H. Ijomanta, Lukman Lawal, Onyeka Ike, Raymond Olugbade, Fanen Gbuku, Charles Akenobo
This paper presents an overview of the implementation of a Digital Oilfield (DOF) system for the real-time management of the Oredo field in OML 111. The Oredo field is predominantly a retrograde condensate field with a few relatively small oil reservoirs. The field operating philosophy involves the dual objective of maximizing condensate production and meeting the daily contractual gas quantities which requires wells to be controlled and routed such that the dual objectives are met. An Integrated Asset Model (IAM) (or an Integrated Production System Model) was built with the objective of providing a mathematical basis for meeting the field's objective. The IAM, combined with a Model Management and version control tool, a workflow orchestration and automation engine, A robust data-management module, an advanced visualization and collaboration environment and an analytics library and engine created the Oredo Digital Oil Field (DOF). The Digital Oilfield is a real-time digital representation of a field on a computer which replicates the behavior of the field. This virtual field gives the engineer all the information required to make quick, sound and rational field management decisions with models, workflows, and intelligently filtered data within a multi-disciplinary organization of diverse capabilities and engineering skill sets. The creation of the DOF involved 4 major steps; DATA GATHERING considered as the most critical in such engineering projects as it helps to set the limits of what the model can achieve and cut expectations. ENGINEERING MODEL REVIEW, UPDATE AND BENCHMARKING; Majorly involved engineering models review and update, real-time data historian deployment etc. SYSTEM PRECONFIGURATION AND DEPLOYMENT; Developed the DOF system architecture and the engineering workflow setup. POST DEPLOYMENT REVIEW AND UPDATE; Currently ongoing till date, this involves after action reviews, updates and resolution of challenges of the DOF, capability development by the operator and optimizing the system for improved performance. The DOF system in the Oredo field has made it possible to integrate, automate and streamline the execution of field management tasks and has significantly reduced the decision-making turnaround time. Operational and field management decisions can now be made within minutes rather than weeks or months. The gains and benefits cuts across the entire production value chain from improved operational safety to operational efficiency and cost savings, real-time production surveillance, optimized production, early problem detection, improved Safety, Organizational/Cross-discipline collaboration, data Centralization and Efficiency. The DOF system did not come without its peculiar challenges observed both at the planning, execution and post evaluation stages which includes selection of an appropriate Data Gathering & acquisition system, Parts interchangeability and device integration with existing field devices, high data latency
{"title":"Digital Oil Field; The NPDC Experience","authors":"H. Ijomanta, Lukman Lawal, Onyeka Ike, Raymond Olugbade, Fanen Gbuku, Charles Akenobo","doi":"10.2118/207169-ms","DOIUrl":"https://doi.org/10.2118/207169-ms","url":null,"abstract":"\u0000 This paper presents an overview of the implementation of a Digital Oilfield (DOF) system for the real-time management of the Oredo field in OML 111.\u0000 The Oredo field is predominantly a retrograde condensate field with a few relatively small oil reservoirs. The field operating philosophy involves the dual objective of maximizing condensate production and meeting the daily contractual gas quantities which requires wells to be controlled and routed such that the dual objectives are met.\u0000 An Integrated Asset Model (IAM) (or an Integrated Production System Model) was built with the objective of providing a mathematical basis for meeting the field's objective. The IAM, combined with a Model Management and version control tool, a workflow orchestration and automation engine, A robust data-management module, an advanced visualization and collaboration environment and an analytics library and engine created the Oredo Digital Oil Field (DOF).\u0000 The Digital Oilfield is a real-time digital representation of a field on a computer which replicates the behavior of the field. This virtual field gives the engineer all the information required to make quick, sound and rational field management decisions with models, workflows, and intelligently filtered data within a multi-disciplinary organization of diverse capabilities and engineering skill sets.\u0000 The creation of the DOF involved 4 major steps;\u0000 DATA GATHERING considered as the most critical in such engineering projects as it helps to set the limits of what the model can achieve and cut expectations. ENGINEERING MODEL REVIEW, UPDATE AND BENCHMARKING; Majorly involved engineering models review and update, real-time data historian deployment etc. SYSTEM PRECONFIGURATION AND DEPLOYMENT; Developed the DOF system architecture and the engineering workflow setup. POST DEPLOYMENT REVIEW AND UPDATE; Currently ongoing till date, this involves after action reviews, updates and resolution of challenges of the DOF, capability development by the operator and optimizing the system for improved performance.