P. Batruny, H. Yahya, N. Kadir, A. Omar, Z. Zakaria, Saravanan Batamale, Noreffendy Jayah
Low rates of penetration (ROP) were experienced in an area with well-known lithology. The vast drilling experience and similarity of drilling conditions in the area, provided the operator with enough data to improve the well schedule and cost performance through the use of machine learning. Machine learning, specifically artificial neural networks (ANN), is a statistical tool to find relations between multiple inputs. Details that would have been missed or considered outliers by a mathematical model can be accounted for and explained in the ANN model. The ANN was trained on thousands of real time data points recorded from selected wells in a specific depth interval. Typical drilling parameters such as weight on bit, rotary speed, bit hydraulics, lithological properties, and dogleg severity were the input parameters chosen in the model to generate ROP. Once the model was calibrated to historical data, it was used to find the best parameters to maximize ROP. R squared factors were 0.729 and 0.675 for 12.25 in. and 17.5 in. sections repectively. This was achieved with an ANN structure of 2 hidden layers consisting of 5 nodes each. Sensitivity analysis identified bit hydraulics, weight on bit, and rotary speed as the major parameters impacting ROP. The ROP model was used to conduct a "virtual drill-off test" to identify drilling parameters that maximize ROP. ROP dependency on weight on bit and lithological analysis suggests bit design can be further improved. Bit hydraulics showed that higher flow rate was needed in sections with higher overbalance. Optimum drilling parameters were tested on four wells and resulted in more than 50% higher ROP compared to original field data. In an industry increasingly dominated by big data, separating the clean data from the "noise" will be a vital topic. This paper aims to provide a blueprint for the use machine learning to optimize ROP in a manner that is simple and easily replicated.
{"title":"Drilling in the Digital Age: An Aproach to Optimizing ROP Using Machine Learning","authors":"P. Batruny, H. Yahya, N. Kadir, A. Omar, Z. Zakaria, Saravanan Batamale, Noreffendy Jayah","doi":"10.2118/197157-ms","DOIUrl":"https://doi.org/10.2118/197157-ms","url":null,"abstract":"\u0000 Low rates of penetration (ROP) were experienced in an area with well-known lithology. The vast drilling experience and similarity of drilling conditions in the area, provided the operator with enough data to improve the well schedule and cost performance through the use of machine learning.\u0000 Machine learning, specifically artificial neural networks (ANN), is a statistical tool to find relations between multiple inputs. Details that would have been missed or considered outliers by a mathematical model can be accounted for and explained in the ANN model. The ANN was trained on thousands of real time data points recorded from selected wells in a specific depth interval. Typical drilling parameters such as weight on bit, rotary speed, bit hydraulics, lithological properties, and dogleg severity were the input parameters chosen in the model to generate ROP. Once the model was calibrated to historical data, it was used to find the best parameters to maximize ROP.\u0000 R squared factors were 0.729 and 0.675 for 12.25 in. and 17.5 in. sections repectively. This was achieved with an ANN structure of 2 hidden layers consisting of 5 nodes each. Sensitivity analysis identified bit hydraulics, weight on bit, and rotary speed as the major parameters impacting ROP. The ROP model was used to conduct a \"virtual drill-off test\" to identify drilling parameters that maximize ROP. ROP dependency on weight on bit and lithological analysis suggests bit design can be further improved. Bit hydraulics showed that higher flow rate was needed in sections with higher overbalance. Optimum drilling parameters were tested on four wells and resulted in more than 50% higher ROP compared to original field data.\u0000 In an industry increasingly dominated by big data, separating the clean data from the \"noise\" will be a vital topic. This paper aims to provide a blueprint for the use machine learning to optimize ROP in a manner that is simple and easily replicated.","PeriodicalId":11091,"journal":{"name":"Day 3 Wed, November 13, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82313581","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}
H. Yonebayashi, Kazuyo Sasaya, Takumi Watanabe, T. Inamura, Atsushi Kobayashi, Takao Iwata
As a part of laboratory Health, Safety and Environment (HSE) management system, the working environment control is applied to eliminate exposure hazards for workers. This control is a continuous effort in our laboratory as the working environment management system. Volatile organic compounds (VOC)s are ones of very common exposure hazardous factors in petroleum R&D laboratory. To better working environment control, the working environment measurement additionally to the chemical risk assessments is conducted at first to assess the concentration of VOCs in accordance with the guideline of domestic act. The measurement design is optimized on the basis of actual chemical use in the monitoring objective laboratories. The chemical records has been tracked in the chemical inventory management system. The measurement is conducted by two methods to assess both of average and the maximum VOC concentrations in the objective laboratory. Based on the measurement results, the objective laboratories are classified into three ranks. If necessary, counter actions will be taken: for instance, ventilation system improvement as building management, and consideration of substitute. Furthermore, the working record what types of chemical used and how long hours to handle them are linked to the health management system in which the workers who handle solvents must take a semi-annual special medical check. Further potential improvements were debated by adopting the process safety management in laboratory phase, and installing flexible exhaust system. The working environment management is important for protecting employee's health. The system is not independent and linked to other HSE management systems. Therefore, a well-organized grand design is worthy as total management system which includes each management system for waste, inventory, procurement, building maintenance, and so on. Because this paper discussed a practical example of HSE management system from both of detailed and high level. The discussion should be useful for considering HSE in laboratory.
