Papers by Fernando Ledesma Solaeche
Day 3 Tue, October 17, 2017, 2017
The GC-01 KwIDF system has been deployed in the East Kuwait area of Burgan oil field and includes... more The GC-01 KwIDF system has been deployed in the East Kuwait area of Burgan oil field and includes real time production surveillance instrumentation for wells and production facility. The raw data from the wells and facility is integrated with well and network models in an automated workflow process for surveillance and analysis of the GC-01 production. The Burgan oil field integrated digital field (KwIDF) automation system utilizes wellhead pressure and water-cut measurements for automated calibration of well and surface network models. The KwIDF system workflow utilizes calibrated well models and real time data to identify changes in GC-01 daily production and reconciles it with the contributing wells. The workflow identifies wells with production changes and associates them with key well and facility parameters for instant diagnosis and analysis of daily production issues. This paper describes the application of real time data and integrated models in an automated workflow for qui...
Abu Dhabi International Petroleum Exhibition & Conference, 2017
Kuwait Oil Company started implementing digital oil field technology in 2009, with a vision to ac... more Kuwait Oil Company started implementing digital oil field technology in 2009, with a vision to achieve integrated operations for measurement, modeling and control of Burgan oil field production. The project involved development of automated workflows connecting real-time data and integrated production models for analyzing asset performance and identifying production optimization opportunities. The workflow calculates variance in daily field production and correlates it to the corresponding well production change alerts attributed to key changes in well and facility parameters. Well health status is determined using key performance parameters and subsequently wells are categorized for planning remedial actions. The workflow further utilizes the integrated surface network model in an automated process to generate production optimization opportunities under various well and plant operating limits and the results are visualized through interactive dashboards in a state-of-the-art collab...
Day 3 Wed, November 15, 2017, 2017
Instrumentation of artificially lifted wells located North, South-East and West of Kuwait was an ... more Instrumentation of artificially lifted wells located North, South-East and West of Kuwait was an essential requirement for real time surveillance of well behavior, and for successful implementation of a digital oil field. The manuscript focuses on challenges and solutions accompanied with setup of a SCADA intelligent software suite and replication configurations applied to remotely monitor and control assets for production optimization purposes. Meetings have been held with Information Technology, SCADA and Well-Surveillance teams to agree on the technical requirements (server's specifications, network diagrams, well connectivity, data road map, data backup, security measures, disaster backup plan, etc…) The availability of having remote terminal unit built-in in the variable speed drive allowed instant access of real time data with ability to remotely control and modify running parameters for artificially lifted wells. Infrastructure has been built based on the company's st...
Using Real-Time Data and Integrated Models to Diagnose Scale Problems and Improve Pump Performance, 2019
The Kuwait Integrated Digital Field project for Gathering-Center 01 (KwIDF GC-01) at Burgan Field... more The Kuwait Integrated Digital Field project for Gathering-Center 01 (KwIDF GC-01) at Burgan Field acquires real-time data from wells and processing facilities as input for its production-surveillance program. Live data from the field is fed into an integrated production model for analyzing and optimizing pump performance. An automated workflow process generates alarms for critical well and facility parameters to identify wells with potential scaling issues. KwIDF workflows are integrated with updated well models to visualize the effect of scale build up on the wellhead performance and thereby assist in quantifying the associated production losses caused by scale deposition. A sensitivity analysis is also performed to identify current and optimal pump operating conditions and prioritize scale cleaning jobs.
The exception-based surveillance of key real-time parameters for wells utilizing electrical submersible pumps (ESPs) in Burgan field has significantly improved diagnostics of scale deposition at wellhead chokes and flowlines. Automated workflows calibrate an integrated production model in real-time, which enables engineers to run a quick analysis of current pump operating conditions and make a proactive plan of action. The application of real-time data and automated models has aided the operator's production team in making informed and timely decisions that enable them to run pumps at optimal operating conditions, with the result that they are able to sustain well production at target levels.
This paper describes an innovative approach to applying real-time data and integrated models in an automated workflow process for enhancing capabilities to diagnose scale deposition in the surface flow network. Examples are presented to demonstrate the application of integrated technology for identifying scaling at wellhead chokes and flowlines and prioritizing a scale removal program for optimizing pump performance.
Integrated Analysis and Optimization for Progressing Cavity Pump Systems in Greater Burgan Field, 2018
Progressing cavity pump (PCP) systems are widely used in the oil and gas industry. Continuously e... more Progressing cavity pump (PCP) systems are widely used in the oil and gas industry. Continuously evaluating PCP performance helps to maximize and sustain fluid production and increase pump run-life. This paper focuses on integrating a real-time platform and advanced software to model, troubleshoot, and optimize PCP systems and their operation.
More than 50% of installed PCP systems located in Great Burgan Field in southeast Kuwait are connected to a real-time SCADA platform. These connected systems are monitored to support daily operations and to identify underperforming wells for troubleshooting. Special attention is given to wells exhibiting critical behaviors or wells with optimization opportunities. Before implementing any actions on these wells, real-time data history is used along with nodal analysis to predict the outcomes. This paper presents an intensive optimization analysis through the following field case studies:
Preventing sucker rod string failure
Evaluating pump submergence
Optimizing fluid production
Identifying optimum operating conditions
Software is used to perform simulations of flow under different operating conditions and to generate a full analysis report based on PCP equipment configured in the well model. The sharp-edge results are not limited to the production rate. They also extend to pump performance and other surface and downhole parameters such as pump torque, intake pressure, and discharge pressure. The outcome of these results assists with making well-informed decisions with the following benefits:
Operating conditions have been improved by estimating the production rate at different speeds.