\u0000 The DOF system in the Oredo field has made it possible to integrate, automate and streamline the execution of field management tasks and has significantly reduced the decision-making turnaround time. Operational and field management decisions can now be made within minutes rather than weeks or months. The gains and benefits cuts across the entire production value chain from improved operational safety to operational efficiency and cost savings, real-time production surveillance, optimized production, early problem detection, improved Safety, Organizational/Cross-discipline collaboration, data Centralization and Efficiency.\u0000 The DOF system did not come without its peculiar challenges observed both at the planning, execution and post evaluation stages which includes selection of an appropriate Data Gathering & acquisition system,\u0000 Parts interchangeability and device integration with existing field devices, high data latency","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"38 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89419470","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 ability to identify underperforming wells and recover the remaining oil in place is a cornerstone for effective reservoir management and field development strategies. As advancement in computing programming capabilities continuous to grow, Python has become an attractive method to build complicated statistical models that predicts, diagnose or analyze well performance, efficiently and accurately. The aim of this study is to develop a computational model that will allows us to diagnose and analyze well performance using nodal analysis with the help of python. In this study, python was used to compute Nodal analysis method using Darcy and Vogel Equations. A case study was carried out using the data obtained from a field operating in the Niger Delta. Again, sensitivity of tubing size was conducted using python. The results obtained showed that a computational model with python has the ability to visualize, model and analyze wells performances. This technique will petroleum engineers to better monitor evaluate and enhance their production operation without the need for expensive softwares. This will reduce operating cost increases revenue.
{"title":"A Computational Model for Wells’ Performance Analysis","authors":"Okon Edet Ita, D. Appah","doi":"10.2118/208249-ms","DOIUrl":"https://doi.org/10.2118/208249-ms","url":null,"abstract":"\u0000 The ability to identify underperforming wells and recover the remaining oil in place is a cornerstone for effective reservoir management and field development strategies. As advancement in computing programming capabilities continuous to grow, Python has become an attractive method to build complicated statistical models that predicts, diagnose or analyze well performance, efficiently and accurately. The aim of this study is to develop a computational model that will allows us to diagnose and analyze well performance using nodal analysis with the help of python. In this study, python was used to compute Nodal analysis method using Darcy and Vogel Equations. A case study was carried out using the data obtained from a field operating in the Niger Delta. Again, sensitivity of tubing size was conducted using python. The results obtained showed that a computational model with python has the ability to visualize, model and analyze wells performances. This technique will petroleum engineers to better monitor evaluate and enhance their production operation without the need for expensive softwares. This will reduce operating cost increases revenue.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82157919","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}
Carbon steel pipelines are used to transport hydrocarbons globally because carbon steel is relatively easier to fabricate, safe for use, raw materials are available and less expensive. Amidst these benefits, carbon steel is susceptible to severe corrosion and other anomalies. Pipeline corrosion is a significant concern in the oil and gas industry. It has caused several minor and catastrophic losses of containment with resultant fatalities, environmental pollutions, asset damage, and production downtimes. The increasing failures of in-service pipelines have led the Department of Petroleum Resources (DPR) to intensify regulatory scrutiny of pipeline integrity assessment and management in Nigeria to ensure strict compliance to the regulatory requirements by the Oil Producing Companies. According to DPR Act (Section 2.5.2.1), all pipelines greater than 6" size diameter must be inspected every five (5) years with intelligent pigs (inline inspection tools) that would provide the accurate condition of the pipeline. However, many pipelines in Nigeria are unpiggable or difficult to inspect with intelligent pigs due to the unavailability of pigging facilities (especially in brownfields), pipelines with short bend radiuses, dual diameters, flow parameters, etcetera. This paper explores case studies involving the use of advanced inline inspection technology to conduct inline inspection of difficult-to-inspect dual-diameter pipelines.
