M. Z. Mohd Sahak, Maung Maung Myo Thant, Shazleen Saadon, T. Krebs, P. Verbeek, M. R. Akdim, L. Villacorte
Separation of stable emulsions produced from chemical enhanced oil recovery (CEOR) in a brownfield production system using conventional 3-phase separators is almost impossible, requiring large quantities of chemical demulsifiers to meet oil production specifications. A new and novel high-voltage high-frequency (HVHF) electro-coalescence (EC) technology has been identified as potential method to enhance separation of EOR produced fluid for improving CEOR implementation feasibility. This paper aims to present results and findings from the recent EC technology development against success criteria and parameters associated for fast-track field application. Electrostatic coalescers are used as an emulsion breaker, crude dehydrator or desalter in production systems and refineries. However, significant developments are required to use this EC technology as a potential treatment technology for tight emulsions/rag layers in CEOR applications. A new prototype of Inline EC was developed and tested in a batch test setup to evaluate the separation efficiency using real crude-brine samples and a cocktail of alkaline-surfactant-polymer (ASP) chemicals. The sensitivities of separation efficiency to different water cut, demulsifier concentration, EC voltage/exposure time, concentrations of alkaline, surfactant and polymer in the brine were measured and optimal process conditions were assessed. The results and findings were evaluated based on defined success criteria and parameters associated with separation efficiency such as volume fractions of the emulsion, oil-in-water (OIW) and water-in-oil concentrations (WIO), respectively. On one of PETRONAS CEOR field case study, the test results show that EC reduced 90% of the tight emulsion. In conclusion, EC leads to a substantial improvement in separation efficiency relative to the case without EC for water cuts below the inversion point. It is also found that the EC treatment without added demulsifier is equally effective in breaking the emulsion as adding a demulsifier without EC treatment, and that EC can potentially minimise or eliminate the application of demulsifiers in the production system.
{"title":"Acceleration of Novel Technology Development for Stabilized Emulsion Treatment in EOR Applications","authors":"M. Z. Mohd Sahak, Maung Maung Myo Thant, Shazleen Saadon, T. Krebs, P. Verbeek, M. R. Akdim, L. Villacorte","doi":"10.2118/207383-ms","DOIUrl":"https://doi.org/10.2118/207383-ms","url":null,"abstract":"\u0000 Separation of stable emulsions produced from chemical enhanced oil recovery (CEOR) in a brownfield production system using conventional 3-phase separators is almost impossible, requiring large quantities of chemical demulsifiers to meet oil production specifications. A new and novel high-voltage high-frequency (HVHF) electro-coalescence (EC) technology has been identified as potential method to enhance separation of EOR produced fluid for improving CEOR implementation feasibility. This paper aims to present results and findings from the recent EC technology development against success criteria and parameters associated for fast-track field application. Electrostatic coalescers are used as an emulsion breaker, crude dehydrator or desalter in production systems and refineries. However, significant developments are required to use this EC technology as a potential treatment technology for tight emulsions/rag layers in CEOR applications. A new prototype of Inline EC was developed and tested in a batch test setup to evaluate the separation efficiency using real crude-brine samples and a cocktail of alkaline-surfactant-polymer (ASP) chemicals. The sensitivities of separation efficiency to different water cut, demulsifier concentration, EC voltage/exposure time, concentrations of alkaline, surfactant and polymer in the brine were measured and optimal process conditions were assessed. The results and findings were evaluated based on defined success criteria and parameters associated with separation efficiency such as volume fractions of the emulsion, oil-in-water (OIW) and water-in-oil concentrations (WIO), respectively. On one of PETRONAS CEOR field case study, the test results show that EC reduced 90% of the tight emulsion. In conclusion, EC leads to a substantial improvement in separation efficiency relative to the case without EC for water cuts below the inversion point. It is also found that the EC treatment without added demulsifier is equally effective in breaking the emulsion as adding a demulsifier without EC treatment, and that EC can potentially minimise or eliminate the application of demulsifiers in the production system.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"8 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74385994","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}
P. Bagga, Tapan Kidambi, Ashish Sharma, Anjana Panchakarla, Aditee Kulkarni
This paper deals with the field development study for an offshore field in the western part of India. The main points of focus are holistic execution of integrated workflows for the delivery of subsea oil and gas wells from a jack up platform in this region. Given that the encountered formations encountered in wells posed significant challenges during the drilling phase, a field level geomechanics study was commissioned to understand and mitigate any challenges and effect smooth drilling and logging operations. Understanding the geomechanical effects by analysing the offset wells drilled in the region provided significant insights into the potential challenges faced while exploring target formations. The proposed well locations were drilled in a structurally complex geological setting. From the analysis of previously drilled wells in the region, it was evident that the variation in insitu properties of the lithologies and the extreme heterogeneity and vugular nature of the encountered carbonates caused significant drillability issues with subsequent losses, excessive cuttings, and several back reaming cycles impacting rig time and leading to generally poor borehole conditions. On the other hand, the shales encountered at shallower depths presented a different challenge, especially with a high swelling tendency, adding to progressively worsening hole conditions and significant fluid invasion. Finally, the basal clastics and the depleted zones with variable rock strengths added to the borehole instability issues, with particular zones projecting losses while others showed influxes. In light of such a plethora of issues, an integrated approach including dynamic real time monitoring of operations, structured LWD and wireline logging programmes, a high level petrophysics, formation evaluation and borehole acoustics for shear radial profiling was carried out. A fit for purpose geomechanical model was built encompassing the results of these analyses and was continually updated in real time during the operations phase. Given the variability in the pressures, temperatures and operational mud weights in each section, execution for successful delivery of the wells was further aided by identification of the optimal mud systems, critical casing setting depths and real time drilling optimization, ensuring good borehole quality throughout for further logging and testing programmes.