{"title":"Monitoring of Volatile Organic Compounds to Sustain Safe Laboratory Working Environment","authors":"H. Yonebayashi, Kazuyo Sasaya, Takumi Watanabe, T. Inamura, Atsushi Kobayashi, Takao Iwata","doi":"10.2118/197259-ms","DOIUrl":"https://doi.org/10.2118/197259-ms","url":null,"abstract":"\u0000 As a part of laboratory Health, Safety and Environment (HSE) management system, the working environment control is applied to eliminate exposure hazards for workers. This control is a continuous effort in our laboratory as the working environment management system. Volatile organic compounds (VOC)s are ones of very common exposure hazardous factors in petroleum R&D laboratory. To better working environment control, the working environment measurement additionally to the chemical risk assessments is conducted at first to assess the concentration of VOCs in accordance with the guideline of domestic act. The measurement design is optimized on the basis of actual chemical use in the monitoring objective laboratories. The chemical records has been tracked in the chemical inventory management system. The measurement is conducted by two methods to assess both of average and the maximum VOC concentrations in the objective laboratory. Based on the measurement results, the objective laboratories are classified into three ranks. If necessary, counter actions will be taken: for instance, ventilation system improvement as building management, and consideration of substitute. Furthermore, the working record what types of chemical used and how long hours to handle them are linked to the health management system in which the workers who handle solvents must take a semi-annual special medical check. Further potential improvements were debated by adopting the process safety management in laboratory phase, and installing flexible exhaust system.\u0000 The working environment management is important for protecting employee's health. The system is not independent and linked to other HSE management systems. Therefore, a well-organized grand design is worthy as total management system which includes each management system for waste, inventory, procurement, building maintenance, and so on. Because this paper discussed a practical example of HSE management system from both of detailed and high level. The discussion should be useful for considering HSE in laboratory.","PeriodicalId":11091,"journal":{"name":"Day 3 Wed, November 13, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75984885","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}
Zheng Sun, Juntai Shi, Zhao-peng Yang, Cai Wang, Tuobin Gou, Minxia He, Wen Zhao, Tianfu Yao, Jiayi Wu, Xiangfang Li
Much attention has been attracted by the successful development of shale gas reservoir in recent decades. Correspondingly, research aspects of shale gas reservoirs become more and more heat among the academic community, especially in the fields of nanoscale gas transport mechanisms as well as the storage modes. Fascinated by the craft interactions exerted by organic or inorganic shale surface, drastic discrepancy takes place in terms of the gas behavior inside the nanoscale dimension and that in conventional dimension. It is crucial to figure out the exact influence on shale gas recovery and overall production efficiency due to the above large difference. Notably, this paper is designed to comprehensively explore the methane storage behavior in shale nanopores, expecting to provide the direct relationship between adsorption gas and free gas content under various environmental conditions. Also, a novel and simple prediction method with regard to ultimate gas recovery is proposed, which is connected to the pore size distribution and formation pressure. First of all, the gas storage modes in a single nanopore with defined pore size are analyzed seriously. As a result, the evaluation model is constructed for adsorption gas and free gas content in a single nanopore. After that, an upscaling method is applied to extend the adaptiability of the model from single nanopore to nanoporous modia. Finally, sensitivity factor analysis work is performed and a recovery prediction methodology is developed. Results suggest that the adsorption gas content will be a larger contribution to total gas content when it comes to small pore radius and low formation pressure. In contrast, free gas content will increase with the increasing pressure and pore size. More importantly, pore size distribution characteristic has a key impact on gas storage modes and ultimate gas recovery. The high proportion of small nanopores plays a detrimental role on gas recovery, resulting in large content of adsorption gas at low pressure, which will not be produced and remain in shale gas reservoirs.
