Jasbindra Singh, M. Lawati, Abdulkareem Hindawi, Mohammed Harthi, Abdel Samiee Rady, Mohammed Al Hinai, Marya Al Salmi, Safiya Al Hatmi, Mohamed Siyabi, Moosa Rawahi, I. Mahruqi, Nasser Al Azri
This paper describes the utilization of produced and treated formation water for planting trees and growing algae in large ponds; in a massive scale in South Oman. A detailed study has been carried out to assess the injection requirements for pressure maintenance in the producing reservoir and using the remaining excess pot-treated water for farming of the palm trees. The produced water has been used as disposal in formations deeper than the producing horizons in the past. The produced water was separated in a processing station that received gross production from a number of fields in South Oman. This water was disposed in the aquifer underlying a producing reservoir that has experienced pressure maintenance due to this disposal. The impact of this excess water disposal on the aquifer was studied to evaluate the risk of breaching cap rock integrity. The risk was not significant but to ensure "no damage to the environment and people" it was decided to reduce or optimize injection rates to maintain the reservoir pressure safeguarding reserves. In addition, the disposal of the water required significant amount of power equivalent to emitting significant amount of CO2 annually just for water disposal. The study was carried out using simple material balance methods to predict the pressure behaviour given an injection profile. The recommendations from the study have already been implemented to convert the deep-water disposal to injection in the aquifer. This has been achieved by the integration of number of interfaces from sub-surface to field operations. All the pieces are in place to take it the next level of execution that is to treat the water at surface for oil removal, hence rendering the water at acceptable quality levels for tree plantation and algae ponds. The project also aims in a future second phase to further treat the water to higher specifications allowing the use of it for agricultural purposes. This would introduce a commercial farm that will depend on this source of water. This would be a novel concept in South Oman where the treated water will be used for farming solving multiple issues at multiple levels namely helping the business achieve its objective of sustained oil production, helping local communities with employment via farming and helping the organization care for the environment by reducing carbon footprints.
{"title":"Greening the Desert While Helping Business and Caring for the Environment","authors":"Jasbindra Singh, M. Lawati, Abdulkareem Hindawi, Mohammed Harthi, Abdel Samiee Rady, Mohammed Al Hinai, Marya Al Salmi, Safiya Al Hatmi, Mohamed Siyabi, Moosa Rawahi, I. Mahruqi, Nasser Al Azri","doi":"10.2118/207307-ms","DOIUrl":"https://doi.org/10.2118/207307-ms","url":null,"abstract":"\u0000 This paper describes the utilization of produced and treated formation water for planting trees and growing algae in large ponds; in a massive scale in South Oman. A detailed study has been carried out to assess the injection requirements for pressure maintenance in the producing reservoir and using the remaining excess pot-treated water for farming of the palm trees.\u0000 The produced water has been used as disposal in formations deeper than the producing horizons in the past. The produced water was separated in a processing station that received gross production from a number of fields in South Oman. This water was disposed in the aquifer underlying a producing reservoir that has experienced pressure maintenance due to this disposal. The impact of this excess water disposal on the aquifer was studied to evaluate the risk of breaching cap rock integrity. The risk was not significant but to ensure \"no damage to the environment and people\" it was decided to reduce or optimize injection rates to maintain the reservoir pressure safeguarding reserves. In addition, the disposal of the water required significant amount of power equivalent to emitting significant amount of CO2 annually just for water disposal. The study was carried out using simple material balance methods to predict the pressure behaviour given an injection profile.\u0000 The recommendations from the study have already been implemented to convert the deep-water disposal to injection in the aquifer. This has been achieved by the integration of number of interfaces from sub-surface to field operations. All the pieces are in place to take it the next level of execution that is to treat the water at surface for oil removal, hence rendering the water at acceptable quality levels for tree plantation and algae ponds.\u0000 The project also aims in a future second phase to further treat the water to higher specifications allowing the use of it for agricultural purposes. This would introduce a commercial farm that will depend on this source of water. This would be a novel concept in South Oman where the treated water will be used for farming solving multiple issues at multiple levels namely helping the business achieve its objective of sustained oil production, helping local communities with employment via farming and helping the organization care for the environment by reducing carbon footprints.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"2 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75276329","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}
Decision making in new fields with little data available relies heavily on physics-based simulation models. However, due to a lack of full understanding of the physical processes governing flow in the unconventional resources, data-driven modeling has emerged as an alternative and complimentary tool to create recovery forecasts that honor the available data. Transfer Learning provides an opportunity to start early-stage analysis of the asset before adequate data becomes available. New challenges in the energy industry as well as shifting dynamics in both domestic and global supply and demand has encouraged some of the petroleum exporting countries in the Middle East to strategize the development of unconventional resources. In this research we have developed a data-driven Transfer Learning framework that allows the basin-wide assessment of new shale gas and tight oil prospects. The proposed Transfer Learning method is developed on real-world data from several thousand horizontal multistage wells in the Eagle Ford super-basin in South Texas. In this method we have integrated reservoir engineering domain expertise in the data pre-processing and feature generation steps. We have also considered the temporal and spatial balancing of the training data to assure that the predictive models honor the real practice of unconventional field development. Our full cycle Transfer Learning workflow consists of dimensionality reduction and unsupervised clustering, supervised learning, and hyperparameter fine-tuning. This workflow enables reservoir engineers to experiment with multiple hypothetical scenarios and observe the impact of additional data in the learning process. We use the developed workflow to examine the performance of a data-driven model of the Eagle Ford Basin on potential plays in the Middle East. Existence of all liquid types of oil, condensate and dry gas in the Eagle Ford has resulted in training a model flexible enough to be tested on various types of assets in a new location. We first present the successful deployment of our model within the Eagle Ford. Next, we use the information from major formations such as Tuwaiq Mountain and Hanifa and show the value of a pre-existing model from a fully-developed shale play on achieving acceptable accuracies with minimal information available in a new field. Our model is developed by data types with relatively low resolution that minimizes overfitting effects and allows generalization to different geologies with basin-wide accuracy. This approach allows conducting accelerated assessment of various sections of a large asset to enhance field development planning processes. This is a first example of such an effort on a basin scale that examines the effectiveness of Transfer Learning on some of the major unconventional plays in the Middle East region. This workflow allows investigating the relationship among geologic and petrophysical variables, drilling and completion parameters, and productivity of a