{"title":"Integrated Geomechanical Operations for Successful Field Development: A Case Study from Western Offshore, India","authors":"P. Bagga, Tapan Kidambi, Ashish Sharma, Anjana Panchakarla, Aditee Kulkarni","doi":"10.2118/207925-ms","DOIUrl":"https://doi.org/10.2118/207925-ms","url":null,"abstract":"\u0000 This paper deals with the field development study for an offshore field in the western part of India. The main points of focus are holistic execution of integrated workflows for the delivery of subsea oil and gas wells from a jack up platform in this region. Given that the encountered formations encountered in wells posed significant challenges during the drilling phase, a field level geomechanics study was commissioned to understand and mitigate any challenges and effect smooth drilling and logging operations. Understanding the geomechanical effects by analysing the offset wells drilled in the region provided significant insights into the potential challenges faced while exploring target formations.\u0000 The proposed well locations were drilled in a structurally complex geological setting. From the analysis of previously drilled wells in the region, it was evident that the variation in insitu properties of the lithologies and the extreme heterogeneity and vugular nature of the encountered carbonates caused significant drillability issues with subsequent losses, excessive cuttings, and several back reaming cycles impacting rig time and leading to generally poor borehole conditions. On the other hand, the shales encountered at shallower depths presented a different challenge, especially with a high swelling tendency, adding to progressively worsening hole conditions and significant fluid invasion. Finally, the basal clastics and the depleted zones with variable rock strengths added to the borehole instability issues, with particular zones projecting losses while others showed influxes.\u0000 In light of such a plethora of issues, an integrated approach including dynamic real time monitoring of operations, structured LWD and wireline logging programmes, a high level petrophysics, formation evaluation and borehole acoustics for shear radial profiling was carried out. A fit for purpose geomechanical model was built encompassing the results of these analyses and was continually updated in real time during the operations phase. Given the variability in the pressures, temperatures and operational mud weights in each section, execution for successful delivery of the wells was further aided by identification of the optimal mud systems, critical casing setting depths and real time drilling optimization, ensuring good borehole quality throughout for further logging and testing programmes.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"108 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82154158","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}
T. Olivares, Rafael Pino, Walid Al-Zahrani, Samy Mahmoud Aly, Mohamed El Nahas
The operational drilling history in a particularly challenging shale consistently shows that once the formation's shale reacts, and starts to disperse, in the face of a typical water base mud application, a variety of hole problems are experienced by the operator. These problems include wellbore instability caused by an unstoppable sloughing of the shale; the experiencing of tight hole conditions while performing the wiper trip; caved shale sticking to shakers while drilling; an increased dilution rate due to mud weight; a low LGS % (low gravity solids), and fluid viscosity. To solve this longstanding drilling challenge, a team formed from operator and service provider experts determined via high-level research and testing the need for an innovative new technology of inhibitive fluid chemistry. After extensive testing, the team determined that a particular environmentally friendly Nano Polymer high-performance water-based mud (HPWBM)—one possessing the unique shale inhibition and cutting encapsulation capabilities capable of stabilizing this sticky shale—was the best fit for this application. We will present the investigational learning and effective field trial drilling of high problematic shale that was evaluated during and subsequently the utilization of nanoparticles (NP) to advance water-based mud (WBM) inhibition properties, proven to offer an eco-friendly Nano Polymer HPWBM substitute with the improved thermal and rheological permanency of the overall WBM formulation. Results will display that while providing more effective drilling and wellbore stability, this technology is also a far cleaner industry alternative.