{"title":"Evaluation About Adsorption Gas and Free Gas Content Inside Shale Matrix under a Wide Range of Atmosphere Conditions","authors":"Zheng Sun, Juntai Shi, Zhao-peng Yang, Cai Wang, Tuobin Gou, Minxia He, Wen Zhao, Tianfu Yao, Jiayi Wu, Xiangfang Li","doi":"10.2118/197176-ms","DOIUrl":"https://doi.org/10.2118/197176-ms","url":null,"abstract":"\u0000 Much attention has been attracted by the successful development of shale gas reservoir in recent decades. Correspondingly, research aspects of shale gas reservoirs become more and more heat among the academic community, especially in the fields of nanoscale gas transport mechanisms as well as the storage modes. Fascinated by the craft interactions exerted by organic or inorganic shale surface, drastic discrepancy takes place in terms of the gas behavior inside the nanoscale dimension and that in conventional dimension. It is crucial to figure out the exact influence on shale gas recovery and overall production efficiency due to the above large difference. Notably, this paper is designed to comprehensively explore the methane storage behavior in shale nanopores, expecting to provide the direct relationship between adsorption gas and free gas content under various environmental conditions. Also, a novel and simple prediction method with regard to ultimate gas recovery is proposed, which is connected to the pore size distribution and formation pressure. First of all, the gas storage modes in a single nanopore with defined pore size are analyzed seriously. As a result, the evaluation model is constructed for adsorption gas and free gas content in a single nanopore. After that, an upscaling method is applied to extend the adaptiability of the model from single nanopore to nanoporous modia. Finally, sensitivity factor analysis work is performed and a recovery prediction methodology is developed. Results suggest that the adsorption gas content will be a larger contribution to total gas content when it comes to small pore radius and low formation pressure. In contrast, free gas content will increase with the increasing pressure and pore size. More importantly, pore size distribution characteristic has a key impact on gas storage modes and ultimate gas recovery. The high proportion of small nanopores plays a detrimental role on gas recovery, resulting in large content of adsorption gas at low pressure, which will not be produced and remain in shale gas reservoirs.","PeriodicalId":11091,"journal":{"name":"Day 3 Wed, November 13, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90191350","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}
Seismic data is one of earliest data acquired in a prospect evaluation and the data are utilized throughout the exploration and production stages of a prospect. With recent advances in the handling of big data, it is essential to re-evaluate the best practices in the seismic data ecosystem. This paper presents the idea to leveragingthe technology advancement in big data and cloud computing for Seismic data ecosystem with the aim to providing an improve user experience. This new seismic platform would be capable of handling, managing and delivering the full spectrum of seismic data varieties starting from acquired field data to interpretation ready processed data. The system to have the following capabilities: Capability to entitle the right portion of data to every user as per interestOrganization of seismic data as per the business unitsData security by sharing data only with legitimate users/groups.Direct or indirect integration with all the data sources and applications who are consuming and/or generating dataSharing of and collaboration on data within company and/or across organization for shareholding partner, perspective seismic buyer for trading and relinquishment, regulatory agency resource certifying agencies and service providers etc. over limited network connectivity.Provide intergration/data deliverivey to End Users applications where this seismic data will be utilizaed Implementation of Seismic ecosystem will enable: Sharing of seismic data by the acquisition, quality control, data processing and interpretation with user communities from one centralized storageCollaboration of stake holders in real time over an encrypted networkLeveraging cloud and mobility technology advancement for agility and interaction. The system will be connected and interactive yet has the power of complex high-performance computing infrastructure on the background.Data delivery and auditing to wider and more diverse user community that consumes data from different platforms.Secure data access based on organizational business units to make sure data does not fall into unauthorized hand.Reduction in seismic data turnaround time by reading and ingesting large volume of data through parallel input/output operation.Improved data delivery and map interface with contextual information out of the centralized data store.Augment traditional workflows with machine learning and artificial intelligence for example automated fault detection, etc., The proposed best practice aims to bring all of the different disciplines working with seismic data to one centralized seismic data repository and enable them to consume and share seismic data from big data lake. This is live and interactive when compared to traditional technologies of using the archive and restore system in standalone application.