Pump life has been improved by evaluating rod load, lift load, and efficiency.
Down-time has been reduced by preventing pump-off conditions.
The procedure serves as a proven guide for analysis and optimization of PCP systems. Improving pump efficiency, achieving the target production rate, identifying problems, and preventing potential failures all help to optimize PCP system performance.
The innovative integration of PCP analysis and optimization provides a means to increase production and reduce the load percentage of surface and subsurface equipment parameters. A real-time SCADA platform combined with the optimization software created an ideal solution to keep wells operating at peak performance levels.
Smart Workflows for Well and Facility Surveillance and Optimization: A Burgan Oil Field Experience, 2017
Kuwait Oil Company started implementing digital oil field technology in 2009, with a vision to ac... more Kuwait Oil Company started implementing digital oil field technology in 2009, with a vision to achieve integrated operations for measurement, modeling and control of Burgan oil field production. The project involved development of automated workflows connecting real-time data and integrated production models for analyzing asset performance and identifying production optimization opportunities. The workflow calculates variance in daily field production and correlates it to the corresponding well production change alerts attributed to key changes in well and facility parameters. Well health status is determined using key performance parameters and subsequently wells are categorized for planning remedial actions. The workflow further utilizes the integrated surface network model in an automated process to generate production optimization opportunities under various well and plant operating limits and the results are visualized through interactive dashboards in a state-of-the-art collaboration center for quick analysis.
This paper discusses the application of smart workflows for analyzing asset performance and recommending production optimization actions in Burgan oil field. It describes how smart workflows are used to integrate real-time well and facility data with production models to assist the operator in faster diagnostics and improved decision making.
The paper demonstrates through field examples how the application of an automated workflow using real-time data and integrated models has improved the conventional approach for asset performance analysis and optimization resulting in significant cost savings for the operator.
Integrated Deployment of Digital Oil Field in Multiple Kuwait Areas in One Platform and Benefits Realized, 2017
Instrumentation of artificially lifted wells located North, South-East and West of Kuwait was an ... more Instrumentation of artificially lifted wells located North, South-East and West of Kuwait was an essential requirement for real time surveillance of well behavior, and for successful implementation of a digital oil field. The manuscript focuses on challenges and solutions accompanied with setup of a SCADA intelligent software suite and replication configurations applied to remotely monitor and control assets for production optimization purposes.
Meetings have been held with Information Technology, SCADA and Well-Surveillance teams to agree on the technical requirements (server's specifications, network diagrams, well connectivity, data road map, data backup, security measures, disaster backup plan, etc…) The availability of having remote terminal unit built-in in the variable speed drive allowed instant access of real time data with ability to remotely control and modify running parameters for artificially lifted wells. Infrastructure has been built based on the company's standard IT security policies, by segregating network levels from field to domain network.
Well surveillance and field development teams from different areas targeted specific wells to be connected to the smart surveillance solution. Lining up different teams at the same time was a challenge to test, configure and confirm the successful connectivity. Integrating data from different areas/servers in one secure location was our main challenge to overcome. Replication of data was the only solution to assure a security channel that communicates between the different fields in to a single secured location with very limited ports to open and supervise. Wells were fully instrumented and equipped with the required gauges, sensors, and emergency shutdown devices, to evaluate well performance instantly.
Web based setup was the best solution for replicating real time data to the corporate level while keeping it secured and separated from the field network and available for all users accessible through end user system portal. Software acting as a real time data surveillance and historian with the remote access capability created a new level of effective surveillance. Management by exception became available at the corporate level to run failure statistics and identify areas for improvements by utilizing the current setup to optimize production and extend life time of equipment.
Achieving this level of surveillance helped in closely monitoring of well behavior, securely transferring and storing data, identifying operational needs of each field, and was considered as an extra level of surveillance. Successful deployment of the digital oil field in all areas of Kuwait integrated in one secured platform helped in utilizing all equipment available, increasing engineers' effectiveness to improve productivity, increase wells production, meet QHSE (quality, health, safety and environment) standards and reduce human risk.
Real Time Intelligent Alarm and Surveillance System in Heavy Oil Project- North Kuwait Illustrated Through Case Examples, 2017
Instrumentation of sucker-rod pumping systems in a large scale thermal pilot was an essential req... more Instrumentation of sucker-rod pumping systems in a large scale thermal pilot was an essential requirement for steam-injection projects. The manuscript focuses on the setup of a real-time smart alarming suite, and the benefits realized in terms of identifying surface and downhole equipment issues and wells requiring critical actions.