{"title":"A Highly Successful Way to Consistently Drill to Target Depth with Nano Polymer Water-Based Mud in a Highly Active, Problematic Shale Interval","authors":"T. Olivares, Rafael Pino, Walid Al-Zahrani, Samy Mahmoud Aly, Mohamed El Nahas","doi":"10.2118/207678-ms","DOIUrl":"https://doi.org/10.2118/207678-ms","url":null,"abstract":"\u0000 The operational drilling history in a particularly challenging shale consistently shows that once the formation's shale reacts, and starts to disperse, in the face of a typical water base mud application, a variety of hole problems are experienced by the operator. These problems include wellbore instability caused by an unstoppable sloughing of the shale; the experiencing of tight hole conditions while performing the wiper trip; caved shale sticking to shakers while drilling; an increased dilution rate due to mud weight; a low LGS % (low gravity solids), and fluid viscosity.\u0000 To solve this longstanding drilling challenge, a team formed from operator and service provider experts determined via high-level research and testing the need for an innovative new technology of inhibitive fluid chemistry. After extensive testing, the team determined that a particular environmentally friendly Nano Polymer high-performance water-based mud (HPWBM)—one possessing the unique shale inhibition and cutting encapsulation capabilities capable of stabilizing this sticky shale—was the best fit for this application.\u0000 We will present the investigational learning and effective field trial drilling of high problematic shale that was evaluated during and subsequently the utilization of nanoparticles (NP) to advance water-based mud (WBM) inhibition properties, proven to offer an eco-friendly Nano Polymer HPWBM substitute with the improved thermal and rheological permanency of the overall WBM formulation. Results will display that while providing more effective drilling and wellbore stability, this technology is also a far cleaner industry alternative.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"46 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86829640","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}
R. Oughanem, T. Gumpenberger, Jean-Grégoire Boero-Rollo, Scherwan Suleiman, J. Ochi, Maria-Magdalena Chiotoroiu, Abdalla Hannes
A water treatment pilot skid called WaOω has been developed by TotalEnergies to test the efficiency of the centrifugation technology in treating the produced water containing back produced polymer. In case of success, this technology would be implemented on field and the water quality targeted by the technology must allow re-injecting the treated produced water in matrix flow regime for pressure maintain and sweep efficiency. The same interest was expressed by OMV and a partnership project has been built. It was also agreed that OMV builds a second pilot skid called PRT that allows carrying out core flood tests onsite to assess the formation damage and related permeability decline that could be induced by the treated produced water. Both pilot skids have been implemented, connected to each other, and tested during more than one year on the OMV's Matzen oil field nearby Vienna where degraded polymer is already back produced by wells and present in the produced water. More than seventy core flooding tests have been performed in different centrifugation conditions in terms of speed and water qualities, some of them on high permeable sand packs representing the field targeted by TotalEnergies and some others on consolidated sandstone samples of lower permeability representing OMV reservoirs. The effect of adding fresh polymer to the treated produced water for EOR purposes has also been investigated. Some complementary core flood tests have also been performed in TotalEnergies labs using reconstituted sand packs and produced waters with and without polymer to understand the contribution of the degraded polymer alone, the produced water quality alone and both to understand the formation damage and some uncommon results observed with the PRT pilot skid. Core flood tests data often obtained on long injection periods revealed of a high quality, reliable and reproducible. They also showed that even if centrifugation seems to be a good technology, the very clean and transparent water that it delivered induced surprisingly some core permeability declines the origin of which would be discussed in this paper. However, it was clearly established that the presence of degraded polymer has a cleaning effect and limits the formation damage induced by the produced water injected on cores if the Total Suspended Solids in the treated water remains at an acceptable level. Adding fresh polymers limited even more the formation damage because their cleaning effect is more pronounced than with degraded polymer.