{"title":"Seismic Data Management for Big Data Era","authors":"Anik Pal, P. Kumar, Faridullah Shah","doi":"10.2118/197369-ms","DOIUrl":"https://doi.org/10.2118/197369-ms","url":null,"abstract":"\u0000 Seismic data is one of earliest data acquired in a prospect evaluation and the data are utilized throughout the exploration and production stages of a prospect. With recent advances in the handling of big data, it is essential to re-evaluate the best practices in the seismic data ecosystem. This paper presents the idea to leveragingthe technology advancement in big data and cloud computing for Seismic data ecosystem with the aim to providing an improve user experience.\u0000 This new seismic platform would be capable of handling, managing and delivering the full spectrum of seismic data varieties starting from acquired field data to interpretation ready processed data. The system to have the following capabilities: Capability to entitle the right portion of data to every user as per interestOrganization of seismic data as per the business unitsData security by sharing data only with legitimate users/groups.Direct or indirect integration with all the data sources and applications who are consuming and/or generating dataSharing of and collaboration on data within company and/or across organization for shareholding partner, perspective seismic buyer for trading and relinquishment, regulatory agency resource certifying agencies and service providers etc. over limited network connectivity.Provide intergration/data deliverivey to End Users applications where this seismic data will be utilizaed\u0000 Implementation of Seismic ecosystem will enable: Sharing of seismic data by the acquisition, quality control, data processing and interpretation with user communities from one centralized storageCollaboration of stake holders in real time over an encrypted networkLeveraging cloud and mobility technology advancement for agility and interaction. The system will be connected and interactive yet has the power of complex high-performance computing infrastructure on the background.Data delivery and auditing to wider and more diverse user community that consumes data from different platforms.Secure data access based on organizational business units to make sure data does not fall into unauthorized hand.Reduction in seismic data turnaround time by reading and ingesting large volume of data through parallel input/output operation.Improved data delivery and map interface with contextual information out of the centralized data store.Augment traditional workflows with machine learning and artificial intelligence for example automated fault detection, etc.,\u0000 The proposed best practice aims to bring all of the different disciplines working with seismic data to one centralized seismic data repository and enable them to consume and share seismic data from big data lake. This is live and interactive when compared to traditional technologies of using the archive and restore system in standalone application.","PeriodicalId":11091,"journal":{"name":"Day 3 Wed, November 13, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91449158","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}
Khalid Javid, Srinivas Ettireddi, Yahia Mokhtar Hafez, Mohamed Hossni Ali, Pedro Ronaldo Marin Centurion, L. Cerrada, Mohamed Sayed Mohamed, Kamel Zahaf, Khalil Ibrahim Alhosani, Abdulla Gharib Al Qamzi
This Green Field was recently commissioned and it was put on production last year. It is a model Digital Oil Field having two artificial islands built to drill all its wells with smart completions like ICVs, ICDs and Permanent Downhole Gauges in all Oil & Gas Producer Wells. This paper will describe the benefits of real-time data utilization for better and most efficient Field/Wells Monitoring along with Better and quick decision-making. Flow tests are performed 2-3 times a week using Multi phase flow meter (MPFM) for each of its wells. Smart and Innovative Dashboard have been created for best screening and grouping of wells as per predefined business rules and alerting Asset Engineers for any wells, which are close to violating any of the Reservoir Management Guidelines, and therefore timely decisions, are made to avoid those violations. Miscible Gas Injection was started from the early days of Field life. Gas Tracers are planned to be injected by the end of this year to achieve the successful and improved surveillance and understandingly Reservoirs and better plan the future wells locations and completion strategy. All Field/well Shut Down duration opportunities are utilized for Pressure Build-up analysis for Oil Producer wells and therefore considerable cost of running Memory gauges and intervention operations is also saved. Successful Digital Oil Field is a result of collaborative and multiple discipline Team Work. Lessons learned and recommendation for any new Digital Oil Field are also presented in the paper. Innovative Dashboards have been created to for best screening of wells and alerting for any wells, which are close to violating any of the Reservoir Management Guidelines, and therefore timely decisions, are made to avoid those violations. The standardized data repository is developed as data integration layer using OSI PI platform products to seamlessly merge real time data with manual data to create a single data reference architecture. This has been a powerful enhancement to ensure a single version of the truth.