Two levels of alarms have been set after reviewing well performance with well-surveillance and field-development teams using real time data gathered through a SCADA system for each parameter for each well individually. The capability in the real-time smart alarming system to set both warning and critical alarm criteria for minimum and maximum values allowed deeper supervision of abnormal conditions, highlighting assets in need of preventive actions. The pre-configured controller alarms have been integrated with software smart alarms to be available in one screen in real time, to immediately take the necessary actions.
The alarm system identified wells with:
Surface equipment problems related to load cell and position sensor issues
Down hole equipment issues related to standing and travelling leaks
Surface network issues related to flow line pressure increases due to back pressure
The presence of such an alarm system prevented major issues that sucker rod pump systems typically experience in terms of high load exerted on the gearbox, high stress applied on rods/sinker bars, and forces applied on surface unit structure. The implementation of such a preventive approach reduced the amount of well trips and downtime, avoiding unwanted incidents, reducing the response action time and unnecessary workover costs
Setting limits for essential parameters that are being reviewed in a fixed period helped in identifying wells far from critical zones to be addressed as candidates for further investigation for production/asset optimization. The real-time intelligent alarming and smart notification system is considered the backbone for production optimization and asset management in the oil and gas industry.
Achieving such a level of effective surveillance/alarming allowed better asset management, prevented equipment failures, prolonged equipment life time, and reduced unnecessary costs. Successful deployment of the smart field approach in the North Large Scale Thermal Pilot for sucker rod lifted pumps helped in utilizing the performance of the equipment, increased oil production and assured smooth operational activities.
Application of Real-Time Data and Integrated Models in an Automated Workflow for Production Surveillance and Analysis in Burgan Oil Field, 2017
The GC-01 KwIDF system has been deployed in the East Kuwait area of Burgan oil field and includes... more The GC-01 KwIDF system has been deployed in the East Kuwait area of Burgan oil field and includes real time production surveillance instrumentation for wells and production facility. The raw data from the wells and facility is integrated with well and network models in an automated workflow process for surveillance and analysis of the GC-01 production.
The Burgan oil field integrated digital field (KwIDF) automation system utilizes wellhead pressure and water-cut measurements for automated calibration of well and surface network models. The KwIDF system workflow utilizes calibrated well models and real time data to identify changes in GC-01 daily production and reconciles it with the contributing wells. The workflow identifies wells with production changes and associates them with key well and facility parameters for instant diagnosis and analysis of daily production issues.
This paper describes the application of real time data and integrated models in an automated workflow for quick identification and analysis of daily field production.
Examples describe how the workflow has been used in quick analysis and decision making to optimize daily production and achieve sustainable targets in one of the production facilities of the Greater Burgan Field in Kuwait.
Installation of a Sucker Rod Pumping System Over a Failed Progressive Cavity Pump to Recover Production Using Rigless Intervention - Burgan Field - South East Kuwait, 2017
The current competitive market conditions in the oil industry and company’s shoestring budgets ca... more The current competitive market conditions in the oil industry and company’s shoestring budgets call for methods to recover crude from wells with minimum costs. This paper focuses on the design, rigless installation, and successful results of a sucker rod pump (SRP) system after the failure of the existing progressive cavity pump (PCP).
The subject well had a PCP at 4,248.05 ft. setting depth failed after 60 days due to a broken rotor. Attempts to fish the parted rotor were unsuccessful. To avoid a workover rig and to reduce non-productive time (NPT), a SRP system with an insert pump anchor was set over the failed PCP system at 4,028 ft. via a flush by unit. A tubing punch job from 4,085 to 4,145 ft. was done for allowing the fluid entering the tubing and passing through the SRP system.
Running a SRP with an insert pump anchor enabled the pump to be set at any depth inside the tubing, above the failed PCP system. Successful installation of the SRP system reduced NPT and standby costs, and eliminated the need for a workover rig. While running the SRP system, the production enhanced by 50% more than the PCP’s maximum recorded rate. On the other hand, the pump can be retrieved and/or the artificial lift method can be converted later on without the requirement of a workover rig.
In Burgan field, Kuwait, the first rigless installation of a sucker rod pump over a failed progressive cavity pump has turned into the reference for methods of how to recover oil when other artificial-lift systems fail.
Conference Presentations by Fernando Ledesma Solaeche
Using Real-Time Data and Integrated Models to Diagnose Scale Problems and Improve Pump Performance, 2019
The Kuwait Integrated Digital Field project for Gathering-Center 01 (KwIDF GC-01) at Burgan Field... more The Kuwait Integrated Digital Field project for Gathering-Center 01 (KwIDF GC-01) at Burgan Field acquires real-time data from wells and processing facilities as input for its production-surveillance program. Live data from the field is fed into an integrated production model for analyzing and optimizing pump performance. An automated workflow process generates alarms for critical well and facility parameters to identify wells with potential scaling issues. KwIDF workflows are integrated with updated well models to visualize the effect of scale build up on the wellhead performance and thereby assist in quantifying the associated production losses caused by scale deposition. A sensitivity analysis is also performed to identify current and optimal pump operating conditions and prioritize scale cleaning jobs.
The exception-based surveillance of key real-time parameters for wells utilizing electrical submersible pumps (ESPs) in Burgan field has significantly improved diagnostics of scale deposition at wellhead chokes and flowlines. Automated workflows calibrate an integrated production model in real-time, which enables engineers to run a quick analysis of current pump operating conditions and make a proactive plan of action. The application of real-time data and automated models has aided the operator's production team in making informed and timely decisions that enable them to run pumps at optimal operating conditions, with the result that they are able to sustain well production at target levels.