{"title":"A Core Flood Test-Program Performed with a Pilot-Skid to Quantify the Permeability Decline Induced by Real Treated Produced Waters Also Containing Degraded Polymer or Not","authors":"R. Oughanem, T. Gumpenberger, Jean-Grégoire Boero-Rollo, Scherwan Suleiman, J. Ochi, Maria-Magdalena Chiotoroiu, Abdalla Hannes","doi":"10.2118/207633-ms","DOIUrl":"https://doi.org/10.2118/207633-ms","url":null,"abstract":"\u0000 A water treatment pilot skid called WaOω has been developed by TotalEnergies to test the efficiency of the centrifugation technology in treating the produced water containing back produced polymer. In case of success, this technology would be implemented on field and the water quality targeted by the technology must allow re-injecting the treated produced water in matrix flow regime for pressure maintain and sweep efficiency. The same interest was expressed by OMV and a partnership project has been built. It was also agreed that OMV builds a second pilot skid called PRT that allows carrying out core flood tests onsite to assess the formation damage and related permeability decline that could be induced by the treated produced water.\u0000 Both pilot skids have been implemented, connected to each other, and tested during more than one year on the OMV's Matzen oil field nearby Vienna where degraded polymer is already back produced by wells and present in the produced water.\u0000 More than seventy core flooding tests have been performed in different centrifugation conditions in terms of speed and water qualities, some of them on high permeable sand packs representing the field targeted by TotalEnergies and some others on consolidated sandstone samples of lower permeability representing OMV reservoirs. The effect of adding fresh polymer to the treated produced water for EOR purposes has also been investigated. Some complementary core flood tests have also been performed in TotalEnergies labs using reconstituted sand packs and produced waters with and without polymer to understand the contribution of the degraded polymer alone, the produced water quality alone and both to understand the formation damage and some uncommon results observed with the PRT pilot skid.\u0000 Core flood tests data often obtained on long injection periods revealed of a high quality, reliable and reproducible. They also showed that even if centrifugation seems to be a good technology, the very clean and transparent water that it delivered induced surprisingly some core permeability declines the origin of which would be discussed in this paper. However, it was clearly established that the presence of degraded polymer has a cleaning effect and limits the formation damage induced by the produced water injected on cores if the Total Suspended Solids in the treated water remains at an acceptable level. Adding fresh polymers limited even more the formation damage because their cleaning effect is more pronounced than with degraded polymer.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"31 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85339563","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}
Abdulrahman Althobaiti, Fadl Abdellatif, A. Alrasheed, H. Trigui, A. Alsaadi, Sahejad Patel
This paper showcases an innovative mobile application powered by IR4.0 technologies including augmented reality (AR) and artificial intelligence (AI). The purpose of this application is to enable digital transformation of analog gauges, digitize their measurements, automate historical data storage, visualize trends, and provide useful information about the gauge to the operator. Utilizing this application will replace the current practice of manual recording of readings in order to reduce human errors as well as promote operational efficiency. With this application, the operator simply points the mobile device's camera towards the gauge and the image is converted to a digital measurement using computer vision algorithms. The digitized readings are sent to a remote database for recordkeeping and data analytics. In order to identify which gauge is being scanned, which is necessary for proper recordkeeping, the application detects a unique QR-code tag attached to the gauge. Additionally, the application utilizes AR technology to overlay gauge specific information (such as gauge type, safe operating range, fluid type, etc.) along with the digitized reading. Visualization of historical readings is another feature in the application that assists the operator in trend monitoring and decision making. Preliminary tests for the prototype application were carried out in a laboratory environment to demonstrate the working principle of this application. Although the technology is in its early stages of development, it shows promising results in terms of accuracy and speed of the computer vision algorithms to detect and digitize the analog gauges. The historical data recorded by the application can also be accessed via the control room using a web interface, where information from various gauges can be retrieved and visualized for analysis and monitoring. Overall, the presented application integrates computer vision and augmented reality to provide an effective solution for digitizing analog gauges while promoting digital transformation efforts within the industry.