{"title":"Real-Time Monitoring of a Green Digital Oil Field in Abu Dhabi Offshore: It's Benefits and Challenges","authors":"Khalid Javid, Srinivas Ettireddi, Yahia Mokhtar Hafez, Mohamed Hossni Ali, Pedro Ronaldo Marin Centurion, L. Cerrada, Mohamed Sayed Mohamed, Kamel Zahaf, Khalil Ibrahim Alhosani, Abdulla Gharib Al Qamzi","doi":"10.2118/197921-ms","DOIUrl":"https://doi.org/10.2118/197921-ms","url":null,"abstract":"\u0000 This Green Field was recently commissioned and it was put on production last year. It is a model Digital Oil Field having two artificial islands built to drill all its wells with smart completions like ICVs, ICDs and Permanent Downhole Gauges in all Oil & Gas Producer Wells. This paper will describe the benefits of real-time data utilization for better and most efficient Field/Wells Monitoring along with Better and quick decision-making. Flow tests are performed 2-3 times a week using Multi phase flow meter (MPFM) for each of its wells.\u0000 Smart and Innovative Dashboard have been created for best screening and grouping of wells as per predefined business rules and alerting Asset Engineers for any wells, which are close to violating any of the Reservoir Management Guidelines, and therefore timely decisions, are made to avoid those violations. Miscible Gas Injection was started from the early days of Field life. Gas Tracers are planned to be injected by the end of this year to achieve the successful and improved surveillance and understandingly Reservoirs and better plan the future wells locations and completion strategy.\u0000 All Field/well Shut Down duration opportunities are utilized for Pressure Build-up analysis for Oil Producer wells and therefore considerable cost of running Memory gauges and intervention operations is also saved.\u0000 Successful Digital Oil Field is a result of collaborative and multiple discipline Team Work. Lessons learned and recommendation for any new Digital Oil Field are also presented in the paper.\u0000 Innovative Dashboards have been created to for best screening of wells and alerting for any wells, which are close to violating any of the Reservoir Management Guidelines, and therefore timely decisions, are made to avoid those violations.\u0000 The standardized data repository is developed as data integration layer using OSI PI platform products to seamlessly merge real time data with manual data to create a single data reference architecture. This has been a powerful enhancement to ensure a single version of the truth.","PeriodicalId":11091,"journal":{"name":"Day 3 Wed, November 13, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79472141","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}
Wenyuan Tian, Minqiang Jia, D. Xiao, Beiwei Luo, Jianfang Yang, Saeed K. Al Suwaidi, Yungang Ji, Mingsheng Lv, A. Shashanka, D. Mao, Xinli Hu
Unconventional studies of UAE is in the early stage, especially in the western part, where the wells were drilled only for conventional oil & gas, with few unconventional data acquired. Shilaif formation is one of the main source rock of Cretaceous in western UAE. The main lithology of Shilaif are argillaceous limestone, lime mudstone and shale. Source rock geochemical analysis and basin modeling studies of western UAE show good source rock of Shilaif with high TOC, large thickness and high maturity mainly distribute in the south-east part of the study area, which is the high potential area for unconventional oil exploration. Based on the available 3D seismic data and log data, a series of techniques were used to predict the sweet spots of unconventional oil of Shilaif source rock, which includes the following main techniques: 1. 3D Seismic CRP Gather Conditioning; 2. Petrophysics Modeling; 3. Pre-stack Inversion; 4. Fracture Prediction; 5. Hydrocarbon Prediction; 6. Pore Pressure Prediction; 7. In-Situ Stress Analysis. Based on these techniques, one SW-NE belt of sweet spots were predicted in Lower Shilaif formation of the study area, with thick good source rock, high oil retention, high brittleness, high pressure, medium fracture and medium DHSR.
{"title":"Unconventional Oil Studies of Shilaif Source Rock in Western UAE","authors":"Wenyuan Tian, Minqiang Jia, D. Xiao, Beiwei Luo, Jianfang Yang, Saeed K. Al Suwaidi, Yungang Ji, Mingsheng Lv, A. Shashanka, D. Mao, Xinli Hu","doi":"10.2118/197729-ms","DOIUrl":"https://doi.org/10.2118/197729-ms","url":null,"abstract":"\u0000 Unconventional studies of UAE is in the early stage, especially in the western part, where the wells were drilled only for conventional oil & gas, with few unconventional data acquired. Shilaif formation is one of the main source rock of Cretaceous in western UAE. The main lithology of Shilaif are argillaceous limestone, lime mudstone and shale. Source rock geochemical analysis and basin modeling studies of western UAE show good source rock of Shilaif with high TOC, large thickness and high maturity mainly distribute in the south-east part of the study area, which is the high potential area for unconventional oil exploration.\u0000 Based on the available 3D seismic data and log data, a series of techniques were used to predict the sweet spots of unconventional oil of Shilaif source rock, which includes the following main techniques: 1. 3D Seismic CRP Gather Conditioning; 2. Petrophysics Modeling; 3. Pre-stack Inversion; 4. Fracture Prediction; 5. Hydrocarbon Prediction; 6. Pore Pressure Prediction; 7. In-Situ Stress Analysis. Based on these techniques, one SW-NE belt of sweet spots were predicted in Lower Shilaif formation of the study area, with thick good source rock, high oil retention, high brittleness, high pressure, medium fracture and medium DHSR.","PeriodicalId":11091,"journal":{"name":"Day 3 Wed, November 13, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80865297","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}
Engineering, procurement and construction (EPC) projects play an important role in oil and Gas & energy as well as petrochemicals & construction (civil) sectors not only for sustainable production but also to meet projected future demands. Therefore successful execution of projects is very important for industry. The paper discusse the proven sources of project delays at macro level. This paper furthers this discussion by introducing a unique mechanism of contractor certification management. This mechanism will oversee the contractor's performance and project delay's contributors. A mechanism to rate the contractors based on their performance will provide another tool to monitor contractors. Contrctactor certification management system might prove very successful mechanism that would help oranizations save their significant cost by timely excution of projects. This mechanism will provide a platform for contractors to compete with others, get high rating and receive significant appreciation.