This paper describes an innovative approach to applying real-time data and integrated models in an automated workflow process for enhancing capabilities to diagnose scale deposition in the surface flow network. Examples are presented to demonstrate the application of integrated technology for identifying scaling at wellhead chokes and flowlines and prioritizing a scale removal program for optimizing pump performance.
Integrated Analysis and Optimization for Progressing Cavity Pump Systems in Greater Burgan Field, 2018
Progressing cavity pump (PCP) systems are widely used in the oil and gas industry. Continuously e... more Progressing cavity pump (PCP) systems are widely used in the oil and gas industry. Continuously evaluating PCP performance helps to maximize and sustain fluid production and increase pump run-life. This paper focuses on integrating a real-time platform and advanced software to model, troubleshoot, and optimize PCP systems and their operation.
More than 50% of installed PCP systems located in Great Burgan Field in southeast Kuwait are connected to a real-time SCADA platform. These connected systems are monitored to support daily operations and to identify underperforming wells for troubleshooting. Special attention is given to wells exhibiting critical behaviors or wells with optimization opportunities. Before implementing any actions on these wells, real-time data history is used along with nodal analysis to predict the outcomes. This paper presents an intensive optimization analysis through the following field case studies:
Preventing sucker rod string failure
Evaluating pump submergence
Optimizing fluid production
Identifying optimum operating conditions
Software is used to perform simulations of flow under different operating conditions and to generate a full analysis report based on PCP equipment configured in the well model. The sharp-edge results are not limited to the production rate. They also extend to pump performance and other surface and downhole parameters such as pump torque, intake pressure, and discharge pressure. The outcome of these results assists with making well-informed decisions with the following benefits:
Operating conditions have been improved by estimating the production rate at different speeds.
Pump life has been improved by evaluating rod load, lift load, and efficiency.
Down-time has been reduced by preventing pump-off conditions.
The procedure serves as a proven guide for analysis and optimization of PCP systems. Improving pump efficiency, achieving the target production rate, identifying problems, and preventing potential failures all help to optimize PCP system performance.
The innovative integration of PCP analysis and optimization provides a means to increase production and reduce the load percentage of surface and subsurface equipment parameters. A real-time SCADA platform combined with the optimization software created an ideal solution to keep wells operating at peak performance levels.
Installation of a Sucker Rod Pumping System Over a Failed Progressive Cavity Pump to Recover Production Using Rigless Intervention - Burgan Field - South East Kuwait, 2017
The current competitive market conditions in the oil industry and company’s shoestring budgets ca... more The current competitive market conditions in the oil industry and company’s shoestring budgets call for methods to recover crude from wells with minimum costs. This paper focuses on the design, rigless installation, and successful results of a sucker rod pump (SRP) system after the failure of the existing progressive cavity pump (PCP).
The subject well had a PCP at 4,248.05 ft. setting depth failed after 60 days due to a broken rotor. Attempts to fish the parted rotor were unsuccessful. To avoid a workover rig and to reduce non-productive time (NPT), a SRP system with an insert pump anchor was set over the failed PCP system at 4,028 ft. via a flush by unit. A tubing punch job from 4,085 to 4,145 ft. was done for allowing the fluid entering the tubing and passing through the SRP system.
Running a SRP with an insert pump anchor enabled the pump to be set at any depth inside the tubing, above the failed PCP system. Successful installation of the SRP system reduced NPT and standby costs, and eliminated the need for a workover rig. While running the SRP system, the production enhanced by 50% more than the PCP’s maximum recorded rate. On the other hand, the pump can be retrieved and/or the artificial lift method can be converted later on without the requirement of a workover rig.
In Burgan field, Kuwait, the first rigless installation of a sucker rod pump over a failed progressive cavity pump has turned into the reference for methods of how to recover oil when other artificial-lift systems fail.
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Papers by Fernando Ledesma Solaeche
The exception-based surveillance of key real-time parameters for wells utilizing electrical submersible pumps (ESPs) in Burgan field has significantly improved diagnostics of scale deposition at wellhead chokes and flowlines. Automated workflows calibrate an integrated production model in real-time, which enables engineers to run a quick analysis of current pump operating conditions and make a proactive plan of action. The application of real-time data and automated models has aided the operator's production team in making informed and timely decisions that enable them to run pumps at optimal operating conditions, with the result that they are able to sustain well production at target levels.
This paper describes an innovative approach to applying real-time data and integrated models in an automated workflow process for enhancing capabilities to diagnose scale deposition in the surface flow network. Examples are presented to demonstrate the application of integrated technology for identifying scaling at wellhead chokes and flowlines and prioritizing a scale removal program for optimizing pump performance.