{"title":"Overcoming Challenges of Pigging the Unpiggable Pipelines","authors":"Chinedu Oragwu, D. Molyneux, L. Lawal, S. Ameh","doi":"10.2118/207147-ms","DOIUrl":"https://doi.org/10.2118/207147-ms","url":null,"abstract":"\u0000 Carbon steel pipelines are used to transport hydrocarbons globally because carbon steel is relatively easier to fabricate, safe for use, raw materials are available and less expensive. Amidst these benefits, carbon steel is susceptible to severe corrosion and other anomalies. Pipeline corrosion is a significant concern in the oil and gas industry. It has caused several minor and catastrophic losses of containment with resultant fatalities, environmental pollutions, asset damage, and production downtimes.\u0000 The increasing failures of in-service pipelines have led the Department of Petroleum Resources (DPR) to intensify regulatory scrutiny of pipeline integrity assessment and management in Nigeria to ensure strict compliance to the regulatory requirements by the Oil Producing Companies. According to DPR Act (Section 2.5.2.1), all pipelines greater than 6\" size diameter must be inspected every five (5) years with intelligent pigs (inline inspection tools) that would provide the accurate condition of the pipeline. However, many pipelines in Nigeria are unpiggable or difficult to inspect with intelligent pigs due to the unavailability of pigging facilities (especially in brownfields), pipelines with short bend radiuses, dual diameters, flow parameters, etcetera.\u0000 This paper explores case studies involving the use of advanced inline inspection technology to conduct inline inspection of difficult-to-inspect dual-diameter pipelines.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"5 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86340824","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}
Ifeanyichukwu Ofia, Esther Briggs, V. Longe, Ricky Iyengumwena, Dominic Wong
The results of computer simulations and laboratory tests have been applied at Porth field in Nigeria to achieve a successful perforation through a blast joint to access hydrocarbon behind pipe. Accessing hydrocarbons behind pipe in multizone completions can be difficult. The options are; an expensive rig-based workover or a cost-effective, rigless, through-tubing perforation. For a rigless through-tubing option, the detonated perforation charges must pass through a blast joint, the casing and the cement and then into the target reservoir. The major concern is usually whether there will be enough penetration {Burky 2018} into the target reservoir interval, given the layers of material resistance that the charges will have to overcome, starting at the blast joint. The Blast joint has a higher wall thickness and a larger outer diameter than that of the conventional tubing string to mitigate against erosion from producing the target interval behind pipe. The goal in perforation operations is achieving the maximum production while reducing perforation damage. {Jackson 2016}. Computer simulations and laboratory tests for a well at Porth field in Nigeria were carried out to determine the potential for successful perforation through a blast joint to access hydrocarbon behind pipe. Coupon tests using different gun sizes and charges where simulated and tested to ascertain the most effective option to achieve the desired reservoir penetration. Both computer simulations and laboratory test results showed that a reasonable depth of penetration into the target reservoir interval was possible to achieve. The perforation job using a 1.56-in., six-shots-per-foot (6 spf), 60° phasing gun was successfully carried out and the well has been tested to a potential of 780bbl/d at a tubing head pressure of 943psi and choke size 20/64th. This success lays the foundation for going after other similar opportunities locked in behind-pipe previously thought inaccessible owing to the presence of a blast joint across the target interval. Associated rig costs for a workover of up to $10 million can be saved on each opportunity using this approach.