{"title":"Assessment of Unconventional Resources Opportunities in the Middle East Tethyan Petroleum System in a Transfer Learning Context","authors":"Cyrus Ashayeri, B. Jha","doi":"10.2118/207723-ms","DOIUrl":"https://doi.org/10.2118/207723-ms","url":null,"abstract":"\u0000 Decision making in new fields with little data available relies heavily on physics-based simulation models. However, due to a lack of full understanding of the physical processes governing flow in the unconventional resources, data-driven modeling has emerged as an alternative and complimentary tool to create recovery forecasts that honor the available data. Transfer Learning provides an opportunity to start early-stage analysis of the asset before adequate data becomes available. New challenges in the energy industry as well as shifting dynamics in both domestic and global supply and demand has encouraged some of the petroleum exporting countries in the Middle East to strategize the development of unconventional resources. In this research we have developed a data-driven Transfer Learning framework that allows the basin-wide assessment of new shale gas and tight oil prospects. The proposed Transfer Learning method is developed on real-world data from several thousand horizontal multistage wells in the Eagle Ford super-basin in South Texas. In this method we have integrated reservoir engineering domain expertise in the data pre-processing and feature generation steps. We have also considered the temporal and spatial balancing of the training data to assure that the predictive models honor the real practice of unconventional field development. Our full cycle Transfer Learning workflow consists of dimensionality reduction and unsupervised clustering, supervised learning, and hyperparameter fine-tuning. This workflow enables reservoir engineers to experiment with multiple hypothetical scenarios and observe the impact of additional data in the learning process. We use the developed workflow to examine the performance of a data-driven model of the Eagle Ford Basin on potential plays in the Middle East. Existence of all liquid types of oil, condensate and dry gas in the Eagle Ford has resulted in training a model flexible enough to be tested on various types of assets in a new location. We first present the successful deployment of our model within the Eagle Ford. Next, we use the information from major formations such as Tuwaiq Mountain and Hanifa and show the value of a pre-existing model from a fully-developed shale play on achieving acceptable accuracies with minimal information available in a new field. Our model is developed by data types with relatively low resolution that minimizes overfitting effects and allows generalization to different geologies with basin-wide accuracy. This approach allows conducting accelerated assessment of various sections of a large asset to enhance field development planning processes. This is a first example of such an effort on a basin scale that examines the effectiveness of Transfer Learning on some of the major unconventional plays in the Middle East region. This workflow allows investigating the relationship among geologic and petrophysical variables, drilling and completion parameters, and productivity of a ","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"54 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"72557244","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}
J. J. Abraham, Cameron Devers, C. Teodoriu, M. Amani
In conventional well design, the cement sheath acts as one of the primary barriers of protection in the well integrity matrix. Once the wellbore cement is set, the well is exposed to various conditions and environments over time which can impact the integrity of the cement, the results of which are poorly studied and documented. Given that there are also multiple cement recipes and formulations – the task of studying downhole cement performance and categorizing said results becomes more complicated, requiring the need for an integrated database of information. The objective of this paper is to document desirable cement properties, develop an optimal method for presenting this data, and construct a database which integrates this information and allows streamlined data entry and retrieval. Multiple variables must be considered when aggregating cement recipes and its corresponding properties over time. To test the behavior of these cement recipes over time, samples are created and aged in various controlled environments, and the properties tested periodically. The database was developed with a suitable interface to provide intuitive data entry and practical analysis capability, with proper inputs for the types of cement used, additives added, properties of the cement mixtures over time and any corresponding analysis performed on the samples in order to maximize best practice. Differences in geology, drilling techniques and standards often require the use of different cement recipes with varied additives to cater to each job. These include accelerators, retarders, extenders, weighing agents, fluid and loss control additives, as well as special additives such as latex, fiber additives and foam cements. The database interface is designed to accommodate these variations in the cement recipes and track the properties of samples over time and give a comprehensive understanding of the behavior of the samples as they age. With information from the industry, literature, and laboratory experiments, properties such as the Unconfined Compressive Strength (UCS), thickening times, gel strength development, densities, to name few will be integrated in the data base. Data analytics strategies will also be applied on the information aggregated, and the properties of the samples over time will be correlated to field data as well as literature to ensure proper representation and accuracy of the data. The database and the knowledge collected will be utilized as a source of information to enhance common cementing practices, as well as develop and refine industry best practices, which will be applicable to any cement job in the world. Currently, the database presented in this paper contains over 1000 unique cement samples, prepared and documented by multiple individuals with an aim to create a unique cement repository and database that focuses on long term cement properties.