More than 50% of installed PCP systems located in Great Burgan Field in southeast Kuwait are connected to a real-time SCADA platform. These connected systems are monitored to support daily operations and to identify underperforming wells for troubleshooting. Special attention is given to wells exhibiting critical behaviors or wells with optimization opportunities. Before implementing any actions on these wells, real-time data history is used along with nodal analysis to predict the outcomes. This paper presents an intensive optimization analysis through the following field case studies:
Preventing sucker rod string failure
Evaluating pump submergence
Optimizing fluid production
Identifying optimum operating conditions
Software is used to perform simulations of flow under different operating conditions and to generate a full analysis report based on PCP equipment configured in the well model. The sharp-edge results are not limited to the production rate. They also extend to pump performance and other surface and downhole parameters such as pump torque, intake pressure, and discharge pressure. The outcome of these results assists with making well-informed decisions with the following benefits:
Operating conditions have been improved by estimating the production rate at different speeds.
Pump life has been improved by evaluating rod load, lift load, and efficiency.
Down-time has been reduced by preventing pump-off conditions.
The procedure serves as a proven guide for analysis and optimization of PCP systems. Improving pump efficiency, achieving the target production rate, identifying problems, and preventing potential failures all help to optimize PCP system performance.
The innovative integration of PCP analysis and optimization provides a means to increase production and reduce the load percentage of surface and subsurface equipment parameters. A real-time SCADA platform combined with the optimization software created an ideal solution to keep wells operating at peak performance levels.
This paper discusses the application of smart workflows for analyzing asset performance and recommending production optimization actions in Burgan oil field. It describes how smart workflows are used to integrate real-time well and facility data with production models to assist the operator in faster diagnostics and improved decision making.
The paper demonstrates through field examples how the application of an automated workflow using real-time data and integrated models has improved the conventional approach for asset performance analysis and optimization resulting in significant cost savings for the operator.
Meetings have been held with Information Technology, SCADA and Well-Surveillance teams to agree on the technical requirements (server's specifications, network diagrams, well connectivity, data road map, data backup, security measures, disaster backup plan, etc…) The availability of having remote terminal unit built-in in the variable speed drive allowed instant access of real time data with ability to remotely control and modify running parameters for artificially lifted wells. Infrastructure has been built based on the company's standard IT security policies, by segregating network levels from field to domain network.
Well surveillance and field development teams from different areas targeted specific wells to be connected to the smart surveillance solution. Lining up different teams at the same time was a challenge to test, configure and confirm the successful connectivity. Integrating data from different areas/servers in one secure location was our main challenge to overcome. Replication of data was the only solution to assure a security channel that communicates between the different fields in to a single secured location with very limited ports to open and supervise. Wells were fully instrumented and equipped with the required gauges, sensors, and emergency shutdown devices, to evaluate well performance instantly.
Web based setup was the best solution for replicating real time data to the corporate level while keeping it secured and separated from the field network and available for all users accessible through end user system portal. Software acting as a real time data surveillance and historian with the remote access capability created a new level of effective surveillance. Management by exception became available at the corporate level to run failure statistics and identify areas for improvements by utilizing the current setup to optimize production and extend life time of equipment.
Achieving this level of surveillance helped in closely monitoring of well behavior, securely transferring and storing data, identifying operational needs of each field, and was considered as an extra level of surveillance. Successful deployment of the digital oil field in all areas of Kuwait integrated in one secured platform helped in utilizing all equipment available, increasing engineers' effectiveness to improve productivity, increase wells production, meet QHSE (quality, health, safety and environment) standards and reduce human risk.
Two levels of alarms have been set after reviewing well performance with well-surveillance and field-development teams using real time data gathered through a SCADA system for each parameter for each well individually. The capability in the real-time smart alarming system to set both warning and critical alarm criteria for minimum and maximum values allowed deeper supervision of abnormal conditions, highlighting assets in need of preventive actions. The pre-configured controller alarms have been integrated with software smart alarms to be available in one screen in real time, to immediately take the necessary actions.
The alarm system identified wells with:
Surface equipment problems related to load cell and position sensor issues
Down hole equipment issues related to standing and travelling leaks
Surface network issues related to flow line pressure increases due to back pressure
The presence of such an alarm system prevented major issues that sucker rod pump systems typically experience in terms of high load exerted on the gearbox, high stress applied on rods/sinker bars, and forces applied on surface unit structure. The implementation of such a preventive approach reduced the amount of well trips and downtime, avoiding unwanted incidents, reducing the response action time and unnecessary workover costs
Setting limits for essential parameters that are being reviewed in a fixed period helped in identifying wells far from critical zones to be addressed as candidates for further investigation for production/asset optimization. The real-time intelligent alarming and smart notification system is considered the backbone for production optimization and asset management in the oil and gas industry.
Achieving such a level of effective surveillance/alarming allowed better asset management, prevented equipment failures, prolonged equipment life time, and reduced unnecessary costs. Successful deployment of the smart field approach in the North Large Scale Thermal Pilot for sucker rod lifted pumps helped in utilizing the performance of the equipment, increased oil production and assured smooth operational activities.
The Burgan oil field integrated digital field (KwIDF) automation system utilizes wellhead pressure and water-cut measurements for automated calibration of well and surface network models. The KwIDF system workflow utilizes calibrated well models and real time data to identify changes in GC-01 daily production and reconciles it with the contributing wells. The workflow identifies wells with production changes and associates them with key well and facility parameters for instant diagnosis and analysis of daily production issues.