{"title":"AR Gauge Scanner Mobile Application","authors":"Abdulrahman Althobaiti, Fadl Abdellatif, A. Alrasheed, H. Trigui, A. Alsaadi, Sahejad Patel","doi":"10.2118/207441-ms","DOIUrl":"https://doi.org/10.2118/207441-ms","url":null,"abstract":"\u0000 This paper showcases an innovative mobile application powered by IR4.0 technologies including augmented reality (AR) and artificial intelligence (AI). The purpose of this application is to enable digital transformation of analog gauges, digitize their measurements, automate historical data storage, visualize trends, and provide useful information about the gauge to the operator. Utilizing this application will replace the current practice of manual recording of readings in order to reduce human errors as well as promote operational efficiency.\u0000 With this application, the operator simply points the mobile device's camera towards the gauge and the image is converted to a digital measurement using computer vision algorithms. The digitized readings are sent to a remote database for recordkeeping and data analytics. In order to identify which gauge is being scanned, which is necessary for proper recordkeeping, the application detects a unique QR-code tag attached to the gauge. Additionally, the application utilizes AR technology to overlay gauge specific information (such as gauge type, safe operating range, fluid type, etc.) along with the digitized reading. Visualization of historical readings is another feature in the application that assists the operator in trend monitoring and decision making.\u0000 Preliminary tests for the prototype application were carried out in a laboratory environment to demonstrate the working principle of this application. Although the technology is in its early stages of development, it shows promising results in terms of accuracy and speed of the computer vision algorithms to detect and digitize the analog gauges. The historical data recorded by the application can also be accessed via the control room using a web interface, where information from various gauges can be retrieved and visualized for analysis and monitoring. Overall, the presented application integrates computer vision and augmented reality to provide an effective solution for digitizing analog gauges while promoting digital transformation efforts within the industry.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"85 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80976117","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}
P. Tiwari, Zoann Low, P. A. Patil, D. Das, P. Chidambaram, R. Tewari
Monitoring of CO2 plume migration in a depleted carbonate reservoir is challenging and demand comprehensive and trailblazing monitoring technologies. 4D time-lapse seismic exhibits the migration of CO2 plume within geological storage but in the area affected by gas chimney due to poor signal-to-noise ratio (SNR), uncertainty in identifying and interpretation of CO2 plume gets exaggerated. High resolution 3D vertical seismic profile (VSP) survey using distributed acoustic sensor (DAS) technology fulfil the objective of obtaining the detailed subsurface image which include CO2 plume migration, reservoir architecture, sub-seismic faults and fracture networks as well as the caprock. Integration of quantitative geophysics and dynamic simulation with illumination modelling dignify the capabilities of 3D DAS-VSP for CO2 plume migration monitoring. The storage site has been studied in detailed and an integrated coupled dynamic simulation were performed and results were integrated with seismic forward modeling to demonstrate the CO2 plume migration with in reservoir and its impact on seismic amplitude. 3D VSP illumination modelling was carried out by integrating reservoir and overburden interpretations, acoustic logs and seismic velocity to illustrate the subsurface coverage area at top of reservoir. Several acquisition survey geometries were simulated based on different source carpet size for effective surface source contribution for subsurface illumination and results were analyzed to design the 3D VSP survey for early CO2 plume migration monitoring. The illumination simulation was integrated with dynamic simulation for fullfield CO2 plume migration monitoring with 3D DAS-VSP by incorporating Pseudo wells illumination analysis. Results of integrated coupled dynamic simulation and 4D seismic feasibility were analyzed for selection of best well location to deploy the multi fiber optic sensor system (M-FOSS) technology. Amplitude response of synthetic AVO (amplitude vs offsets) gathers at the top of carbonate reservoir were analyzed for near, mid and far angle stacks with respect to pre-production as well as pre-injection reservoir conditions. Observed promising results of distinguishable 25-30% of CO2 saturation in depleted reservoir from 4D time-lapse seismic envisage the application of 3D DAS-VSP acquisition. The source patch analysis of 3D VSP illumination modelling results indicate that a source carpet of 6km×6km would be cos-effectively sufficient to produce a maximum of approximately 2km in diameter subsurface illumination at the top of the reservoir. The Pseudo wells illumination analysis results show that current planned injection wells would probably able to monitor early CO2 injection but for the fullfield monitoring additional monitoring wells or a hybrid survey of VSP and surface seismic would be required. The integrated modeling approach ensures that 4D Seismic in subsurface CO2 plume monitoring is robust. Monitoring pressure build-ups fr
{"title":"3D DAS-VSP Illumination Modeling for CO2 Plume Migration Monitoring in Offshore Sarawak, Malaysia","authors":"P. Tiwari, Zoann Low, P. A. Patil, D. Das, P. Chidambaram, R. Tewari","doi":"10.2118/207842-ms","DOIUrl":"https://doi.org/10.2118/207842-ms","url":null,"abstract":"\u0000 Monitoring of CO2 plume migration in a depleted carbonate reservoir is challenging and demand comprehensive and trailblazing monitoring technologies. 4D time-lapse seismic exhibits the migration of CO2 plume within geological storage but in the area affected by gas chimney due to poor signal-to-noise ratio (SNR), uncertainty in identifying and interpretation of CO2 plume gets exaggerated. High resolution 3D vertical seismic profile (VSP) survey using distributed acoustic sensor (DAS) technology fulfil the objective of obtaining the detailed subsurface image which include CO2 plume migration, reservoir architecture, sub-seismic faults and fracture networks as well as the caprock. Integration of quantitative geophysics and dynamic simulation with illumination modelling dignify the capabilities of 3D DAS-VSP for CO2 plume migration monitoring.