{"title":"The Need for a Comprehensive Cement Database - A Novel Approach to Best Practices by Cataloging Cement Properties","authors":"J. J. Abraham, Cameron Devers, C. Teodoriu, M. Amani","doi":"10.2118/208112-ms","DOIUrl":"https://doi.org/10.2118/208112-ms","url":null,"abstract":"\u0000 In conventional well design, the cement sheath acts as one of the primary barriers of protection in the well integrity matrix. Once the wellbore cement is set, the well is exposed to various conditions and environments over time which can impact the integrity of the cement, the results of which are poorly studied and documented. Given that there are also multiple cement recipes and formulations – the task of studying downhole cement performance and categorizing said results becomes more complicated, requiring the need for an integrated database of information. The objective of this paper is to document desirable cement properties, develop an optimal method for presenting this data, and construct a database which integrates this information and allows streamlined data entry and retrieval.\u0000 Multiple variables must be considered when aggregating cement recipes and its corresponding properties over time. To test the behavior of these cement recipes over time, samples are created and aged in various controlled environments, and the properties tested periodically. The database was developed with a suitable interface to provide intuitive data entry and practical analysis capability, with proper inputs for the types of cement used, additives added, properties of the cement mixtures over time and any corresponding analysis performed on the samples in order to maximize best practice.\u0000 Differences in geology, drilling techniques and standards often require the use of different cement recipes with varied additives to cater to each job. These include accelerators, retarders, extenders, weighing agents, fluid and loss control additives, as well as special additives such as latex, fiber additives and foam cements. The database interface is designed to accommodate these variations in the cement recipes and track the properties of samples over time and give a comprehensive understanding of the behavior of the samples as they age. With information from the industry, literature, and laboratory experiments, properties such as the Unconfined Compressive Strength (UCS), thickening times, gel strength development, densities, to name few will be integrated in the data base. Data analytics strategies will also be applied on the information aggregated, and the properties of the samples over time will be correlated to field data as well as literature to ensure proper representation and accuracy of the data.\u0000 The database and the knowledge collected will be utilized as a source of information to enhance common cementing practices, as well as develop and refine industry best practices, which will be applicable to any cement job in the world. Currently, the database presented in this paper contains over 1000 unique cement samples, prepared and documented by multiple individuals with an aim to create a unique cement repository and database that focuses on long term cement properties.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"126 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79074401","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}
The production technology working environment of an oil brownfield is usually an inconsistent collection of tools and spreadsheets. In this paper, we will explore Wintershall Dea's digitalisation journey from a patchwork of tools and spreadsheets to a unified corporate Production Technology Workbench (PTW) solution starting from the replacement of an existing and ageing tool on an asset on the Norwegian continental shelf and ending by incorporating the requirements of other assets from Wintershall Dea's diverse and geographically dispersed portfolio. The project started by selecting the low-code application platform suitable to be used as the basis for the journey. After a proof-of-concept stage, an Agile project was launched owned by the asset and with a geographically dispersed Development Team conformed by Wintershall Dea's Product Owners, IT/OT experts, UX consultants and Eigen's scrum master and Development Team. After the delivery of the MVP, a second Product Owner was incorporated from a second asset. The Agile project continued to deliver on enhanced functionality and requirements that would most benefit both assets. The original production system calculations and workflows are vital for the asset. However, such patchworks are not easy to work with and complex to maintain or change. This had a negative effect on the efficiency as work is time-consuming and cumbersome. Well anomalies were often detected by actively looking for them daily in various plots, reports and platforms, and therefore the detection and response time to production events was delayed. A Production Technology dashboard with built-in / automated data processing for standard tasks provides engineers with the required transparency of data to identify issues and pain-points in a timely manner. This helps engineers to proactively intervene to mitigate unplanned losses and downtime, reducing the amount of deferred production. Investment in a corporate-wide unified (standard UX) platform, will help engineers when starting new assignments to spot issues easier and