{"title":"Successful Implementation of Blast Joint Perforation Technology in a Dual String Completion","authors":"Ifeanyichukwu Ofia, Esther Briggs, V. Longe, Ricky Iyengumwena, Dominic Wong","doi":"10.2118/207175-ms","DOIUrl":"https://doi.org/10.2118/207175-ms","url":null,"abstract":"\u0000 The results of computer simulations and laboratory tests have been applied at Porth field in Nigeria to achieve a successful perforation through a blast joint to access hydrocarbon behind pipe.\u0000 Accessing hydrocarbons behind pipe in multizone completions can be difficult. The options are; an expensive rig-based workover or a cost-effective, rigless, through-tubing perforation. For a rigless through-tubing option, the detonated perforation charges must pass through a blast joint, the casing and the cement and then into the target reservoir. The major concern is usually whether there will be enough penetration {Burky 2018} into the target reservoir interval, given the layers of material resistance that the charges will have to overcome, starting at the blast joint. The Blast joint has a higher wall thickness and a larger outer diameter than that of the conventional tubing string to mitigate against erosion from producing the target interval behind pipe. The goal in perforation operations is achieving the maximum production while reducing perforation damage. {Jackson 2016}.\u0000 Computer simulations and laboratory tests for a well at Porth field in Nigeria were carried out to determine the potential for successful perforation through a blast joint to access hydrocarbon behind pipe. Coupon tests using different gun sizes and charges where simulated and tested to ascertain the most effective option to achieve the desired reservoir penetration. Both computer simulations and laboratory test results showed that a reasonable depth of penetration into the target reservoir interval was possible to achieve. The perforation job using a 1.56-in., six-shots-per-foot (6 spf), 60° phasing gun was successfully carried out and the well has been tested to a potential of 780bbl/d at a tubing head pressure of 943psi and choke size 20/64th.\u0000 This success lays the foundation for going after other similar opportunities locked in behind-pipe previously thought inaccessible owing to the presence of a blast joint across the target interval. Associated rig costs for a workover of up to $10 million can be saved on each opportunity using this approach.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78772655","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 vital purpose of this research work is to examine the impacts of occupational health and safety management on employee's performance. It aims to investigate the nexus between the practice of OHS, safe working environment and performance of employees. The research work adopt a descriptive approach to scrutinize the contributions of provision of adequate health and safety equipment to performance of employees at Ardova Plc. Aside collecting primary data from the staffs of Ardova Plc in Lagos State cutting across diverse socio-economic class, simple random sampling was utilised in the study using 90 questionnaires to collect the primary data. However, descriptive data was therefore analyzed using Statistical Tool to show the Cross-tabulation, correlation and Chi-Square Test. The research study concludes that practice of occupational health and safety management can boost employee performance, and further suggest some policy recommendations.
{"title":"Occupational Health and Safety Management and Employees’ Performance in Ardova Plc","authors":"O. O. Olagunju, Ejekwu Pascal Andy","doi":"10.2118/207080-ms","DOIUrl":"https://doi.org/10.2118/207080-ms","url":null,"abstract":"The vital purpose of this research work is to examine the impacts of occupational health and safety management on employee's performance. It aims to investigate the nexus between the practice of OHS, safe working environment and performance of employees. The research work adopt a descriptive approach to scrutinize the contributions of provision of adequate health and safety equipment to performance of employees at Ardova Plc. Aside collecting primary data from the staffs of Ardova Plc in Lagos State cutting across diverse socio-economic class, simple random sampling was utilised in the study using 90 questionnaires to collect the primary data. However, descriptive data was therefore analyzed using Statistical Tool to show the Cross-tabulation, correlation and Chi-Square Test. The research study concludes that practice of occupational health and safety management can boost employee performance, and further suggest some policy recommendations.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"347 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77783259","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}
O. Nwankwo, Jennifer. S Muku, Oladipo G. Ogunbona, Chidi. B Ike, M. Amosa, Ebipador Ogionwo
The Offshore Safety Permit (OSP) Program is the Personnel Accountability System, being utilized by the Nigerian Oil and Gas Industry Regulator, in line with global best practices to manage the details of over 40,000 oil workers registered to work on offshore and swamp facilities and track their movements to-and-fro such facilities. The Program was introduced in 2012 to standardize requirement for personnel travel to offshore and swamp locations and to eliminate issues such as: non-compliance with mandatory competency and safety training; non-compliance with medical fitness to work requirement; unauthorized extended stay on facilities at offshore/remote location; inaccurate documentation of personnel movement to-and-fro facilities at offshore/remote location leading to delayed/wrong incident reporting. This paper examines, through the review of the OSP policy, Guidelines and database, the value addition of the program since its inception., detailed and insightful discussions are made on the importance and potentials of the OSP program as a simple but integral policy and planning tool in managing risks, enhancing collaboration and improving safety and emergency services in Nigeria's oil and gas industry.