\u0000 The storage site has been studied in detailed and an integrated coupled dynamic simulation were performed and results were integrated with seismic forward modeling to demonstrate the CO2 plume migration with in reservoir and its impact on seismic amplitude. 3D VSP illumination modelling was carried out by integrating reservoir and overburden interpretations, acoustic logs and seismic velocity to illustrate the subsurface coverage area at top of reservoir. Several acquisition survey geometries were simulated based on different source carpet size for effective surface source contribution for subsurface illumination and results were analyzed to design the 3D VSP survey for early CO2 plume migration monitoring. The illumination simulation was integrated with dynamic simulation for fullfield CO2 plume migration monitoring with 3D DAS-VSP by incorporating Pseudo wells illumination analysis.\u0000 Results of integrated coupled dynamic simulation and 4D seismic feasibility were analyzed for selection of best well location to deploy the multi fiber optic sensor system (M-FOSS) technology. Amplitude response of synthetic AVO (amplitude vs offsets) gathers at the top of carbonate reservoir were analyzed for near, mid and far angle stacks with respect to pre-production as well as pre-injection reservoir conditions. Observed promising results of distinguishable 25-30% of CO2 saturation in depleted reservoir from 4D time-lapse seismic envisage the application of 3D DAS-VSP acquisition. The source patch analysis of 3D VSP illumination modelling results indicate that a source carpet of 6km×6km would be cos-effectively sufficient to produce a maximum of approximately 2km in diameter subsurface illumination at the top of the reservoir. The Pseudo wells illumination analysis results show that current planned injection wells would probably able to monitor early CO2 injection but for the fullfield monitoring additional monitoring wells or a hybrid survey of VSP and surface seismic would be required. The integrated modeling approach ensures that 4D Seismic in subsurface CO2 plume monitoring is robust. Monitoring pressure build-ups fr","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"69 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81403547","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}
Gaining insights from the dense network of interrelated documents involved in E&P projects requires experience, knowledge, and awareness about the existence of the required data. This framework aims to facilitate the decision-making process while consuming shorter time periods and lower costs, without sacrificing the accuracy of the data and decreasing the probability of human errors. The high complexity of E&P Projects results in a dense network of interrelated documents which are produced to cover the various aspects and details of the project. Gaining insights from old data requires experience, knowledge, and awareness about the existence of the required data. Accordingly, the knowledge accumulated over the time from various projects can be considered a key asset, since it can be leveraged to perform more informed decisions. This paper presents a framework that aim at capturing organizational knowledge locked in paper-based datasets and store it in a structured digital format that facilitates its retrieval and enables analyses which help uncover valuable insights. This research aims to generate valuable data from existing archives while causing minimal disturbance to existing business processes and workflows. The framework performs four main functions: image processing, text recognition, Data Analytics and Data storage. Initially the text recognition module; which is performs Image Processing to enhance the quality of the scanned files, and optical character recognition using LSTM which extracts the text contained in images. The Data Analytics Module, then cleanses and mines the extracted text using Big Data Analytics tools. Text Matching and searching is performed on the Spark Dataframe using regular expressions to identify different attributes and their different types. Finally, the data is stored in a SQL Database. In order to measure the workflow's accuracy a manual baseline was generated for a sample project. The accuracy is measured using field-level verification, since it was found to be the most fit-for-purpose, as it allows to measure the accuracy of the workflow on the level of each field.
{"title":"Smart Archive Generation Using Computer Vision, NLP and Big Data","authors":"M. Marzouk, M. Elzahed","doi":"10.2118/207365-ms","DOIUrl":"https://doi.org/10.2118/207365-ms","url":null,"abstract":"\u0000 Gaining insights from the dense network of interrelated documents involved in E&P projects requires experience, knowledge, and awareness about the existence of the required data. This framework aims to facilitate the decision-making process while consuming shorter time periods and lower costs, without sacrificing the accuracy of the data and decreasing the probability of human errors. The high complexity of E&P Projects results in a dense network of interrelated documents which are produced to cover the various aspects and details of the project. Gaining insights from old data requires experience, knowledge, and awareness about the existence of the required data. Accordingly, the knowledge accumulated over the time from various projects can be considered a key asset, since it can be leveraged to perform more informed decisions. This paper presents a framework that aim at capturing organizational knowledge locked in paper-based datasets and store it in a structured digital format that facilitates its retrieval and enables analyses which help uncover valuable insights. This research aims to generate valuable data from existing archives while causing minimal disturbance to existing business processes and workflows. The framework performs four main functions: image processing, text recognition, Data Analytics and Data storage. Initially the text recognition module; which is performs Image Processing to enhance the quality of the scanned files, and optical character recognition using LSTM which extracts the text contained in images. The Data Analytics Module, then cleanses and mines the extracted text using Big Data Analytics tools. Text Matching and searching is performed on the Spark Dataframe using regular expressions to identify different attributes and their different types. Finally, the data is stored in a SQL Database. In order to measure the workflow's accuracy a manual baseline was generated for a sample project. The accuracy is measured using field-level verification, since it was found to be the most fit-for-purpose, as it allows to measure the accuracy of the workflow on the level of each field.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"23 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81348190","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}