quicker independently of the asset they are assigned to. But beyond a standardization, each engineer needs to be able to create individual workflows (for effects such as scaling, slugging, sand etc.) for their needs by means of the self-service capabilities of the technology. Also, the quick access to frequently used and relevant data could be accessed through one platform, making everyday life of the production engineer more efficient and smoother. Over the timeframe of 15+ Sprints the Product Owners refined and re-defined the exact functionality they would like to see delivered. The PTW concept seeks to minimise the time that engineers require to learn the tool and use it to inspect, analyse, and make decisions to optimise the production of the field. This is one of Wintershall Dea's first projects executed following Agile, using a geographically dispersed team, during the restrictions im
{"title":"Production Technology Workbench: Developing and Scaling a Corporate Digital Product Using Agile Methods","authors":"Joel Chacon, Peter Dabrowski","doi":"10.2118/207922-ms","DOIUrl":"https://doi.org/10.2118/207922-ms","url":null,"abstract":"\u0000 \u0000 \u0000 The production technology working environment of an oil brownfield is usually an inconsistent collection of tools and spreadsheets. In this paper, we will explore Wintershall Dea's digitalisation journey from a patchwork of tools and spreadsheets to a unified corporate Production Technology Workbench (PTW) solution starting from the replacement of an existing and ageing tool on an asset on the Norwegian continental shelf and ending by incorporating the requirements of other assets from Wintershall Dea's diverse and geographically dispersed portfolio.\u0000 \u0000 \u0000 \u0000 The project started by selecting the low-code application platform suitable to be used as the basis for the journey. After a proof-of-concept stage, an Agile project was launched owned by the asset and with a geographically dispersed Development Team conformed by Wintershall Dea's Product Owners, IT/OT experts, UX consultants and Eigen's scrum master and Development Team. After the delivery of the MVP, a second Product Owner was incorporated from a second asset. The Agile project continued to deliver on enhanced functionality and requirements that would most benefit both assets.\u0000 \u0000 \u0000 \u0000 The original production system calculations and workflows are vital for the asset. However, such patchworks are not easy to work with and complex to maintain or change. This had a negative effect on the efficiency as work is time-consuming and cumbersome. Well anomalies were often detected by actively looking for them daily in various plots, reports and platforms, and therefore the detection and response time to production events was delayed. A Production Technology dashboard with built-in / automated data processing for standard tasks provides engineers with the required transparency of data to identify issues and pain-points in a timely manner. This helps engineers to proactively intervene to mitigate unplanned losses and downtime, reducing the amount of deferred production. Investment in a corporate-wide unified (standard UX) platform, will help engineers when starting new assignments to spot issues easier and quicker independently of the asset they are assigned to. But beyond a standardization, each engineer needs to be able to create individual workflows (for effects such as scaling, slugging, sand etc.) for their needs by means of the self-service capabilities of the technology. Also, the quick access to frequently used and relevant data could be accessed through one platform, making everyday life of the production engineer more efficient and smoother. Over the timeframe of 15+ Sprints the Product Owners refined and re-defined the exact functionality they would like to see delivered.\u0000 \u0000 \u0000 \u0000 The PTW concept seeks to minimise the time that engineers require to learn the tool and use it to inspect, analyse, and make decisions to optimise the production of the field. This is one of Wintershall Dea's first projects executed following Agile, using a geographically dispersed team, during the restrictions im","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":"84193531","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}
The Cotton Valley sand and Haynesville shale formations are situated in East Texas, USA, producing oil, gas, and condensate on land. Most of the producing assets are mature and souring, and the presence of hydrogen sulfide in the produced fluids and gas provides both operational concerns in terms of solids deposition and asset integrity in the production facilities as well as complexity when considering the processing, export, and sale of condensate and gas. Produced gas was traditionally treated with MEA triazine hydrogen sulfide scavenger prior to liquification by LNG plant. There have been historical issues with both the levels of hydrogen sulfide left in the gas and also solids formation in the process, which threatened periodic shutdown of the LNG plant. A holistic approach was used to improve the overall sulfur removal process. This includes the reduction or elimination of solids formation as well as improvement in the system scavenging efficiency. The approach considered current operating procedures, system parameters, equipment design (contactors), and H2S scavenger chemistry.