{"title":"Contractor Certification Management System for Effective Project Handling","authors":"Z. Abbas, Abdulla Ahmed Al Shehi","doi":"10.2118/197690-ms","DOIUrl":"https://doi.org/10.2118/197690-ms","url":null,"abstract":"\u0000 Engineering, procurement and construction (EPC) projects play an important role in oil and Gas & energy as well as petrochemicals & construction (civil) sectors not only for sustainable production but also to meet projected future demands. Therefore successful execution of projects is very important for industry. The paper discusse the proven sources of project delays at macro level. This paper furthers this discussion by introducing a unique mechanism of contractor certification management. This mechanism will oversee the contractor's performance and project delay's contributors. A mechanism to rate the contractors based on their performance will provide another tool to monitor contractors. Contrctactor certification management system might prove very successful mechanism that would help oranizations save their significant cost by timely excution of projects. This mechanism will provide a platform for contractors to compete with others, get high rating and receive significant appreciation.","PeriodicalId":11091,"journal":{"name":"Day 3 Wed, November 13, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84641612","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}
H. Aborshaid, Yara A. Alzahid, P. Mostaghimi, J. McClure, Cheng-Wei Chen, Chenhao Sun, R. Armstrong, M. Asali
Alkaline Surfactant (AS) flooding is an enhanced oil recovery (EOR) method to mobilize residual oil. Deatailed understanding of transport during these recovery mechanisms requires detailed pore-scale studies. This point leads to the utilization of X-ray imaging for its application in pore-scale characterization. Synchrotron-based X-ray imaging is an advanced technique that is capable of capturing the dynamics of pore fluids at the microscopic scale. The aim of this project is to investigate the pore-scale flow of AS flooding at two different salinities in carbonate rocks using real time 3D images collected by synchrotron-based X-ray imaging. The morphologies of the non-wetting phase are first computed, and oil recovery in the two scenarios is estimated. In addition, the wetting states of the two conditions are assessed by contact angle measurements. It was observed that optimum, or Winsor type III mobilized more oil, since it yielded a higher recovery value, as compared to under-optimum or Winsor type II-. Alkaline surfactant at optimal salinity was marked as an ideal condition that effectively reduces interfacial tension (IFT) to mobilize residual oil. This study provides insights in the pore-scale flow mechanisms that occur during AS flooding, which are important for understanding the basic EOR mechanism of this particular flood.
{"title":"Synchrotron-Based X-ray Micro-Computed Tomography for Real Time Investigation of Alkaline Surfactant Flooding","authors":"H. Aborshaid, Yara A. Alzahid, P. Mostaghimi, J. McClure, Cheng-Wei Chen, Chenhao Sun, R. Armstrong, M. Asali","doi":"10.2118/197741-ms","DOIUrl":"https://doi.org/10.2118/197741-ms","url":null,"abstract":"Alkaline Surfactant (AS) flooding is an enhanced oil recovery (EOR) method to mobilize residual oil. Deatailed understanding of transport during these recovery mechanisms requires detailed pore-scale studies. This point leads to the utilization of X-ray imaging for its application in pore-scale characterization. Synchrotron-based X-ray imaging is an advanced technique that is capable of capturing the dynamics of pore fluids at the microscopic scale. The aim of this project is to investigate the pore-scale flow of AS flooding at two different salinities in carbonate rocks using real time 3D images collected by synchrotron-based X-ray imaging. The morphologies of the non-wetting phase are first computed, and oil recovery in the two scenarios is estimated. In addition, the wetting states of the two conditions are assessed by contact angle measurements. It was observed that optimum, or Winsor type III mobilized more oil, since it yielded a higher recovery value, as compared to under-optimum or Winsor type II-. Alkaline surfactant at optimal salinity was marked as an ideal condition that effectively reduces interfacial tension (IFT) to mobilize residual oil. This study provides insights in the pore-scale flow mechanisms that occur during AS flooding, which are important for understanding the basic EOR mechanism of this particular flood.","PeriodicalId":11091,"journal":{"name":"Day 3 Wed, November 13, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88640176","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}
K SinghSunil, R. Wasnik, H. Singh, F. Kamal, Oussama Takieddine
