. Rock testing provides crucial input parameters for accurate modeling and enhances the understanding of rock behavior, contributing to the assessment of reservoir performance and storage integrity. The conclusion drawn from this study is that geomechanical modeling and rock testing are essential tools for assessing the role of geomechanics in hydrogen extraction. By integrating these approaches, operators can gain valuable insights into the mechanical behavior of subsurface formations, optimize extraction techniques, and ensure the safe and efficient operation of hydrogen extraction projects. The innovation of this study lies in highlighting the importance of geomechanical modeling and rock testing in the context of hydrogen extraction. By incorporating these approaches, operators can make informed decisions regarding reservoir behavior, wellbore stability, and storage integrity, leading to enhanced operational efficiency and safety.","PeriodicalId":433009,"journal":{"name":"All Days","volume":"270 1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139311297","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}