{"title":"Total Systems Approach to Reduce Fouling and Improve System Efficiency Using Hydrogen Sulfide Scavengers","authors":"J. A. Mcrae, Willem-Louis Marais, A. Jenkins","doi":"10.2118/207992-ms","DOIUrl":"https://doi.org/10.2118/207992-ms","url":null,"abstract":"\u0000 The Cotton Valley sand and Haynesville shale formations are situated in East Texas, USA, producing oil, gas, and condensate on land. Most of the producing assets are mature and souring, and the presence of hydrogen sulfide in the produced fluids and gas provides both operational concerns in terms of solids deposition and asset integrity in the production facilities as well as complexity when considering the processing, export, and sale of condensate and gas.\u0000 Produced gas was traditionally treated with MEA triazine hydrogen sulfide scavenger prior to liquification by LNG plant. There have been historical issues with both the levels of hydrogen sulfide left in the gas and also solids formation in the process, which threatened periodic shutdown of the LNG plant. A holistic approach was used to improve the overall sulfur removal process. This includes the reduction or elimination of solids formation as well as improvement in the system scavenging efficiency. The approach considered current operating procedures, system parameters, equipment design (contactors), and H2S scavenger chemistry.","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":"81876933","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}
Bruce William Becker, F. Baldino, Alessandro Aleandri
The Liverpool Bay Asset Carbon Capture and Storage (LBA CCS) project is being developed in parallel with, and as an integral part of, the HyNet North West integrated project, which is aimed at decarbonizing the important industrial region of North-West England and North Wales. The Liverpool Bay Asset (100% Eni UK Limited) is approaching the end of its production life and would be progressively decommissioned over the period 2023 to 2025 without the prospect of re-configuring to a CCS project. Eni plans to reuse and repurpose the depleted hydrocarbon reservoirs of the Hamilton, Hamilton North and Lennox fields together with their associated infrastructure to transport and store carbon dioxide (CO2) emissions captured upstream by the HyNet NW partners. A Carbon Dioxide Appraisal and Storage Licence was awarded to Eni by the UK Oil & Gas Authority (OGA) in October 2020 for this purpose. The project has now completed the Concept Selection Phase and the paper describes the multidisciplinary work covering subsurface, facilities and drilling engineering, flow assurance and project management that has been completed to select the development concept for advancement into the concept definition phase. It demonstrates the viability and benefits of re-using depleted fields and existing infrastructure originally installed for hydrocarbon production to reduce the unit cost of storage, a key metric for all CCS projects.
{"title":"Liverpool Bay Area CCS: An advanced Case Study to Achieve UK's Carbon Neutrality","authors":"Bruce William Becker, F. Baldino, Alessandro Aleandri","doi":"10.2118/207418-ms","DOIUrl":"https://doi.org/10.2118/207418-ms","url":null,"abstract":"\u0000 The Liverpool Bay Asset Carbon Capture and Storage (LBA CCS) project is being developed in parallel with, and as an integral part of, the HyNet North West integrated project, which is aimed at decarbonizing the important industrial region of North-West England and North Wales. The Liverpool Bay Asset (100% Eni UK Limited) is approaching the end of its production life and would be progressively decommissioned over the period 2023 to 2025 without the prospect of re-configuring to a CCS project. Eni plans to reuse and repurpose the depleted hydrocarbon reservoirs of the Hamilton, Hamilton North and Lennox fields together with their associated infrastructure to transport and store carbon dioxide (CO2) emissions captured upstream by the HyNet NW partners. A Carbon Dioxide Appraisal and Storage Licence was awarded to Eni by the UK Oil & Gas Authority (OGA) in October 2020 for this purpose.\u0000 The project has now completed the Concept Selection Phase and the paper describes the multidisciplinary work covering subsurface, facilities and drilling engineering, flow assurance and project management that has been completed to select the development concept for advancement into the concept definition phase. It demonstrates the viability and benefits of re-using depleted fields and existing infrastructure originally installed for hydrocarbon production to reduce the unit cost of storage, a key metric for all CCS projects.","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":"81722814","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}
S. M. Al Yammahi, Mohamed Obaid Al Kaabi, Rashid Al Zaabi, Sachin A. Shendge, Manly Vista Dizon, Ananda Sarkar
Crude storage tanks are an important asset in every oil company. Having adequate storage capacities is important economically and ensure steady supply of oil in the market. Hence, taking a huge tank out of service for refurbishment is technically and safety critical, and as much as putting it back into service on time. This paper presents an advanced methodology and assessment of tank refurbishment process of large capacity Crude Storage Tanks, in compliance with the International Codes and Standards resulting in optimization of the project schedule by approximately 40% as compared to conventional methodology of refurbishment. By deploying the advance techniques, detailed assessment, and dynamic planning we have been able to accelerate the completion of the project, improve tank availability time without compromising with the Integrity and HSE.