This paper describes the application of real time data and integrated models in an automated workflow for quick identification and analysis of daily field production.
Examples describe how the workflow has been used in quick analysis and decision making to optimize daily production and achieve sustainable targets in one of the production facilities of the Greater Burgan Field in Kuwait.
The subject well had a PCP at 4,248.05 ft. setting depth failed after 60 days due to a broken rotor. Attempts to fish the parted rotor were unsuccessful. To avoid a workover rig and to reduce non-productive time (NPT), a SRP system with an insert pump anchor was set over the failed PCP system at 4,028 ft. via a flush by unit. A tubing punch job from 4,085 to 4,145 ft. was done for allowing the fluid entering the tubing and passing through the SRP system.
Running a SRP with an insert pump anchor enabled the pump to be set at any depth inside the tubing, above the failed PCP system. Successful installation of the SRP system reduced NPT and standby costs, and eliminated the need for a workover rig. While running the SRP system, the production enhanced by 50% more than the PCP’s maximum recorded rate. On the other hand, the pump can be retrieved and/or the artificial lift method can be converted later on without the requirement of a workover rig.
In Burgan field, Kuwait, the first rigless installation of a sucker rod pump over a failed progressive cavity pump has turned into the reference for methods of how to recover oil when other artificial-lift systems fail.
Conference Presentations by Fernando Ledesma Solaeche
The exception-based surveillance of key real-time parameters for wells utilizing electrical submersible pumps (ESPs) in Burgan field has significantly improved diagnostics of scale deposition at wellhead chokes and flowlines. Automated workflows calibrate an integrated production model in real-time, which enables engineers to run a quick analysis of current pump operating conditions and make a proactive plan of action. The application of real-time data and automated models has aided the operator's production team in making informed and timely decisions that enable them to run pumps at optimal operating conditions, with the result that they are able to sustain well production at target levels.
This paper describes an innovative approach to applying real-time data and integrated models in an automated workflow process for enhancing capabilities to diagnose scale deposition in the surface flow network. Examples are presented to demonstrate the application of integrated technology for identifying scaling at wellhead chokes and flowlines and prioritizing a scale removal program for optimizing pump performance.
More than 50% of installed PCP systems located in Great Burgan Field in southeast Kuwait are connected to a real-time SCADA platform. These connected systems are monitored to support daily operations and to identify underperforming wells for troubleshooting. Special attention is given to wells exhibiting critical behaviors or wells with optimization opportunities. Before implementing any actions on these wells, real-time data history is used along with nodal analysis to predict the outcomes. This paper presents an intensive optimization analysis through the following field case studies:
Preventing sucker rod string failure
Evaluating pump submergence
Optimizing fluid production
Identifying optimum operating conditions
Software is used to perform simulations of flow under different operating conditions and to generate a full analysis report based on PCP equipment configured in the well model. The sharp-edge results are not limited to the production rate. They also extend to pump performance and other surface and downhole parameters such as pump torque, intake pressure, and discharge pressure. The outcome of these results assists with making well-informed decisions with the following benefits:
Operating conditions have been improved by estimating the production rate at different speeds.
Pump life has been improved by evaluating rod load, lift load, and efficiency.
Down-time has been reduced by preventing pump-off conditions.
The procedure serves as a proven guide for analysis and optimization of PCP systems. Improving pump efficiency, achieving the target production rate, identifying problems, and preventing potential failures all help to optimize PCP system performance.
The innovative integration of PCP analysis and optimization provides a means to increase production and reduce the load percentage of surface and subsurface equipment parameters. A real-time SCADA platform combined with the optimization software created an ideal solution to keep wells operating at peak performance levels.
The subject well had a PCP at 4,248.05 ft. setting depth failed after 60 days due to a broken rotor. Attempts to fish the parted rotor were unsuccessful. To avoid a workover rig and to reduce non-productive time (NPT), a SRP system with an insert pump anchor was set over the failed PCP system at 4,028 ft. via a flush by unit. A tubing punch job from 4,085 to 4,145 ft. was done for allowing the fluid entering the tubing and passing through the SRP system.
Running a SRP with an insert pump anchor enabled the pump to be set at any depth inside the tubing, above the failed PCP system. Successful installation of the SRP system reduced NPT and standby costs, and eliminated the need for a workover rig. While running the SRP system, the production enhanced by 50% more than the PCP’s maximum recorded rate. On the other hand, the pump can be retrieved and/or the artificial lift method can be converted later on without the requirement of a workover rig.
In Burgan field, Kuwait, the first rigless installation of a sucker rod pump over a failed progressive cavity pump has turned into the reference for methods of how to recover oil when other artificial-lift systems fail.
The exception-based surveillance of key real-time parameters for wells utilizing electrical submersible pumps (ESPs) in Burgan field has significantly improved diagnostics of scale deposition at wellhead chokes and flowlines. Automated workflows calibrate an integrated production model in real-time, which enables engineers to run a quick analysis of current pump operating conditions and make a proactive plan of action. The application of real-time data and automated models has aided the operator's production team in making informed and timely decisions that enable them to run pumps at optimal operating conditions, with the result that they are able to sustain well production at target levels.