{"title":"The Implementation of Offshore Safety Program OSP in Nigerian Oil and Gas Industry- A Performance Assessment","authors":"O. Nwankwo, Jennifer. S Muku, Oladipo G. Ogunbona, Chidi. B Ike, M. Amosa, Ebipador Ogionwo","doi":"10.2118/207121-ms","DOIUrl":"https://doi.org/10.2118/207121-ms","url":null,"abstract":"\u0000 The Offshore Safety Permit (OSP) Program is the Personnel Accountability System, being utilized by the Nigerian Oil and Gas Industry Regulator, in line with global best practices to manage the details of over 40,000 oil workers registered to work on offshore and swamp facilities and track their movements to-and-fro such facilities. The Program was introduced in 2012 to standardize requirement for personnel travel to offshore and swamp locations and to eliminate issues such as: non-compliance with mandatory competency and safety training; non-compliance with medical fitness to work requirement; unauthorized extended stay on facilities at offshore/remote location; inaccurate documentation of personnel movement to-and-fro facilities at offshore/remote location leading to delayed/wrong incident reporting. This paper examines, through the review of the OSP policy, Guidelines and database, the value addition of the program since its inception., detailed and insightful discussions are made on the importance and potentials of the OSP program as a simple but integral policy and planning tool in managing risks, enhancing collaboration and improving safety and emergency services in Nigeria's oil and gas industry.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"37 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89105016","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}
Clathrate hydrates are non-stoichiometric compounds of water and gas molecules coexisting at relatively low temperatures and high pressures. The gas molecules are trapped in cage-like structures of the water molecules by hydrogen bonds. There are several hydrate deposits in permafrost and oceanic sediments with an enormous amount of energy. The energy content of methane in hydrate reservoirs is considered to be up to 50 times that of conventional petroleum resources, with about 2,500 to 20,000 trillion m3 of methane gas. More than 220 hydrate deposits in permafrost and oceanic sediments have been identified to date. The exploration and production of these deposits to recover the trapped methane gas could overcome the world energy challenges and create a sustainable energy future. Furthermore, global warming is a major issue facing the world at large and it is caused by greenhouse gas emissions such as carbon dioxide. As a result, researchers and organizations have proposed various methods of reducing the emission of carbon dioxide gas. One of the proposed methods is the geological storage of carbon dioxide in depleted oil and gas reservoirs, oceanic sediments, deep saline aquifers, and depleted hydrate deposits. Studies have shown that there is the possibility of methane gas production and carbon dioxide storage in hydrate reservoirs using the injection of carbon dioxide and nitrogen gas mixture. However, the conventional hydrocarbon production methods cannot be used for the hydrate reservoirs due to the nature of these reservoirs. In addition, thermal stimulation and depressurization are not effective methods for methane gas production and carbon sequestration in hydrate-bearing sediments. Therefore, the gas replacement method for methane production and carbon dioxide storage in clathrate hydrate is investigated in this paper. The research studies (experiments, modeling/simulation, and field tests) on CO2/N2 gas mixture injection for the optimization of methane gas recovery in hydrate reservoirs are reviewed. It was discovered that the injection of the gas mixture enhanced the recovery process by replacing methane gas in the small and large cages of the hydrate. Also, the presence of N2 molecules significantly increased fluid injectivity and methane recovery rate. In addition, a significant amount of free water was not released and the hydrate phase was stable during the replacement process. It is an effective method for permanent storage of carbon dioxide in the hydrate layer. However, further research studies on the effects of gas composition, particle size, and gas transport on the replacement process and swapping rate are required.