{"title":"Crude Oil Storage Tank Refurbishment Duration Optimized by 40% Through Advanced Techniques","authors":"S. M. Al Yammahi, Mohamed Obaid Al Kaabi, Rashid Al Zaabi, Sachin A. Shendge, Manly Vista Dizon, Ananda Sarkar","doi":"10.2118/207976-ms","DOIUrl":"https://doi.org/10.2118/207976-ms","url":null,"abstract":"\u0000 Crude storage tanks are an important asset in every oil company. Having adequate storage capacities is important economically and ensure steady supply of oil in the market. Hence, taking a huge tank out of service for refurbishment is technically and safety critical, and as much as putting it back into service on time.\u0000 This paper presents an advanced methodology and assessment of tank refurbishment process of large capacity Crude Storage Tanks, in compliance with the International Codes and Standards resulting in optimization of the project schedule by approximately 40% as compared to conventional methodology of refurbishment. By deploying the advance techniques, detailed assessment, and dynamic planning we have been able to accelerate the completion of the project, improve tank availability time without compromising with the Integrity and HSE.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"32 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80404718","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}
Göktug Diker, Herwig Frühbauer, Edna Michelle Bisso Bi Mba
Wintershall Dea is developing together with partners a digital system to monitor and optimize electrical submersible pump (ESP) performance based on the data from Mittelplate oil field. This tool is using machine learning (ML) models which are fed by historic data and will notify engineers and operators when operating conditions are trending beyond the operating envelope, which enables an operator to mitigate upcoming performance problems. In addition to traditional engineering methods, such a system will capture knowledge by continuous improvement based on ML. With this approach the engineer has a system at hand to support the day-to-day work. Manual monitoring and on demand investigations are now backed up by an intelligent system which permanently monitors the equipment. In order to create such a system, a proof of concept (PoC) study has been initiated with industry partners and data scientists to evaluate historic events, which are used to train the ML-systems. This phase aims to better understand the capabilities of machine learning and data science in the subsurface domain as well as to build up trust for the engineers with such systems. The concept evaluation has shown that the intensive collaboration between engineers and data scientist is essential. A continuous and structured exchange between engineering and data science resulted in a mutual developed product, which fits the engineer's needs based on the technical capabilities and limits set by ML-models. To organize such a development, new project management elements like agile working methods, sprints and scrum methods were utilized. During the development Wintershall Dea has partnered with two organizations. One has a pure data science background and the other one was the data science team of the ESP manufacturer. After the PoC period the following conclusions can be derived: (1) data quality and format is key to success; (2) detailed knowledge of the equipment speeds up the development and the quality of the results; (3) high model accuracy requires a high number of events in the training dataset. The overall conclusion of this PoC is that the collaboration between engineers and data scientists, fostered by the agile project management toolkit and suitable datasets, leads to a successful development. Even when the limits of the ML-algorithms are hit, the model forecast, in combination with traditional engineering methods, adds significant value to the ESP performance. The novelty of such a system is that the production engineer will be supported by trusted ML-models and digital systems. This system in combination with the traditional engineering tools improves monitoring of the equipment and taking decisions leading to increased equipment performance.
{"title":"Development of a Digital ESP Performance Monitoring System Based on Artificial Intelligence","authors":"Göktug Diker, Herwig Frühbauer, Edna Michelle Bisso Bi Mba","doi":"10.2118/207929-ms","DOIUrl":"https://doi.org/10.2118/207929-ms","url":null,"abstract":"\u0000 Wintershall Dea is developing together with partners a digital system to monitor and optimize electrical submersible pump (ESP) performance based on the data from Mittelplate oil field. This tool is using machine learning (ML) models which are fed by historic data and will notify engineers and operators when operating conditions are trending beyond the operating envelope, which enables an operator to mitigate upcoming performance problems. In addition to traditional engineering methods, such a system will capture knowledge by continuous improvement based on ML.\u0000 With this approach the engineer has a system at hand to support the day-to-day work. Manual monitoring and on demand investigations are now backed up by an intelligent system which permanently monitors the equipment. In order to create such a system, a proof of concept (PoC) study has been initiated with industry partners and data scientists to evaluate historic events, which are used to train the ML-systems.\u0000 This phase aims to better understand the capabilities of machine learning and data science in the subsurface domain as well as to build up trust for the engineers with such systems.\u0000 The concept evaluation has shown that the intensive collaboration between engineers and data scientist is essential. A continuous and structured exchange between engineering and data science resulted in a mutual developed product, which fits the engineer's needs based on the technical capabilities and limits set by ML-models. To organize such a development, new project management elements like agile working methods, sprints and scrum methods were utilized.\u0000 During the development Wintershall Dea has partnered with two organizations. One has a pure data science background and the other one was the data science team of the ESP manufacturer.