This paper describes an innovative approach to applying real-time data and integrated models in an automated workflow process for enhancing capabilities to diagnose scale deposition in the surface flow network. Examples are presented to demonstrate the application of integrated technology for identifying scaling at wellhead chokes and flowlines and prioritizing a scale removal program for optimizing pump performance.
More than 50% of installed PCP systems located in Great Burgan Field in southeast Kuwait are connected to a real-time SCADA platform. These connected systems are monitored to support daily operations and to identify underperforming wells for troubleshooting. Special attention is given to wells exhibiting critical behaviors or wells with optimization opportunities. Before implementing any actions on these wells, real-time data history is used along with nodal analysis to predict the outcomes. This paper presents an intensive optimization analysis through the following field case studies:
Preventing sucker rod string failure
Evaluating pump submergence
Optimizing fluid production
Identifying optimum operating conditions
Software is used to perform simulations of flow under different operating conditions and to generate a full analysis report based on PCP equipment configured in the well model. The sharp-edge results are not limited to the production rate. They also extend to pump performance and other surface and downhole parameters such as pump torque, intake pressure, and discharge pressure. The outcome of these results assists with making well-informed decisions with the following benefits:
Operating conditions have been improved by estimating the production rate at different speeds.
Pump life has been improved by evaluating rod load, lift load, and efficiency.
Down-time has been reduced by preventing pump-off conditions.
The procedure serves as a proven guide for analysis and optimization of PCP systems. Improving pump efficiency, achieving the target production rate, identifying problems, and preventing potential failures all help to optimize PCP system performance.
The innovative integration of PCP analysis and optimization provides a means to increase production and reduce the load percentage of surface and subsurface equipment parameters. A real-time SCADA platform combined with the optimization software created an ideal solution to keep wells operating at peak performance levels.
This paper discusses the application of smart workflows for analyzing asset performance and recommending production optimization actions in Burgan oil field. It describes how smart workflows are used to integrate real-time well and facility data with production models to assist the operator in faster diagnostics and improved decision making.
The paper demonstrates through field examples how the application of an automated workflow using real-time data and integrated models has improved the conventional approach for asset performance analysis and optimization resulting in significant cost savings for the operator.
Meetings have been held with Information Technology, SCADA and Well-Surveillance teams to agree on the technical requirements (server's specifications, network diagrams, well connectivity, data road map, data backup, security measures, disaster backup plan, etc…) The availability of having remote terminal unit built-in in the variable speed drive allowed instant access of real time data with ability to remotely control and modify running parameters for artificially lifted wells. Infrastructure has been built based on the company's standard IT security policies, by segregating network levels from field to domain network.
Well surveillance and field development teams from different areas targeted specific wells to be connected to the smart surveillance solution. Lining up different teams at the same time was a challenge to test, configure and confirm the successful connectivity. Integrating data from different areas/servers in one secure location was our main challenge to overcome. Replication of data was the only solution to assure a security channel that communicates between the different fields in to a single secured location with very limited ports to open and supervise. Wells were fully instrumented and equipped with the required gauges, sensors, and emergency shutdown devices, to evaluate well performance instantly.
Web based setup was the best solution for replicating real time data to the corporate level while keeping it secured and separated from the field network and available for all users accessible through end user system portal. Software acting as a real time data surveillance and historian with the remote access capability created a new level of effective surveillance. Management by exception became available at the corporate level to run failure statistics and identify areas for improvements by utilizing the current setup to optimize production and extend life time of equipment.
Achieving this level of surveillance helped in closely monitoring of well behavior, securely transferring and storing data, identifying operational needs of each field, and was considered as an extra level of surveillance. Successful deployment of the digital oil field in all areas of Kuwait integrated in one secured platform helped in utilizing all equipment available, increasing engineers' effectiveness to improve productivity, increase wells production, meet QHSE (quality, health, safety and environment) standards and reduce human risk.
Two levels of alarms have been set after reviewing well performance with well-surveillance and field-development teams using real time data gathered through a SCADA system for each parameter for each well individually. The capability in the real-time smart alarming system to set both warning and critical alarm criteria for minimum and maximum values allowed deeper supervision of abnormal conditions, highlighting assets in need of preventive actions. The pre-configured controller alarms have been integrated with software smart alarms to be available in one screen in real time, to immediately take the necessary actions.
The alarm system identified wells with:
Surface equipment problems related to load cell and position sensor issues
Down hole equipment issues related to standing and travelling leaks
Surface network issues related to flow line pressure increases due to back pressure
The presence of such an alarm system prevented major issues that sucker rod pump systems typically experience in terms of high load exerted on the gearbox, high stress applied on rods/sinker bars, and forces applied on surface unit structure. The implementation of such a preventive approach reduced the amount of well trips and downtime, avoiding unwanted incidents, reducing the response action time and unnecessary workover costs
Setting limits for essential parameters that are being reviewed in a fixed period helped in identifying wells far from critical zones to be addressed as candidates for further investigation for production/asset optimization. The real-time intelligent alarming and smart notification system is considered the backbone for production optimization and asset management in the oil and gas industry.