{"title":"A Comprehensive Review on CO2/N2 Mixture Injection for Methane Gas Recovery in Hydrate Reservoirs","authors":"Azeez G. Aregbe, Ayoola Idris Fadeyi","doi":"10.2118/207092-ms","DOIUrl":"https://doi.org/10.2118/207092-ms","url":null,"abstract":"\u0000 Clathrate hydrates are non-stoichiometric compounds of water and gas molecules coexisting at relatively low temperatures and high pressures. The gas molecules are trapped in cage-like structures of the water molecules by hydrogen bonds. There are several hydrate deposits in permafrost and oceanic sediments with an enormous amount of energy. The energy content of methane in hydrate reservoirs is considered to be up to 50 times that of conventional petroleum resources, with about 2,500 to 20,000 trillion m3 of methane gas. More than 220 hydrate deposits in permafrost and oceanic sediments have been identified to date.\u0000 The exploration and production of these deposits to recover the trapped methane gas could overcome the world energy challenges and create a sustainable energy future. Furthermore, global warming is a major issue facing the world at large and it is caused by greenhouse gas emissions such as carbon dioxide. As a result, researchers and organizations have proposed various methods of reducing the emission of carbon dioxide gas. One of the proposed methods is the geological storage of carbon dioxide in depleted oil and gas reservoirs, oceanic sediments, deep saline aquifers, and depleted hydrate deposits. Studies have shown that there is the possibility of methane gas production and carbon dioxide storage in hydrate reservoirs using the injection of carbon dioxide and nitrogen gas mixture. However, the conventional hydrocarbon production methods cannot be used for the hydrate reservoirs due to the nature of these reservoirs. In addition, thermal stimulation and depressurization are not effective methods for methane gas production and carbon sequestration in hydrate-bearing sediments.\u0000 Therefore, the gas replacement method for methane production and carbon dioxide storage in clathrate hydrate is investigated in this paper. The research studies (experiments, modeling/simulation, and field tests) on CO2/N2 gas mixture injection for the optimization of methane gas recovery in hydrate reservoirs are reviewed. It was discovered that the injection of the gas mixture enhanced the recovery process by replacing methane gas in the small and large cages of the hydrate. Also, the presence of N2 molecules significantly increased fluid injectivity and methane recovery rate. In addition, a significant amount of free water was not released and the hydrate phase was stable during the replacement process. It is an effective method for permanent storage of carbon dioxide in the hydrate layer. However, further research studies on the effects of gas composition, particle size, and gas transport on the replacement process and swapping rate are required.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86940210","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 dynamics of tracer particles in a viscous Newtonian fluid is studied analytically and numerically through channels of varying thickness for fluids undergoing creeping flow. Exact analytical solutions of mass conservation equations of tracer particles including consideration for pressure forces are obtained. Results of the analysis indicates that Stokes velocity is an indispensable parameter and is dependent on parameters such as channel thickness (height), viscosity of the fluid, pressure gradient driven the fluid and Reynolds number corresponding to the channel thickness. The accuracy of the solution obtained is verified by comparing its velocity profiles with those obtained from finite-element-based numerical simulation studies.
{"title":"Velocity Dependence and Tracer Dispersion in Newtonian Fluids Undergoing Creeping Flow","authors":"I. Ayuba, T. L. Akanji, J. Gomes","doi":"10.2118/208251-ms","DOIUrl":"https://doi.org/10.2118/208251-ms","url":null,"abstract":"\u0000 The dynamics of tracer particles in a viscous Newtonian fluid is studied analytically and numerically through channels of varying thickness for fluids undergoing creeping flow. Exact analytical solutions of mass conservation equations of tracer particles including consideration for pressure forces are obtained. Results of the analysis indicates that Stokes velocity is an indispensable parameter and is dependent on parameters such as channel thickness (height), viscosity of the fluid, pressure gradient driven the fluid and Reynolds number corresponding to the channel thickness. The accuracy of the solution obtained is verified by comparing its velocity profiles with those obtained from finite-element-based numerical simulation studies.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"15 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82311170","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}
In an era where cost is a significant component of decision making, every possibility of reducing operational cost in the Oil and Gas industry is a welcome development. The volatile nature of the Oil market creates uncertainty in the industry. One way to manage this uncertainty is by the ability to predict and optimize our operations to reduce all of our cost elements. When cost is planned and predicted as accurately as possible, the operation optimizations can be managed efficiently. Practically, all new drills require CT unloading of the completion or kill fluids to allow the natural flow of the wells. Hitherto, there is no mathematical model that combines information from one of the wells in an unloading dual completion project that can be used to aid decision-making in the other well for the same unloading project and thereby result in an effective cost-saving. Deploying the mathematical model of cost element prediction and optimization can minimize operational unloading costs. The two strings of the dual completion flow from different reservoirs. Still, the link between the two drainages post completion is the kill fluid density, and can aid in cost estimation for optimum benefit. The lesson learned or data acquired from the lifting of the slave reservoir string can be optimized to effectively and efficiently lift the master reservoir string. The decision of first unloading the slave reservoir string is critical for correct prediction and optimization of the ultimate cost. The mathematical model was able to predict the consumable cost elements such as the gallon of nitrogen and time that may be spent on the long string from the correlative analysis of the short string. The more energy is required for unloading the short string and it is the more critical well than the long string because it is the slave string since no consideration as such is given to it when beneficiating the kill fluid to target the long string reservoir pressure with a certain safety overbalance. The rule for the mud weight or the weight of the kill fluid is the highest depth with highest reservoir pressure which is the sand on the long string. With the data from the short string and upper sand reservoir, the lift depth and unloading operation can be optimized to save cost. The short string will incur the higher cost and as such should be lifted last and the optimization can be done with the factor of the LS.