\u0000 After the PoC period the following conclusions can be derived: (1) data quality and format is key to success; (2) detailed knowledge of the equipment speeds up the development and the quality of the results; (3) high model accuracy requires a high number of events in the training dataset.\u0000 The overall conclusion of this PoC is that the collaboration between engineers and data scientists, fostered by the agile project management toolkit and suitable datasets, leads to a successful development. Even when the limits of the ML-algorithms are hit, the model forecast, in combination with traditional engineering methods, adds significant value to the ESP performance.\u0000 The novelty of such a system is that the production engineer will be supported by trusted ML-models and digital systems. This system in combination with the traditional engineering tools improves monitoring of the equipment and taking decisions leading to increased equipment performance.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"104 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80439890","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}
M. Alkhowaildi, M. Mahmoud, M. Bataweel, B. Tawabini
Amid the rise in energy demand over recent years, natural gas from tight reservoirs has been targeted abundantly around the globe by different oil operators. Hydraulic fracturing technology has been instrumental in the successful exploitation of energy from tight formations. The process is associated with enormous usage of water. Hydraulic fracturing requires as little as 500,000 gallons of freshwater, and up to 6 million gallons per well depending on the type of well and the number of stages treated. Now operators, as well as service companies worldwide, have shown a desire to use produced water in field operations to enhance economics and reduce their environmental footprint. Reusing produced water in field operations appears to be a win-win proposition by transforming the industry's biggest waste product into a resource. This paper highlights the recent findings in published articles about formulating a fracturing fluid from produced water as a base fluid. The rheological properties and fluid performance requirements, such as proppant carrying capacity, mixing, fluid efficiency, ability to crosslink and break, and cleanup after treatment, will be evaluated in detail. This paper identified the critical parameters associated with high TDS fluids (produced water) such as pH, hydration time, ionic strength, and suspended solids, collected the corresponding optimal ranges for these parameters in laboratory tests, and reported some of the validity of the findings under actual conditions in field trials around the world. Most studies demonstrated the feasibility of using untreated produced water as a base fluid for crosslinked gel-based hydraulic fracturing. Through adjusting the hydration time, the gel loading, and the amount of breakers applied, it is conceivable that crosslinked gels with optimal rheological characteristics can be formulated with untreated produced water. Multiple generations of guar- and CMHPG-based crosslinked fracturing fluids, developed with 100% untreated produced water, exhibited optimal viscosities exceeding 200 cp at 40 s−1 for at least 60 minutes. The ability to provide fracturing fluids with high-salinity produced water can be a successful water conservation approach and an attractive solution for enhancing operation economics. Some studies indicated that using produced water can be better than freshwater because the produced water is more compatible with the reservoir and may be less likely to cause conditions such as salinity shock, which can damage the formation. More studies are needed to understand the associated technical challenges further.
{"title":"A Comprehensive Review on the Characteristics, Challenges and Reuse Opportunities Associated with Produced Water in Fracturing Operations","authors":"M. Alkhowaildi, M. Mahmoud, M. Bataweel, B. Tawabini","doi":"10.2118/207835-ms","DOIUrl":"https://doi.org/10.2118/207835-ms","url":null,"abstract":"\u0000 Amid the rise in energy demand over recent years, natural gas from tight reservoirs has been targeted abundantly around the globe by different oil operators. Hydraulic fracturing technology has been instrumental in the successful exploitation of energy from tight formations. The process is associated with enormous usage of water. Hydraulic fracturing requires as little as 500,000 gallons of freshwater, and up to 6 million gallons per well depending on the type of well and the number of stages treated. Now operators, as well as service companies worldwide, have shown a desire to use produced water in field operations to enhance economics and reduce their environmental footprint. Reusing produced water in field operations appears to be a win-win proposition by transforming the industry's biggest waste product into a resource.\u0000 This paper highlights the recent findings in published articles about formulating a fracturing fluid from produced water as a base fluid. The rheological properties and fluid performance requirements, such as proppant carrying capacity, mixing, fluid efficiency, ability to crosslink and break, and cleanup after treatment, will be evaluated in detail. This paper identified the critical parameters associated with high TDS fluids (produced water) such as pH, hydration time, ionic strength, and suspended solids, collected the corresponding optimal ranges for these parameters in laboratory tests, and reported some of the validity of the findings under actual conditions in field trials around the world.\u0000 Most studies demonstrated the feasibility of using untreated produced water as a base fluid for crosslinked gel-based hydraulic fracturing. Through adjusting the hydration time, the gel loading, and the amount of breakers applied, it is conceivable that crosslinked gels with optimal rheological characteristics can be formulated with untreated produced water. Multiple generations of guar- and CMHPG-based crosslinked fracturing fluids, developed with 100% untreated produced water, exhibited optimal viscosities exceeding 200 cp at 40 s−1 for at least 60 minutes.\u0000 The ability to provide fracturing fluids with high-salinity produced water can be a successful water conservation approach and an attractive solution for enhancing operation economics. Some studies indicated that using produced water can be better than freshwater because the produced water is more compatible with the reservoir and may be less likely to cause conditions such as salinity shock, which can damage the formation. More studies are needed to understand the associated technical challenges further.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80693010","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}