The wellhead tower facilities in Offshore are designed to receive well fluid from different oil fields and transport through pipelines for further processing. The functional requirements for any typical wellhead tower do not vary much; leading to similar design features in most of the Offshore facilities. This paper discusses the best practices applied in standardization of Offshore wellhead tower’s design and highlights its advantages in execution of EPC projects. In the standardized design, the sizing of equipment and piping for a wellhead tower are normally pre-defined and fixed for all new projects. The pre-defined design specifications are finalized based on best engineering practices and field experiences. For example; the well flow line size of about 6" is found sufficient for typical oil production platforms as well as meets conventional line sizing criteria for most of the projects. Similarly, the material of construction for all piping and equipment can also be pre-selected as part of the standardized design for all new wellhead towers. The execution of an EPC project from detailed design stage to commissioning, within a given schedule is essential for success of any project. In conventional design approach, various design activities for a wellhead tower such as engineering calculations, design verification and specialized engineering studies are repeated for each project even though the design is already pre-fixed. This is a time-consuming approach and takes significant amount of time without any value addition. This also delays the procurement activities leading to cascading effect on fabrication, installation and commissioning of the facilities. In the standardized approach, design details such as equipment/line sizes, layout is already finalized and EPC contractor is mainly required to update engineering deliverables based on the vendor design information/details. This approach significantly reduces the project schedule. The standardized approach provides an opportunity for fast-track execution of the projects. In addition, it leads to better management of material resulting in reduced maintenance and shutdown period during operational phase. The standardized design also provides flexibility to the operator for easy maintenance and operation of the similar facilities at other locations. NPCC has recently successfully executed many wellhead tower projects involving standardized design approach. Based on the experience gained and the lessons learnt through these projects, NPCC proposes the best engineering practices that can be adopted for the execution of standardized offshore wellhead towers design providing benefits to all stakeholders.
{"title":"Best Engineering Practices in Standardization of Offshore Wellhead Tower Design – EPC Contractor’s Experience","authors":"K SinghSunil, R. Wasnik, H. Singh, F. Kamal, Oussama Takieddine","doi":"10.2118/197298-ms","DOIUrl":"https://doi.org/10.2118/197298-ms","url":null,"abstract":"\u0000 The wellhead tower facilities in Offshore are designed to receive well fluid from different oil fields and transport through pipelines for further processing. The functional requirements for any typical wellhead tower do not vary much; leading to similar design features in most of the Offshore facilities. This paper discusses the best practices applied in standardization of Offshore wellhead tower’s design and highlights its advantages in execution of EPC projects.\u0000 In the standardized design, the sizing of equipment and piping for a wellhead tower are normally pre-defined and fixed for all new projects. The pre-defined design specifications are finalized based on best engineering practices and field experiences. For example; the well flow line size of about 6\" is found sufficient for typical oil production platforms as well as meets conventional line sizing criteria for most of the projects. Similarly, the material of construction for all piping and equipment can also be pre-selected as part of the standardized design for all new wellhead towers.\u0000 The execution of an EPC project from detailed design stage to commissioning, within a given schedule is essential for success of any project. In conventional design approach, various design activities for a wellhead tower such as engineering calculations, design verification and specialized engineering studies are repeated for each project even though the design is already pre-fixed. This is a time-consuming approach and takes significant amount of time without any value addition. This also delays the procurement activities leading to cascading effect on fabrication, installation and commissioning of the facilities. In the standardized approach, design details such as equipment/line sizes, layout is already finalized and EPC contractor is mainly required to update engineering deliverables based on the vendor design information/details. This approach significantly reduces the project schedule. The standardized approach provides an opportunity for fast-track execution of the projects. In addition, it leads to better management of material resulting in reduced maintenance and shutdown period during operational phase. The standardized design also provides flexibility to the operator for easy maintenance and operation of the similar facilities at other locations.\u0000 NPCC has recently successfully executed many wellhead tower projects involving standardized design approach. Based on the experience gained and the lessons learnt through these projects, NPCC proposes the best engineering practices that can be adopted for the execution of standardized offshore wellhead towers design providing benefits to all stakeholders.","PeriodicalId":11091,"journal":{"name":"Day 3 Wed, November 13, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87354309","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}
A. Mahmoud, Abdulla Khayami, M. Mansoor, Mohamed Buasali