Achieving such a level of effective surveillance/alarming allowed better asset management, prevented equipment failures, prolonged equipment life time, and reduced unnecessary costs. Successful deployment of the smart field approach in the North Large Scale Thermal Pilot for sucker rod lifted pumps helped in utilizing the performance of the equipment, increased oil production and assured smooth operational activities.
The Burgan oil field integrated digital field (KwIDF) automation system utilizes wellhead pressure and water-cut measurements for automated calibration of well and surface network models. The KwIDF system workflow utilizes calibrated well models and real time data to identify changes in GC-01 daily production and reconciles it with the contributing wells. The workflow identifies wells with production changes and associates them with key well and facility parameters for instant diagnosis and analysis of daily production issues.
This paper describes the application of real time data and integrated models in an automated workflow for quick identification and analysis of daily field production.
Examples describe how the workflow has been used in quick analysis and decision making to optimize daily production and achieve sustainable targets in one of the production facilities of the Greater Burgan Field in Kuwait.
The subject well had a PCP at 4,248.05 ft. setting depth failed after 60 days due to a broken rotor. Attempts to fish the parted rotor were unsuccessful. To avoid a workover rig and to reduce non-productive time (NPT), a SRP system with an insert pump anchor was set over the failed PCP system at 4,028 ft. via a flush by unit. A tubing punch job from 4,085 to 4,145 ft. was done for allowing the fluid entering the tubing and passing through the SRP system.
Running a SRP with an insert pump anchor enabled the pump to be set at any depth inside the tubing, above the failed PCP system. Successful installation of the SRP system reduced NPT and standby costs, and eliminated the need for a workover rig. While running the SRP system, the production enhanced by 50% more than the PCP’s maximum recorded rate. On the other hand, the pump can be retrieved and/or the artificial lift method can be converted later on without the requirement of a workover rig.
In Burgan field, Kuwait, the first rigless installation of a sucker rod pump over a failed progressive cavity pump has turned into the reference for methods of how to recover oil when other artificial-lift systems fail.
The exception-based surveillance of key real-time parameters for wells utilizing electrical submersible pumps (ESPs) in Burgan field has significantly improved diagnostics of scale deposition at wellhead chokes and flowlines. Automated workflows calibrate an integrated production model in real-time, which enables engineers to run a quick analysis of current pump operating conditions and make a proactive plan of action. The application of real-time data and automated models has aided the operator's production team in making informed and timely decisions that enable them to run pumps at optimal operating conditions, with the result that they are able to sustain well production at target levels.
This paper describes an innovative approach to applying real-time data and integrated models in an automated workflow process for enhancing capabilities to diagnose scale deposition in the surface flow network. Examples are presented to demonstrate the application of integrated technology for identifying scaling at wellhead chokes and flowlines and prioritizing a scale removal program for optimizing pump performance.
More than 50% of installed PCP systems located in Great Burgan Field in southeast Kuwait are connected to a real-time SCADA platform. These connected systems are monitored to support daily operations and to identify underperforming wells for troubleshooting. Special attention is given to wells exhibiting critical behaviors or wells with optimization opportunities. Before implementing any actions on these wells, real-time data history is used along with nodal analysis to predict the outcomes. This paper presents an intensive optimization analysis through the following field case studies:
Preventing sucker rod string failure
Evaluating pump submergence
Optimizing fluid production
Identifying optimum operating conditions
Software is used to perform simulations of flow under different operating conditions and to generate a full analysis report based on PCP equipment configured in the well model. The sharp-edge results are not limited to the production rate. They also extend to pump performance and other surface and downhole parameters such as pump torque, intake pressure, and discharge pressure. The outcome of these results assists with making well-informed decisions with the following benefits:
Operating conditions have been improved by estimating the production rate at different speeds.
Pump life has been improved by evaluating rod load, lift load, and efficiency.
Down-time has been reduced by preventing pump-off conditions.
The procedure serves as a proven guide for analysis and optimization of PCP systems. Improving pump efficiency, achieving the target production rate, identifying problems, and preventing potential failures all help to optimize PCP system performance.
The innovative integration of PCP analysis and optimization provides a means to increase production and reduce the load percentage of surface and subsurface equipment parameters. A real-time SCADA platform combined with the optimization software created an ideal solution to keep wells operating at peak performance levels.
The subject well had a PCP at 4,248.05 ft. setting depth failed after 60 days due to a broken rotor. Attempts to fish the parted rotor were unsuccessful. To avoid a workover rig and to reduce non-productive time (NPT), a SRP system with an insert pump anchor was set over the failed PCP system at 4,028 ft. via a flush by unit. A tubing punch job from 4,085 to 4,145 ft. was done for allowing the fluid entering the tubing and passing through the SRP system.
Running a SRP with an insert pump anchor enabled the pump to be set at any depth inside the tubing, above the failed PCP system. Successful installation of the SRP system reduced NPT and standby costs, and eliminated the need for a workover rig. While running the SRP system, the production enhanced by 50% more than the PCP’s maximum recorded rate. On the other hand, the pump can be retrieved and/or the artificial lift method can be converted later on without the requirement of a workover rig.
In Burgan field, Kuwait, the first rigless installation of a sucker rod pump over a failed progressive cavity pump has turned into the reference for methods of how to recover oil when other artificial-lift systems fail.