B. Altaf, A. Allouti, Rachit Kedia, A. Abdullayev, M. Bedewi
The presence of hydrogen sulphide (H2S) in produced reservoir fluids mandates precautions in the design and operation of the surface facilities. The toxicity and corrosive nature of H2S, and the need to prevent both plugging of reservoir formations and increasing the sulphur content of the produced oil dictates the criticality of forecasting and monitoring the volumes and concentrations of H2S flowing through the whole asset. Ensuring the concentration is within acceptable operational limits is critical to safeguard the overall asset and the integrity of the surface pipeline network. The objective of this study was to utilize a history matched Digital Twin Integrated Asset Model (IAM) to predict the volumes and concentrations of H2S in a field located offshore Abu Dhabi by modeling the multi-stage separation, H2S removal, and re-injection facilities for gas injection and gas lifts. The field consists of multiple stacked carbonate reservoirs sharing the same surface facilities. The proposed modelling of H2S removal strategy involved a series of steps beginning with the sweetening of the produced associated gas for fuel gas requirements and mixing the extracted H2S volumes with the gas injection and gas lift streams. The sweetening process effectively mitigated any potential asset integrity issues arising due to corrosion of the power generation system and other surface facility assets. The stripped H2S gas, re-combined with the remaining produced gas, was used for gas-lifts and reinjected into the lower reservoirs for pressure maintenance and enhanced oil recovery (EOR). A next-generation surface-subsurface coupled simulator was utilized for the modeling of this field including the full asset surface pipeline network, the H2S removal plant, bypass lines and re-injection facilities for gas injection and gas-lifts. The Digital Twin IAM approach provided a robust method for tracking and predicting the concentration and volume of H2S in the produced gas over a period of 50 years. The simulation allowed tracking the H2S from its initial location in the reservoirs, into the production wells, then through the pipelines, all the way to the surface facilities where the sweetening of the produced is handled. Moreover, the use of the Digital Twin allowed the verification of the disposal plan of the extracted H2S, showing that mixing it with the re-injection gas stream is a feasible option. Recommendations based on the model were provided to the production and facilities team, leading to a robust long-term field development plan that ensures asset integrity.
{"title":"A Holistic Approach to Simulate the Impact of H2S on Production and Injection Surface Facilities Using an Integrated Asset Model as a Digital Twin","authors":"B. Altaf, A. Allouti, Rachit Kedia, A. Abdullayev, M. Bedewi","doi":"10.2118/207586-ms","DOIUrl":"https://doi.org/10.2118/207586-ms","url":null,"abstract":"\u0000 The presence of hydrogen sulphide (H2S) in produced reservoir fluids mandates precautions in the design and operation of the surface facilities. The toxicity and corrosive nature of H2S, and the need to prevent both plugging of reservoir formations and increasing the sulphur content of the produced oil dictates the criticality of forecasting and monitoring the volumes and concentrations of H2S flowing through the whole asset. Ensuring the concentration is within acceptable operational limits is critical to safeguard the overall asset and the integrity of the surface pipeline network.\u0000 The objective of this study was to utilize a history matched Digital Twin Integrated Asset Model (IAM) to predict the volumes and concentrations of H2S in a field located offshore Abu Dhabi by modeling the multi-stage separation, H2S removal, and re-injection facilities for gas injection and gas lifts. The field consists of multiple stacked carbonate reservoirs sharing the same surface facilities. The proposed modelling of H2S removal strategy involved a series of steps beginning with the sweetening of the produced associated gas for fuel gas requirements and mixing the extracted H2S volumes with the gas injection and gas lift streams.\u0000 The sweetening process effectively mitigated any potential asset integrity issues arising due to corrosion of the power generation system and other surface facility assets. The stripped H2S gas, re-combined with the remaining produced gas, was used for gas-lifts and reinjected into the lower reservoirs for pressure maintenance and enhanced oil recovery (EOR). A next-generation surface-subsurface coupled simulator was utilized for the modeling of this field including the full asset surface pipeline network, the H2S removal plant, bypass lines and re-injection facilities for gas injection and gas-lifts.\u0000 The Digital Twin IAM approach provided a robust method for tracking and predicting the concentration and volume of H2S in the produced gas over a period of 50 years. The simulation allowed tracking the H2S from its initial location in the reservoirs, into the production wells, then through the pipelines, all the way to the surface facilities where the sweetening of the produced is handled.\u0000 Moreover, the use of the Digital Twin allowed the verification of the disposal plan of the extracted H2S, showing that mixing it with the re-injection gas stream is a feasible option. Recommendations based on the model were provided to the production and facilities team, leading to a robust long-term field development plan that ensures asset integrity.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80741042","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}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：