A significant number of Kharaib horizontal and deviated producers drilled over the last decade have suffered from casing leaks, with many occurring in the first two years of production due to the exposure to highly corrosive water from the overlying giant water-bearing formation known as Shuaiba formation, resulting in production losses and water dumping from Shuaiba formation into the Kharaib reservoir through these damaged wellbores. This paper investigates the impact of Shuaiba dump flooding on the Kharaib reservoir’s performance, the integrated reservoir management study that was conducted and the implementation of the study’s findings to achieve the best results. Severe casing leaks are the main production problems facing the Kharaib reservoir. A few repairs were attempted initially, however, high costs and failure rates led to a decision to cement squeeze all remaining casing leak wells, recomplete them in shallower reservoirs, and drill new replacement wells. All new Kharaib wells were designed with an extra casing to protect against the Shuaiba reservoir’s corrosive water. Although there are no longer any casing leak wells in Kharaib, their impact remains. The pre-casing leak production numbers and well counts are yet to be matched, and there is a large volume of hydrocarbons to be produced from the Kharaib reservoir. In addition, wells that are offset of old casing leak wells showed an increase in water cut, while the performance of new wells drilled down-structure of casing leak wells suffered from early water breakthrough. There is also strong evidence that the isolation in many casing leak wells, performed during the recompletion workovers, may be unsuccessful. All these factors indicate that dump flooding is likely ongoing in the Kharaib reservoir. The consequences of dump flooding have not all been negative. An increase in average reservoir pressure and a strengthening of the reservoir’s weak water drive mechanism were observed. Currently, many wells have shown an increase in oil production, while other wells have shown steady oil production with a very gentle decline which is particularly reflected in wells located up-structure of the casing leaks. As a result of the study, many wells have been drilled in carefully selected locations in order to take advantage of the flooding, and the results of the study concluded a sustained production with a low water cut. Moving forward, there are further opportunities to increase the recovery factor by mitigating the unwanted effects of Shuaiba dump flooding and utilizing the phenomenon to its best potential.
{"title":"Integrated Reservoir Study to Maximize Oil Recovery by Optimizing Shuaiba Dump Flooding into the Kharaib Reservoir","authors":"A. Mahmoud, Abdulla Khayami, M. Mansoor, Mohamed Buasali","doi":"10.2118/197641-ms","DOIUrl":"https://doi.org/10.2118/197641-ms","url":null,"abstract":"\u0000 A significant number of Kharaib horizontal and deviated producers drilled over the last decade have suffered from casing leaks, with many occurring in the first two years of production due to the exposure to highly corrosive water from the overlying giant water-bearing formation known as Shuaiba formation, resulting in production losses and water dumping from Shuaiba formation into the Kharaib reservoir through these damaged wellbores. This paper investigates the impact of Shuaiba dump flooding on the Kharaib reservoir’s performance, the integrated reservoir management study that was conducted and the implementation of the study’s findings to achieve the best results.\u0000 Severe casing leaks are the main production problems facing the Kharaib reservoir. A few repairs were attempted initially, however, high costs and failure rates led to a decision to cement squeeze all remaining casing leak wells, recomplete them in shallower reservoirs, and drill new replacement wells. All new Kharaib wells were designed with an extra casing to protect against the Shuaiba reservoir’s corrosive water. Although there are no longer any casing leak wells in Kharaib, their impact remains. The pre-casing leak production numbers and well counts are yet to be matched, and there is a large volume of hydrocarbons to be produced from the Kharaib reservoir. In addition, wells that are offset of old casing leak wells showed an increase in water cut, while the performance of new wells drilled down-structure of casing leak wells suffered from early water breakthrough. There is also strong evidence that the isolation in many casing leak wells, performed during the recompletion workovers, may be unsuccessful. All these factors indicate that dump flooding is likely ongoing in the Kharaib reservoir.\u0000 The consequences of dump flooding have not all been negative. An increase in average reservoir pressure and a strengthening of the reservoir’s weak water drive mechanism were observed. Currently, many wells have shown an increase in oil production, while other wells have shown steady oil production with a very gentle decline which is particularly reflected in wells located up-structure of the casing leaks. As a result of the study, many wells have been drilled in carefully selected locations in order to take advantage of the flooding, and the results of the study concluded a sustained production with a low water cut. Moving forward, there are further opportunities to increase the recovery factor by mitigating the unwanted effects of Shuaiba dump flooding and utilizing the phenomenon to its best potential.","PeriodicalId":11091,"journal":{"name":"Day 3 Wed, November 13, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85366049","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}
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