Umar Alfazazi, Nithin Chacko Thomas, E. Al-Shalabi, W. Alameri
Polymer flooding in carbonate reservoirs is greatly affected by polymer retention, which is mainly due to polymer-rock surface interactions. Consequently, this leads to a delay in polymer front propagation and related oil recovery response. This work investigates the effect of oil presence and wettability restoration on polymer retention under harsh reservoir conditions of high temperature and high salinity (HTHS). An ATBS-based polymer was used for this study. Polymer single- and two-phase dynamic retention tests as well as bulk- and in-situ rheological experiments were conducted on Indiana limestone outcrops and in the presence of high salinity brine of 243,000 ppm at temperature of 50 °C. A total of four coreflooding experiments were conducted on core samples with similar petrophysical properties. Bulk rheology tests showed that the polymer is stable at HTHS conditions. Also, polymer retention and in-situ rheology tests highlighted the significance of oil presence in the core samples where retention was found to be around 40-50 and 25-30 μg/g-rock in the absence and presence of oil, respectively. An additional 50% reduction in retention was further observed on a restored wettability (aged) core sample. Polymer inaccessible pore volume (IPV) was found to be high in the range of 23 to 28%, which was supported by the 1D saturation profiles obtained from the CT scanner. The ATBS-based polymer shows excellent results for applications in carbonates under harsh conditions without considerable polymer loss or plugging. This paper also provides valuable insights into the impact of oil presence and wettability restoration on polymer retention. Furthermore, this study shows that careful consideration of the latter factor is necessary to avoid unrepresentative and inflated polymer retention values in oil reservoirs.
{"title":"Investigation of Oil Presence and Wettability Restoration Effects on Sulfonated Polymer Retention in Carbonates Under Harsh Conditions","authors":"Umar Alfazazi, Nithin Chacko Thomas, E. Al-Shalabi, W. Alameri","doi":"10.2118/207892-ms","DOIUrl":"https://doi.org/10.2118/207892-ms","url":null,"abstract":"\u0000 Polymer flooding in carbonate reservoirs is greatly affected by polymer retention, which is mainly due to polymer-rock surface interactions. Consequently, this leads to a delay in polymer front propagation and related oil recovery response. This work investigates the effect of oil presence and wettability restoration on polymer retention under harsh reservoir conditions of high temperature and high salinity (HTHS). An ATBS-based polymer was used for this study. Polymer single- and two-phase dynamic retention tests as well as bulk- and in-situ rheological experiments were conducted on Indiana limestone outcrops and in the presence of high salinity brine of 243,000 ppm at temperature of 50 °C. A total of four coreflooding experiments were conducted on core samples with similar petrophysical properties.\u0000 Bulk rheology tests showed that the polymer is stable at HTHS conditions. Also, polymer retention and in-situ rheology tests highlighted the significance of oil presence in the core samples where retention was found to be around 40-50 and 25-30 μg/g-rock in the absence and presence of oil, respectively. An additional 50% reduction in retention was further observed on a restored wettability (aged) core sample. Polymer inaccessible pore volume (IPV) was found to be high in the range of 23 to 28%, which was supported by the 1D saturation profiles obtained from the CT scanner. The ATBS-based polymer shows excellent results for applications in carbonates under harsh conditions without considerable polymer loss or plugging. This paper also provides valuable insights into the impact of oil presence and wettability restoration on polymer retention. Furthermore, this study shows that careful consideration of the latter factor is necessary to avoid unrepresentative and inflated polymer retention values in oil reservoirs.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"195 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79808776","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}
Elugai Palanichamy Selvarasu, Eslah Ali Al Hammadi
Engineering Division provides services & support to Operations and Projects. Division develops deliverable / report / recommendation for various studies, operation issues related to Engineering, root cause analysis, etc. Division receives an average of five request in a week. Division is handling 175+ studies at a time with support of multiple discipline Engineers within division and are in different stages. The division was handling the complete business process manually with dedicated resources to track the review, approval, execution and progress monitor. It was difficult to track all the steps since the information were scattered with many stakeholders and manual entries are not robust / fool proof. The manual control was insufficient to manage document movement, monitoring engineering activities and progress. This paper highlights the methodology used to digitalize the business process and also the improvement / benefit realized.