{"title":"Cost Element Modelling, Prediction and Optimization in a Dual-Completion Well During a Coiled Tubing Unloading Operation","authors":"M. P. Ekeregbe","doi":"10.2118/207113-ms","DOIUrl":"https://doi.org/10.2118/207113-ms","url":null,"abstract":"\u0000 In an era where cost is a significant component of decision making, every possibility of reducing operational cost in the Oil and Gas industry is a welcome development. The volatile nature of the Oil market creates uncertainty in the industry. One way to manage this uncertainty is by the ability to predict and optimize our operations to reduce all of our cost elements. When cost is planned and predicted as accurately as possible, the operation optimizations can be managed efficiently.\u0000 Practically, all new drills require CT unloading of the completion or kill fluids to allow the natural flow of the wells. Hitherto, there is no mathematical model that combines information from one of the wells in an unloading dual completion project that can be used to aid decision-making in the other well for the same unloading project and thereby result in an effective cost-saving. Deploying the mathematical model of cost element prediction and optimization can minimize operational unloading costs. The two strings of the dual completion flow from different reservoirs. Still, the link between the two drainages post completion is the kill fluid density, and can aid in cost estimation for optimum benefit. The lesson learned or data acquired from the lifting of the slave reservoir string can be optimized to effectively and efficiently lift the master reservoir string. The decision of first unloading the slave reservoir string is critical for correct prediction and optimization of the ultimate cost.\u0000 The mathematical model was able to predict the consumable cost elements such as the gallon of nitrogen and time that may be spent on the long string from the correlative analysis of the short string. The more energy is required for unloading the short string and it is the more critical well than the long string because it is the slave string since no consideration as such is given to it when beneficiating the kill fluid to target the long string reservoir pressure with a certain safety overbalance. The rule for the mud weight or the weight of the kill fluid is the highest depth with highest reservoir pressure which is the sand on the long string.\u0000 With the data from the short string and upper sand reservoir, the lift depth and unloading operation can be optimized to save cost. The short string will incur the higher cost and as such should be lifted last and the optimization can be done with the factor of the LS.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"14 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86400396","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}
Faster and more accurate decisions are what the Oil and Gas industry needs with the world's fast-evolving energy needs and economy. The area of Artificial intelligence and Data-driven modelling is relatively new and has not found popular application in the industry. AI is an emerging technology that can be used to predict event outcomes and automate anomaly-detection processes. The various applications of AI in different industries were researched into. This paper highlighted important processes that can be improved with the application of Artificial Intelligence through data-driven modelling. It also highlights areas in the various industries where AI intelligence is already being applied and ways it can be improved. AI and data-driven modelling has the potential to improve exploration accuracy, reduce production down-time, reduce cost of maintenance, and reduce health and safety risks. This body of information can serve as a guideline for adopting AI in the oil and gas industry. A trend of industry-tailored intelligence solutions would be more effective in the evolving energy industry.
{"title":"Applications of AI and Data-Driven Modeling in Energy Production and Marketing Processes","authors":"J. Ugoyah, Anita Igbine","doi":"10.2118/207153-ms","DOIUrl":"https://doi.org/10.2118/207153-ms","url":null,"abstract":"\u0000 Faster and more accurate decisions are what the Oil and Gas industry needs with the world's fast-evolving energy needs and economy. The area of Artificial intelligence and Data-driven modelling is relatively new and has not found popular application in the industry. AI is an emerging technology that can be used to predict event outcomes and automate anomaly-detection processes.\u0000 The various applications of AI in different industries were researched into. This paper highlighted important processes that can be improved with the application of Artificial Intelligence through data-driven modelling. It also highlights areas in the various industries where AI intelligence is already being applied and ways it can be improved.\u0000 AI and data-driven modelling has the potential to improve exploration accuracy, reduce production down-time, reduce cost of maintenance, and reduce health and safety risks.\u0000 This body of information can serve as a guideline for adopting AI in the oil and gas industry. A trend of industry-tailored intelligence solutions would be more effective in the evolving energy industry.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"17 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74993131","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：