{"title":"Improvement Realized Through Digitized Engineering Business Process","authors":"Elugai Palanichamy Selvarasu, Eslah Ali Al Hammadi","doi":"10.2118/208048-ms","DOIUrl":"https://doi.org/10.2118/208048-ms","url":null,"abstract":"\u0000 Engineering Division provides services & support to Operations and Projects. Division develops deliverable / report / recommendation for various studies, operation issues related to Engineering, root cause analysis, etc. Division receives an average of five request in a week. Division is handling 175+ studies at a time with support of multiple discipline Engineers within division and are in different stages.\u0000 The division was handling the complete business process manually with dedicated resources to track the review, approval, execution and progress monitor.\u0000 It was difficult to track all the steps since the information were scattered with many stakeholders and manual entries are not robust / fool proof. The manual control was insufficient to manage document movement, monitoring engineering activities and progress.\u0000 This paper highlights the methodology used to digitalize the business process and also the improvement / benefit realized.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82749016","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. Kumar, V. Pathak, P. Agrawal, Z. Alias, T. Narwal, A. Hadhrami
Effective gas utilization is critical to any gas injection development project to maximize recoveries for a given purchase of make-up gas, whilst reducing the Green Gas House (GHG) emissions. This paper describes the use of a fully implicit Integrated Production System Model (IPSM) for two inter-connected production system networks, coupling multiple, critically sour oil reservoirs undergoing Miscible Gas Injection (MGI) for Enhanced Oil Recovery (EOR) using produced sour gas from oil and condensate fields in South Oman. The IPSM model links sixteen reservoir models with varying levels of complexities to the facilities network. Complexities in the facilities include multiple nodal constraints that necessitate the use of an Equation of State model (EOS). The IPSM model honors the gas balance implicitly. Gas flood optimization includes prioritizing low GOR production wells (at reservoir and well level) whilst maintaining reservoir pressure above Minimum Miscibility Pressures (MMP). Development schedule optimization also helps in optimizing the compressor size, the key Capex component. Compositional modeling allows continuous tracking of souring levels at different nodes, providing integrity status of overall production system network. The current IPSM model helps in optimization of schedule for the phased development of the oil reservoirs and eventually the most efficient gas utilization. This has enabled low pressure operation in some reservoirs providing oil at very low unit technical cost while waiting for gas availability. Compositional tracking for H2S helps in operating the facilities within design limits whilst planning future developments to cater to this design. Some key parameters can be parameterized for quick sensitivity analysis for an informed decision making for business opportunities. The production potential of the system is also tracked to ensure there is a cushion in the system to deal with any unexpected changes. This feature helps in planning and optimizing the scheduled turn-around activities for these two inter-connected production system networks. The novelty of this work is collaboration across multiple disciplines, especially the surface and subsurface because of complex interactions between facilities constraints and reservoir performance (associated with produced gas reinjection). Compositional tracking and injection gas apportionment across multiple reservoirs is key to the overall value maximization in this complex development.
{"title":"Production Optimization Coupling Multiple Reservoirs and Facilities With Sour Gas Re-Injection for Miscible EOR in South Oman","authors":"K. Kumar, V. Pathak, P. Agrawal, Z. Alias, T. Narwal, A. Hadhrami","doi":"10.2118/207289-ms","DOIUrl":"https://doi.org/10.2118/207289-ms","url":null,"abstract":"\u0000 Effective gas utilization is critical to any gas injection development project to maximize recoveries for a given purchase of make-up gas, whilst reducing the Green Gas House (GHG) emissions. This paper describes the use of a fully implicit Integrated Production System Model (IPSM) for two inter-connected production system networks, coupling multiple, critically sour oil reservoirs undergoing Miscible Gas Injection (MGI) for Enhanced Oil Recovery (EOR) using produced sour gas from oil and condensate fields in South Oman.\u0000 The IPSM model links sixteen reservoir models with varying levels of complexities to the facilities network. Complexities in the facilities include multiple nodal constraints that necessitate the use of an Equation of State model (EOS). The IPSM model honors the gas balance implicitly. Gas flood optimization includes prioritizing low GOR production wells (at reservoir and well level) whilst maintaining reservoir pressure above Minimum Miscibility Pressures (MMP). Development schedule optimization also helps in optimizing the compressor size, the key Capex component. Compositional modeling allows continuous tracking of souring levels at different nodes, providing integrity status of overall production system network.\u0000 The current IPSM model helps in optimization of schedule for the phased development of the oil reservoirs and eventually the most efficient gas utilization. This has enabled low pressure operation in some reservoirs providing oil at very low unit technical cost while waiting for gas availability. Compositional tracking for H2S helps in operating the facilities within design limits whilst planning future developments to cater to this design. Some key parameters can be parameterized for quick sensitivity analysis for an informed decision making for business opportunities. The production potential of the system is also tracked to ensure there is a cushion in the system to deal with any unexpected changes. This feature helps in planning and optimizing the scheduled turn-around activities for these two inter-connected production system networks.\u0000 The novelty of this work is collaboration across multiple disciplines, especially the surface and subsurface because of complex interactions between facilities constraints and reservoir performance (associated with produced gas reinjection). Compositional tracking and injection gas apportionment across multiple reservoirs is key to the overall value maximization in this complex development.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"11 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75919595","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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